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%(/ %(/ %(/ %(/ %(/ %(/ %(/ %(/ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϭϯϯͬ<ͲϱϱͬW ϭϴ͘ϳϯ ^ƵƌĨ ϭϬϬΖ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϳͬ>ͲϴϬͬDŽĚͲƵƚƚ ϴ͘ϲϴϭ ^ƵƌĨ ϭ͕ϴϵϱΖ ϳΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϲͬ>ͲϴϬͬd ϲ͘Ϯϳϲ ^ƵƌĨ ϰ͕ϵϱϬΖ ϰͲϭͬϮΗ >ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ,ǇĚƌŝůϱϮϭ ϯ͘ϵϱϴ ϰ͕ϳϬϯΖ ϭϬ͕ϬϳϭΖ dh/E'd/> ϰͲϭͬϮΗ dƵďŝŶŐ ϭϮ͘ϲηͬ>ͲϴϬͬDŽĚͲƵƚƚ ϯ͘ϵϱϴ ^ƵƌĨ ϰ͕ϳϬϯΖ WZ&KZd/KEd/> ŽŶĞ dŽƉ ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ >ϱϭh Ϯ͕ϲϮϰ͛ Ϯ͕ϲϯϴ͛ Ϯ͕Ϭϵϱ͛ Ϯ͕ϭϬϯ͛ ϭϰ͛ ϬϯͬϬϲͬϮϮ KƉĞŶ >ϱϭ> Ϯ͕ϲϱϴ͛ Ϯ͕ϲϳϬ͛ Ϯ͕ϭϭϰ͛ Ϯ͕ϭϮϬ͛ ϭϮ͛ ϬϯͬϬϲͬϮϮ KƉĞŶ >ϱϮh Ϯ͕ϲϴϴ͛ Ϯ͕ϲϵϯ͛ Ϯ͕ϭϯϬ͛ Ϯ͕ϭϯϯ͛ ϱ͛ ϬϯͬϬϱͬϮϮ KƉĞŶ >ϱϮ> Ϯ͕ϳϮϰ͛ Ϯ͕ϳϯϯ͛ Ϯ͕ϭϱϬ͛ Ϯ͕ϭϱϱ͛ ϵ͛ ϬϯͬϬϱͬϮϮ KƉĞŶ >ϲϬh ϯ͕ϯϱϱ͛ ϯ͕ϯϲϯ͛ Ϯ͕ϱϬϬ͛ Ϯ͕ϱϬϰ͛ ϴ͛ ϬϮͬϬϵͬϮϮ KƉĞŶ >ϲϬ> ϯ͕ϯϲϲ͛ ϯ͕ϯϳϳ͛ Ϯ͕ϱϬϲ͛ Ϯ͕ϱϭϮ͛ ϭϭ͛ ϬϮͬϬϵͬϮϮ KƉĞŶ >ϲϱ ϯ͕ϰϯϮ͛ ϯ͕ϰϯϵ͛ Ϯ͕ϱϰϯ͛ Ϯ͕ϱϰϳ͛ ϳ͛ ϬϮͬϬϵͬϮϮ KƉĞŶ >ϳϬh ϯ͕ϰϴϮ͛ ϯ͕ϰϵϰ͛ Ϯ͕ϱϳϭ͛ Ϯ͕ϱϳϴ͛ ϭϮ͛ ϬϮͬϬϵͬϮϮ KƉĞŶ >ϳϬ> ϯ͕ϱϬϲ͛ ϯ͕ϱϮϵ͛ Ϯ͕ϱϴϰ͛ Ϯ͕ϱϵϴ͛ Ϯϯ͛ ϬϮͬϬϵͬϮϮ KƉĞŶ >ϳϯ ϯ͕ϱϴϴ͛ ϯ͕ϱϵϰ͛ Ϯ͕ϲϯϭ͛ Ϯ͕ϲϯϰ͛ ϲ͛ ϬϮͬϬϵͬϮϮ KƉĞŶ >ϳϰ ϯ͕ϲϮϰ͛ ϯ͕ϲϯϭ͛ Ϯ͕ϲϱϮ͛ Ϯ͕ϲϱϲ͛ ϳ͛ ϬϮͬϬϵͬϮϮ KƉĞŶ >ϴϬh ϯ͕ϳϴϭ͛ ϯ͕ϳϴϲ͛ Ϯ͕ϳϰϭ͛ Ϯ͕ϳϰϰ͛ ϱ͛ ϬϮͬϬϴͬϮϮ KƉĞŶ >ϴϬ> ϯ͕ϴϬϳ͛ ϯ͕ϴϭϳ͛ Ϯ͕ϳϱϲ͛ Ϯ͕ϳϲϭ͛ ϭϬ͛ ϬϮͬϬϴͬϮϮ KƉĞŶ >ϴϭ ϯ͕ϴϯϮ͛ ϯ͕ϴϯϳ͛ Ϯ͕ϳϲϵ͛ Ϯ͕ϳϳϮ͛ ϱ͛ ϬϮͬϬϴͬϮϮ KƉĞŶ >ϴϮ ϯ͕ϴϳϬ͛ ϯ͕ϴϴϯ͛ Ϯ͕ϳϵϬ͛ Ϯ͕ϳϵϳ͛ ϭϯ͛ ϬϮͬϬϴͬϮϮ KƉĞŶ >ϵϬ ϰ͕Ϭϭϱ͛ ϰ͕ϬϮϱ͛ Ϯ͕ϴϳϭ͛ Ϯ͕ϴϳϳ͛ ϭϬ͛ ϬϮͬϬϴͬϮϮ KƉĞŶ >ϵϬϭ ϰ͕ϬϯϬ͛ ϰ͕Ϭϰϭ͛ Ϯ͕ϴϴϬ͛ Ϯ͕ϴϴϲ͛ ϭϭ͛ ϬϮͬϬϴͬϮϮ KƉĞŶ >ϵϬϰ ϰ͕Ϭϱϱ͛ ϰ͕Ϭϲϭ͛ Ϯ͕ϴϵϰ͛ Ϯ͕ϴϵϳ͛ ϲ͛ ϬϮͬϬϴͬϮϮ KƉĞŶ >ϵϬϱ ϰ͕Ϭϲϱ͛ ϰ͕Ϭϳϴ͛ Ϯ͕ϵϬϬ͛ Ϯ͕ϵϬϳ͛ ϭϯ͛ ϬϮͬϬϴͬϮϮ KƉĞŶ >ϵϭ ϰ͕ϬϵϬ͛ ϰ͕ϭϬϬ͛ Ϯ͕ϵϭϰ͛ Ϯ͕ϵϭϵ͛ ϭϬ͛ ϬϭͬϭϮͬϮϮ KƉĞŶ >ϵϭ ϰ͕ϭϯϭ͛ ϰ͕ϭϰϭ͛ Ϯ͕ϵϯϳ͛ Ϯ͕ϵϰϮ͛ ϭϬ͛ ϬϭͬϭϮͬϮϮ KƉĞŶ >ϵϮͲϰ ϰ͕Ϯϯϵ͛ ϰ͕Ϯϰϯ͛ Ϯ͕ϵϵϳ͛ ϯ͕ϬϬϬ͛ ϰ͛ ϬϭͬϭϮͬϮϮ KƉĞŶ >ϵϮͲϱ ϰ͕Ϯϱϭ͛ ϰ͕Ϯϱϳ͛ ϯ͕ϬϬϰ͛ ϯ͕ϬϬϴ͛ ϲ͛ ϬϭͬϭϮͬϮϮ KƉĞŶ >ϵϯh ϰ͕ϯϬϴ͛ ϰ͕ϯϭϴ͛ ϯ͕Ϭϯϳ͛ ϯ͕ϬϰϮ͛ ϭϬ͛ ϬϭͬϭϭͬϮϮ KƉĞŶ >ϵϯ> ϰ͕ϯϯϱ͛ ϰ͕ϯϰϱ͛ ϯ͕ϬϱϮ͛ ϯ͕Ϭϱϴ͛ ϭϬ͛ ϬϭͬϭϭͬϮϮ KƉĞŶ >ϵϳh ϰ͕ϱϱϮ͛ ϰ͕ϱϱϴ͛ ϯ͕ϭϳϲ͛ ϯ͕ϭϴϬ͛ ϲ͛ ϬϭͬϭϭͬϮϮ KƉĞŶ /ƐŽůĂƚĞĚWĞƌĨƐŽŶWĂŐĞϮ 'UDIWB WĂŐĞϮŽĨϮ hƉĚĂƚĞĚďǇ͗:>>ϬϰͬϬϰͬϮϮ ^,Dd/tĞůů͗WĂǆƚŽŶϬϭ Wd͗ϮϬϰͲϬϭϬ W/͗ϱϬͲϭϯϯͲϮϬϱϯϱͲϬϬͲϬϬ WZ&KZd/KEd/> ŽŶĞ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ >ϭϬϱ ϰ͕ϳϴϭ͛ ϰ͕ϴϬϭ͛ ϯ͕ϯϭϯ͛ ϯ͕ϯϮϱ͛ ϮϬ͛ ϭϮͬϮϬͬϮϭ /ƐŽůĂƚĞĚ >ͲϭϭϬ ϰ͕ϴϳϬ͛ ϰ͕ϴϳϱ͛ ϯ͕ϯϲϴ͛ ϯ͕ϯϳϭ͛ ϱ͛ ϭϮͬϮϬͬϮϭ /ƐŽůĂƚĞĚ >ϭϭϱ ϰ͕ϵϱϵ͛ ϰ͕ϵϳϵ͛ ϯ͕ϰϮϰ͛ ϯ͕ϰϯϳ͛ ϮϬ͛ ϭϮͬϮϬͬϮϭ /ƐŽůĂƚĞĚ >ͲϭϮϬ ϱ͕Ϭϲϰ͛ ϱ͕Ϭϲϵ͛ ϯ͕ϰϵϮ͛ ϯ͕ϰϵϲ͛ ϱ͛ ϭϮͬϮϬͬϮϭ /ƐŽůĂƚĞĚ >ͲϭϮϬ ϱ͕ϬϴϮ͛ ϱ͕Ϭϴϴ͛ ϯ͕ϱϬϰ͛ ϯ͕ϱϬϴ͛ ϲ͛ ϭϮͬϮϬͬϮϭ /ƐŽůĂƚĞĚ >Ͳϭϯϭ ϱ͕ϭϮϮ͛ ϱ͕ϭϮϲ͛ ϯ͕ϱϯϭ͛ ϯ͕ϱϯϰ͛ ϰ͛ ϭϮͬϮϬͬϮϭ /ƐŽůĂƚĞĚ >Ͳϭϯϯ ϱ͕ϭϴϲ͛ ϱ͕ϭϵϭ͛ ϯ͕ϱϳϳ͛ ϯ͕ϱϴϭ͛ ϱ͛ ϭϮͬϮϬͬϮϭ /ƐŽůĂƚĞĚ dͲϲ ϱ͕ϴϱϲ͛ ϱ͕ϴϴϰ͛ ϰ͕ϭϰϵ͛ ϰ͕ϭϲϳ͛ Ϯϴ͛ ϭϮͬϮϬͬϮϭ /ƐŽůĂƚĞĚ ϱ͕ϴϳϱ͛ ϱ͕ϴϵϱ͛ ϰ͕ϭϱϴ͛ ϰ͕ϭϳϳ͛ ϮϬ͛ ϭϮͬϮϬͬϮϭ /ƐŽůĂƚĞĚ dͲϴ ϲ͕ϬϮϲΖ ϲ͕ϬϯϲΖ ϰ͕ϮϵϳΖ ϰ͕ϯϬϲΖ ϭϬΖ ϵͬϮϮͬϮϬϬϱ /ƐŽůĂƚĞĚ ϲ͕ϬϲϴΖ ϲ͕ϬϴϴΖ ϰ͕ϯϯϱΖ ϰ͕ϯϱϰΖ ϮϬΖ ϵͬϮϮͬϮϬϬϱ /ƐŽůĂƚĞĚ ϲ͕ϭϭϴΖ ϲ͕ϭϯϲΖ ϰ͕ϯϴϮΖ ϰ͕ϯϵϴΖ ϭϴΖ ϭϬͬϲͬϮϬϬϱ /ƐŽůĂƚĞĚ ϲ͕ϭϱϮΖ ϲ͕ϭϴϲΖ ϰ͕ϰϭϯΖ ϰ͕ϰϰϱΖ ϯϰΖ ϵͬϮϮͬϮϬϬϱ /ƐŽůĂƚĞĚ ϲ͕ϮϵϵΖ ϲ͕ϯϭϵΖ ϰ͕ϱϰϵΖ ϰ͕ϱϲϴΖ ϮϬΖ ϱͬϯϭͬϮϬϬϴ /ƐŽůĂƚĞĚ ϲ͕ϯϱϰΖ ϲ͕ϯϲϬΖ ϰ͕ϲϬϬΖ ϰ͕ϲϬϲΖ ϲΖ ϭϬͬϲͬϮϬϬϱ /ƐŽůĂƚĞĚ dͲϭϮ ϲ͕ϲϴϮΖ ϲ͕ϳϬϮΖ ϰ͕ϵϬϰΖ ϰ͕ϵϮϰΖ ϮϬΖ ϭϬͬϲͬϮϬϬϱ /ƐŽůĂƚĞĚ ϲ͕ϳϯϴΖ ϲ͕ϳϱϴΖ ϰ͕ϵϱϴΖ ϰ͕ϵϳϲΖ ϮϬΖ ϭϬͬϰͬϮϬϬϱ /ƐŽůĂƚĞĚ dͲϮϬ ϲ͕ϵϰϴΖ ϲ͕ϵϲϴΖ ϱ͕ϭϱϰΖ ϱ͕ϭϲϭΖ ϮϬΖ ϭϬͬϰͬϮϬϬϱ /ƐŽůĂƚĞĚ dͲϯϬ ϳ͕ϭϱϴΖ ϳ͕ϭϵϴΖ ϱ͕ϯϲϵΖ ϱ͕ϰϬϵΖ ϰϬΖ ϭϬͬϰͬϮϬϬϱ /ƐŽůĂƚĞĚ ϳ͕ϭϲϮΖ ϳ͕ϭϴϮΖ ϱ͕ϯϳϯΖ ϱ͕ϯϵϯΖ ϮϬΖ ϯͬϭϱͬϮϬϬϱ /ƐŽůĂƚĞĚ ϳ͕ϭϵϴΖ ϳ͕ϮϱϭΖ ϱ͕ϰϬϵΖ ϱ͕ϰϲϭΖ ϱϯΖ ϭϬͬϯͬϮϬϬϱ /ƐŽůĂƚĞĚ ϳ͕ϰϯϴΖ ϳ͕ϰϱϴΖ ϱ͕ϲϰϴΖ 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&ƌĂĐ'ƌĂĚсϬ͘ϳϱƉƐŝͬĨƚDĂǆ^ƵƌĨWƌĞƐƐƵƌĞсϯ͕ϳϬϬƉƐŝŐ 'Ͳ&ƵŶĐƚŝŽŶϮͲϰ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ůŝŶĞ ϭϮͬϮϬͬϮϭ ϯͬϭϴͬϮϮ <>ĐƌĞǁĂƌƌŝǀĞƐĂƚĨĂĐŝůŝƚǇĂŶĚŽďƚĂŝŶƐƉĞƌŵŝƚ͕d'^D͘ŝƐĐƵƐƐƌĞĐĞŶƚƐůŝĐŬůŝŶĞĐƌĂŶĞŝŶĐŝĚĞŶƚ͘ZŝŐƵƉŚŽƚŽŝůƚƌƵĐŬƚŽ/ ĂŶĚƉĞƌĨŽƌŵD/dͲ/ƚŽϮϬϬϬƉƐŝĨŽƌϯϬŵŝŶƵƚĞƐ͘Ϭ͘ϴďďůƐŽĨϱϬͬϱϬŵĞƚŚĂŶŽůŵŝǆƉƵŵƉĞĚ͘'ŽŽĚƚĞƐƚ͘ZŝŐƵƉĞͲůŝŶĞ ĞƋƵŝƉŵĞŶƚĂŶĚƉƌĞƐƐƵƌĞƚĞƐƚůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϮϱϬϬƉƐŝŚŝŐŚ͘KͲƌŝŶŐŽŶďŽƚƚŽŵĐƌŽƐƐŽǀĞƌĨĂŝůĞĚĚƵƌŝŶŐůŽǁƚĞƐƚ͕ ƌĞƉůĂĐĞĚĂŶĚŐŽƚƉĂƐƐŝŶŐƚĞƐƚƐ͘ƌŵĂŶĚZ/,ǁŝƚŚǁĞŝŐŚƚďĂƌͬ>ͬηϭϬ^ĞƚƚŝŶŐdŽŽůǁŝƚŚϯ͘ϱΗK/W͘ŽƌƌĞůĂƚĞƚŽ zĞůůŽǁũĂĐŬĞƚ'WdůŽŐĚĂƚĞĚϵͲϯͲϮϭĂŶĚƐĞƚƉůƵŐĂƚϰϳϲϬΖ͘dĂŐƉůƵŐƚŽǀĞƌŝĨǇƐĞƚ͘WKK,͘ƌĞĂŬŽĨĨůƵďƌŝĐĂƚŽƌĂŶĚŝŶƐƉĞĐƚ ƐĞƚƚŝŶŐƚŽŽů͕ůŽŽŬĞĚŐŽŽĚ͘DŝǆĐĞŵĞŶƚĂŶĚĐĂƉƚƵƌĞƐĂŵƉůĞ͘&ŝůůϯϬΖǆϮ͘ϱΗďĂŝůĞƌǁŝƚŚϱ͘ϱŐĂůůŽŶƐŽĨĐĞŵĞŶƚĂŶĚZ/,͘ƵŵƉ ĐĞŵĞŶƚŽŶƉůƵŐ͘WKK,͘ƌĞĂŬŽĨĨůƵďƌŝĐĂƚŽƌĂŶĚŝŶƐƉĞĐƚƚŽŽůƐ͕ŐŽŽĚĚƵŵƉ͘DŝǆĐĞŵĞŶƚĂŶĚĐĂƉƚƵƌĞƐĂŵƉůĞ͘&ŝůůϯϬΖǆϮ͘ϱΗ ďĂŝůĞƌǁŝƚŚϱ͘ϱŐĂůůŽŶƐŽĨĐĞŵĞŶƚĂŶĚZ/,͘ƵŵƉĐĞŵĞŶƚŽŶƉůƵŐ͘WKK,͘ƌĞĂŬŽĨĨůƵďƌŝĐĂƚŽƌĂŶĚŝŶƐƉĞĐƚƚŽŽůƐ͕ŐŽŽĚ ĚƵŵƉ͘DŝǆĐĞŵĞŶƚĂŶĚĐĂƉƚƵƌĞƐĂŵƉůĞ͘&ŝůůϯϬΖǆϮ͘ϱΗďĂŝůĞƌǁŝƚŚϱŐĂůůŽŶƐŽĨĐĞŵĞŶƚĂŶĚZ/,͘ƵŵƉĐĞŵĞŶƚŽŶƉůƵŐ͘ϭϲ 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ǀĞƌŝĨǇŐŽŽĚŝŶũĞĐƚŝŽŶƉƌĞͲũŽď͘ZŝŐƵƉ,ĂůůŝďƵƌƚŽŶĐĞŵĞŶƚĞƋƵŝƉŵĞŶƚĂŶĚƉƌĞƐƐƵƌĞƚĞƐƚůŝŶĞƐƚŽϮϱϬƉƐŝůŽǁͬϯϱϬϬƉƐŝŚŝŐŚ͘ WŝƐƚŽŶĐŽǀĞƌŽŶƉƌŝŵĂƌǇƉƵŵƉůĞĂŬŝŶŐ͕ƌĞƉĂŝƌĂŶĚƐǁĂƉƚŽďĂĐŬƵƉƉƵŵƉ͘'ŽŽĚƚĞƐƚ͘WƵŵƉϱďďůƐǁĂƚĞƌƐƉĂĐĞƌĨŽůůŽǁĞĚ ďǇϲϯďďůƐϭϱ͘ϯƉƉŐĐĞŵĞŶƚĂƚϮͲϯďƉŵ͘ƌŽƉďĂůůĂŶĚĚŝƐƉůĂĐĞĐĞŵĞŶƚƚŽƉƵŶĐŚĞƐǁŝƚŚϳϬ͘ϱďďůƐǁĂƚĞƌĂƚϰďƉŵ͘&ŝŶĂůůŝĨƚ ƉƌĞƐƐƵƌĞ͗ϲϱϬƉƐŝ͘^ŚƵƚŝŶ/ĂŶĚĨƌĞĞǌĞƉƌŽƚĞĐƚƚƵďŝŶŐǁŝƚŚϭͬϮďďůŵĞƚŚĂŶŽů͘/ŝƐĨƌĞĞǌĞƉƌŽƚĞĐƚĞĚĨƌŽŵϭ͘ϱďďů ŵĞƚŚĂŶŽůĐĂƉŽƌŝŐŝŶĂƚŝŶŐŝŶƚƵďŝŶŐ͘WƵƌŐĞĐŽŶƚƌŽůůŝŶĞǁŝƚŚϮŐĂůůŽŶƐŽĨŵĞƚŚĂŶŽů͘dƌĂƉϭϮϱϬƉƐŝŽŶǁĞůůǁŝƚŚďŽƚƚŽŵ ŵĂƐƚĞƌǀĂůǀĞƐ͘ƐƚŝŵĂƚĞĚdK͗ϭϯϮϬΖ͘tĂƐŚƵƉĂŶĚƌŝŐĚŽǁŶĐĞŵĞŶƚĞƌƐ͘ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ůŝŶĞ ϭϮͬϮϬͬϮϭ ϯͬϭϴͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ WĂǆƚŽŶϭ ϱϬͲϭϯϯͲϮϬϱϯϱͲϬϬͲϬϬ ϮϬϰͲϬϭϬ ϬϭͬϬϯͬϮϬϮϮͲDŽŶĚĂǇ <>ĐƌĞǁĂƌƌŝǀĞƐĂƚĨĂĐŝůŝƚǇĂŶĚŽďƚĂŝŶƐƉĞƌŵŝƚ͕d'^D͘ZŝŐƵƉĞůŝŶĞĞƋƵŝƉŵĞŶƚĂŶĚƉƌĞƐƐƵƌĞƚĞƐƚůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁ ͬϮϱϬϬƉƐŝŚŝŐŚ͘Z/,ǁŝƚŚ>ƚŽŽůƐƚƌŝŶŐ͘WĞƌĨŽƌŵĨƌĞĞƉŝƉĞĐĂůŝďƌĂƚŝŽŶĂŶĚůŽŐĂƚϵϬϬΖ͘Z/,ƚŽWdĂŶĚƚĂŐĂƚϰϲϮϬΖ͘>ŽŐ ϮϬϬΖƌĞƉĞĂƚƉĂƐƐ͕ĚƌŽƉďĂĐŬĚŽǁŶƚŽďŽƚƚŽŵĂŶĚůŽŐŵĂŝŶƉĂƐƐƚŽϵϬϬΖ͘'ŽŽĚůŽŐƌĞƉĞĂƚĂďŝůŝƚǇ͘dKĨŽƵŶĚĂƚϭϮϱϬΖ͘ ĞŵĞŶƚŝƐŽĨŐŽŽĚƋƵĂůŝƚǇƚŚƌŽƵŐŚŽƵƚůŽŐŐĞĚŝŶƚĞƌǀĂů͘WKK,ĂŶĚƌŝŐĚŽǁŶĞůŝŶĞ͘ ϬϭͬϭϭͬϮϮͲdƵĞƐĚĂǇ <>ĐƌĞǁĂƌƌŝǀĞƐŽŶůŽĐĂƚŝŽŶĂŶĚŽďƚĂŝŶƐƉĞƌŵŝƚ͕d'^D͘ZŝŐƵƉĞůŝŶĞĂŶĚƉƌĞƐƐƵƌĞƚĞƐƚůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϮϱϬϬ ƉƐŝŚŝŐŚ͘ƌŵĂŶĚZ/,ǁŝƚŚϲΖϮͲϳͬϴΗ,ŐƵŶ͘ŽƌƌĞůĂƚĞƚŽŽƉĞŶŚŽůĞůŽŐĂŶĚƐĞŶĚƚŽƚŽǁŶĨŽƌĐŽƌƌĞĐƚŝŽŶ͘^ŚŝĨƚĞĚůŽŐĚŽǁŶ Ϯ͘ϱΖƉĞƌŐĞŽůŽŐŝƐƚŝŶƐƚƌƵĐƚŝŽŶ͘WĞƌĨŽƌĂƚĞĚ>ͺϵϳƵĨƌŽŵϰϱϱϮͲϰϱϱϴΖ͘WƌĞƐƐƵƌĞƌĞŵĂŝŶĞĚĨůĂƚĂƚϳϭϬƉƐŝ͘WKK,͘ƌĞĂŬŽĨĨ ůƵďƌŝĐĂƚŽƌĂŶĚůĂǇĚŽǁŶŐƵŶ͕ĂůůƐŚŽƚƐĨŝƌĞĚĂŶĚŐƵŶǁĂƐĚƌǇ͘WƌĞƐƐƵƌĞďĞŐŝŶƐƚŽŝŶĐƌĞĂƐĞĂŶĚŚĂƐŐŽŶĞƵƉƚŽϴϬϬƉƐŝΛ ϭϮ͗ϬϬ͕ŐĂŝŶŝŶŐĂƚĂďŽƵƚϮƉƐŝͬŵŝŶ͘ƌŵĂŶĚZ/,ǁŝƚŚϭϬΖϮͲϳͬϴΗ,ŐƵŶ͘ŽƌĞůĂƚĞƚŽŽƉĞŶŚŽůĞůŽŐĂŶĚƐĞŶĚƚŽƚŽǁŶĨŽƌ ĐŽƌƌĞĐƚŝŽŶ͘KŶĚĞƉƚŚ͘WĞƌĨŽƌĂƚĞĚ>ϵϯͺ>ĨƌŽŵϰϯϯϱͲϰϯϰϱΖ͘WƌĞƐƐƵƌĞĂƚϴϰϬƉƐŝĐůŝŵďŝŶŐĂƚϮƉƐŝͬŵŝŶ͘WKK,͘ƌĞĂŬŽĨĨ ůƵďƌŝĐĂƚŽƌĂŶĚůĂǇĚŽǁŶŐƵŶ͕ĂůůƐŚŽƚƐĨŝƌĞĚĂŶĚŐƵŶǁĂƐĚƌǇ͘ƌŵĂŶĚZ/,ǁŝƚŚϭϬΖϮͲϳͬϴΗ,ŐƵŶ͘ŽƌĞůĂƚĞƚŽŽƉĞŶŚŽůĞ ůŽŐĂŶĚƐĞŶĚƚŽƚŽǁŶĨŽƌĐŽƌƌĞĐƚŝŽŶ͘KŶĚĞƉƚŚ͘WĞƌĨŽƌĂƚĞĚ>ϵϯͺƵĨƌŽŵϰϯϬϴͲϰϯϭϴΖ͘WƌĞƐƐƵƌĞĂƚϭϬϰϬƉƐŝ͘WKK,͘ƌĞĂŬ ŽĨĨůƵďƌŝĐĂƚŽƌĂŶĚůĂǇĚŽǁŶŐƵŶ͕ĂůůƐŚŽƚƐĨŝƌĞĚĂŶĚŐƵŶǁĂƐĚƌǇ͘>ĂǇĚŽǁŶĞůŝŶĞ͕ƐĞĐƵƌĞǁĞůůĂŶĚĂŶĚ^&EĨŽƌƚĞƐƚŝŶŐ͘ ϬϭͬϭϮͬϮϮͲtĞĚŶĞƐĚĂǇ <>ĐƌĞǁĂƌƌŝǀĞƐĂƚĨĂĐŝůŝƚǇĂŶĚŽďƚĂŝŶƐƉĞƌŵŝƚ͕d'^D͘^ƚĂƌƚĂŶĚǁĂƌŵƵƉĞůŝŶĞĞƋƵŝƉŵĞŶƚ͘WŝĐŬƵƉƚŽƉƐŚĞĂǀĞĂŶĚ ůƵďƌŝĐĂƚŽƌ͘ƌŵĂŶĚZ/,ǁŝƚŚϲΖϮͲϳͬϴΗ,ŐƵŶ͘ŽƌƌĞůĂƚĞƚŽŽƉĞŶŚŽůĞůŽŐĂŶĚƐĞŶĚƚŽƚŽǁŶĨŽƌĐŽƌƌĞĐƚŝŽŶ͘KŶĚĞƉƚŚ͘ WĞƌĨŽƌĂƚĞ>ϵϮͲϱĨƌŽŵϰϮϱϭͲϰϮϱϳΖ͘ƐƚŝŵĂƚĞĚŐĂŝŶŽĨϯϬŵĐĨ͘WKK,͘ƌĞĂŬŽĨĨůƵďƌŝĐĂƚŽƌĂŶĚůĂǇĚŽǁŶŐƵŶ͘ůůƐŚŽƚƐ ĨŝƌĞĚĂŶĚŐƵŶǁĂƐĚƌǇ͘ƌŵĂŶĚZ/,ǁŝƚŚϰΖϮͲϳͬϴΗ,ŐƵŶ͘ŽƌƌĞůĂƚĞƚŽŽƉĞŶŚŽůĞůŽŐĂŶĚƐĞŶĚƚŽƚŽǁŶĨŽƌĐŽƌƌĞĐƚŝŽŶ͘KŶ ĚĞƉƚŚ͘WĞƌĨŽƌĂƚĞ>ϵϮͲϰĨƌŽŵϰϮϯϵͲϰϮϰϯΖ͘ƐƚŝŵĂƚĞĚŐĂŝŶŽĨϭϬŵĐĨ͘WKK,͘ƌĞĂŬŽĨĨůƵďƌŝĐĂƚŽƌĂŶĚůĂǇĚŽǁŶŐƵŶ͘ůů ƐŚŽƚƐĨŝƌĞĚĂŶĚŐƵŶǁĂƐĚƌǇ͘ƌŵĂŶĚZ/,ǁŝƚŚϭϬΖϮͲϳͬϴΗ,ŐƵŶ͘ŽƌƌĞůĂƚĞƚŽŽƉĞŶŚŽůĞůŽŐĂŶĚƐĞŶĚƚŽƚŽǁŶĨŽƌ ĐŽƌƌĞĐƚŝŽŶ͘KŶĚĞƉƚŚ͘WĞƌĨŽƌĂƚĞ>ϵϭĨƌŽŵϰϭϯϭͲϰϭϰϭΖ͘WKK,͘EŽĐŚĂŶŐĞŝŶƌĂƚĞ͘ƌĞĂŬŽĨĨůƵďƌŝĐĂƚŽƌĂŶĚůĂǇĚŽǁŶ ŐƵŶ͘ůůƐŚŽƚƐĨŝƌĞĚĂŶĚŐƵŶǁĂƐĂůŝƚƚůĞďŝƚǁĞƚ͘ƌŵĂŶĚZ/,ǁŝƚŚϭϬΖϮͲϳͬϴΗ,ŐƵŶ͘ŽƌƌĞůĂƚĞƚŽŽƉĞŶŚŽůĞůŽŐĂŶĚƐĞŶĚ ƚŽƚŽǁŶĨŽƌĐŽƌƌĞĐƚŝŽŶ͘KŶĚĞƉƚŚ͘WĞƌĨŽƌĂƚĞ>ϵϮĨƌŽŵϰϬϵϬͲϰϭϬϬΖ͘ZĂƚĞĐŽŵĞƐƵƉĂƉƉƌŽǆŝŵĂƚĞůǇϮϬϬŵĐĨ͘WKK,͘ƌĞĂŬ ŽĨĨůƵďƌŝĐĂƚŽƌĂŶĚůĂǇĚŽǁŶŐƵŶ͘ůůƐŚŽƚƐĨŝƌĞĚĂŶĚŐƵŶǁĂƐĚƌǇ͘ZŝŐĚŽǁŶ͕ƐĞĐƵƌĞǁĞůůĂŶĚŵŽǀĞŽǀĞƌƚŽWĂǆƚŽŶϱ͘ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ůŝŶĞ ϭϮͬϮϬͬϮϭ ϯͬϭϴͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ WĂǆƚŽŶϭ ϱϬͲϭϯϯͲϮϬϱϯϱͲϬϬͲϬϬ ϮϬϰͲϬϭϬ ϬϮͬϬϴͬϮϬϮϮͲdƵĞƐĚĂǇ zĞůůŽǁũĂĐŬĞƚĐƌĞǁĂƌƌŝǀĞƐĂƚĨĂĐŝůŝƚǇĂŶĚŽďƚĂŝŶƐƉĞƌŵŝƚ͕d'^D͘ZŝŐƵƉĞůŝŶĞĞƋƵŝƉŵĞŶƚĂŶĚƉƌĞƐƐƵƌĞƚĞƐƚƚŽϮϱϬƉƐŝůŽǁͬ ϮϱϬϬƉƐŝŚŝŐŚ͘ƌŵĂŶĚZ/,ǁŝƚŚϮͲϳͬϴΗƐǁŝƚĐŚĞĚŐƵŶĂƐƐĞŵďůǇ;ϭϯΖĂŶĚϲΖŐƵŶƐͿĂŶĚ'WdƚŽŽů͘>ŽŐĨůŽǁŝŶŐ'WdƉĂƐƐĨƌŽŵ ƐƵƌĨĂĐĞƚŽWd;ϰϱϱϴΖͿ͘>ŽŐƐĞĐŽŶĚĨůŽǁŝŶŐ'WdƉĂƐƐĂĐƌŽƐƐƉĞƌĨŽƌĂƚŝŽŶƐ͘ŽƌƌĞůĂƚĞƚŽŽƉĞŶŚŽůĞůŽŐĂŶĚƐĞŶĚƚŽƚŽǁŶĨŽƌ ĐŽƌƌĞĐƚŝŽŶ͘KŶĚĞƉƚŚ͘WĞƌĨŽƌĂƚĞĚ>ͺϵϬϱĨƌŽŵϰϬϲϱͲϰϬϳϴΖ͘/ŶŝƚŝĂů͗ϱϮϬŵĐĨΛϳϱƉƐŝ͘ϱŵŝŶ͗ϱϯϮŵĐĨΛϳϱƉƐŝ͘ϭϬŵŝŶ͗ ϱϮϵΛϳϰƉƐŝ͘ϭϱŵŝŶ͗ϱϯϬŵĐĨΛϳϰƉƐŝ͘WĞƌĨŽƌĂƚĞĚ>ͺϵϬϰĨƌŽŵϰϬϱϱͲϰϬϲϭΖ͘/ŶŝƚŝĂů͗ϱϯϬŵĐĨΛϳϰƉƐŝ͘ϱŵŝŶ͗ϱϮϰŵĐĨ ΛϳϱƉƐŝ͘ϭϬŵŝŶ͗ϯϱϵŵĐĨΛϳϮƉƐŝ͘ϭϱŵŝŶ͗ϭϮϬϬŵĐĨΛϭϬϴƉƐŝ͘^ǁĂďďŝŶŐĨůƵŝĚǁŚŝůĞWKK,͘^ƚĂďŝůŝǌĞĚƌĂƚĞϱϲϬŵĐĨΛ ϳϲƉƐŝ͘ƌĞĂŬŽĨĨůƵďƌŝĐĂƚŽƌĂŶĚůĂǇĚŽǁŶŐƵŶƐ͕ĂůůƐŚŽƚƐĨŝƌĞĚĂŶĚŐƵŶƐǁĞƌĞǁĞƚ͘ƌŵĂŶĚZ/,ǁŝƚŚϮͲϳͬϴΗƐǁŝƚĐŚĞĚŐƵŶ ĂƐƐĞŵďůǇ;ϭϭΖĂŶĚϭϬΖŐƵŶƐͿ͘ŽƌƌĞůĂƚĞƚŽŽƉĞŶŚŽůĞůŽŐĂŶĚƐĞŶĚƚŽƚŽǁŶĨŽƌĐŽƌƌĞĐƚŝŽŶ͘KŶĚĞƉƚŚ͘WĞƌĨŽƌĂƚĞĚ>ͺϵϬϭ ĨƌŽŵϰϬϯϬͲϰϬϰϭΖ͘/ŶŝƚŝĂůϱϰϳŵĐĨΛϳϱƉƐŝ͘ϱŵŝŶ͗ϱϰϵŵĐĨΛϳϱƉƐŝ͘ϭϬŵŝŶ͗ϱϰϴŵĐĨΛϳϱƉƐŝ͘ϭϱŵŝŶ͗ϱϱϮŵĐĨΛϳϱƉƐŝ͘ WĞƌĨŽƌĂƚĞĚ>ϵϬĨƌŽŵϰϬϭϱͲϰϬϮϱΖ͘/ŶŝƚŝĂů͗ϱϰϵŵĐĨΛϳϱƉƐŝ͘ϱŵŝŶ͗ϱϱϴŵĐĨΛϳϱƉƐŝ͘ϭϬŵŝŶ͗ϯϬϲŵĐĨΛϳϮƉƐŝ͘ϭϱ ŵŝŶ͗ϯϲϯŵĐĨΛϳϯƉƐŝ͘^ǁĂďďŝŶŐĨůƵŝĚǁŚŝůĞWKK,͘^ƚĂďŝůŝǌĞĚƌĂƚĞϰϳϬŵĐĨΛϳϲƉƐŝ͘ƌĞĂŬŽĨĨůƵďƌŝĐĂƚŽƌĂŶĚůĂǇĚŽǁŶ ŐƵŶƐ͕ĂůůƐŚŽƚƐĨŝƌĞĚĂŶĚŐƵŶƐǁĞƌĞǁĞƚ͘ƌŵĂŶĚZ/,ǁŝƚŚϮͲϳͬϴΗƐǁŝƚĐŚĞĚŐƵŶĂƐƐĞŵďůǇ;ϭϯΖĂŶĚϱΖŐƵŶƐͿ͘ŽƌƌĞůĂƚĞƚŽ ŽƉĞŶŚŽůĞůŽŐĂŶĚƐĞŶĚƚŽƚŽǁŶĨŽƌĐŽƌƌĞĐƚŝŽŶ͘KŶĚĞƉƚŚ͘WĞƌĨŽƌĂƚĞĚ>ͺϴϮĨƌŽŵϯϴϳϬͲϯϴϴϯΖ͘/ŶŝƚŝĂů͗ϰϲϯŵĐĨΛϳϱƉƐŝ͘ϱ ŵŝŶ͗ϱϭϳŵĐĨΛϳϱƉƐŝ͘ϭϬŵŝŶ͗ϰϵϮŵĐĨΛϳϱƉƐŝ͘ϭϱŵŝŶ͗ϱϬϬŵĐĨΛϳϱƉƐŝ͘WĞƌĨŽƌĂƚĞĚ>ͺϴϭĨƌŽŵϯϴϯϮͲϯϴϯϳΖ͘/ŶŝƚŝĂů͗ ϰϵϲŵĐĨΛϳϱƉƐŝ͘ϱŵŝŶ͗ϰϰϴŵĐĨΛϳϱƉƐŝ͘ϭϬŵŝŶ͗ϰϳϬŵĐĨΛϳϱƉƐŝ͘ϭϱŵŝŶ͗ϱϬϬŵĐĨΛϳϱƉƐŝ͘^ůŽǁĞĚĚŽǁŶǁŚŝůĞ WKK,ƚŽĂǀŽŝĚƵƉƐĞƚƚŝŶŐƐǇƐƚĞŵ͘ƌĞĂŬŽĨĨůƵďƌŝĐĂƚŽƌĂŶĚůĂǇĚŽǁŶŐƵŶƐ͕ĂůůƐŚŽƚƐĨŝƌĞĚĂŶĚŐƵŶƐǁĞƌĞǁĞƚ͘ƌŵĂŶĚZ/, ǁŝƚŚϮͲϳͬϴΗƐǁŝƚĐŚĞĚŐƵŶĂƐƐĞŵďůǇ;ϭϬΖĂŶĚϱΖŐƵŶƐͿĂŶĚ'WdƚŽŽů͘>ŽŐĨůŽǁŝŶŐ'WdƉĂƐƐĨƌŽŵƐƵƌĨĂĐĞƚŽϰϱϬϬΖ͘ŽƌƌĞůĂƚĞ ƚŽŽƉĞŶŚŽůĞůŽŐĂŶĚƐĞŶĚƚŽƚŽǁŶĨŽƌĐŽƌƌĞĐƚŝŽŶ͘KŶĞƉƚŚ͘WĞƌĨŽƌĂƚĞ>ͺϴϬ>ĨƌŽŵϯϴϬϳͲϯϴϭϳΖ͘/ŶŝƚŝĂů͗ϰϳϱŵĐĨΛϳϰ ƉƐŝ͘ϱŵŝŶ͗ϱϭϮŵĐĨΛϳϰƉƐŝ͘ϭϬŵŝŶ͗ϰϴϳŵĐĨΛϳϰƉƐŝ͘ϭϱŵŝŶ͗ϰϴϭŵĐĨΛϳϰƉƐŝ͘>ͺϴϬhĨƌŽŵϯϳϴϭͲϯϳϴϲΖ͘/ŶŝƚŝĂů͗ϰϴϯ ŵĐĨΛϳϰƉƐŝ͘ϱŵŝŶ͗ϱϲϭŵĐĨΛϳϱƉƐŝ͘ϭϬŵŝŶ͗ϱϱϰŵĐĨΛϳϱƉƐŝ͘ϭϱŵŝŶ͗ϱϰϱŵĐĨΛϳϱƉƐŝ͘>ŽŐĨůŽǁŝŶŐ'WdƉĂƐƐĂĐƌŽƐƐ ƉĞƌĨŽƌĂƚŝŽŶƐ͘WKK,͘ƌĞĂŬŽĨĨůƵďƌŝĐĂƚŽƌĂŶĚůĂǇĚŽǁŶŐƵŶƐ͕ĂůůƐŚŽƚƐĨŝƌĞĚĂŶĚŐƵŶƐǁĞƌĞǁĞƚ͘>ĂǇĚŽǁŶĞůŝŶĞĞƋƵŝƉŵĞŶƚ ĂŶĚƐĞĐƵƌĞǁĞůů͘^&E͘ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ůŝŶĞ ϭϮͬϮϬͬϮϭ ϯͬϭϴͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ WĂǆƚŽŶϭ ϱϬͲϭϯϯͲϮϬϱϯϱͲϬϬͲϬϬ ϮϬϰͲϬϭϬ ϬϮͬϬϵͬϮϬϮϮͲtĞĚŶĞƐĚĂǇ zĞůůŽǁũĂĐŬĞƚĐƌĞǁĂƌƌŝǀĞƐĂƚĨĂĐŝůŝƚǇĂŶĚŽďƚĂŝŶƐƉĞƌŵŝƚ͕d'^D͘tĂƌŵƵƉĞůŝŶĞĞƋƵŝƉŵĞŶƚĂŶĚƉŝĐŬƵƉůƵďƌŝĐĂƚŽƌ͘ƌŵĂŶĚ Z/,ǁŝƚŚƐǁŝƚĐŚĞĚϮͲϳͬϴΗŐƵŶĂƐƐĞŵďůǇ;ϳΖĂŶĚϲΖŐƵŶƐͿ͘ŽƌƌĞůĂƚĞƚŽŽƉĞŶŚŽůĞůŽŐĂŶĚƐĞŶĚƚŽƚŽǁŶĨŽƌĐŽƌƌĞĐƚŝŽŶ͘KŶ ĚĞƉƚŚ͘WĞƌĨŽƌĂƚĞĚ>ͺϳϰĨƌŽŵϯϲϮϰͲϯϲϯϭΖ͘/ŶŝƚŝĂů͗ϲϱϬŵĐĨΛϳϯƉƐŝ͘ϱŵŝŶ͗ϲϱϮŵĐĨΛϳϯƉƐŝ͘ϭϬŵŝŶ͗ϲϱϱŵĐĨΛϳϯƉƐŝ͘ ϭϱŵŝŶ͗ϲϱϬŵĐĨΛϳϯƉƐŝ͘WĞƌĨŽƌĂƚĞĚ>ͺϳϯĨƌŽŵϯϱϴϴͲϯϱϵϰΖ͘/ŶŝƚŝĂůϲϱϬŵĐĨΛϳϯƉƐŝ͘ϱŵŝŶ͗ϲϱϰŵĐĨΛϳϯƉƐŝ͘ϭϬŵŝŶ͗ ϲϰϵŵĐĨΛϳϯƉƐŝ͘ϭϱŵŝŶ͗ϲϱϲŵĐĨΛϳϯƉƐŝ͘WKK,͕ďƌĞĂŬŽĨĨůƵďƌŝĐĂƚŽƌĂŶĚůĂǇĚŽǁŶŐƵŶƐ͘ůůƐŚŽƚƐĨŝƌĞĚ͕ŐƵŶƐǁĞƌĞǁĞƚ ĂŶĚŚĂĚĂďŽƵƚϭͬϮŐĂůůŽŶŽĨƐĂŶĚǇƐůƵĚŐĞŝŶƚŚĞŵ͘ƌŵĂŶĚZ/,ǁŝƚŚϮϯΖϮͲϳͬϴΗŐƵŶ͘^ĞŶĚƚŽƚŽǁŶĨŽƌĐŽƌƌĞĐƚŝŽŶ͘KŶ ĚĞƉƚŚ͘WĞƌĨŽƌĂƚĞĚ>ͺϳϬ>ĨƌŽŵϯϱϬϲͲϯϱϮϵΖ͘/ŶŝƚŝĂů͗ϲϲϳŵĐĨΛϳϯƉƐŝ͘ϱŵŝŶ͗ϲϱϬŵĐĨΛϳϯƉƐŝ͘ϭϬŵŝŶ͗ϲϱϱŵĐĨΛϳϯƉƐŝ͘ ϭϱŵŝŶ͗ϲϰϵŵĐĨΛϳϯƉƐŝ͘WKK,͕ďƌĞĂŬŽĨĨůƵďƌŝĐĂƚŽƌĂŶĚůĂǇĚŽǁŶŐƵŶ͘ůůƐŚŽƚƐĨŝƌĞĚĂŶĚŐƵŶǁĂƐǁĞƚ͘ƌŵĂŶĚZ/, ǁŝƚŚƐǁŝƚĐŚĞĚϮͲϳͬϴΗŐƵŶĂƐƐĞŵďůǇ;ϭϮΖĂŶĚϳΖŐƵŶƐͿ͘ŽƌƌĞůĂƚĞƚŽŽƉĞŶŚŽůĞůŽŐĂŶĚƐĞŶĚƚŽƚŽǁŶĨŽƌĐŽƌƌĞĐƚŝŽŶ͘KŶ ĚĞƉƚŚ͘WĞƌĨŽƌĂƚĞĚ>ͺϳϬhĨƌŽŵϯϰϴϮͲϯϰϵϰΖ͘/ŶŝƚŝĂů͗ϲϰϭŵĐĨΛϳϯƉƐŝ͘ϱŵŝŶ͗ϲϰϳŵĐĨΛϳϯƉƐŝ͘ϭϬŵŝŶ͗ϲϰϰŵĐĨΛϳϯ ƉƐŝ͘ϭϱŵŝŶ͗ϲϱϬŵĐĨΛϳϯƉƐŝ͘WĞƌĨŽƌĂƚĞĚ>ͺϲϱĨƌŽŵϯϰϯϮͲϯϰϯϵΖ͘/ŶŝƚŝĂůϲϱϱŵĐĨΛϳϯƉƐŝ͘ϱŵŝŶ͗ϲϯϰŵĐĨΛϳϮƉƐŝ͘ϭϬ ŵŝŶ͗ϲϲϯƉƐŝΛϳϮƉƐŝ͘ϭϱŵŝŶ͗ϲϰϬŵĐĨΛϳϮƉƐŝ͘WKK,͕ďƌĞĂŬŽĨĨůƵďƌŝĐĂƚŽƌĂŶĚůĂǇĚŽǁŶŐƵŶƐ͘ůůƐŚŽƚƐĨŝƌĞĚĂŶĚŐƵŶƐ ǁĞƌĞǁĞƚ͘ƌŵĂŶĚZ/,ǁŝƚŚƐǁŝƚĐŚĞĚϮͲϳͬϴΗŐƵŶĂƐƐĞŵďůǇ;ϭϭΖĂŶĚϴΖŐƵŶƐͿ͘ŽƌƌĞůĂƚĞƚŽŽƉĞŶŚŽůĞůŽŐĂŶĚƐĞŶĚƚŽƚŽǁŶ ĨŽƌĐŽƌƌĞĐƚŝŽŶ͘KŶĚĞƉƚŚ͘WĞƌĨŽƌĂƚĞ>ͺϲϬ>ĨƌŽŵϯϯϲϲͲϯϯϳϳΖ͘/ŶŝƚŝĂů͗ϲϮϳŵĐĨΛϲϴƉƐŝ͘ϱŵŝŶ͗ϲϮϱŵĐĨΛϲϳƉƐŝ͘ϭϬŵŝŶ͗ 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current contact information if different from above. 204-010 T36449 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.04.06 14:45:55 -08'00' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 3/03/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Paxton 1 (PTD 204-010) GPT/PERF 2/08/2022 Please include current contact information if different from above. 204-010 T36387 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.04 09:29:43 -09'00' MEMORANDUM TO: Jim Regg P.I. Supervisor l FROM: Bob Noble Petroleum Inspector Well Name NINILCHIK UNIT PAXTON I Insp Num: mitRCN220212150514 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, February 14, 2022 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC 1 NINILCHIK UNIT PAXTON I Src: Inspector Reviewed By.- P.I. y:P.I. Supry Comm API Well Number 50-133-20535-00-00 Inspector Name: Bob Noble Permit Number: 204-010-0 Inspection Date: 2/12/2022 ' Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min _ Yp N TVI) Tubiing -- o z2zs - z1s6 _ I — --- -- PTD 2oaoloo T e Test sPT 90 - 90 Test SI 2000 2159 BBL Pum ed °2-- ___- r • -- zso 2so - - BBL Returned o.2 -/1 OA 2so 280 Interval OTHER P/F P Notes: This well is a gas producer producing. MIT -IA to test intergery of well after IA cement and perf jobs. Called to PT to 2000 psi Monday, February 14, 2022 Page I of 1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Ryan Rupert; Davies, Stephen F (OGC) Cc:Juanita Lovett; Todd Sidoti - (C); Jacob Flora; Dan Marlowe Subject:RE: Paxton-01 (PTD#204-010) Date:Tuesday, February 8, 2022 8:44:00 AM Ryan, You have approval to perf the entire “Interval to shoot” in your email below. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Monday, February 7, 2022 4:50 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com>; Todd Sidoti - (C) <Todd.Sidoti@hilcorp.com>; Jacob Flora <Jake.Flora@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: Paxton-01 (PTD#204-010) Bryan- We’re headed out for additional perfs on Paxton-01 tomorrow. One interval we’d like to shoot does straddle 2 approved sundry intervals. With the approximate nature of these depths, I assume no new approval is needed, but wanted to keep everyone in the loop nonetheless. All perfs are within the same pool still. Please let me know if this will be an issue. Thanks, Sundried intervals: Sand Perforation Top Perforation Bottom Perforation Top Perforation Bottom Total Footage (MD)(MD)(TVD)(TVD)(MD) BEL_90B1 ±4,030’±4,034’±2,880’±2,882’4‘ BEL_90B1 ±4,038’±4,041’±2,884’±2,886’3‘ Interval to shoot Sand Perforation Top Perforation Bottom Perforation Top Perforation Bottom Total Footage (MD)(MD)(TVD)(TVD)(MD) BEL_90B1 ±4,030’±4,041’±2,880’±2,886’11‘ 1Guhl, Meredith D (OGC)From:McLellan, Bryan J (OGC)Sent:Tuesday, March 1, 2022 9:08 AMTo:Jacob FloraCc:Juanita Lovett; Roby, David S (OGC); Davies, Stephen F (OGC)Subject:RE: Paxton 1 AOGCC 10-403 321-457 PTD 204-010 Approved 09-11-21 (additional perforations)Jake, Yes it is acceptable to perforate the additional zone shown in you email below under the existing sundry 321‐457. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Monday, February 28, 2022 1:51 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com> Subject: Paxton 1 AOGCC 10‐403 321‐457 PTD 204‐010 Approved 09‐11‐21 (additional perforations) Hello Bryan, On this well we did an IA squeeze, isolated the Beluga, and are now testing our way up‐hole. On the sundry we submitted a table and not a depth range as I’ve done more recently. We want to add a sand into the proposed perforations that was left off the original table, the Beluga 52u. All sands are in the same pool. Please advise if this is acceptable, we hope to be on the well Wednesday. Thanks, CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Jake Proposed: Paxton 1 Perforation Table – 2.28.22 Sand Perforation Top Perforation Bottom Perforation Top Perforation Bottom Total Footage Expected Bottom Hole Pressure (MD) (MD) (TVD) (TVD) (MD) (psi) BEL_50u ±2,540’ ±2,548’ ±2,048’ ±2,052’ 8‘ 562 (RFT in Paxton 10 ‐ 2020) BEL_50L ±2,574’ ±2,602’ ±2,067’ ±2,083’ 28‘ BEL_51u ±2,624’ ±2,638’ ±2,095’ ±2,102’ 14‘ 566 (RFT in Paxton 10 ‐ 2020) BEL_51L ±2,658’ ±2,670’ ±2,114’ ±2,121’ 12‘ BEL_52u ±2,688’ ±2,293’ ±2,130’ ±2,134’ 5‘ 602 (RFT in Paxton 10 ‐ 2020) BEL_52L ±2,724’ ±2,733’ ±2,151’ ±2,156’ 9‘ Sundried: The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. 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: 1/13/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PAXTON-01 (PTD 204-010) CIBP 12/20/2021 Please include current contact information if different from above. Received By: 01/26/2022 37' (6HW By Abby Bell at 11:35 am, Jan 26, 2022 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: 1/19/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Paxton 1 (PTD 204-010) Perf 1/12/2022 Please include current contact information if different from above. Received By: 01/20/2022 37' (6HW By Abby Bell at 10:31 am, Jan 20, 2022 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: 1/19/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Paxton 1 (PTD 204-010) CBL 1/03/2022 Please include current contact information if different from above. Received By: 01/20/2022 37' (6HW By Abby Bell at 10:20 am, Jan 20, 2022 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Jacob Flora Subject:RE: Paxton 01 AOGCC 10-403 321-457 PTD 204-010 Approved 09-11-21 (chemical injection line question) Date:Wednesday, December 29, 2021 9:38:00 AM Jake, Yes this plan is acceptable. The chemical injection line only needs to be cemented if you perforate through it. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Wednesday, December 29, 2021 8:30 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Paxton 01 AOGCC 10-403 321-457 PTD 204-010 Approved 09-11-21 (chemical injection line question) Hi Bryan, This is a project that I’ve taken over. We have started prepping this well for an IA cement job and I came across one step I’d like to address. The way the program was written it says we will cement the chemical injection line to the nipple at 2517’. The majority of the target sands are below this depth. I’d like to leave the line open, purging it after the fullbore cement job, to allow future use for soap injection for these lower sands. We would then cement it prior to perforating anything above the Beluga 50, most likely at a much later date. Beluga 34 – 49 1944’ – 2503’ MD Chemical nipple 2517’ MD Beluga 50 – 99 2540’ – 4693’ MD Please advise if this is acceptable. Thanks, CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Jacob Flora Subject:RE: Paxton 01 AOGCC 10-403 321-457 PTD 204-010 Approved 09-11-21 (CBL FOR REVIEW) Date:Wednesday, January 5, 2022 11:20:00 AM Jake, CBL ooks good. You have approval to perforate per Sundry 321-457. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Tuesday, January 4, 2022 12:05 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Paxton 01 AOGCC 10-403 321-457 PTD 204-010 Approved 09-11-21 (CBL FOR REVIEW) Hi Bryan, Please find attached CBL that was run 1/3/22 (the IA cement was pumped on 12/30/21). Thanks, Jake From: Todd Sidoti - (C) <Todd.Sidoti@hilcorp.com> Sent: Tuesday, January 4, 2022 11:17 AM To: Jacob Flora <Jake.Flora@hilcorp.com> Subject: Pax 1 CBL Here it is. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: 11/09/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PAXTON 1 (PTD 204-010) GPT/PERF 09/03/2021 Please include current contact information if different from above. 37' (6HW Received By: 11/10/2021 By Abby Bell at 9:30 am, Nov 10, 2021 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: _Patch / N2/ Cmt Pkr_ 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): 10,115'see schematic Casing Collapse Structural Conductor 1,500psi Surface 4,760psi Intermediate 7,020psi Production Liner 7,500psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Ryan Rupert Operations Manager Contact Email: Contact Phone: 777-8503 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 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 15, 2021 10,071'5,368' 4-1/2" 8,276' Perforation Depth MD (ft): 4,950' See Attached Schematic 4-1/2" 20" 9-5/8" 100' 7"4,950' 1,895' 3,060psi 6,870psi 100' 1,682' 3,418 100' 1,895' 12.6# / L-80 TVD Burst 4,703 MD 8,160psi Length Size CO 701C Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0384372 / FEE-PRIVATE 204-010 50-133-20535-00-00 Paxton-01 Ninilchik Field / Beluga-Tyonek Gas Pool COMMISSION USE ONLY Authorized Name: 8,430psi Tubing Grade: Tubing MD (ft): See Attached Schematic ryan.rupert @hilcorp.com 8,320'5,913'4,193'~1462 psi 5,913' ZXP Liner Packer : N/A 4,703(MD) / 3,266(TVD) : N/A Perforation Depth TVD (ft): Tubing Size: Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 4:21 pm, Sep 08, 2021 321-457 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.09.08 15:17:59 -08'00' Taylor Wellman (2143) CT BOP test to 3500 psi. SFD 9/9/2021 DSR-9/8/21 AOGCC review of cement bond log required before perforating. XX BJM 9/9/21 MITIA to 2000 psi post perf. CT dts 9/9/2021 JLC 9/10/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.10 14:58:39 -08'00' RBDMS HEW 9/13/2021 Well: Paxton-01 Date: 9/8/2021 Well Name:Paxton-01 API Number:50-133-20535-00-00 Current Status:Gas Producer Leg:N/A Regulatory Contact:Donna Ambruz 777-8305 Permit to Drill Number:204-010 First Call Engineer:Ryan Rupert (907) 777-8503 (O)(907) 301-1736 (C) Second Call Engineer:Todd Sidoti (907) 632-4113 (C) Max. Expected BHP:~ 1515 psi @ 3243’ TVD Based on highest observed offset P (BEL-99u RFT in Pax-10 from 2020) Max. Potential Surface Pressure ~ 1191 psi Based on 0.1 psi/ft to surface Well Summary Paxton-01 is currently making ~500mcfd and minimal water production. The well has several unshot beluga sands above the current LTP at 4703’ MD. By cementing the 4-1/2” x 7” annulus, we can maintain a monitorable annulus while enabling access to these sands above the LTP, ultimately increasing rate. All proposed perfs are within the same pool. The goal of this project is to cement the 4-1/2” x 7” annulus to allow for recompletion and offtake above the current packer, while still maintaining an isolated monitorable annulus, and maintaining current production from below the LTP. Notes Regarding Wellbore Condition x MIT History o 3/12/04: MIT of 4-1/2” liner and 7” casing to 1500psi for 30 minutes (Pass) o 2/29/04: 7” casing tested to 3000psi for 30minutes (Pass) x Min ID = 3.858” at 2517’ MD (Chemical injection nipple) x Inclination o Max = 57 degrees at 3123’ MD o Sail angle of ~57 degrees from 2200’ MD – 4500’ MD o Then rolls to 31 degrees by 5500’ MD x Recent history o 9/4/21 EL made it down to 5300’ MD with GPT and 2-7/8” guns (no tag) o 8/29/21: SL made it down to 5545’ SLMD with a 3.66” gauge ring and tagged SL ran a 22’ dummy patch (3.62” OD) to 5412’ SLMD and set down o 10/27/20: GPT ran down to 5050’ MD. No fluid seen, no tag Perf’d two 20’ intervals as deep as 4979’ MD with 2-7/8” guns. o 12/7/18: SL tagged at 5170’ SLMD and bailed 15’ of clay/mud down to 5185’ MD. Able to cycle pressure and get it to unload sand/water and come online. o 12/6/18: SL tagged at 5150’ SLMD (above all perfs) and bailed 20’ of clay/mud o 10/25/18: EL tagged at 5861’ MD. RDMO (didn’t shoot anything) o 10/21/18: CT FCO CT dry tagged fill at 5656’ CT performed a FCO with a 2.5” DJN to 5910’ CTMD Agree. SFD 9/9/2021 s several unshot beluga sands a All proposed perfs are within the same pool. Well: Paxton-01 Date: 9/8/2021 Nitrogen Risk x Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect, and people could enter. x Consider tank placement based on wind direction and current weather forecast (venting Nitrogen during this job) x Ensure all crews are aware of stop work authority E-Line / Pumping procedure 1. RU Pump truck 2. MIT-IA to 2000psi 3. MIRU E-line and pressure control equipment 4. PT lubricator to 250psi low / 2,500 psi High 5. MU drillable plug (likely composite plug) 6. RIH and set 4-1/2” plug at ±4680’ MD a. 4652’: Top full joint b. 4694’: Bottom full tubing joint c. 4700’: Bottom 6’ pup d. 4704’: Top SealBore Receptacle e. 4715’: Bottom seal assembly f. 4720’: Top ZXP Packer g. 4730’: Top hanger h. 4740’: Top full casing joint 7. Load tubing with source water (~72bbls) 8. MIT-T to 2500psi (or higher to match max ECD of cement job) 9. MU and RIH with tubing puncher 10. Hold at least 100psi on tubing to achieve overbalance to IA a. IA fluid is 6% KCL with corrosion inhibitor: 8.64ppg at 3260’ TVD = 1465psi outside b. Using source water in tubing: 8.33ppg at 3260’ TVD = 1412psi inside 11. Punch from ±4655-4660’ MD 12. Establish circulation from tubing to IA. Contingency: if circulation can’t be established, may have to come uphole and punch again. 13. Swap well over to all source water at max rate: IA volume = 88bbls 14. RDMO EL and pump truck IA Cementing Procedure 1. RU cement truck, PT lines. 2. Be prepared to pump down chemical injection line during IA cement job to keep port clear 3. Mix and pump ±61bbls 15.3# cement down tubing, taking returns from IA. a. Planned TOC in IA is 1500’ MD / 1413’ TVD. (59bbls) b. Pump down chemical injection line until tubing displacement is complete Planned TOC in IA is 1500’ MD / Verified cement volume - bjm MIT-IA to 2000psi Well: Paxton-01 Date: 9/8/2021 4. Chase with wiper ball and displace 4-1/2” tubing to 100’ above the tubing punch (~2 bbls) with source water 5. SI master valve and IA and trap pressure on the tubing 6. RDMO cementers 7. WOC 3 days Logging Procedure 1. MIRU SL or EL and pressure control equipment 2. PT lubricator to 250psi low / 2,500 psi High 3. Log CBL from 100’ above estimated ToC in tubing to surface 4. RDMO Chemical Injection mandrel cementing 1. Verify injection into chemical injection line. 2. If injection is achievable, permanently abandon the lines by injecting up to 5 gallons of cement a. Control lines calcs: 0.25” OD, 0.152” ID = 2.5 gal b. Want to inject at least 2.5 gal c. Perform before CT mill out of tubing CT Millout procedure 1. MIRU CTU, 24hr notice for BOP test 2. Conduct BOP test to 250psi low / 3500psi high 3. Mix up working fluid of 6% KCL a. This will protect open perfs below b. WBV will be ~90bbls at the end 4. MIT-IA to 2000psi charted for 30 minutes 5. Once pass, MU CT motor/mill assembly 6. Make a few passes while pumping across CIM at 2517’ MD to clean any cement stringers / debris 7. RIH and obtain dry tag of ToC 8. Mill up cement and plug a. Please track total volumes, as we want to know total losses to formation at the end of the job. b. Use 6% KCL for working fluid when perfs are exposed. Ok to use source water before then c. Likely to lose returns when break through plug 9. Once through plug, regardless of returns or not, stop pumping and dry drift to top fill (don’t want to flood open zones below) 10. POOH and pickup a nozzle 11. RIH and perform nitrified foam FCO to below the T-6 a. 2018 CT FCO lost returns once they uncovered the top perf at the time (T-6) b. Likely up to 6 bbls fill from 5545’ – 5913’ MD c. Bottom perf = 5895’ MD d. Estimated ToC at ~5913’ MD e. CIBP at 5923’ ELMD Conduct BOP test to 250psi low / 3500psi high This will fill entire volume of chem injection line. bjm Send results to AOGCC for approval before perforating. - bjm Well: Paxton-01 Date: 9/8/2021 f. Use caution as don’t want to disturb CIBP nor cement cap 12. POOH chasing fill uphole 13. If well won’t re-establish flow on its own, may need to continue N2 lift from bottom. 14. Once well is flowing on its own, RDMO CT E-Line Perf procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 2,500 psi High 3. Rig up perf gun (Likely 2-7/8” – 3-3/8” 4-6 spf) 4. RIH and perforate the sands listed in the attached table per Geo/RE. a. Consult with OE for what WHP’s to use. May be shot while flowing b. Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. c.Use Gamma/CCL to correlate. d.Record initial and 5/10/15 minute tubing pressures after firing e. Consult with RE/Geo between each perf interval: i. Matt Petrowsky (Geo): 814-421-6753 ii. Anthony McConkey (RE): 529-6199 5. RD E-Line Unit and turn well over to production. 6. Perform a post-perf MIT-IA to 2000psi once job is complete and well has been brought online within 5 days. Contingency screen (If continued T-6 solids production is an issue) 1. MIRU E-line, PT lubricator to 250 psi low / 2,500 psi high 2. MU 4-1/2” packer with screen assembly 3. RIH and set above T-6 a. Set between 5510’ and 5840’ MD dependent on fill b. Target 5600’ MD 4. RD E-Line Unit and turn well over to production. Contingency EL Plug or Patch 1. MIRU E-line, PT lubricator to 250 psi low / 2,500 psi high 2. RIH W/ GPT tool and find fluid level 3. RU Nitrogen Truck a. Push water back into formation b. Use GPT tool to confirm water level is below interval to perf c. Consult OE for pressure to leave on well for perforating 4. Once fluid level is below interval to isolate, MU 4-1/2” patch or plug 5. RIH and set plug or patch per OE. 6. RD E-Line Unit and turn well over to production. Attachments: 1. Proposed Perf Table 2. Current schematic 3. Proposed Schematic 4. Standard Well procedure – N2 Operations Perform a post-perf MIT-IA to 2000psi once job is complete and well has been brought online within 5 days.Provide 24 hrs notice to AOGCC for witness. Send MIT results to AOGCC. Draft_ Page 1 of 2 Updated by CRR 09-08-21 SCHEMATIC Ninilchik Unit Well: Paxton 01 PTD: 204-010 API: 50-133-20535-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 133 / K-55 / PE 18.73 Surf 100' 9-5/8" Surface 47 / L-80 / Mod-Butt 8.681 Surf 1,895' 7" Intermediate 26 / L-80 / BTC 6.276 Surf 4,950' 4-1/2" Liner 12.6 / L-80 / Hydril 521 3.958 4,703' 10,071' TUBING DETAIL 4-1/2" Tubing 12.6#/L-80/Mod-Butt 3.958 Surf 4,703' JEWELRY DETAIL No Depth ID OD Item 1 2,517’ 3.858 5.93 Baker Chemical Injection Nipple 2 4,703' ZXP Liner Packer w/ 15' Tieback Extension 3 4,727' Flex Lock Liner Hanger 4 5,913’ 3.958 CIBP w/ 10’ cement/TOC @ 5,913’ 10/05/16 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status BEL 105 4,781’ 4,801’ 3,313’ 3,325’ 20’ 10/27/2020 Open BEL-110 4,870’ 4,875’ 3,368’ 3,371’ 5’ 9/2/2021 Open BEL 115 4,959’ 4,979’ 3,424’ 3,437’ 20’ 10/27/2020 Open BEL-120 5,064’ 5,069’ 3,492’ 3,496’ 5’ 9/2/2021 Open BEL-120 5,082’ 5,088’ 3,504’ 3,508’ 6’ 9/2/2021 Open BEL-131 5,122’ 5,126’ 3,531’ 3,534’ 4’ 9/2/2021 Open BEL-133 5,186’ 5,191’ 3,577’ 3,581’ 5’ 9/2/2021 Open T-6 5,856’ 5,884’ 4,149’ 4,167’ 28’ 5/17/2014 Open 5,875’ 5,895’ 4,158’ 4,177’ 20’ 11/22/2016 Open T-8 6,026' 6,036' 4,297' 4,306' 10' 9/22/2005 Isolated 6,068' 6,088' 4,335' 4,354' 20' 9/22/2005 Isolated 6,118' 6,136' 4,382' 4,398' 18' 10/6/2005 Isolated 6,152' 6,186' 4,413' 4,445' 34' 9/22/2005 Isolated 6,299' 6,319' 4,549' 4,568' 20' 5/31/2008 Isolated 6,354' 6,360' 4,600' 4,606' 6' 10/6/2005 Isolated More perfs on p2 More perfs on p2 OPEN HOLE / CEMENT DETAIL 9-5/8” 12-1/4” hole: 230 bbls of 12ppg Type I cement. 60 bbls cement back to surface 7" 8-1/2” Hole: 70bbls 12.5ppg lead cement pumped followed by 36bbls of 13.5ppg tail cement. Full returns throughout job. Volumetric ToC using 35% washout from OH caliper = 1,390’ MD 4-1/2” Liner 7” Hole (BiCenter Bit): 219bbls 12.8ppg class G cement pumped. 20bbl losses throughout job. 40bbls spacer pumped, and got 25bbls spacer back to surface. 4/10/04 CBL show’s top of solid cement at 5830’ MD. Patchy cement up to 5,330’ MD. Draft_ Page 2 of 2 Updated by CRR 09-08-21 SCHEMATIC Ninilchik Unit Well: Paxton 01 PTD: 204-010 API: 50-133-20535-00-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status T-12 6,682' 6,702' 4,904' 4,924' 20' 10/6/2005 Isolated 6,738' 6,758' 4,958' 4,976' 20' 10/4/2005 Isolated T-20 6,948' 6,968' 5,154' 5,161' 20' 10/4/2005 Isolated T-30 7,158' 7,198' 5,369' 5,409' 40' 10/4/2005 Isolated 7,162' 7,182' 5,373' 5,393' 20' 3/15/2005 Isolated 7,198' 7,251' 5,409' 5,461' 53' 10/3/2005 Isolated 7,438' 7,458' 5,648' 5,668' 20' 3/15/2005 Isolated 7,570' 7,588' 5,780' 5,798' 18' 10/3/2005 Isolated T-42 7,794' 7,814' 6,004' 6,024' 20' 2/25/2005 Isolated T-50 8,188' 8,208' 6,397' 6,417' 20' 10/3/2005 Isolated 8,188' 8,266' 6,397' 6,475' 78' 5/6/2004 Isolated 8,234' 8,254' 6,443' 6,463' 20' 4/30/2004 Isolated 8,402' 8,437' 6,611' 6,646' 35' 5/7/2004 Isolated T-65 8,784' 8,804' 6,993' 7,013' 20' 5/27/2004 Isolated T-83 8,916' 8,936' 7,125' 7,199' 20' 5/28/2004 Isolated T-90 9,088' 9,142' 7,297' 7,351' 54' 5/28/2004 Isolated 9,113' 9,133' 7,322' 7,242' 20' 4/21/2004 Isolated 9,220' 9,256' 7,429' 7,465' 36' 5/7/2004 Isolated T-130 9,542' 9,558' 7,750' 7,766' 16' 4/20/2004 Isolated FISH: Expro 30.9' OVL: 1-7/16" rope socket w/1" fishing neck (1.0'), 1-3/4" swivel (1.2'), 1-11/16" tungsten wt bar (21'), 3-1/8" CCL (2.5'), 3" junk basket (5.0'), and 3.78" gauge ring (.17') Fracked Tyonek Perfs 8,188'-8,266' MD on 2/10/2005 48,553 lbs of 20/40 Ottawa including 12.5% 12/20 Flex Sand Lightning 1800 6% KCL based fluid ramped 1-8 ppg Frac Grad=0.75 psi/ft Max Surf Pressure=3,700 psig G-Function 2-4 Draft_ Paxton 1_PROPOSED_IA_Cement(9-8-21)Page 1 of 2 Updated by: CRR 9/8/21 PROPOSED IA Cement SCHEMATIC Well: Paxton 01 PTD: 204-010 API: 50-133-20535-00-00 TD =10,115’ MD / 8,320’ TVD PBTD = 5,913’ MD / 4,193’ TVD T-6 RKB: MSL = 153’ / 17’ AGL 7” 20” 9-5/8” 1 2 3 4-1/2” 4 BEL 115 BEL 105 BEL 110 BEL 120 / 131 / 133 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 133 / K-55 / PE 18.73 Surf 100' 9-5/8" Surface 47 / L-80 / Mod-Butt 8.681 Surf 1,895' 7" Intermediate 26 / L-80 / BTC 6.276 Surf 4,950' 4-1/2" Liner 12.6 / L-80 / Hydril 521 3.958 4,703' 10,071' TUBING DETAIL 4-1/2" Tubing 12.6#/L-80/Mod-Butt 3.958 Surf 4,703' No Depth ID Item 1 2,517’ 3.858 Baker Chemical Injection Nipple:To be cemented 2 4,703' ZXP Liner Packer w/ 15' Tieback Extension (Top ZXP at 4720’ ELMD) 3 4,727' Flex Lock Liner Hanger 4 5,913’ CIBP w/ 10’ cement/TOC @ 5,913’ 10/05/16 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status 1,895’1,682’Surface Casing Shoe BEL_34 ±1,944’ ±1,951’ ±1,712’ ±1,716’ 7‘ Shallowest proposed above packer BEL_99A ±4,693’ ±4,701’ ±3,259’ ±3,264’ 8‘ Deepest proposed above packer 4,720’3,276’Packer BEL 105 4,781’ 4,801’ 3,313’ 3,325’ 20’ 10/27/2020 Open BEL-110 4,870’ 4,875’ 3,368’ 3,371’ 5’ 9/2/2021 Open BEL 115 4,959’ 4,979’ 3,424’ 3,437’ 20’ 10/27/2020 Open BEL-120 5,064’ 5,069’ 3,492’ 3,496’ 5’ 9/2/2021 Open BEL-120 5,082’ 5,088’ 3,504’ 3,508’ 6’ 9/2/2021 Open BEL-131 5,122’ 5,126’ 3,531’ 3,534’ 4’ 9/2/2021 Open BEL-133 5,186’ 5,191’ 3,577’ 3,581’ 5’ 9/2/2021 Open BEL_136L ±5,499’ ±5,506’ ±3,823’ ±3,829’ 7‘ Deepest proposed T-6 5,856’ 5,884’ 4,149’ 4,167’ 28’ 5/17/2014 Open 5,875’ 5,895’ 4,158’ 4,177’ 20’ 11/22/2016 Open T-8 6,026'6,036'4,297'4,306'10'9/22/2005 Isolated 6,068'6,088'4,335'4,354'20'9/22/2005 Isolated 6,118'6,136'4,382'4,398'18'10/6/2005 Isolated 6,152'6,186'4,413'4,445'34'9/22/2005 Isolated 6,299'6,319'4,549'4,568'20'5/31/2008 Isolated 6,354'6,360'4,600'4,606'6'10/6/2005 Isolated More perfs on p2 More perfs on p2 OPEN HOLE / CEMENT DETAIL 9-5/8”12-1/4” hole: 230 bbls of 12ppg Type I cement. 60 bbls cement back to surface 7"8-1/2” Hole: 70bbls 12.5ppg lead cement pumped followed by 36bbls of 13.5ppg tail cement. Full returns throughout job.Volumetric ToC using 35% washout from OH caliper = 1,390’ MD 4-1/2” Liner 7” Hole (BiCenter Bit): 219bbls 12.8ppg class G cement pumped. 20bbl losses throughout job. 40bbls spacer pumped and got 25bbls spacer back to surface. 4/10/04 CBL show’s top of solid cement at 5830’ MD. Patchy cement up to 5,330’ MD. 4-1/2” Tubing 6.276” ID of casing. Planned ToC at 1500’ MD Draft_ Paxton 1_PROPOSED_IA_Cement(9-8-21)Page 2 of 2 Updated by: CRR 9/8/21 PROPOSED IA Cement SCHEMATIC Well: Paxton 01 PTD: 204-010 API: 50-133-20535-00-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status T-12 6,682'6,702'4,904'4,924'20'10/6/2005 Isolated 6,738'6,758'4,958'4,976'20'10/4/2005 Isolated T-20 6,948'6,968'5,154'5,161'20'10/4/2005 Isolated T-30 7,158'7,198'5,369'5,409'40'10/4/2005 Isolated 7,162'7,182'5,373'5,393'20'3/15/2005 Isolated 7,198'7,251'5,409'5,461'53'10/3/2005 Isolated 7,438'7,458'5,648'5,668'20'3/15/2005 Isolated 7,570'7,588'5,780'5,798'18'10/3/2005 Isolated T-42 7,794'7,814'6,004'6,024'20'2/25/2005 Isolated T-50 8,188'8,208'6,397'6,417'20'10/3/2005 Isolated 8,188'8,266'6,397'6,475'78'5/6/2004 Isolated 8,234'8,254'6,443'6,463'20'4/30/2004 Isolated 8,402'8,437'6,611'6,646'35'5/7/2004 Isolated T-65 8,784'8,804'6,993'7,013'20'5/27/2004 Isolated T-83 8,916'8,936'7,125'7,199'20'5/28/2004 Isolated T-90 9,088'9,142'7,297'7,351'54'5/28/2004 Isolated 9,113'9,133'7,322'7,242'20'4/21/2004 Isolated 9,220'9,256'7,429'7,465'36'5/7/2004 Isolated T-130 9,542'9,558'7,750'7,766'16'4/20/2004 Isolated FISH: Expro 30.9' OVL: 1-7/16" rope socket w/1" fishing neck (1.0'), 1-3/4" swivel (1.2'), 1-11/16" tungsten wt bar (21'), 3-1/8" CCL (2.5'), 3" junk basket (5.0'), and 3.78" gauge ring (.17') Fracked Tyonek Perfs 8,188'-8,266' MD on 2/10/2005 48,553 lbs of 20/40 Ottawa including 12.5% 12/20 Flex Sand Lightning 1800 6% KCL based fluid ramped 1-8 ppg Frac Grad=0.75 psi/ft Max Surf Pressure=3,700 psig G-Function 2-4 Paxton 1 Sand Perf Top Perf Bottom Perf Top Perf Bottom Total Footage Expected Bottom Hole Pressure (MD)(MD)(TVD)(TVD)(MD)(psi) BEL_34 ±1,944’ ±1,951’ ±1,712’ ±1,716’ 7‘713 (RFT in Kalotsa 5 – 2020) BEL_37u ±1,965’ ±1,972’ ±1,725’ ±1,729’ 7‘732.5 (RFT in Paxton 10 – 2020)BEL_37L ±1,990’ ±1,996’ ±1,740’ ±1,743’ 6‘ BEL_38 ±2,007’ ±2,012’ ±1,750’ ±1,752’ 5‘748 (RFT in Kalotsa 5 – 2020) BEL_40 ±2,053’ ±2,065’ ±1,777’ ±1,783’ 12‘804 (calculated from 0.452 psi./ft. gradient) BEL_41u ±2,082’ ±2,088’ ±1,793’ ±1,797’ 6‘ 386 (RFT in Paxton 10 – 2020) BEL_41mu ±2,090’ ±2,096’ ±1,798’ ±1,801’ 6‘ BEL_41mL ±2,101’ ±2,111’ ±1,804’ ±1,810’ 10‘ BEL_41L ±2,119’ ±2,123’ ±1,814’ ±1,817’ 4‘ BEL_43 ±2,151’ ±2,158’ ±1,832’ ±1,837’ 7‘726 (RFT in Kalotsa 3 – 2017) BEL_44 ±2,184’ ±2,192’ ±1,851’ ±1,856’ 8‘653 (RFT in Paxton 10 – 2020) BEL_45 ±2,206’ ±2,260’ ±1,863’ ±1,893’ 54‘650 (RFT in Paxton 10 – 2020) BEL_49 ±2,497’ ±2,503’ ±2,024’ ±2,027’ 6‘767 (RFT in Kalotsa 7 – 2020) BEL_50u ±2,540’ ±2,548’ ±2,048’ ±2,052’ 8‘562 (RFT in Paxton 10 – 2020)BEL_50L ±2,574’ ±2,602’ ±2,067’ ±2,083’ 28‘ BEL_51u ±2,624’ ±2,656’ ±2,095’ ±2,112’ 26‘566 (RFT in Paxton 10 – 2020)BEL_51L ±2,658’ ±2,670’ ±2,113’ ±2,121’ 12‘ BEL_52 ±2,724’ ±2,733’ ±2,151’ ±2,156’ 9‘602 (RFT in Paxton 10 – 2020) BEL_53u ±2,773’ ±2,778’ ±2,177’ ±2,180’ 5‘ 320 (RFT in Paxton 10 – 2020)BEL_53m ±2,814’ ±2,825’ ±2,200’ ±2,206’ 11‘ BEL_53L ±2,835’ ±2,844’ ±2,211’ ±2,216’ 9‘ BEL_56u ±3,033’ ±3,035’ ±2,321’ ±2,322’ 2‘ 965 (RFT in Kalotsa 2 – 2017)BEL_56m ±3,062’ ±3,066’ ±2,337’ ±2,339’ 4‘ BEL_56L ±3,082’ ±3,085’ ±2,348’ ±2,350’ 3‘ BEL_58A ±3,171’ ±3,203’ ±2,397’ ±2,415’ 32‘462 (RFT in Kalotsa 4 – 2017) BEL_59u ±3,282’ ±3,313’ ±2,459’ ±2,476’ 31‘889 (RFT in Kalotsa 7 – 2020)BEL_59L ±3,323’ ±3,329’ ±2,482’ ±2,485’ 6‘ BEL_60u ±3,355’ ±3,363’ ±2,500’ ±2,504’ 8‘871 (RFT in Kalotsa 4 – 2017)BEL_60L ±3,366’ ±3,377’ ±2,505’ ±2,512’ 11‘ BEL_65 ±3,432’ ±3,439’ ±2,543’ ±2,547’ 7‘1048 (RFT in Kalotsa 2 – 2017) BEL_70u ±3,482’ ±3,522’ ±2,571’ ±2,593’ 40‘389 (RFT in Kalotsa 4 – 2017)BEL_70L ±3,526’ ±3,530’ ±2,596’ ±2,598’ 4‘ BEL_73 ±3,588’ ±3,594’ ±2,631’ ±2,634’ 6‘1056 (RFT in Kalotsa 2 – 2017) BEL_74 ±3,624’ ±3,631’ ±2,652’ ±2,655’ 7‘1182.5 (RFT in Paxton 10 – 2020) BEL_80u ±3,781’ ±3,786’ ±2,741’ ±2,744’ 5‘1250 (RFT in Paxton 10 – 2020) BEL_80L ±3,806’ ±3,817’ ±2,755’ ±2,761’ 11‘1250 (RFT in Paxton 10 – 2020) BEL_81 ±3,832’ ±3,837’ ±2,769’ ±2,772’ 5‘1150 (RFT in Kalotsa 7 – 2020) BEL_82 ±3,870’ ±3,883’ ±2,791’ ±2,798’ 13‘1115 (RFT in Paxton 10 – 2020) BEL_83 ±3,930’ ±3,933’ ±2,824’ ±2,825’ 3‘1253 (RFT in Kalotsa 7 – 2020) BEL_88 ±3,950’ ±3,955’ ±2,835’ ±2,837’ 5‘1,282 (calculated from 0.452 psi./ft. gradient) FIT at casing shoe was 16.8 ppg EMW BEL_90A ±4,013’ ±4,025’ ±2,870’ ±2,877’ 12‘1,285 (RFT in Kalotsa 7 – 2020) BEL_90B1 ±4,030’ ±4,034’ ±2,880’ ±2,882’ 4‘ 1,505 (RFT in Paxton 10 – 2020) BEL_90B2 ±4,038’ ±4,041’ ±2,884’ ±2,886’ 3‘ BEL_90B3 ±4,046’ ±4,050’ ±2,889’ ±2,891’ 4‘ BEL_90B4 ±4,055’ ±4,061’ ±2,894’ ±2,897’ 6‘ BEL_90B5 ±4,065’ ±4,078’ ±2,900’ ±2,907’ 13‘ BEL_91 ±4,090’ ±4,104’ ±2,914’ ±2,922’ 14‘1,319 (calculated via 0.452 psi/ft. gradient) BEL_91A ±4,128’ ±4,142’ ±2,935’ ±2,943’ 12‘1,328 (calculated via 0.452 psi/ft. gradient) BEL_92-1 ±4,192’ ±4,195’ ±2,971’ ±2,973’ 3‘1,343 (calculated via 0.452 psi/ft. gradient) BEL_92-2 ±4,208’ ±4,210’ ±2,980’ ±2,981’ 2‘1,347 (calculated via 0.452 psi/ft. gradient) BEL_92-4 ±4,239’ ±4,243’ ±2,997’ ±3,000’ 4‘1,356 (calculated via 0.452 psi/ft. gradient) BEL_92-5 ±4,250’ ±4,257’ ±3,004’ ±3,007’ 7‘1,358 (calculated via 0.452 psi/ft. gradient) BEL_93u ±4,308’ ±4,321’ ±3,037’ ±3,044’ 13‘1,342 (RFT in Kalotsa 7 – 2020)BEL_93L ±4,335’ ±4,349’ ±3,052’ ±3,060’ 14‘ BEL_97u ±4,552’ ±4,558’ ±3,176’ ±3,179’ 6‘ 1,499 (RFT in Paxton 10 – 2020)BEL_97m ±4,580’ ±4,583’ ±3,193’ ±3,194’ 3‘ BEL_97L ±4,586’ ±4,588’ ±3,196’ ±3,197’ 2‘ BEL_98 ±4,625’ ±4,629’ ±3,219’ ±3,221’ 4‘1,448 (RFT in Paxton 10 – 2020) BEL_99u ±4,663’ ±4,665’ ±3,242’ ±3,243’ 2‘1,515 (RFT in Paxton 10 – 2020)BEL_99L ±4,679’ ±4,682’ ±3,251’ ±3,253’ 3‘ BEL_99A ±4,693’ ±4,701’ ±3,259’ ±3,264’ 8‘1,483 (RFT in Dionne 6 – 2008) BEL_105 ±4,781’ ±4,801’ ±3,313’ ±3,325 20‘1,235 (RFT in Paxton 10 – 2020) BEL_110 ±4,870’ ±4,875’ ±3,367’ ±3,371’ 5‘647 (RFT in Paxton 10 – 2020)BEL_110 ±4,870’ ±4,875’ ±3,367’ ±3,371’ 5‘ BEL_115 ±4,958’ ±4,981’ ±3,423’ ±3,437’ 23‘1,026 (RFT in Paxton 10 – 2020) BEL_120 ±5,064’ ±5,069’ ±3,492’ ±3,495’ 5‘683 (RFT in Kalotsa 7 – 2020) BEL_131 ±5,122’ ±5,128’ ±3,531’ ±3,535’ 6‘1,069 (RFT in Kalotsa 3 – 2017) BEL_133 ±5,174’ ±5,176’ ±3,568’ ±3,569’ 2‘1,124 (RFT in Kalotsa 7 – 2020) BEL_134u ±5,206’ ±5,229’ ±3,591’ ±3,608’ 23‘ 772 (RFT in Paxton 10 – 2020)BEL_134m ±5,235’ ±5,242’ ±3,613’ ±3,618’ 7‘ BEL_134L ±5,257’ ±5,260’ ±3,629’ ±3,632’ 3‘ BEL_135u ±5,341’ ±5,345’ ±3,694’ ±3,697’ 4‘477 (RFT in Paxton 10 – 2020)BEL_135L ±5,349’ ±5,357’ ±3,700’ ±3,707’ 8‘ BEL_136u ±5,451’ ±5,465’ ±3,783’ ±3,794’ 14‘435 (RFT in Paxton 10 – 2020)BEL_136L ±5,499’ ±5,506’ ±3,823’ ±3,829’ 7‘ T-6 ±5,859’ ±5,910’ ±4,144’ ±4,190’ 51‘749 (RFT in Kalotsa 7 – 2020) STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 1 Carlisle, Samantha J (CED) From:McLellan, Bryan J (CED) Sent:Thursday, September 9, 2021 12:28 PM To:Ryan Rupert Cc:Donna Ambruz; Taylor Wellman Subject:RE: [EXTERNAL] Paxton 1 (PTD 204-010) Sundry ThanksRyan. Iagreethatnoneoftheproposedperfsrepresentariskoffracturingfracturingoutofzonebasedontheestimatedpore pressuresprovided. FYI,hereisthekindofchartI’musingtoevaluatethepotentialtofracoutofzonewhenyouhavealargeTVDrangeof openperfs. BryanMcLellan SeniorPetroleumEngineer AlaskaOil&GasConservationCommission 333W7thAve Anchorage,AK99501 Bryan.mclellan@alaska.gov +1(907)250Ͳ9193 2 From:RyanRupert<Ryan.Rupert@hilcorp.com> Sent:Thursday,September9,20219:25AM To:McLellan,BryanJ(CED)<bryan.mclellan@alaska.gov> Cc:DonnaAmbruz<dambruz@hilcorp.com>;TaylorWellman<twellman@hilcorp.com> Subject:RE:[EXTERNAL]Paxton1(PTD204Ͳ010)Sundry 1. AnFITwasobtainedatthe9Ͳ5/8”shoewhendrilledat16.8ppg.Giventhatandthelistedpressures,Idon’tsee anyzonecapableofgeneratinggreaterthanthe16.8ppgatthe9Ͳ5/8”shoe.(15.8ppgisthehighestIgot).SoI don’tthinkanyparticularrestrictions/evaluationsareneededonthiswell. 2. Chemicalinjectionline:0.25”OD,0.152”IDdownto2517’MD=2.5gal Ryan Rupert Kenai Ops Engineer (13146) 907-301-1736 (Cell) 907-777-8503 (Office) From:McLellan,BryanJ(CED)<bryan.mclellan@alaska.gov> Sent:Thursday,September9,20219:18AM To:RyanRupert<Ryan.Rupert@hilcorp.com> Subject:[EXTERNAL]Paxton1(PTD204Ͳ010)Sundry Ryan, Afewquestions,requestsregardingthissundryprocedure: 1. Thanksforincludingtheporepressureswiththeperfzones.Theproposedperfsareveryshallow,soplease provideananalysisofpotentialtofracoutofshallowzoneswhenexposedtohighshutͲinpressurefromdeep zones.Whatisthefracpressureatthe9Ͳ5/8”shoe?Whatisyourstrategytoavoidpotentialtofracoutof zone? 2. Whatisthevolumeofthechemicalinjectionline? BryanMcLellan SeniorPetroleumEngineer AlaskaOil&GasConservationCommission 333W7thAve Anchorage,AK99501 Bryan.mclellan@alaska.gov +1(907)250Ͳ9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:McLellan, Bryan J (CED) To:Ryan Rupert Cc:Donna Ambruz; Anthony McConkey; Taylor Wellman Subject:Re: Paxton-01 Sundry #321-414(PTD#204-010) Date:Friday, September 3, 2021 7:46:08 AM Ryan, yes you can add these additional perfs under this sundry. Bryan Mclellan Sent from my iPhone On Sep 2, 2021, at 2:10 PM, Ryan Rupert <Ryan.Rupert@hilcorp.com> wrote: Bryan- Apologies for the edit on this sundry. Can we please add the following 2 intervals to the approved perf table? All existing and proposed perfs are within the same pool. Please don’t hesitate to call with any questions. Thank you, Sand Top (MD) Bottom (MD) Top (TVD) Bottom (TVD)Length Beluga 133 ±5,186’±5,191’±3,577’±3,581’5’ Beluga 120 ±5,082’±5,088’±3,504’±3,508’6’ Ryan Rupert Kenai Ops Engineer (13146) 907-301-1736 (Cell) 907-777-8503 (Office) The information contained in this email message is confidential and may be legally privileged and is intended only forthe use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. 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 10,115 feet 5,913 feet true vertical 8,320 feet 5,545 (fill) feet Effective Depth measured 5,913 feet 4,703 feet true vertical 4,193 feet 3,266 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 4,703' (MD) 3,266' (TVD) 4,703' (MD) Packers and SSSV (type, measured and true vertical depth)ZXP Liner Packer N/A 3,266' (TVD) N/A 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: Taylor Wellman 777-8449 Contact Name:Ryan Rupert Authorized Title:Operations Manager Contact Email: Contact Phone:777-8503 WINJ WAG 508 Water-Bbl MD 100' 1,895' 10,071' 0 Oil-Bbl measured true vertical Packer 4-1/2" 3,418' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Ninilchik Field / Beluga-Tyonek Gas PoolN/A measured TVD Tubing Pressure 990 Ninilchik Unit Paxton 1 N/A ADL0384372 / Fee Private 4,950' Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-010 50-133-20535-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-414 78 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 5,368' 498 8,276' 0 Representative Daily Average Production or Injection Data 100' 1,895' 4,950' Conductor Surface Intermediate Production 7,500psi Casing Structural 20" 9-5/8" 7" Length 8,160psi 6,870psi Collapse 1,500psi 4,760psi 7,020psi ryan.rupert@hilcorp.com Senior Engineer:Senior Res. Engineer: 8,430psi Burst 3,060psi100' 1,682' t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 10:46 am, Sep 08, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.09.08 10:32:35 -08'00' Taylor Wellman (2143) BJM 10/26/21 RBDMS HEW 9/8/2021 SFD 9/8/2021DSR-9/8/21 Rig Start Date End Date 9/2/21 9/3/21 Daily Operations: 09/02/2021 - Thursday Yellowjacket arrives at Paxton 2, PTW, PJSM, Job scope. 13:30 Rig up E-line, PT 250 lo/2,500 high. 15:00 RIH with 5' 2-7/8" 6SPF guns, GPT, GR. 16:30 Make correlation pass, send to town, No correction needed. 17:00 Spot and shoot 5' gun in the Bel-133 5,186'-5,191'. Gas rate was 480mcf before shot, 600 after 10 minutes. 17:30 OOH all shots fired. 18:00 RIH with 4' 6SPF gun & 5' 6SPF gun with switch and GR. 18:30 Make correlation pass, send to town, No correction needed. 19:00 Spot and shoot 4' gun in the BEL=131 5,122'-5,126'. Gas rate 600 before shot, 615mcf after 10 minutes. 19:15 Spot and shoot 5' gun in the BEL-120 5,064'-5,069'. 19:45 OOH all shots fired, lay down equip, secure well for night. Gas rate after all shots 570mcf. 09/03/2021- Friday 8:00 Yellowjacket arrives at Paxton 2 PTW, PJSM, Job scope. 9:00 RIH with 6' 2-7/8" 6SPF gun, GPT, GR. 9:45 Make correlation pass send to town, No correction needed. 10:20 Spot and shoot 6' gun in the BEL-120 5,082'-5,088'. No increase of gas rate. OOH all shots fired. 11:00 RIH with 5' 2-7/8" 6SPF gun, GPT, GR. 11:45 Make correlation pass, send to town, Need to shift up 1'. 12:00 Spot 1' higher, shoot 5' gun in the BEL-110 4,870'-4,875'. 12:30 OOH all shots fired, RDMO, secure well, No increase of gas rate, 570mcf after all shots. Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Paxton 1 50-133-20535-00-00 204-010 shoot 5' gun in the BEL-120 5,064'-5,069'. shoot 6' gun in the BEL-120 5,082'-5,088' shoot 5' gun in the BEL-110 4,870'-4,875' shoot 5' gun in the Bel-133 5,186'-5,191'. shoot 4' gun in the BEL=131 5,122'-5,126' Draft_ Page 1 of 2 Updated by CRR 09-08-21 SCHEMATIC Ninilchik Unit Well: Paxton 01 PTD: 204-010 API: 50-133-20535-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 133 / K-55 / PE 18.73 Surf 100' 9-5/8" Surface 47 / L-80 / Mod-Butt 8.681 Surf 1,895' 7" Intermediate 26 / L-80 / BTC 6.276 Surf 4,950' 4-1/2" Liner 12.6 / L-80 / Hydril 521 3.958 4,703' 10,071' TUBING DETAIL 4-1/2" Tubing 12.6#/L-80/Mod-Butt 3.958 Surf 4,703' JEWELRY DETAIL No Depth ID OD Item 1 2,517’ 3.858 5.93 Baker Chemical Injection Nipple 2 4,703' ZXP Liner Packer w/ 15' Tieback Extension 3 4,727' Flex Lock Liner Hanger 4 5,913’ 3.958 CIBP w/ 10’ cement/TOC @ 5,913’ 10/05/16 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status BEL 105 4,781’ 4,801’ 3,313’ 3,325’ 20’ 10/27/2020 Open BEL-110 4,870’ 4,875’ 3,368’ 3,371’ 5’ 9/2/2021 Open BEL 115 4,959’ 4,979’ 3,424’ 3,437’ 20’ 10/27/2020 Open BEL-120 5,064’ 5,069’ 3,492’ 3,496’ 5’ 9/2/2021 Open BEL-120 5,082’ 5,088’ 3,504’ 3,508’ 6’ 9/2/2021 Open BEL-131 5,122’ 5,126’ 3,531’ 3,534’ 4’ 9/2/2021 Open BEL-133 5,186’ 5,191’ 3,577’ 3,581’ 5’ 9/2/2021 Open T-6 5,856’ 5,884’ 4,149’ 4,167’ 28’ 5/17/2014 Open 5,875’ 5,895’ 4,158’ 4,177’ 20’ 11/22/2016 Open T-8 6,026' 6,036' 4,297' 4,306' 10' 9/22/2005 Isolated 6,068' 6,088' 4,335' 4,354' 20' 9/22/2005 Isolated 6,118' 6,136' 4,382' 4,398' 18' 10/6/2005 Isolated 6,152' 6,186' 4,413' 4,445' 34' 9/22/2005 Isolated 6,299' 6,319' 4,549' 4,568' 20' 5/31/2008 Isolated 6,354' 6,360' 4,600' 4,606' 6' 10/6/2005 Isolated More perfs on p2 More perfs on p2 OPEN HOLE / CEMENT DETAIL 9-5/8” 12-1/4” hole: 230 bbls of 12ppg Type I cement. 60 bbls cement back to surface 7" 8-1/2” Hole: 70bbls 12.5ppg lead cement pumped followed by 36bbls of 13.5ppg tail cement. Full returns throughout job. Volumetric ToC using 35% washout from OH caliper = 1,390’ MD 4-1/2” Liner 7” Hole (BiCenter Bit): 219bbls 12.8ppg class G cement pumped. 20bbl losses throughout job. 40bbls spacer pumped, and got 25bbls spacer back to surface. 4/10/04 CBL show’s top of solid cement at 5830’ MD. Patchy cement up to 5,330’ MD. EL-120 BE 5,064’ 5,069’ 3,492’3,496’5’9/2/2021 Open EL-120BE 5,082’5,088’ 3,504’3,508’6’9/2/2021 Open EL-131 BE 5,122’ 5,126’ 3,531’3,534’4’9/2/2021 Open EL-133 BE 5,186’ 5,191’ 3,577’3,581’5’9/2/2021 Open EL-110 BE 4,870’ 4,875’ 3,368’3,371’5’9/2/2021 Open Draft_ Page 2 of 2 Updated by CRR 09-08-21 SCHEMATIC Ninilchik Unit Well: Paxton 01 PTD: 204-010 API: 50-133-20535-00-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status T-12 6,682' 6,702' 4,904' 4,924' 20' 10/6/2005 Isolated 6,738' 6,758' 4,958' 4,976' 20' 10/4/2005 Isolated T-20 6,948' 6,968' 5,154' 5,161' 20' 10/4/2005 Isolated T-30 7,158' 7,198' 5,369' 5,409' 40' 10/4/2005 Isolated 7,162' 7,182' 5,373' 5,393' 20' 3/15/2005 Isolated 7,198' 7,251' 5,409' 5,461' 53' 10/3/2005 Isolated 7,438' 7,458' 5,648' 5,668' 20' 3/15/2005 Isolated 7,570' 7,588' 5,780' 5,798' 18' 10/3/2005 Isolated T-42 7,794' 7,814' 6,004' 6,024' 20' 2/25/2005 Isolated T-50 8,188' 8,208' 6,397' 6,417' 20' 10/3/2005 Isolated 8,188' 8,266' 6,397' 6,475' 78' 5/6/2004 Isolated 8,234' 8,254' 6,443' 6,463' 20' 4/30/2004 Isolated 8,402' 8,437' 6,611' 6,646' 35' 5/7/2004 Isolated T-65 8,784' 8,804' 6,993' 7,013' 20' 5/27/2004 Isolated T-83 8,916' 8,936' 7,125' 7,199' 20' 5/28/2004 Isolated T-90 9,088' 9,142' 7,297' 7,351' 54' 5/28/2004 Isolated 9,113' 9,133' 7,322' 7,242' 20' 4/21/2004 Isolated 9,220' 9,256' 7,429' 7,465' 36' 5/7/2004 Isolated T-130 9,542' 9,558' 7,750' 7,766' 16' 4/20/2004 Isolated FISH: Expro 30.9' OVL: 1-7/16" rope socket w/1" fishing neck (1.0'), 1-3/4" swivel (1.2'), 1-11/16" tungsten wt bar (21'), 3-1/8" CCL (2.5'), 3" junk basket (5.0'), and 3.78" gauge ring (.17') Fracked Tyonek Perfs 8,188'-8,266' MD on 2/10/2005 48,553 lbs of 20/40 Ottawa including 12.5% 12/20 Flex Sand Lightning 1800 6% KCL based fluid ramped 1-8 ppg Frac Grad=0.75 psi/ft Max Surf Pressure=3,700 psig G-Function 2-4 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: ____Patch / 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): 10,115'see schematic Casing Collapse Structural Conductor 1,500psi Surface 4,760psi Intermediate 7,020psi Production Liner 7,500psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Ryan Rupert Operations Manager Contact Email: Contact Phone: 777-8503 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 ryan.rupert @hilcorp.com 8,320'5,913'4,193'~1462 psi 5,913' ZXP Liner Packer : N/A 4,703(MD) / 3,266(TVD) : N/A Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: 8,430psi 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 ADL0384372 / FEE-PRIVATE 204-010 50-133-20535-00-00 Paxton-01 Ninilchik Field / Beluga-Tyonek Gas Pool Length Size CO 701C Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 12.6# / L-80 TVD Burst 4,703 MD 8,160psi 3,060psi 6,870psi 100' 1,682' 3,418 100' 1,895' 20" 9-5/8" 100' 7"4,950' 1,895' Perforation Depth MD (ft): 4,950' See Attached Schematic 4-1/2" 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 4, 2021 10,071'5,368' 4-1/2" 8,276' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 1:25 pm, Aug 23, 2021 321-414 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.08.23 13:00:15 -08'00' Taylor Wellman (2143) 8/23/21SFD 8/23/2021 10-404 BJM 9/1/21 dts 9/1/2021 JLC 9/2/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.02 10:14:56 -08'00' RBDMS HEW 9/2/2021 Well: Paxton-01 Date: 8/20/2021 Well Name:Paxton-01 API Number:50-133-20535-00-00 Current Status:Gas Producer Leg:N/A Regulatory Contact:Donna Ambruz 777-8305 Permit to Drill Number:204-010 First Call Engineer:Ryan Rupert (907) 777-8503 (O)(907) 301-1736 (C) Second Call Engineer:Todd Sidoti (907) 632-4113 (C) Max. Expected BHP:~ 1880 psi @ 4177’ TVD (Based on 0.45 psi/ft) Max. Potential Surface Pressure ~ 1462 psi (Based on 0.1 psi/ft to surface) Well Summary Paxton-01 has several unshot beluga sands currently accessible below the LTP at 4703’ MD. There are many sands to complete above the LTP later in this well’s life, but that will require a workover to modify the completions, and establish a higher barrier above the sands. So now is the time to perf the unshot sands below the LTP. The 4-1/2” liner cement is known to be poor or non-existent in these upper sections. However, the BEL 105/115 perfs shot in October-2020 did increase the rate. All proposed perfs are within the same pool. The goal of this project is to perforate remaining Beluga sands below the 4-1/2” LTP to increase production from the well. Notes Regarding Wellbore Condition x Min ID = 3.858” at 2517’ MD (Chemical injection nipple) x Inclination o Max = 57 degrees at 3123’ MD o Sail angle of ~57 degrees from 2200’ MD – 4500’ MD o Then rolls to 31 degrees by 5500’ MD x Recent history o 10/27/20: GPT ran down to 5050’ MD. No fluid seen, no tag Perf’d two 20’ intervals as deep as 4979’ MD with 2-7/8” guns. o 12/7/18: SL tagged at 5170’ SLMD and bailed 15’ of clay/mud down to 5185’ MD. Able to cycle pressure and get it to unload sand/water and come online. o 12/6/18: SL tagged at 5150’ SLMD (above all perfs) and bailed 20’ of clay/mud o 10/25/18: EL tagged at 5861’ MD. RDMO (didn’t shoot anything) o 10/21/18: CT FCO CT dry tagged fill at 5656’ CT performed a FCO with a 2.5” DJN to 5910’ CTMD Nitrogen Risk x Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. x Consider tank placement based on wind direction and current weather forecast (venting Nitrogen during this job) x Ensure all crews are aware of stop work authority o perf the unshot sands below the LTP. All proposed perfs are within the same pool. Well: Paxton-01 Date: 8/20/2021 SL drift (non-sundried steps) 1. MIRU SL and PT to 250psi low / 2500psi high 2. D&T to PBTD with 3.60” gauge ring 3. D&T to 5600’ MD to mimic a 20’ x 3.60” permanent patch 4. RDMO E-Line Perf 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 2,500 psi High 3. Rig up perf gun (Likely 2-7/8” – 3-3/8” 4-6 spf) 4. RIH and perforate the sand listed in the table below, per Geo/RE. Sand Perforation Top (MD) Perforation Bottom (MD) Perforation Top (TVD) Perforation Bottom (TVD) Total Footage (MD) BEL_110 ±4,870’±4,875’±3,367’±3,371’5‘ BEL_110 ±4,870’±4,875’±3,367’±3,371’5‘ BEL_120 ±5,064’±5,069’±3,492’±3,495’5‘ BEL_131 ±5,122’±5,128’±3,531’±3,535’6‘ BEL_133 ±5,174’±5,176’±3,568’±3,569’2‘ BEL_134u ±5,206’±5,229’±3,591’±3,608’23‘ BEL_134m ±5,235’±5,242’±3,613’±3,618’7‘ BEL_134L ±5,257’±5,260’±3,629’±3,632’3‘ BEL_135u ±5,341’±5,345’±3,694’±3,697’4‘ BEL_135L ±5,349’±5,357’±3,700’±3,707’8‘ BEL_136u ±5,451’±5,465’±3,783’±3,794’14‘ BEL_136L ±5,499’±5,506’±3,823’±3,829’7‘ Consult with OE for what WHP’s to use. May be shot while flowing Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. a.Use Gamma/CCL to correlate. b. Record initial and 5/10/15 minute tubing pressures after firing c. Consult with RE/Geo between each perf interval: i. Matt Petrowsky (Geo): 814-421-6753 ii. Anthony McConkey (RE): 529-6199 5. RD E-Line Unit and turn well over to production. Well: Paxton-01 Date: 8/20/2021 Contingency EL Plug or Patch 1. MIRU E-line, PT lubricator to 250 psi low / 2,500 psi high 2. RIH W/ GPT tool and find fluid level 3. RU Nitrogen Truck a. Push water back into formation b. Use GPT tool to confirm water level is below interval to perf c. Consult OE for pressure to leave on well for perforating 4. Once fluid level is below interval to isolate, MU 4-1/2” patch or plug 5. RIH and set plug or patch per OE. 6. RD E-Line Unit and turn well over to production. Attachments: 1. Current schematic 2. Proposed Schematic 3. Standard Well procedure – N2 Operations Draft_ Paxton 1 Schematic(7-30-21)Page 1 of 2 Updated by: CRR 7/30/21 SCHEMATIC Well: Paxton 01 PTD: 204-010 API: 50-133-20535-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 133 / K-55 / PE 18.73 Surf 100' 9-5/8"Surface 47 / L-80 / Mod-Butt 8.681 Surf 1,895' 7"Intermediate 26 / L-80 / BTC 6.276 Surf 4,950' 4-1/2"Liner 12.6 / L-80 / Hydril 521 3.958 4,703'10,071' TUBING DETAIL 4-1/2"Tubing 12.6#/L-80/Mod-Butt 3.958 Surf 4,703' JEWELRY DETAIL No Depth ID OD Item 1 2,517’3.858 5.93 Baker Chemical Injection Nipple 2 4,703'ZXP Liner Packer w/ 15' Tieback Extension 3 4,727'Flex Lock Liner Hanger 4 5,913’3.958 CIBP w/ 10’ cement/TOC @ 5,913’ 10/05/16 PERFORATION DETAIL Zone Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status BEL 105 4,781’4,801’3,313’3,325’20’10/27/2020 Open BEL 115 4,959’4,979’3,424’3,437’20’10/27/2020 Open T-6 5,856’5,884’4,149’4,167’28’5/17/2014 Open 5,875’5,895’4,158’4,177’20’11/22/2016 Open T-8 6,026'6,036'4,297'4,306'10'9/22/2005 Isolated 6,068'6,088'4,335'4,354'20'9/22/2005 Isolated 6,118'6,136'4,382'4,398'18'10/6/2005 Isolated 6,152'6,186'4,413'4,445'34'9/22/2005 Isolated 6,299'6,319'4,549'4,568'20'5/31/2008 Isolated 6,354'6,360'4,600'4,606'6'10/6/2005 Isolated More perfs on p2 More perfs on p2 OPEN HOLE / CEMENT DETAIL 9-5/8”12-1/4” hole: 230 bbls of 12ppg Type I cement. 60 bbls cement back to surface 7"8-1/2” Hole: 70bbls 12.5ppg lead cement pumped followed by 36bbls of 13.5ppg tail cement. Full returns throughout job.Volumetric ToC using 35% washout from OH caliper = 1,390’ MD 4-1/2” 7” Hole (BiCenter Bit): 219bbls 12.8ppg class G cement pumped. 20bbl losses throughout job. 40bbls spacer pumped, and got 25bbls spacer back to surface. 4/10/04 CBL show’s top of solid cement at 5830’ MD. Patchy cement up to 5,330’ MD. Draft_ Paxton 1 Schematic(7-30-21)Page 2 of 2 Updated by: CRR 7/30/21 SCHEMATIC Well: Paxton 01 PTD: 204-010 API: 50-133-20535-00-00 PERFORATION DETAIL Zone Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status T-12 6,682'6,702'4,904'4,924'20'10/6/2005 Isolated 6,738'6,758'4,958'4,976'20'10/4/2005 Isolated T-20 6,948'6,968'5,154'5,161'20'10/4/2005 Isolated T-30 7,158'7,198'5,369'5,409'40'10/4/2005 Isolated 7,162'7,182'5,373'5,393'20'3/15/2005 Isolated 7,198'7,251'5,409'5,461'53'10/3/2005 Isolated 7,438'7,458'5,648'5,668'20'3/15/2005 Isolated 7,570'7,588'5,780'5,798'18'10/3/2005 Isolated T-42 7,794'7,814'6,004'6,024'20'2/25/2005 Isolated T-50 8,188'8,208'6,397'6,417'20'10/3/2005 Isolated 8,188'8,266'6,397'6,475'78'5/6/2004 Isolated 8,234'8,254'6,443'6,463'20'4/30/2004 Isolated 8,402'8,437'6,611'6,646'35'5/7/2004 Isolated T-65 8,784'8,804'6,993'7,013'20'5/27/2004 Isolated T-83 8,916'8,936'7,125'7,199'20'5/28/2004 Isolated T-90 9,088'9,142'7,297'7,351'54'5/28/2004 Isolated 9,113'9,133'7,322'7,242'20'4/21/2004 Isolated 9,220'9,256'7,429'7,465'36'5/7/2004 Isolated T-130 9,542'9,558'7,750'7,766'16'4/20/2004 Isolated FISH: Expro 30.9' OVL: 1-7/16" rope socket w/1" fishing neck (1.0'), 1-3/4" swivel (1.2'), 1-11/16" tungsten wt bar (21'), 3-1/8" CCL (2.5'), 3" junk basket (5.0'), and 3.78" gauge ring (.17') Fracked Tyonek Perfs 8,188'-8,266' MD on 2/10/2005 48,553 lbs of 20/40 Ottawa including 12.5% 12/20 Flex Sand Lightning 1800 6% KCL based fluid ramped 1-8 ppg Frac Grad=0.75 psi/ft Max Surf Pressure=3,700 psig G-Function 2-4 Draft_ Paxton 1_Lower_Perfs_PROPOSED(8-20-21)Page 1 of 2 Updated by: CRR 8/20/21 PROPOSED SCHEMATIC Well: Paxton 01 PTD: 204-010 API: 50-133-20535-00-00 TD =10,115’ MD / 8,320’ TVD PBTD = 5,913’ MD / 4,193’ TVD T-6 RKB: MSL = 153’ / 17’ AGL 7” 20” 9-5/8” 1 2 3 4-1/2” 4 TOF tagged @ 5185’ MD on 12/07/18 BEL 115 BEL 105 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 133 / K-55 / PE 18.73 Surf 100' 9-5/8" Surface 47 / L-80 / Mod-Butt 8.681 Surf 1,895' 7" Intermediate 26 / L-80 / BTC 6.276 Surf 4,950' 4-1/2" Liner 12.6 / L-80 / Hydril 521 3.958 4,703' 10,071' TUBING DETAIL 4-1/2" Tubing 12.6#/L-80/Mod-Butt 3.958 Surf 4,703' JEWELRY DETAIL No Depth ID OD Item 1 2,517’ 3.858 5.93 Baker Chemical Injection Nipple 2 4,703' ZXP Liner Packer w/ 15' Tieback Extension 3 4,727' Flex Lock Liner Hanger 4 5,913’ 3.958 CIBP w/ 10’ cement/TOC @ 5,913’ 10/05/16 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Perfs per sundry BEL 105 4,781’ 4,801’ 3,313’ 3,325’ 20’ 10/27/2020 Open BEL 115 4,959’ 4,979’ 3,424’ 3,437’ 20’ 10/27/2020 Open T-6 5,856’ 5,884’ 4,149’ 4,167’ 28’ 5/17/2014 Open 5,875’ 5,895’ 4,158’ 4,177’ 20’ 11/22/2016 Open T-8 6,026'6,036'4,297'4,306'10'9/22/2005 Isolated 6,068'6,088'4,335'4,354'20'9/22/2005 Isolated 6,118'6,136'4,382'4,398'18'10/6/2005 Isolated 6,152'6,186'4,413'4,445'34'9/22/2005 Isolated 6,299'6,319'4,549'4,568'20'5/31/2008 Isolated 6,354'6,360'4,600'4,606'6'10/6/2005 Isolated More perfs on p2 More perfs on p2 OPEN HOLE / CEMENT DETAIL 9-5/8”12-1/4” hole: 230 bbls of 12ppg Type I cement. 60 bbls cement back to surface 7"8-1/2” Hole: 70bbls 12.5ppg lead cement pumped followed by 36bbls of 13.5ppg tail cement. Full returns throughout job.Volumetric ToC using 35% washout from OH caliper = 1,390’ MD 4-1/2” 7” Hole (BiCenter Bit): 219bbls 12.8ppg class G cement pumped. 20bbl losses throughout job. 40bbls spacer pumped, and got 25bbls spacer back to surface. 4/10/04 CBL show’s top of solid cement at 5830’ MD. Patchy cement up to 5,330’ MD. Draft_ Paxton 1_Lower_Perfs_PROPOSED(8-20-21)Page 2 of 2 Updated by: CRR 8/20/21 PROPOSED SCHEMATIC Well: Paxton 01 PTD: 204-010 API: 50-133-20535-00-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status T-12 6,682'6,702'4,904'4,924'20'10/6/2005 Isolated 6,738'6,758'4,958'4,976'20'10/4/2005 Isolated T-20 6,948'6,968'5,154'5,161'20'10/4/2005 Isolated T-30 7,158'7,198'5,369'5,409'40'10/4/2005 Isolated 7,162'7,182'5,373'5,393'20'3/15/2005 Isolated 7,198'7,251'5,409'5,461'53'10/3/2005 Isolated 7,438'7,458'5,648'5,668'20'3/15/2005 Isolated 7,570'7,588'5,780'5,798'18'10/3/2005 Isolated T-42 7,794'7,814'6,004'6,024'20'2/25/2005 Isolated T-50 8,188'8,208'6,397'6,417'20'10/3/2005 Isolated 8,188'8,266'6,397'6,475'78'5/6/2004 Isolated 8,234'8,254'6,443'6,463'20'4/30/2004 Isolated 8,402'8,437'6,611'6,646'35'5/7/2004 Isolated T-65 8,784'8,804'6,993'7,013'20'5/27/2004 Isolated T-83 8,916'8,936'7,125'7,199'20'5/28/2004 Isolated T-90 9,088'9,142'7,297'7,351'54'5/28/2004 Isolated 9,113'9,133'7,322'7,242'20'4/21/2004 Isolated 9,220'9,256'7,429'7,465'36'5/7/2004 Isolated T-130 9,542'9,558'7,750'7,766'16'4/20/2004 Isolated FISH: Expro 30.9' OVL: 1-7/16" rope socket w/1" fishing neck (1.0'), 1-3/4" swivel (1.2'), 1-11/16" tungsten wt bar (21'), 3-1/8" CCL (2.5'), 3" junk basket (5.0'), and 3.78" gauge ring (.17') Fracked Tyonek Perfs 8,188'-8,266' MD on 2/10/2005 48,553 lbs of 20/40 Ottawa including 12.5% 12/20 Flex Sand Lightning 1800 6% KCL based fluid ramped 1-8 ppg Frac Grad=0.75 psi/ft Max Surf Pressure=3,700 psig G-Function 2-4 STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 1. Operations 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: N2, Pull Cap String 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 10,115 feet 5,913 feet true vertical 8,320 feet 5,683 (fill) feet Effective Depth measured 5,913 feet 4,703 feet true vertical 4,193 feet 3,266 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 4,703' (MD) 3,266' (TVD) 4,703' (MD) Packers and SSSV (type, measured and true vertical depth)ZXP Liner Packer N/A 3,266' (TVD) N/A 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: Taylor Wellman 777-8449 Contact Name:Jake Flora Authorized Title:Operations Manager Contact Email: Contact Phone:777-8442 WINJ WAG 743 Water-Bbl MD 100' 1,895' 10,071' 17 Oil-Bbl measured true vertical Packer 4-1/2" 3,418' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Ninilchik Field / Beluga-Tyonek Gas PoolN/A measured TVD Tubing Pressure 8730 Ninilchik Unit Paxton 1 N/A ADL0384372 / Fee Private 4,950' Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-010 50-133-20535-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-442 570 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 14 Authorized Signature with date: Authorized Name: 14 Casing Pressure Liner 5,368' 2,700 8,276' 0 Representative Daily Average Production or Injection Data 100' 1,895' 4,950' Conductor Surface Intermediate Production 7,500psi Casing Structural 20" 9-5/8" 7" Length 8,160psi 6,870psi Collapse 1,500psi 4,760psi 7,020psi jake.flora@hilcorp.com Senior Engineer:Senior Res. Engineer: 8,430psi Burst 3,060psi100' 1,682' t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 3:27 pm, Nov 18, 2020 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.11.18 13:37:49 -09'00' Taylor Wellman DSR-11/19/2020 RBDMS HEW 11/20/2020 SFD 11/24/2020 2,700 gls 12/9/20 Rig Start Date End Date Cap-String 10/24/20 10/27/20 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Paxton 1 50-133-20535-00 204-010 PTW and JSA. Wind was blowing 20 to 25 mph and gusting to 32 to 38 mph according to my Windy App and Joe Dalebout's Temp and wind. He did not want to run his crane with this kinda wind. Checked with Chad Ebenezer and he checked with John and Matt. AKE-Line didn't have a wind checker device but it was blowing pretty good. Chad said it was up to AKE-Line to make the decision and they said try again in morning.TP was 446.6 psi. SLB N2 brought their N2 pump truck and stagged ithere at Paxton. Will check wind from my house in the morning on wind conditions also call SD Pad for update. 10/27/2020 - Tuesday PTW, JSA and SIMOPS w/AKE-Line and SLB N2. Rig up equipment and pressure test to 250 psi low and 3,000 psi high. TP - 463.3 psi. RIH w/GPT and tie into OHL that Matthew Petrowsky and Anthony McConkey brought from Anch. Ran correlation log and let Matt look over. Log good. Found no fluid to 5,050'. POOH and logged from 5,050' to 4,650'. RIH w/ 2-7/8" x 20' HC Razor, 6 spf 60 deg phase and correlated to GPT log. Also had roller boggie on end of perf gun. Ran a strip correlation log and got ok from Matt here. Pressured up tubing to 1,000 psi of N2 while going in hole. Spotted and fired gun from 4,959' to 4,979' with 1,000 psi tubing . After 5 min - 902 psi, 10 min - 842 psi and 15 min - 805 psi. All shots fired and gun was dry. RIH w/ 2-7/8" x 20' HC Razor, 6 spf 60 deg phase and correlated to GPT log. Also had roller boggie on end of perf gun. Ran a strip correlation log and got ok from matt here. Spotted and fired gun from 4,781' to 4,801' with 769 psi tubing. After 5 min - 789 psi, 10 min - 797 psi and 15 min - 802 psi. All shots fired and gun was dry. Rig down lubricator and equip. Turn well over to field. Used 250 gals of N2. Daily Operations: PTW/JSA. Rig up cap string truck. PT lubricator to 250 psi low and 3,500 psi high. Pull cap string (~5,100') out of hole. Got all of it out. Shut well in, Rig down lubricator. 10/26/2020 - Monday 10/24/2020 - Saturday fired gun from 4,959' to 4,979' 4,781' to 4,801' _____________________________________________________________________________________ Updated by DMA 11-06-20 SCHEMATIC Ninilchik Field Well: Paxton 01 Last Completed: 5/29/2004 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 133 / K-55 / PE 18.73 Surf 100' 9-5/8" Surface 47 / L-80 / Mod-Butt 8.681 Surf 1,895' 7" Intermediate 29 / L-80 / BTC 6.184 Surf 4,950' 4-1/2" Liner 12.6 / L-80 / Hydril 521 3.958 4,703' 10,071' TUBING DETAIL 4-1/2" Tubing 12.6#/L-80/Mod-Butt 3.958 Surf 4,703' JEWELRY DETAIL No Depth ID OD Item 1 2,517’ 3.858 5.93 Baker Chemical Injection Nipple 2 4,703' ZXP Liner Packer w/ 15' Tieback Extension 3 4,727' Flex Lock Liner Hanger 4 5,913’ 3.958 CIBP w/ 10’ cement/TOC @ 5,913’ 10/05/16 5 9,946' Landing Collar 6 10,028' Float Collar 7 10,071' Float Shoe PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status BEL 105 4,781’ 4,801’ 3,313’ 3,325’ 20’ 10/27/2020 Open BEL 115 4,959’ 4,979’ 3,424’ 3,437’ 20’ 10/27/2020 Open T-6 5,856’ 5,884’ 4,149’ 4,167’ 28’ 5/17/2014 Open 5,875’ 5,895’ 4,158’ 4,177’ 20’ 11/22/2016 Open T-8 6,026' 6,036' 4,297' 4,306' 10' 9/22/2005 Isolated 6,068' 6,088' 4,335' 4,354' 20' 9/22/2005 Isolated 6,118' 6,136' 4,382' 4,398' 18' 10/6/2005 Isolated 6,152' 6,186' 4,413' 4,445' 34' 9/22/2005 Isolated 6,299' 6,319' 4,549' 4,568' 20' 5/31/2008 Isolated 6,354' 6,360' 4,600' 4,606' 6' 10/6/2005 Isolated T-12 6,682' 6,702' 4,904' 4,924' 20' 10/6/2005 Isolated 6,738' 6,758' 4,958' 4,976' 20' 10/4/2005 Isolated T-20 6,948' 6,968' 5,154' 5,161' 20' 10/4/2005 Isolated T-30 7,158' 7,198' 5,369' 5,409' 40' 10/4/2005 Isolated 7,162' 7,182' 5,373' 5,393' 20' 3/15/2005 Isolated 7,198' 7,251' 5,409' 5,461' 53' 10/3/2005 Isolated 7,438' 7,458' 5,648' 5,668' 20' 3/15/2005 Isolated 7,570' 7,588' 5,780' 5,798' 18' 10/3/2005 Isolated T-42 7,794' 7,814' 6,004' 6,024' 20' 2/25/2005 Isolated T-50 8,188' 8,208' 6,397' 6,417' 20' 10/3/2005 Isolated 8,188' 8,266' 6,397' 6,475' 78' 5/6/2004 Isolated 8,234' 8,254' 6,443' 6,463' 20' 4/30/2004 Isolated 8,402' 8,437' 6,611' 6,646' 35' 5/7/2004 Isolated T-65 8,784' 8,804' 6,993' 7,013' 20' 5/27/2004 Isolated T-83 8,916' 8,936' 7,125' 7,199' 20' 5/28/2004 Isolated T-90 9,088' 9,142' 7,297' 7,351' 54' 5/28/2004 Isolated 9,113' 9,133' 7,322' 7,242' 20' 4/21/2004 Isolated 9,220' 9,256' 7,429' 7,465' 36' 5/7/2004 Isolated T-130 9,542' 9,558' 7,750' 7,766' 16' 4/20/2004 Isolated Fracked Tyonek Perfs 8,188'-8,266' MD on 2/10/2005 48,553 lbs of 20/40 Ottawa including 12.5% 12/20 Flex Sand Lightning 1800 6% KCL based fluid ramped 1-8 ppg Frac Grad=0.75 psi/ft Max Surf Pressure=3,700 psig G-Function 2-4 FISH: Expro 30.9' OVL: 1-7/16" rope socket w/1" fishing neck (1.0'), 1-3/4" swivel (1.2'), 1-11/16" tungsten wt bar (21'), 3-1/8" CCL (2.5'), 3" junk basket (5.0'), and 3.78" gauge ring (.17') BEL 105 4,781’4,801’3,313’3,325’20’10/27/2020 Open BEL 115 4,959’4,979’3,424’3,437’20’10/27/2020 Open p 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, Pull/Run Cap String 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): 10,115'5,683' (fill) Casing Collapse Structural Conductor 1,500psi Surface 4,760psi Intermediate 7,020psi Production Liner 7,500psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): ZXP Liner Packer / N/A 4,703(MD) & 3,266(TVD) / N/A 12. Attachments:Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL 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 8,320'5,913'4,193'1202 psi 5,913' Perforation Depth TVD (ft):Tubing Size: COMMISSION USE ONLY Authorized Name: 8,430psi 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 ADL0384372 / FEE-PRIVATE 204-010 50-133-20535-00-00 Ninilchik Unit Paxton 1 Ninilchik Field / Beluga-Tyonek Gas Pool Length Size CO 701C Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 12.6# / L-80 TVD Burst 4,703 MD 8,160psi 3,060psi 6,870psi 100' 1,682' 3,418 100' 1,895' 20" 9-5/8" 100' 7"4,950' 1,895' Perforation Depth MD (ft): 4,950' See Attached Schematic 4-1/2" 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: October 25, 2020 10,071'5,368' 4-1/2" 8,276' m n P 66 t g Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:49 am, Oct 15, 2020 320-422 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.10.14 16:39:12 -08'00' Taylor Wellman N2, Pull/Run Cap Stringg 10-404 DSR-10/15/2020SFD 10/15/2020 320-442 Perforate X VTL 10/21/20Comm 10/22/2020 dts 10/22/2020 RBDMS HEW 11/12/2020 Well Prognosis Well: Pax-01 Date: 10/12/2020 Well Name: Pax-01 API Number: Current Status: Online Gas Producer Leg: N/A Estimated Start Date: 10/25/20 Rig: E-line Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 204-010 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (C) Maximum Expected BHP: ~ 1544 psi @ 3424’ TVD (Based on a 0.45 psi/ft gradient) Max. Potential Surface Pressure: ~ 1202 psi Using Max BHP minus 0.1 psi/ft. gas gradient to surface). Well Summary / Objective Paxton-01 was a 2004 new drill currently producing from the T-6. The objective of this job is to add rate by perforating the Beluga 105 & 115 sands while continuing to produce the T-6. Notes Regarding Wellbore Condition Paxton 1 has sand issues; on 10/03/18 sandy fill was tagged at 5636’ with a 2.5” bailer. Two months later on 12/07/18 top of fill was found at 5185’ with a 3” bailer. Given the history additional fill should be expected above 5185’. In 2019 a 3/8” capillary string was run to 5100’MD to continuously inject soap to aid in water unloading. Pre-Job Operations: 1. RU Cap string truck, PT lubricator to 250psi Low, 3000psi Hi. Pull capillary string. Turn well over to production. 2. SI well 1-2 days prior to RU E-line. E-line Procedure: 3. MIRU E-Line. 4. PT BOP equipment to 250 psi Low / 3,500 psi High. (Notify AOGCC 24 hrs in advance on BOP test.) 5. RIH with GPT and locate fluid level, tag PBTD. POOH. 6. RIH and perforate the following intervals bottom to top: Sand MD Top MD Bottom TVD Top TVD Bottom Total Footage (MD) Expected Pressure Gun Size (6 SPF) BEL 105 ±4,781' ±4,801' ±3,313' ±3,325' 20' 1494 2.875” BEL 115 ±4,959' ±4,979' ±3,424' ±3,437' 20' 1544 2.875” a. Make GR/CCL correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. b. Spacing allowance is based on CO 701C. Proposed intervals are in the Beluga/Tyonek Gas Pool. Paxton-01 was a 2004 new drill currently producing from the T-6. The objective of this job is to add rate by perforating the Beluga 105 & 115 sands while continuing to produce the T-6. 2.875”BEL 105 ±4,781' ±4,801' ±3,313' ±3,325' 20' 1494 2.875”BEL 115 ±4,959' ±4,979' ±3,424' ±3,437' 20' 1544 PT lubricator VTL 10/21/20 Well Prognosis Well: Pax-01 Date: 10/12/2020 c. Record initial and 5/10/15 minute tubing pressures after firing. d. Consult with RE/Geo between each perf interval: i. Anthony McConkey: RE - 529-6199 ii. Matthew Petrowsky: Geo – 814-421-6753 7. Once sufficient production has been added per RE/Geo, RD E-Line Unit. 8. CONTINGENT: If a zone is shown to make undesirable sand/water, set patch for shut-off a. MU 4-1/2” patch per vendor recommendation b. RIH and set over identified perf interval 9. CONTINGENT: If the fluid level is found > 1000 ft above the proposed perforations consult with town about using N2 to depress fluid level. 10. CONTINGENT: Re-run 3/8” capillary string to ~5000’MD if new gas rate is not sufficient to keep well unloaded. 11. Return well to production. Attachments: 1. Actual Schematic 2. Proposed Schematic Re-run 3/8” capillary string to ~5000’MD if new gas rate is not sufficient to keep well _____________________________________________________________________________________ Updated by DMA 07-05-19 SCHEMATIC Ninilchik Field Well: Paxton 01 Last Completed: 5/29/2004 TD =10,115’ MD / 8,320’ TVD PBTD = 5,913’ MD / 4,193’ TVD 6 5 T-6 RKB: MSL = 153’ / 17’ AGL 7” TOF tagged @ 6,047’ MD on 8/15/2016 20” 9-5/8” 1 2 3 4-1/2” 7 4 TOF tagged @ 5185TT’5 MD on 12/07/18 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 133 / K-55 / PE 18.73 Surf 100' 9-5/8"Surface 47 / L-80 /Mod-Butt 8.681 Surf 1,895' 7"Intermediate 29 / L-80 / BTC 6.184 Surf 4,950' 4-1/2"Liner 12.6 / L-80 / Hydril 521 3.958 4,703'10,071' TUBING DETAIL 4-1/2"Tubing 12.6#/L-80/Mod-Butt 3.958 Surf 4,703' JEWELRY DETAIL No Depth ID OD Item 1 2,517’3.858 5.93 Baker Chemical Injection Nipple 2 4,703'ZXP Liner Packer w/ 15' Tieback Extension 3 4,727'Flex Lock Liner Hanger 4 5,913’3.958 CIBP w/ 10’ cement/TOC @ 5,913’10/05/16 5 9,946'Landing Collar 6 10,028'Float Collar 7 10,071'Float Shoe PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status T-6 5,856’ 5,884’ 4,149’ 4,167’28’5/17/2014 Open 5,875’ 5,895’ 4,158’4,177’20’11/22/2016 Open T-8 6,026'6,036'4,297'4,306'10'9/22/2005 Isolated 6,068'6,088'4,335'4,354'20'9/22/2005 Isolated 6,118'6,136'4,382'4,398'18'10/6/2005 Isolated 6,152'6,186'4,413'4,445'34'9/22/2005 Isolated 6,299'6,319'4,549'4,568'20'5/31/2008 Isolated 6,354'6,360'4,600'4,606'6'10/6/2005 Isolated T-12 6,682'6,702'4,904'4,924'20'10/6/2005 Isolated 6,738'6,758'4,958'4,976'20'10/4/2005 Isolated T-20 6,948'6,968'5,154'5,161'20'10/4/2005 Isolated T-30 7,158'7,198'5,369'5,409'40'10/4/2005 Isolated 7,162'7,182'5,373'5,393'20'3/15/2005 Isolated 7,198'7,251'5,409'5,461'53'10/3/2005 Isolated 7,438'7,458'5,648'5,668'20'3/15/2005 Isolated 7,570'7,588'5,780'5,798'18'10/3/2005 Isolated T-42 7,794'7,814'6,004'6,024'20'2/25/2005 Isolated T-50 8,188'8,208'6,397'6,417'20'10/3/2005 Isolated 8,188'8,266'6,397'6,475'78'5/6/2004 Isolated 8,234'8,254'6,443'6,463'20'4/30/2004 Isolated 8,402'8,437'6,611'6,646'35'5/7/2004 Isolated T-65 8,784'8,804'6,993'7,013'20'5/27/2004 Isolated T-83 8,916'8,936'7,125'7,199'20'5/28/2004 Isolated T-90 9,088'9,142'7,297'7,351'54'5/28/2004 Isolated 9,113'9,133'7,322'7,242'20'4/21/2004 Isolated 9,220'9,256'7,429'7,465'36'5/7/2004 Isolated T-130 9,542'9,558'7,750'7,766'16'4/20/2004 Isolated OPEN HOLE / CEMENT DETAIL 9-5/8" 12-1/4" hole, Cmt w/ 515 sks (230 bbls) 12 ppg Type 1 cmt. 134 sks (60 bbls) to Surface 7"8-1/2" hole, Cmt w/ 180 sks (70 bbls) 12.5 ppg Lead & 110 sks (36 bbls) 13.5 ppg Tail Cmt bumped plug. 4-1/2"7" hole w/ 690sks (219 bbls) of 12.8 ppg class G cmt. Fracked Tyonek Perfs 8,188'-8,266' MD on 2/10/2005 48,553 lbs of 20/40 Ottawa including 12.5% 12/20 Flex Sand Lightning 1800 6% KCL based fluid ramped 1-8 ppg Frac Grad=0.75 psi/ft Max Surf Pressure=3,700 psig G-Function 2-4 FISH: Expro 30.9' OVL: 1-7/16" rope socket w/1" fishing neck (1.0'), 1-3/4" swivel (1.2'), 1-11/16" tungsten wt bar (21'), 3-1/8" CCL (2.5'), 3" junk basket (5.0'), and 3.78" gauge ring (.17') Capillary String 3/8” 2205 Stainless Steel (11,500’ spool) Top Bottom MD 0’ 5,100’ TVD 0’ 3,517’ Cap String _____________________________________________________________________________________ Updated by DMA 07-05-19 PROPOSED SCHEMATIC Ninilchik Field Well: Paxton 01 Last Completed: 5/29/2004 TD =10,115’ MD / 8,320’ TVD PBTD = 5,913’ MD / 4,193’ TVD 6 5 T-6 RKB: MSL = 153’ / 17’ AGL 7” TOF ta gged @ 6,047’ MD on 8/15/2016 20” 9-5/8” 1 2 3 4-1/2” 7 4 TOF tagged @ 5185’ MD on 12/07/18 BEL 115 BEL 105 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 133 / K-55 / PE 18.73 Surf 100' 9-5/8"Surface 47 / L-80 /Mod-Butt 8.681 Surf 1,895' 7"Intermediate 29 / L-80 / BTC 6.184 Surf 4,950' 4-1/2"Liner 12.6 / L-80 / Hydril 521 3.958 4,703'10,071' TUBING DETAIL 4-1/2"Tubing 12.6#/L-80/Mod-Butt 3.958 Surf 4,703' JEWELRY DETAIL No Depth ID OD Item 1 2,517’3.858 5.93 Baker Chemical Injection Nipple 2 4,703'ZXP Liner Packer w/ 15' Tieback Extension 3 4,727'Flex Lock Liner Hanger 4 5,913’3.958 CIBP w/ 10’ cement/TOC @ 5,913’10/05/16 5 9,946'Landing Collar 6 10,028'Float Collar 7 10,071'Float Shoe PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status BEL-105 4,781’4,801’3,313’3,325’20’NA Planned BEL 115 4,959’4,979’3,424’3,437’20’NA Planned T-6 5,856’ 5,884’ 4,149’ 4,167’28’5/17/2014 Open 5,875’ 5,895’ 4,158’4,177’20’11/22/2016 Open T-8 6,026'6,036'4,297'4,306'10'9/22/2005 Isolated 6,068'6,088'4,335'4,354'20'9/22/2005 Isolated 6,118'6,136'4,382'4,398'18'10/6/2005 Isolated 6,152'6,186'4,413'4,445'34'9/22/2005 Isolated 6,299'6,319'4,549'4,568'20'5/31/2008 Isolated 6,354'6,360'4,600'4,606'6'10/6/2005 Isolated T-12 6,682'6,702'4,904'4,924'20'10/6/2005 Isolated 6,738'6,758'4,958'4,976'20'10/4/2005 Isolated T-20 6,948'6,968'5,154'5,161'20'10/4/2005 Isolated T-30 7,158'7,198'5,369'5,409'40'10/4/2005 Isolated 7,162'7,182'5,373'5,393'20'3/15/2005 Isolated 7,198'7,251'5,409'5,461'53'10/3/2005 Isolated 7,438'7,458'5,648'5,668'20'3/15/2005 Isolated 7,570'7,588'5,780'5,798'18'10/3/2005 Isolated T-42 7,794'7,814'6,004'6,024'20'2/25/2005 Isolated T-50 8,188'8,208'6,397'6,417'20'10/3/2005 Isolated 8,188'8,266'6,397'6,475'78'5/6/2004 Isolated 8,234'8,254'6,443'6,463'20'4/30/2004 Isolated 8,402'8,437'6,611'6,646'35'5/7/2004 Isolated T-65 8,784'8,804'6,993'7,013'20'5/27/2004 Isolated T-83 8,916'8,936'7,125'7,199'20'5/28/2004 Isolated T-90 9,088'9,142'7,297'7,351'54'5/28/2004 Isolated 9,113'9,133'7,322'7,242'20'4/21/2004 Isolated 9 220'9 256'7 429'7 465'36'5/7/2004 IsolatedOPEN HOLE / CEMENT DETAIL'7 429'7 465'/ 9-5/8" 12-1/4" hole, Cmt w/ 515 sks (230 bbls) 12 ppg Type 1 cmt. 134 sks (60 bbls) to Surface 7"8-1/2" hole, Cmt w/ 180 sks (70 bbls) 12.5 ppg Lead & 110 sks (36 bbls) 13.5 ppg Tail Cmt bumped plug. 4-1/2"7" hole w/ 690sks (219 bbls) of 12.8 ppg class G cmt. Fracked Tyonek Perfs 8,188'-8,266' MD on 2/10/2005 48,553 lbs of 20/40 Ottawa including 12.5% 12/20 Flex Sand Lightning 1800 6% KCL based fluid ramped 1-8 ppg Frac Grad=0.75 psi/ft Max Surf Pressure=3,700 psig G-Function 2-4 FISH: Expro 30.9' OVL: 1-7/16" rope socket w/1" fishing neck (1.0'), 1-3/4" swivel (1.2'), 1-11/16" tungsten wt bar (21'), 3-1/8" CCL (2.5'), 3" junk basket (5.0'), and 3.78" gauge ring (.17') Capillary String 3/8” 2205 Stainless Steel (11,500’ spool) Top Bottom MD 0’ 5,100’ TVD 0’ 3,517’ 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. From:Jake Flora - (C) To:Loepp, Victoria T (CED) Subject:RE: [EXTERNAL] Paxton 1(PTD 204-010, Sundry 320-442) Perforate Date:Wednesday, October 21, 2020 12:00:04 PM I apologize, I intermixed the terminology. It will be a Lubricator and NOT a BOP. Thanks, Jake From: Loepp, Victoria T (CED) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, October 21, 2020 11:40 AM To: Jake Flora - (C) <Jake.Flora@hilcorp.com> Subject: [EXTERNAL] Paxton 1(PTD 204-010, Sundry 320-442) Perforate Jake, Are you planning to use a BOP or a lubricator? See Step 4. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JUL 16 2919 1. Operations Abandon LJ Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Li Performed: Suspend ❑ Re -Perforate ] Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ �rforale New Pool Repair Well ❑ Re-enter Susp Well ❑ Other: Install Cap String❑✓ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development ❑✓ Slratigraphic❑ Exploratory ❑ Service ❑ 204-010 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-20535-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0384372 / Fee Private Ninilchik Unit Paxton 1 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Ninilchik Field / Beluga-Tyonek Gas Pool 11. Present Well Condition Summary: Total Depth measured 10,115 feel Plugs measured 5,913 feet true vertical 8,320 feet Junk measured 5,683 (fill) feet Effective Depth measured 5,913 feet Packer measured 4,703 feet true vertical 4,193 feet true vertical 3,266 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 100' 20" 100' 100' 3,060psi 1,500psi Surface 1,895' 9-5/8" 1,895' 1,682' 6,870psi 4,760psi Intermediate 4,950' 7" 4,950' 3,418' 8,160psi 7,020psi Production Liner 5,368' 4-1/2" 10,071' 8,276' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# / L-80 4,703' (MD) 3,266' (TVD) 4,703' (MD) Packers and SSSV (type, measured and true vertical depth) ZXP Liner Packer N/A 3,266' (TVD) N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure I Tubing Pressure Prior to well operation:1 0 0 0 310 1 86 Subsequent to operation: 0 896 3 310 1 187 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations FA Exploratory Development ❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil LJ Gas ✓ WDSPL LJ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-276 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: lkramer@—K'1com.com L Authorized Signature: Date: 24 ) 9 Contact Phone: 777-8420 fi Form 10-404 Revised 412017 "I L'ts d RBDMSJ&JUt. 18 2019 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Paxton 1 ICapStringl 50-133-20535-00 204-010 6/21/19 6/21/19 Daily Operations: 06/21/2019 - Friday Pax -1: 3/8" cap string set at 5,100'MD. Foot valve opening pressure is 3,800psi. Hanging weight of string was 750 Ibs, pick up weight was 1,100 Ibs. RKft M9-= W 11TAGL SCHEMATIC CASING DETAIL Ninilchik Field Well: Paxton 01 Last Completed: 5/29/2004 Size Type Wt/Grade/Conn ID Top stm 20" Conductor 133 / K-55 / PE 18.73 Surf 100' 9-5/8" Surface 47 / L-80 / Mod -Butt 8.681 Surf 1,895' 7" Intermediate 29 / L-80 / BTC 6.184 Surf 4,950' 4-1/2" Liner 12.6 / L-80 / Hydril 521 3.958 4,703' 10,071' JL utt 1 3.958 1 Surf 1 4,703' Item ical Injection Nipple cker w/ 15' Tieback Extension er Hanger cement/TOC @ 5,913' 10/05/16 at TAIL .(TVD) FT Date Status 167' 28' 5/17/2014 Open 177' 20' 11/22/2016 Open 306' 10' 9/22/2005 Isolated 354' 20' 9/22/2005 Isolated 398' 18' 10/6/2005 Isolated 445' 34' 9/22/2005 Isolated 568' 20' 5/31/2008 Isolated 606' 6' 10/6/2005 1 Isolated 924' 20' 10/6/2005 Isolated 976' 20' 10/4/2005 Isolated 161' 20' 10/4/2005 Isolated 409' 40' 10/4/2005 Isolated 393' 20' 3/15/2005 Isolated 461' 53' 10/3/2005 Isolated 668' 20' 3/15/2005 Isolated 798' 18' 10/3/2005 Isolated D24' 20' 2/25/2005 Isolated 417' 20' 10/3/2005 Isolated 475' 78' 5/6/2004 Isolated 463' 20' 4/30/2004 Isolated 546' 35' 5/7/2004 Isolated 713' 20' 5/27/2004 Isolated 199' 20' 5/28/2004 Isolated 351' 54' 5/28/2004 Isolated 242' 20' 4/21/2004 Isolated 465' 36' 5/7/2004 Isolated 766' 16' 4/20/2004 Isolated IT DETAIL 1 cmt. 134 sks Capillary String 3/8" 2205 Stainless Steel(11,SDD'spOol) Top Bottom MD 0' SAW TVD 0' 3,517' 1U=10,113 MU!A} 1W PSTD= 5,917 M1)14,193'TVD FISH: Expro 30.9' OVL: 1-7/16" rope socket w/1" fishing neck (1.0'), 1-3/4" swivel (1.2'), 1-11/16" tungsten wt bar (21'), 3-1/8" CCL (2.5'), 3" junk basket (5.0'), and 3.78" gauge ring (.17') Updated by DMA 07-05-19 THE STATE OfALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga-Tyonek Gas Pool, Paxton 1 Permit to Drill Number: 204-010 Sundry Number: 319-276 fry- .'S'i�i�•6Tr!� Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a og c c.a las ka. gov Enclosed is the approved application for the 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, J ssie�elowski Commissioner DATED this I?, day of June, 2019. RBDMS 110 -"'JUN 13 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED MAY 31 2019 QTc 19 1. Type of Request: Abandon [:]Plug Perforations ❑ Fracture Stimulate 1-1RepairWell ElOperations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Pertorate New Pool ❑ Re-enter Soap Well ❑ Alter Casing ❑ Other:lnstall Cap String ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑' ' Stratigraphic ❑ Service ❑ 204-010 ' 3. Address: 3800 Centerpoint Dr, Suite 1400 P 6. API Number: Anchorage Alaska 99503 50-133-20535-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 701C Will planned perforations require a spacing exception? Yes ❑ No ❑� Ninilchik Unit Paxton 1 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0384372 / FEE -PRIVATE Ninilchik Field / Beluga-Tyonek Gas Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (it): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,115' 8,320' 5,913' 4,193'-2,800psi 5,913' 5,683' (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 100' 20" 100' 100' 3,060psi 1,500psi Surface 1,895' 9-5/8" 1,895' 1,682' 6,870psi 4,760psi Intermediate 4,950' 7" 14,950' 3,418 8,160psi 7,020psi Production Liner 5,368' 4-1/2" 10,071' 8,276' 8,430psi 7,500psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6# / L-80 4,703 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): ZXP Liner Packer/ N/A 4,703(MD) & 3,266(TVD) / N/A 12. Attachments: Proposal Summary �j Wellbore schematic 14 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: June 15, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Man Contact Email: 1kramer2hi1c0m.c0m Contact Phone: 777-8420 4 Authorized Signature: Date: COMMISSION OSE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ^ 2-7 f Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: IMS JUN 1 3 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ u Spacing Exception Required? Yes ❑ No Subsequent Form Required: �'— 1 O I APPROVED BY COMMISSIONER THE COMMISSION Date: ' Approved by:t/af Form10UO3 Revised 4/2017 f Aropper! application i0i 1p71Golrt utlda[e of approval. Submit Form and J �Iechments in upli6 3 /� U Hilwm Alaska. M Well Prognosis Well: PAX -1 Date:05/30/2019 Well Name: Paxton 1 API Number: 50-133-20535-00 Current Status: Gas Producer Leg: N/A Estimated Start Date: 06-15-19 Rig: N/A Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 204-010 First Call Engineer: Ted Kramer (907) 777-8420 (0) (987) 867-0665 (M) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 227-5293 (M) AFE Number: Current Surface Pressure: — 545 psi (From 10/2018 SI) Maximum Expected BHP: —1,458 psi @ 4,177' ND (Calc'd Assuming Half column water) Max. Allowable Surface Pressure: —2,137 psi (Based on 0.0526 psi/ft gas gradient) Brief Well Summary This well was drilled and completed as a gas well in 2004. Subsequent perforations were added in 2005, followed by performing a coil tubing cleanout to 9,850', and running a velocity string in 2007. The velocity string was pulled in December 2011, where the velocity string was found flow -cut. A coil tubing cleanout was competed in October 2018 with the T-6 being re -perforated at that time. The well has a water loading problem which is being handled by injecting soap down the chemical injection line to 2517' and dropping soap sticks. The purpose of this work is to install a CAP string to continuously inject soap deeper in the well. Summary Procedure 756 1. MIRU Cap String Truck, PT lubricator to 3,000 psi Hi 250 Low. 2. Install new wellhead packoff. 3. PU 3/8" capillary string. RIH and set at +/- 5395'. 4. Set spool of remaining line near well. 5. Rig down Cap String Truck. 6. Turn well over to production. Attachments: 1. As -built Well Schematic 2. Proposed Well Schematic K flil.rp Alaaka. LLC fe®: MSL =163'/1T ACL TD --10,115' PBTD=9,998' SCHEMATIC CASING DETAIL Ninilchik Field Well: Paxton 01 Last Completed: 5/29/2004 Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 133 / K-55 / PE 18.73 Surf 100' 9-5/8" Surface 47/L-80/Mod-Butt 8.681 Surf 1,895' 7" Intermediate 29/L-80/BTC 6.184 Surf 4,950' 4-1/2" Liner 32.6/L-BO/Hydr11521 3.958 4,703' 10,071' TUBING DETAIL 4-1/2" Tubing 12.6#/L-80/Mod-Butt 1 3.958 Surf 4,703' JEWELRY DETAIL No Depth ID OD Item 1 2,517' 3.858 5.93 Baker Chemical Injection Nipple 2 4,703' ZXP Liner Packer w/ 15' Tieback Extension 3 4,727' Flex Lock Liner Hanger 4 5,913' 3.958 CIBP w/ 10' cement 5 9,946' Landing Collar 6 10,028' Float Collar 7 10,071' Float Shoe PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (ND) Btm (TVD) FT Date Status 5,856' 5,884' 4,149' 4,167' 28' 5/17/2014 Open 76 5,875' 5,895' 4,158' 4,177' 20' 11/22/2016 Open 6,026' 6,036' 4,297' 4,306' 10' 9/22/2005 Isolated 6,068' 6,088' 4,335' 4,354' 20' 9/22/2005 Isolated 6,118' 6,136' 4,382' 4,398' 18' 10/6/2005 Isolated T-8 6,152' 6,186' 4,413' 4,445' 34' 9/22/2005 Isolated 6,299' 6,319' 4,549' 4,568' 20' 5/31/2008 Isolated 6,354' 6,360' 4,600' 4,606' 6' 10/6/2005 Isolated 6,682' 6,702' 4,904' 4,924' 20' 10/6/2005 Isolated T-12 6,738' 6,758' 4,958' 4,976' 20' 10/4/2005 Isolated T-20 6,948' 6,968' S,154' 5,161' 20' 30/4/2005 Isolated 7,158' 7,198' 5,369' 5,409' 40' 10/4/2005 Isolated 7,162' 7,182' 5,373' 5,393' 20' 3/15/2005 Isolated T-30 7,198' 7,251' 5,409' 5,461' 53' 10/3/2005 Isolated 7,438' 7,458' 5,648' 5,668' 20' 3/15/2005 Isolated 7,570' 7,588' 5,780' 5,798' 1 18' 10/3/2005 Isolated T-42 7,794' 7,814' 6,004' 6,024' 20' 2/25/2005 Isolated 8,188' 8,208' 6,397' 6,417' 20' 10/3/2005 Isolated 8,188' 8,266' 6,397' 6,475' 78' 5/6/2004 Isolated T-50 8,234' 8,254' 6,443' 6,463' 20' 4/30/2004 Isolated 8,402' 8,437' 6,611' 6,646' 35' 5/7/2004 Isolated T-65 8,784' 8,804' 6,993' 7,013' 20' 5/27/2004 Isolated T-83 8,916' 8,936' 7,125' 7,199' 20' 5/28/2004 Isolated 9,088' 9,142' 7,297' 7,351' 54' 5/28/2004 Isolated 7-90 9,113' 9,133' 7,322' 7,242' 20' 4/21/2004 Isolated 9,220' 9,256' 7,429' 7,465' 36' 5/7/2004 Isolated T-130 9,542' 9,558' 7,750' 7,766' 16' 4/20/2004 Isolated u� OPEN HOLE / CEMENT DETAIL 12.8 Fracked Tvonek Perfs 8,188'-8,266' MD on 2/10/2005 48,55316s of 20/40 Ottawa Including 12.5% 12/20 Flex Sand Lightning 1800 6% KCl based fluid ramped 1-8 ppg Frac Grad=0.75 psi/ft Max Surf Pressure=3,700 psig G -Function 2-4 FISH: Expro 30.9' OVL: 1-7/16" rope socket w/1" fishing neck (1.0'), 1-3/4" swivel (1.2'), 1.11/16" tungsten wt bar (21'), 3-1/8" CCL (2.5'), 3" junk basket (5.0'), and 3.78" gauge ring (.17') Updated by DMA 10-13-18 ela Field Well: PROPOSED SCHEMATIC eI: Paxton 01 Hilrorn Alaska. L1c Last Completed: 5/29/2004 CASING DETAIL wa3 KSI-=153'1 ITPGL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 133/K-55/PE 18.73 Surf 100' 9-5/8" Surface 47/L-80/Mod-Butt 8.681 Surf 1,895' 7" Intermediate 29/L-80/BTC 6.184 1 Surf 4,950' 4-1/2" Uner 12.6 / L-80 / Hydril521 3.958 4,703' 10,071' JL utt I 3.958 I Surf 4,703' Item ical Injection Nipple cker w/ 15' Tieback Extension er Hanger cement ar _TAIL (TVD) FT Date Status 167' 28' 5/17/2014 Oen 177' 20' 11/22/2016 Open 306' 10' 9/22/2005 Isolated 354' 20' 9/22/2005 isolated 398' 38' 10/6/2005 Isolated 445' 34' 9/22/2005 Isolated 568' 20' 5/31/2008 Isolated 606' 6' 10/6/2005 Isolated 924' 20' 10/6/2005 Isolated 976' 20' 10/4/2005 Isolated 161' 20' 10/4/2005 Isolated 409' 40' 10/4/2005 Isolated 393' 20' 3/15/2005 Isolated 461' 53' 10/3/2005 Isolated 668' 20' 3/15/2005 Isolated 798' 18' 10/3/2005 Isolated 024' 20' 2/25/2005 Isolated 417' 20' 10/3/2005 isolated 475' 78' 5/6/2004 Isolated 463' 20' 4/30/2004 Isolated 646' 35' 5/7/2004 Isolated D23' 20' 5/27/2004 Isolated 199' 20' 5/28/2004 1 Isolated 351' 54' 5/28/2004 Isolated 242' 20' 4/2104 Isolated 465' 36' 5/7/20/2004 Isolated 766' 16' 4/20/2004 1 Isolated IT DETAIL 110 sks (36 bbis)13.5 Capillary String - Proposed to Install 3/B" 2205 Stainless Steel(11,500'spool) Top Bottom MD 0' 25,395' TVD 0' 23,737' IU --1D,776' FUIU=91946' FISH: Expro 30.9' OVL: 1-7/16" rope socket w/1" fishing neck (1.0'), 1-3/4" swivel (1.2'), 1-11/16" tungsten wt bar (21'), 3-1/8" CCL (2.5'), 3" junk basket (5.0'), and 3.78" gauge ring (.17') Updated by DMA 05-31-19 STATE OF ALASKA AAA OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon H Plug Perforations U Fracture Stimulate U Pull Tubing H Operations shutdown LJ Performed: Suspend ❑ Perforate E Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ 8rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Reperforate ❑I 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 2Exploratory ❑ 204-010 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic Service ❑ 6.API Number: Anchorage,AK 99503 50-133-20535-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0384372/Fee Private Ninilchik Unit Paxton 1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Ninilchik Field/Beluga-Tyonek Gas Pool 11.Present Well Condition Summary: RECTIVED Total Depth measured 10,115 feet Plugs measured 5,913 feet true vertical 8,320 feet Junk measured 8,744(Fill) feet DEC 22 201b Effective Depth measured 5,913 feet Packer measured 4,703 feet ti true vertical 4,193 feet true vertical 3,266 feet ' "' Casing Length Size MD ND Burst Collapse Structural Conductor 100' 20" 100' 100' 3,060psi 1,500psi Surface 1,895' 9-5/8" 1,895' 1,682' 6,870psi 4,760psi Intermediate 4,950' 7" 4,950' 3,418' 8,160psi 7,020psi Production Liner 5,368' 4-1/2" 10,071' 8,276' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 4,703'(MD) 3,266'(ND) 4,703'(MD) Packers and SSSV(type,measured and true vertical depth) ZXP Liner Packer N/A 3,266'(ND) N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A �,p r -,.. Treatment descriptions including volumes used and final pressure: N/AA � � `' �` 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 2671 34 0 227 Subsequent to operation: 0 2060 24 0 ----- 210- 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas Q WDSPL ff Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 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: 316-485&316-558 Contact Taylor Nasse-777-8354 Email tnassec hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature Phone 907-777-8405 Date i 2l2z/r( Form 10-404 Revised 5/2015 1 "_ r Z Z�l !/' /_ 4 RBDMS L✓DeC 2j 2016 Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Paxton 1 E-Line 50-133-20535-00 204-010 10/6/16 11/22/16 Daily Operations: 10/06/2016-Thursday PTW and JSA. Spot equip and rig up lubricator. Pressure test lubricator to 250 psi low and 2,000 psi high. RIH with 3" magna range plug, tie into CBL log and tag at 5,923'. Call town and discuss setting plug there. Proposed plug depth was 6,010'. Run correlation log and send to town. Get ok to set plug at 5,923'. Spot plug and set at 5 923'. Lost 100 lbs line wt when plug set. Picked up 30' and went back down and tag plug. POOH. Everything shows good set. Had 1,000 psi on tubing when plug was set. RIH with 3.5"_x 20' dump bailer and tie into CBL log. Dump 10' (6.4 gals) of Neo cement. POOH. Good dump. Cement in place at 1720 hrs and est TOC at 5,913'. Gave cement sample to Dean. POOH. Good dump. Rig down lubricator and turn well back over to field. 11/22/2016-Tuesday MIRU E-line. PTW and JSA. RU lub and arm gun. PT to 250 psi low and 3,000 psi high. RIH w/2-7/8" x 20' Connex HC, 6 spf, 60 deg phase and tag at 5,896'. Run correlation log and send to town. Get ok to perf from 5,875'to 5,8951,`Spot and fired gun w/ 1,070 psi on tubing.Tubing gained 4 psi and that was all. POOH. All shots fired and gun was dry. Rig down lubricator and turn well over to field. • 1111 .11 SCHEMATIC Ninilchik Field Well: Paxton 01 ' Last Completed: 5/29/2004 Hilcorp Alaska,LLC p CASING DETAIL RK&MSL=153'/17'AGL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 133/K-55/PE 18.73 Surf 100' 9-5/8" Surface 47/ BSf , ' 7" Intermediate 29/-L-80L-80/Mod-/BTC 6.184 Suurrf 41,950895' 49--571//"28''' -1/2" Liner 12.6/L-80/Hydril utt 521 3.9588.681 4,703' 10,071' 20"ai . TUBING DETAIL 4-1/2" Tubing 12.6#/L-80/Mod-Butt 3.958 Surf 4,703' JEWELRY DETAIL No Depth ID OD Item 1 2,517' 3.858 5.93 Baker Chemical Injection Nipple 9-5/n1 lk 2 4,703' ZXP Liner Packer w/15'Tieback Extension 1 Ti 3 4,727' Flex Lock Liner Hanger 4 9,946' Landing Collar 5 10,028' Float Collar 6 10,071' Float Shoe _ 7 5,913' 3.958 CIBP w/10'cement PERFORATION DETAIL Zone lop(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 5,875' 5,895' 4,158' 4,177' 20' 11/22/2016 Open.\,' T-6 5,856' 5,884' 4,149' 4,167' 28' 5/17/2014 pen 6,026' 6,036' 4,297' 4,306' 10' 9/22/2005 Isolated 6,068' 6,088' 4,335' 4,354' 20' 9/22/2005 Isolated 6,118' 6,136' 4,382' 4,398' 18' 10/6/2005 Isolated $ T-8 6,152' 6,186' 4,413' 4,445' 34' 9/22/2005 Isolated 6,299' 6,319' 4,549' 4,568' 20' 5/31/2008 Isolated 2 6,354' 6,360' 4,600' 4,606' 6' 10/6/2005 Isolated T-12 6,682' 6,702' 4,904' 4,924' 20' 10/6/2005 Isolated 6,738' 6,758' 4,958' 4,976' 20' 10/4/2005 Isolated T-20 6,948' 6,968' 5,154' 5,161' 20' 10/4/2005 Isolated ! 3 7,158' 7,198' 5,369' 5,409' 40' 10/4/2005 Isolated 7,162' 7,182' 5,373' 5,393' 20' 3/15/2005 Isolated r T-30 7,198' 7,251' 5,409' 5,461' 53' 10/3/2005 Isolated K 7,438' 7,458' 5,648' 5,668' 20' 3/15/2005 Isolated 7,570' 7,588' 5,780' 5,798' 18' 10/3/2005 Isolated T-42 7,794' 7,814' 6,004' 6,024' 20' 2/25/2005 Isolated 8,188' 8,208' 6,397' 6,417' 20' 10/3/2005 Isolated 8,188' 8,266' 6,397' 6,475' 78' 5/6/2004 Isolated 7 L T-50 8,234' 8,254' 6,443' 6,463' 20' 4/30/2004 Isolated 8,402' 8,437' 6,611' 6,646' 35' 5/7/2004 Isolated T-65 8,784' 8,804' 6,993' 7,013' 20' 5/27/2004 Isolated T-83 8,916' 8,936' 7,125' 7,199' 20' 5/28/2004 Isolated - 9,088' 9,142' 7,297' 7,351' 54' 5/28/2004 Isolated 7I T-90 9,113' 9,133' 7,322' 7,242' 20' 4/21/2004 Isolated 9,220' 9,256' 7,429' 7,465' 36' 5/7/2004 Isolated TOF tagged @6,047 MD -= Seth Nolan Hilcorp Alaska, LCC 2_-1.-1loq GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 na „zi, i.t,t RECEIVED Fax: 907 777-8510 E-mail: snolan@hilcorp.com NOV DATA LOGG O 7' vn /3e/29-16. m BEtialA AOGCC DATE 11/18/2016 To: Alaska Oil & Gas Conservation Commission Makana Bender Petroleum Geology Assistant 333 W 7th Ave Ste 100 RECEIVED Anchorage, AK 99501 NOV 2 2 201b DATA TRANSMITTALitkr)GAyq Paxton 1 Prints: Plug Setting Record 5" CD: Final Well Data PAXTON_i_PLUG_060CT16.pdf 11/8/2016 1:23PM PDF Document 525 KB PAXTON_1_PLUG_060CT16_CORRELATION.... 11/8/2016 1:23 PM LAS File 130 KB PAXTON_1_PLUG_06OCT16_img.tif 11/8/2016 1:23 PM TIF File 1,658 KB A PAXTON_1_PLUG 060CT16_SETTING_PASS... 11/8/2016 1:23PM LAS File 37 KB 'v Thumbs.db 11/18/2016 2:28 PM Data Base File 12 KB SCANNED APR 2 2417, Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: � G , Date: ti OF T7� • . �yyy�8A THE STATE Alaska Oil and Gas ofLASI�:A Conservation Commission of tft 5 }ft 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 F ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager SCANNED APR , 1017 Hilcorp Alaska, LLC " 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga-Tyonek Gas Pool,NU Paxton 1 Permit to Drill Number: 204-010 Sundry Number: 316-558 Dear Mr. Helgeson: 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, r Daniel . Seamount, Jr. Commissioner 71- DATED this c day of November, 2016. RBDMS Lk/ NOV 1 0 2016 • STATE OF ALASKA Or: 2 8 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown El Suspend ❑ Perforate ❑, • Other Stimulate ❑ Pull Tubing El Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. Re-perforate •0 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development ❑✓ - 204-010 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic El Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20535-00-00 ' 7.If perforating: 7O1 f�, 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. > /G. I // Ninilchik Unit Paxton 1 , Will planned perforations require a spacing exception? Yes ❑ No Q 9.Property Designation(Lease Number): 77 /_ 10.Field/Pool(s): ADL0384372/ADl,D2`59242 / 4 r rr✓� � Ct.:z ( Ninilchik Field/Beluga-Tyonek Gas Pool 11. PRESENfWELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 10,115' 8,320' • 8,744' 6,953' 925 psi N/A 8,744'(fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 100' 20" 100' 100' 3,060psi 1,500psi Surface 1,895' 9-5/8" 1,895' 1,682' 6,870psi 4,760psi Intermediate 4,950' 7" 4,950' 3,418 8,160psi 7,020psi Production Liner 5,368' 4-1/2" 10,071' 8,276' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.61E/L-80 4,703 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): ZXP Liner Packer/N/A 4,703(MD)&3,266(ND)/N/A 12.Attachments: Proposal Summary Q 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: November 11,2016 OIL ❑ WINJ ❑ WDSPL ❑ Suspended CI 16.Verbal Approval: Date: GAS D• WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Taylor Nasse-777-8354 Email tnpse@hilcgrp.cc ! Printed Name Chad Helgeson Title Operations Manager SignatureG ` Phone 907-777-8405 Date (C/'F / COMMISSION USE ONLY 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 ❑ RBDMS V-- NOV 1 0 2016 Spacing Exception Required? Yes ❑ No Subsequent Form Required: `0 ii O 11 a / / APPROVED BY ,/` iek/ �� Approved by: • COMMISSIONER THE COMMISSION Date: Uh jrfG NSubmit Form ane Form 10-403 Revised 1/2015 0 I/a�j�g alid for 12 months from the date of approval. a Attachments' Duplicate • • • Well Prognosis Well: Paxton#1 Hilcorp Alaska,LL, Date:10/28/2016 Well Name: Paxton#1 API Number: 50-133-20535-00-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: 11/11/16 Rig: Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 204-010 First Call Engineer: Taylor Nasse (907)777-8354(0) (907)903-0341 (M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824(M) AFE Number: Current Surface Pressure: 227 psi Maximum Expected BHP: — 1,190 psi @ 4,167'ND (SIBHP survey on 8/15/16) Max. Potential Surface Pressure: —925 psi (SIBHP survey on 8/15/16) Brief Well Summary Paxton#1 was originally drilled and completed as a gas well in 2004.The well originally produced up until 2009 from a number of different perforated intervals in the Tyonek before loading up due to fill. The v-string was removed and a coiled tubing clean out was performed in 2011, but was unable to run in with a 3.80" mill past 6,080'so the decision was made to leave the v-string out of the well and, as a result,the well was unable to sustain flow. Hilcorp added perforations in the Tyonek T-6 interval in May 2014 and brought the well back online and recently plugged back the open intervals below the T-6 in September 2016. The purpose of this work/sundry is to reperforate the T-6 interval. E-Line Procedure: 1. MIRU E-line, PT lubricator to 2,000 psi Hi 250 Low. 2. Perforate the Tyonek sands with 2-7/8" 6 SPF 60 deg phased perf guns. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. Proposed Perforated Intervals Sands Top (MD) Btm (MD) FT Tyonek T6 ±5,859 ±5,906 ±47 3. POOH. 4. RD e-line. 5. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic • • Ninilchik Field SCHEMATIC Well: Paxton 01 Ililcorp Alaska,LLC Last Completed: 5/29/2004 CASING DETAIL RIRMSL=153'/1TAGL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 133/K-55/PE 18.73 Surf 100' 9-5/8" Surface 47/L-80/Mod-Butt 8.681 Surf 1,895' 7" Intermediate 29/L-80/BTC 6.184 Surf 4,950' 4-1/2" Liner 12.6/L-80/Hydril 521 3.958 4,703' 10,071' 20"agl . TUBING DETAIL 4-1/2" Tubing 12.6#/L-80/Mod-Butt 3.958 Surf 4,703' JEWELRY DETAIL No Depth ID OD Item �y °a 1 2,517' 3.858 5.93 Baker Chemical Injection Nipple 9-5/8"a b+ A 2 4,703' ZXP Liner Packer w/15'Tieback Extension ,, in 3 4,727' Flex Lock Liner Hanger I 4 9,946' Landing Collar z. 5 10,028' Float Collar 6 10,071' Float Shoe 7 5,913' 3.958 CIBP w/10'cement PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status l': T-6 5,856' 5,884' 4,149' 4,167' 28' 5/17/2014 Open 6,026' 6,036' 4,297' 4,306' 10' 9/22/2005 Isolated :M 6,068' 6,088' 4,335' 4,354' 20' 9/22/2005 Isolated 6,118' 6,136' 4,382' 4,398' 18' 10/6/2005 Isolated T-8 6,152' 6,186' 4,413' 4,445' 34' 9/22/2005 Isolated 6,299' 6,319' 4,549' 4,568' 20' 5/31/2008 Isolated s 6,354' 6,360' 4,600' 4,606' 6' 10/6/2005 Isolated 2 6,682' 6,702' 4,904' 4,924' 20' 10/6/2005 Isolated T-12 6,738' 6,758' 4,958' 4,976' 20' 10/4/2005 Isolated T-20 6,948' 6,968' 5,154' 5,161' 20' 10/4/2005 Isolated 1* c ' V7,158' 7,198' 5,369' 5,409' 40' 10/4/2005 Isolated *' �) s 7,162' 7,182' 5,373' 5,393' 20' 3/15/2005 Isolated T-30 7,198' 7,251' 5,409' 5,461' 53' 10/3/2005 Isolated .. et ■• 7,438' 7,458' 5,648' 5,668' 20' 3/15/2005 Isolated ' i ) II 7,570' 7,588' 5,780' 5,798' 18' 10/3/2005 Isolated r` T-42 7,794' 7,814' 6,004' 6,024' 20' 2/25/2005 Isolated ., 8,188' 8,208' 6,397' 6,417' 20' 10/3/2005 Isolated 8,188' 8,266' 6,397' 6,475' 78' 5/6/2004 Isolated i,4 • T-50 8,234' 8,254' 6,443' 6,463' 20' 4/30/2004 Isolated to y' k 8,402' 8,437' 6,611' 6,646' 35' 5/7/2004 Isolated T-65 8,784' 8,804' 6,993' 7,013' 20' 5/27/2004 Isolated , T-83 8,916' 8,936' 7,125' 7,199' 20' 5/28/2004 Isolated ' 9,088' 9,142' 7,297' 7,351' 54' 5/28/2004 Isolated T-90 9,113' 9,133' 7,322' 7,242' 20' 4/21/2004 Isolated _ 7 9,220' 9,256' 7,429' 7,465' 36' 5/7/2004 Isolated � � T-130 9,542' 9,558' 7,750' 7,766' 16' 4/20/2004 Isolated TOE tagged @ 6,047'MD on 8/15/2016 OPEN HOLE/CEMENT DETAIL .4. 9-5/8" 12-1/4" hole, Cmt w/515 sks(230 bbls)12 ppg Type 1 cmt.134 sks(60 bbls)to Surface _ 7" 8-1/2" hole, Cmt w/180 sks(70 bbls)12.5 ppg Lead&110 sks(36 bbls)13.5 ppg Tail Cmt bumped plug. 4-1/2" 7"hole w/690sks(219 bbls)of 12.8 ppg class G cmt. Fracked Tyonek Perfs 8,188'-8,266' MD on 2/10/2005 48,553 lbs of 20/40 Ottawa including 12.5%12/20 Flex Sand j ' Lightning 1800 6%KCL based fluid ramped 1-8 ppg e 4 Frac Grad=0.75 psi/ft Max Surf Pressure=3,700 psig a uz" 5 G-Function 2-4 6 TD=10,115' PBTD=9,946' FISH: Expro 30.9'OVL:1-7/16"rope socket w/1"fishing neck(1.0'), 1-3/4"swivel(1.2'),1-11/16"tungsten wt bar(21'),3-1/8"CCL(2.5'),3"junk basket(5.0'),and 3.78"gauge ring(.17') Updated by DMA 10-10-16 • PROPOSED • Ninilchik Field SCHEMATIC Well: Paxton 01 HiacorpAlaska,1.1k Last Completed: 5/29/2004 CASING DETAIL RKY MSL=153'/17'PGL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 133/K-55/PE 18.73 Surf 100' iii. 9-5/8" Surface 47/L-80/Mod-Butt 8.681 Surf 1,895' 7" Intermediate 29/L-80/BTC 6.184 Surf 4,950' 4 1/2" Liner 12.6/L-80/Hydril 521 3.958 4,703' 10,071' 27' TUBING DETAIL 4-1/2" Tubing 12.6#/L-80/Mod-Butt 3.958 Surf 4,703' JEWELRY DETAIL No Depth ID OD Item 1 2,517' _ 3.858 5.93 Baker Chemical Injection Nipple 9-5/8 4 6 2 4,703' ZXP Liner Packer w/15'Tieback Extension 3 4,727' Flex Lock Liner Hanger 4 9,946' Landing Collar z 5 10,028' Float Collar 6 10,071' Float Shoe k` 7 5,913' 3.958 CIBP w/10'cement *,, . PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status q. 5,859' 5,906' 4,144' 4,187' Proposed T-6 5,856' 5,884' 4,149' 4,167' 28' _ 5/17/2014 Open , 6,026' 6,036' 4,297' 4,306' 10' 9/22/2005 Isolated 6,068' 6,088' 4,335' 4,354' 20' 9/22/2005 Isolated 6,118' 6,136' 4,382' 4,398' 18' 10/6/2005 Isolated T-8 6,152' 6,186' 4,413' 4,445' 34' 9/22/2005 Isolated „„ 6,299' 6,319' 4,549' 4,568' 20' 5/31/2008 Isolated } 2 6,354' 6,360' 4,600' 4,606' 6' 10/6/2005 Isolated 6,682' 6,702' 4,904' 4,924' 20' 10/6/2005 Isolated �' T-12 6,738' 6,758' 4,958' 4,976' 20' 10/4/2005 Isolated ' _ T-20 6,948' 6,968' 5,154' 5,161' 20' 10/4/2005 Isolated 3 7,158' 7,198' 5,369' 5,409' 40' 10/4/2005 Isolated - 7,162' 7,182' 5,373' 5,393' 20' 3/15/2005 Isolated t Pi ,{ {T -30 7,198' 7,251' 5,409' 5,461' 53' 10/3/2005 Isolated it 11 7,438' 7,458' 5,648' 5,668' 20' 3/15/2005 Isolated 7,570' 7,588' 5,780' 5,798' 18' 10/3/2005 Isolated T-42 7,794' 7,814' 6,004' 6,024' 20' 2/25/2005 Isolated 8,188' 8,208' 6,397' 6,417' 20' 10/3/2005 Isolated 8,188' 8,266' 6,397' 6,475' 78' 5/6/2004 Isolated Y T-50 8,234' _ 8,254' 6,443' 6,463' 20' 4/30/2004 Isolated 8,402' 8,437' 6,611' 6,646' 35' 5/7/2004 Isolated T-65 8,784' 8,804' 6,993' 7,013' 20' 5/27/2004 Isolated ' T-83 8,916' 8,936' 7,125' 7,199' 20' 5/28/2004 Isolated 9,088' 9,142' 7,297' 7,351' 54' 5/28/2004 Isolated 7 T-90 9,113' 9,133' 7,322' 7,242' 20' , 4/21/2004 Isolated 9,220' 9,256' 7,429' 7,465' 36' 5/7/2004 Isolated TOF tamed @6,047 MD T-130 9,542' 9,558' 7,750' 7,766' 16' 1 4/20/2004 Isolated on 8/15/2016 OPEN HOLE/CEMENT DETAIL 9-5/8" 12-1/4" hole, Cmt w/515 sks(230 bbls)12 ppg Type 1 cmt.134 sks(60 bbls)to Surface 7" 8-1/2" hole, Cmt w/180 sks(70 bbls)12.5 ppg Lead&110 sks(36 bbls)13.5 ppg Tail Cmt bumped plug. A, r1,* 4-1/2" 7"hole w/690sks(219 bbls)of 12.8 ppg class G cmt. Fracked Tyonek Perfs 8,188'-8,266' MD on 2/10/2005 ',' - 48,553 lbs of 20/40 Ottawa including 12.5%12/20 Flex Sand 4 Lightning 1800 6%KCL based fluid ramped:L-8 ppg 4-a12 i',,,"''i: 5 Frac Grad=0.75 psi/ft Max Surf Pressure=3,700 psig 6 G-Function 2-4 TD=10,115' PBTD=9,946' FISH: Expro 30.9'OVL:1-7/16"rope socket w/1"fishing neck(1.0'), 1-3/4"swivel(1.2'),1-11/16"tungsten wt bar(21'),3-1/8"CCL(2.5'),3"junk basket(5.0'),and 3.78"gauge ring(.17') Updated by DMA 10-10-16 • S tiOF 714, THE STATE Alaska Oil and Gas ;,; ft f cKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 of 1�e` Main: Fax: 907.276.7542 ALAg www.aogcc.alaska.gov Chad Helgeson Operations Manager ' . Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga- Tyonek Gas Pool, Paxton 1 Permit to Drill Number: 204-010 Sundry Number: 316-485 Dear Mr. Helgeson: 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 Foerster Chair DATED this 20 day of September, 2016. RBDMS w SEP 2 6 2016 S RECEIVED • STATE OF ALASKA SEP 21 201b ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A ' 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations [ • Fracture Stimulate 0 Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate El Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: El 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development Q . 204-010 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number Anchorage,Alaska 99503 50-133-20535-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.592 Ninilchik Unit Paxton 1 • Will planned perforations require a spacing exception? Yes ❑ No ❑., 9.Property Designation(Lease Number): 10.Field/Pool(s): / �. //�J, ADL0384372/ADL0359242 Ninilchik Field/ Gas Pool "r f�— lt '7"`. 11. PRESENT WELL CONDITION SUMMARY �J /t f°2/./4, Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 10,115' . 8,320' • 8,744' ' 6,953' 925 psi N/A 8,744'(fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 100' 20" 100' 100' 3,060psi 1,500psi Surface 1,895' 9-5/8" 1,895' 1,682' 6,870psi 4,760psi Intermediate 4,950' 7" 4,950' 3,418 8,160psi 7,020psi Production Liner 5,368' 4-1/2" 10,071' 8,276' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6#/L-80 4,703 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): ZXP Liner Packer/N/A 4,703(MD)&3,266(TVD)/N/A 12.Attachments: Proposal Summary Q 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: October 5,2016 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS Q WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Taylor Nasse-777-8354 Email tnassg@hilcorp.cpm Printed Name Chad Helgeson Title Operations Manager Signature �� Phone 907-777-8405 Date J/Z 1/1 (a COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test El Location Clearance ❑ Other: 44SF c11-2...-L.. ‘L, Post Initial Injection MIT Req'd? Yes ❑ No ❑ nL� Spacing Exception Required? Yes ❑ No f Subsequent Form Required: /0 _ LI RBDMS uV SEP Z 6 2016 APPROVED BY Approved by:al61.7 / COMMISSIONER THE COMMISSION Date: '—23-I 6 G A � ei"Z L-/� Submit Form and I0Form 10-403 Revised 11/2015 4-33.1 +NriiA lid for 12 m the from the date of approval. yachmentDuplicateu r 4, • • Well Prognosis Well: Paxton#1 Ilacorp Alaska,Lb Date:09/19/2016 Well Name: Paxton#1 API Number: 50-133-20535-00-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: 10/05/16 Rig: Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 204-010 First Call Engineer: Taylor Nasse (907) 777-8354(0) (907) 903-0341 (M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824 (M) AFE Number: Current Surface Pressure: 227 psi Maximum Expected BHP: — 1,190 psi @ 4,167' TVD (SIBHP survey on 8/15/16) Max. Potential Surface Pressure: —925 psi (SIBHP survey on 8/15/16) Brief Well Summary Paxton#1 was originally drilled and completed as a gas well in 2004.The well originally produced up until 2009 from a number of different perforated intervals in the Tyonek before loading up due to fill. The v-string was removed and a coiled tubing clean out was performed in 2011, but was unable to run in with a 3.80" mill past 6,080' so the decision was made to leave the v-string out of the well and, as a result, the well was unable to . sustain flow. Hilcorp added perforations in the Tyonek T-6 interval in May 2014 and brought the well back online. The purpose of this work/sundry is to set a plug below the T-6 interval in order to isolate water and sand coming from the lower open intervals. Notes Regarding Wellbore Condition • Indication of a restriction at 6,080'. • Fluid level at 1,740' MD with 245 psig surface pressure on 8/15/16. E-Line Procedure: 1. MIRU E-line, PT lubricator to 2,000 psi Hi 250 Low. 2. MU 4-1/2" CIBP and setting tool. 3. RIH and set CIBP at+/-6,010'. POOH w/setting tool. 4. MU dump bailer and fill w/cement. 5. RIH and dump cement on top of CIBP (10' =6 gallons). POOH w/dump bailer. 6. RD e-line. 7. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic • ll 410 • Ninilchik Field • SCHEMATIC Well: Paxton 01 Hilcorp Alaska,LLC Last Completed: 5/29/2004 CASING DETAIL RKEt MSL=153'/17 AGL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 133/K-55/PE 18.73 Surf100' 9-5/8" Surface 47/L-80/Mod-Butt 8.681 Surf1,895' 7" Intermediate 29/L 80/BTC 6.184 Surf 4,950' 4-1/2" Liner 12.6/L-80/Hydril 521 3.958 4,703' 10,071' 20" . TUBING DETAIL 4-1/2" Tubing 12.6#/L-80/Mod-Butt 3.958 Surf 4,703' JEWELRY DETAIL "I 5,4 No Depth ID OD Item 1 2,517' 3.858 5.93 Baker Chemical Injection Nipple 9-5/8`4 qA .,s,,, 1 2 4,703' ZXP Liner Packer w/15'Tieback Extension .3 `: 3 4,727' Flex Lock Liner Hanger 4 9,946' Landing Collar 5 10,028' Float Collar 6 10,071' Float Shoe a 1, PERFORATION DETAIL "a Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status T-6 5,856' 5,884' 4,149' 4,167' 28' 5/17/14 Open 6,026' 6,036' 4,297' 4,306' 10' 9/22/2005 Open 6,068' 6,088' 4,335' 4,354' 20' 9/22/2005 Open 6,118' 6,136' 4,382' 4,398' 18' 10/6/2005 Open T-8 6,152' 6,186' 4,413' 4,445' 34' 9/22/2005 Open ,. 6,299' 6,319' 4,549' 4,568' 20' 5/31/2008 Open 6,354' 6,360' 4,600' 4,606' 6' 10/6/2005 Open '" 6,682' 6,702' 4,904' 4,924' 20' 10/6/2005 Open • ' gmj`. . 2 T-12 6,738' 6,758' 4,958' 4,976' 20' 10/4/2005 Open _ ,_f'' T-20 6,948' 6,968' 5,154' 5,161' 20' 10/4/2005 Open ' • 7,158' 7,198' 5,369' 5,409' 40' 10/4/2005 Open l.; :' 3 7,162' 7,182' 5,373' 5,393' 20' 3/15/2005 Open J T-30 7,198' 7,251' 5,409' 5,461' 53' 10/3/2005 Open '' 7,438' 7,458' 5,648' 5,668' 20' 3/15/2005 Open 1,.r ''„t 7,570' 7,588' 5,780' 5,798' 18' 10/3/2005 Open T-42 7,794' 7,814' 6,004' 6,024' 20' 2/25/2005 Open 8,188' 8,208' 6,397' 6,417' 20' 10/3/2005 Open 8,188' 8,266' 6,397' 6,475' 78' 5/6/2004 Open ;, t. T-50 8,234' 8,254' 6,443' 6,463' 20' 4/30/2004 Open �/ 8,402' 8,437' 6,611' 6,646' 35' 5/7/2004 Open r' L i. T-65 8,784' 8,804' 6,993' 7,013' 20' 5/27/2004 Covered r 1-83 8,916' 8,936' 7,125' 7,199' 20' 5/28/2004 Covered ` r` 9,088' 9,142' 7,297' 7,351' 54' 5/28/2004 Covered TOF tagged @ 6,041 NA +'1<-' • o a s/2oi6 54 T-90 9,113' 9,133' 7,322' 7,242' 20' 4/21/2004 Covered 5 9,220' 9,256' 7,429' 7,465' 36' 5/7/2004 Covered T-130 9,542' 9,558' 7,750' 7,766' 16' 4/20/2004 Covered OPEN HOLE/CEMENT DETAIL 9-5/8" 12-1/4" hole, Cmt w/515 sks(230 bbls)12 ppg Type 1 cmt.134 sks(60 bbls)to Surface 7" 8-1/2" hole, Cmt w/180 sks(70 bbls)12.5 ppg Lead&110 sks(36 bbls)13.5 ppg Tail Cmt bumped plug. 4-1/2" 7"hole w/690sks(219 bbls)of 12.8 ppg class G cmt. Fracked Tyonek Perfs 8,188'-8,266' MD on 2/10/2005 48,553 lbs of 20/40 Ottawa including 12.5%12/20 Flex Sand Lightning 1800 6%KCL based fluid ramped 1-8 ppg 4 Frac Grad=0.75 psi/ft Max Surf Pressure=3,700 psig 4-1/2" t , " ' 5 6-Function 2-4 6 TD=10,115' PBTD=9,946' FISH: Expro 30.9'OVL:1-7/16"rope socket w/1"fishing neck(1.0'), 1-3/4"swivel(1.2'),1-11/16"tungsten wt bar(21'),3-1/8"CCL(2.5'),3"junk basket(5.0'),and 3.78"gauge ring(.17') Revised By:TDF 6-13-2014 . H 0 PROPOSED . • Ninilchik Field SCHEMATIC Well: Paxton 01 Hilcurp Alaska,LLC Last Completed: 5/29/2004 CASING DETAIL RKB:MSL=153'/1T/SGL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 133/K-55/PE 18.73 Surf 100' 9-5/8" Surface 47/L-80/Mod-Butt 8.681 Surf 1,895' 7" Intermediate 29/L-80/BTC 6.184 Surf 4, ' 4-1/2" Liner 12.6/L-80/Hydril 521 3.958 4,703' 10,950071' 2a• TUBING DETAIL 4-1/2" Tubing 12.6#/L-80/Mod-Butt 3.958 Surf 4,703' JEWELRY DETAIL No Depth ID OD Item 1 2,517' 3.858 5.93 Baker Chemical Injection Nipple 9-5/8 4 6 2 4,703' ZXP Liner Packer w/15'Tieback Extension 3 4,727' Flex Lock Liner Hanger 4 9,946' Landing Collar 5 10,028' Float Collar 6 10,071' Float Shoe 7 6,010' 3.958 CIBP w/10'cement PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status yt. T-6 5,856' 5,884' 4,149' 4,167' 28' 5/17/14 Open 6,026' 6,036' 4,297' 4,306' 10' 9/22/2005 Isolated 6,068' 6,088' 4,335' 4,354' 20' 9/22/2005 Isolated 6,118' 6,136' 4,382' 4,398' 18' 10/6/2005 Isolated ie T 8 6,152' 6,186' 4,413' 4,445' 34' 9/22/2005 Isolated Y , 6,299' 6,319' 4,549' 4,568' 20' 5/31/2008 Isolated 6,354' 6,360' 4,600' 4,606' 6' 10/6/2005 Isolated 6,682' 6,702' 4,904' 4,924' 20' 10/6/2005 Isolated T-12 6,738' 6,758' 4,958' 4,976' 20' 10/4/2005 Isolated M T-20 6,948' 6,968' 5,154' 5,161' 20' 10/4/2005 Isolated r= jC 7,158' 7,198' 5,369' 5,409' 40' 10/4/2005 Isolated 3 7,162' 7,182' 5,373' 5,393' 20' 3/15/2005 Isolated l 5J T-30 7,198' 7,251' 5,409' 5,461' 53' 10/3/2005 Isolated 11-E 1 7,438' 7,458' 5,648' 5,668' 20' 3/15/2005 Isolated r II I 7,570' 7,588' 5,780' 5,798' 18' 10/3/2005 Isolated - T-42 7,794' 7,814' 6,004' 6,024' 20' 2/25/2005 Isolated 8,188' 8,208' 6,397' 6,417' 20' 10/3/2005 Isolated 8,188' 8,266' 6,397' 6,475' 78' 5/6/2004 Isolated T-50 8,234' 8,254' 6,443' 6,463' 20' 4/30/2004 Isolated y' L [, 8,402' 8,437' 6,611' 6,646' 35' 5/7/2004 Isolated T-65 8,784' 8,804' 6,993' 7,013' 20' 5/27/2004 Isolated T-83 8,916' 8,936' 7,125' 7,199' 20' 5/28/2004 Isolated 9,088' 9,142' 7,297' 7,351' 54' 5/28/2004 Isolated --- T-90 9,113' 9,133' 7,322' 7,242' 20' 4/21/2004 Isolated 9,220' 9,256' 7,429' 7,465' 36' 5/7/2004 Isolated T-130 9,542' 9,558' 7,750' 7,766' 16' 4/20/2004 Isolated TOF tagged @6,047 MD -"--.-- on 8/15/2016 "- °n8/]Sn016 OPEN HOLE/CEMENT DETAIL 9-5/8" 12-1/4" hole, Cmt w/515 sks(230 bbls)12 ppg Type 1 cmt.134 sks(60 bbls)to Surface 7" 8-1/2" hole, Cmt w/180 sks(70 bbls)12.5 ppg Lead&110 sks(36 bbls)13.5 ppg Tail Cmt bumped plug. 4-1/2" 7"hole w/690sks(219 bbls)of 12.8 ppg class G cmt. Fracked Tyonek Perfs 8,188'-8,266' MD on 2/10/2005 48,553 lbs of 20/40 Ottawa including 12.5%12/20 Flex Sand Lightning 1800 6%KCL based fluid ramped 1-8 ppg 4 Frac Grad=0.75 psi/ft Max Surf Pressure=3,700 psig 4-V2" t :' , 5 G-Function 2-4 6 TD=10,115' PBTD=9,946' FISH: Expro 30.9'OVL:1-7/16"rope socket w/1"fishing neck(1.0'), 1-3/4"swivel(1.2'),1-11/16"tungsten wt bar(21'),3-1/8"CCL(2.5'),3"junk basket(5.0'),and 3.78"gauge ring(.17') Revised By:TDF 6-13-2014 ��4.- 11/7,—. ...�T. LJ. , S A ,)=E1K -',L' s d q —`.--, °1 r p l 1. ( ! 2 A. It'';- ',L–� : a,__1,e � i _ t q -- 333 Wesi Seven h Avenue :e �ovE.RNQR SEAN I ARN1 I_(. Ancnora«e, Alaska 95501 3572 wain 907 279 1433 Ql s� ,,�, MAY` 6 2114 , SCANNED Paul Chan Operations Engineer `� b (.,L —0 ` 0 Hilcorp Alaska, LLC c� l 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, SD Tyonek Undefined Gas Pool,Ninilchik Unit Paxton 1 Sundry Number: 314-283 Dear Mr. Chan: 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, -'I Daniel T. Seamount, Jr. Commissioner DATED this day of May, 2014. Encl. ��G 5l taiii RECEIVED 0 ' STATE OF ALASKA r ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 0 1 2014 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations ❑ Perforate 0 , Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other.Clean-out/Complete ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development Q - 204-010 ' 3.Address: Stratigraphic ❑ Service 1:16.API Number: 3800 Centerpoint Drive,Anchorage AK,99503 50-133-20535-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 592 Will planned perforations require a spacing exception? Yes❑ No 0 Ninilchik Unit Paxton 1 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0384372/ADL0359242 Ninilchik Field/SD Tyonek 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): 10,115 • 8,320 • 8,744' 6,953' N/A 8,744'(Fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 100' 20" 100' 100' 3,060psi 1,500psi Surface 1,895' 9-5/8" 1,895' 1,682' 6,870psi 4,760psi Intermediate 4,950' 7" 4,950' 3.418 8,160psi 7,020psi Production Liner 5,368' 4-1/2" 10,071' 8,276' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6x#/L-80 4,703 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): ZXP Liner Packer/N/A 4,703(MD)&3,266(TVD)/N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphic n Development n Service n 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 5/7/2014 Oil ❑ Gas ❑✓ . WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is tr - -n• correct to the best of my knowledge. Contact Paul Chan ` Email DchanehiIcorD.comT) Printed Nae Paul C . Title Operations Engineer Signature ' - . - 907-777-8333 Date 5/1/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: j. Spacing Exception Required? Yes ❑ No Orr Subsequent Form Required: / -.4Oq APPROVED BY Approved by: iv, / COMMISSIONER THE COMMISSION Date: 57,// 1"---- S•6-/1 ^ ^ i ^ l ♦ pp Submit Fop and Form 10-403(Revised 10/2012) Appro t s o 2 months from the date of approval. Attachments in Duplicate RBDMS MAY 13 201 ,-,i4gr .S : c. t,,t Well Work Program 11 Well: Paxton 1 AFE: 1421366 Hilcorp Alaska,LLQ Well Name: Paxton 1 API Number: 50-133-20535-00 Current Status: SI Gas Well Rig: Estimated Start Date: May 7, 2014 Estimated Duration: Reg.Approval Req'std? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 204-010 First Call Engineer: Paul Chan (907) 777-8333 (0) (907) 345-3161 (H) (907)444-2881 (C) Second Call Engineer: Mike Dunn (907) 777-8382 (0) (907) 351-4191 (M) Measured Bottom Hole Pressure: —2,450 psi at 6,032' TVD (SBHPS taken 2/5/2010) Maximum Expected BHP: —2,450 psi at 6,032' TVD Max. Anticipated Surface Pressure: —2,225 psi (0.038 psi/ft gas gradient) Brief Well Summary: Paxton 1 was drilled and completed as a gas well in 2004.The well last produced in 2009 from a number of different perforated intervals in the Tyonek. The well had made some fill and was producing up a velocity string making 700MSCFD when the well loaded up with water and died. The v-string was pulled and found to have a hole in it across from a productive interval at "6,080'. Coil tubing cleaned out the well to 9,208' but was unable to get below 6,080'CTMD with a 3.80" mill in December 2011.The velocity string was not rerun due to the inability to drift the wellbore with the 3.80" mill and the well is incapable of sustained flow without a v- string. The well was recently produced on 3/17/2014 for 1 hour at "1.OMMcfd into existing compression before it loaded up and died. OBJECTIVE: Add rate from the Tyonek T-6 sands. Procedure: 1. RU SL and PT lubricator to 250 psi low/3,000 psi high 2. RIH with 2-1/2" GR/JB and tag fill (last reported at 8,744' MD on 4/13/12). Restriction noted at 6,376'. Review historical WSR for more details. Note FL if any. POOH. 3. RIH with 2-7/8" GR/JB and tag. Note FL and deepest depth reached on WSR. POOH. 4. PU 2-7/8" dummy gun and drift to—6,250'SLM. 5. POOH and RD SL. 6. RU e-line and PT lubricator to 250 psi low/3,000 psi high. 7. Perforate the Tyonek T-6 sand with 2-7/8" 6 SPF 60 deg phased GEODynamics Connex gun. Depths are 7 from the Expro CBL dated April 10, 2004. Make correlation pass and send log in to Dave Buthman and Paul Chan. Proposed Perforated Intervals Sands Top (MD) Btm (MD) FT Tyonek T-6 5,859' 5,886' 27 8. Turn well over to production Attachments: As-built Well Schematic, Proposed Well Schematic . II Ninilchik Field • SCHEMATIC Well: Paxton 01 ` flacon)Alaska,i.l.c Last Completed: 5/29/2004 CASING DETAIL RKB:MSL=153'/1TAGL Size Type Wt/Grade/Conn ID Top Btm / 20" Conductor 133/K-55/PE 18.73 Surf 100' ', 9-5/8" Surface 47/L-80/Mod-Butt 8.681 Surf 1,895' 7" Intermediate 29/L-80/BTC 6.184 Surf 4,950' 4-1/2" Liner 12.6/L-80/Hydril 521 3.958 4,703' 10,071' 20" J TUBING DETAIL 4-1/2"1 Tubing 12.6#/L-80/Mod-Butt 3.958 Surf 4,703' n • JEWELRY DETAIL t, No Depth ID OD Item 9-5/8"1 6 1 2,517' 3.858 5.93 Baker Chemical Injection Nipple 2 4,703' ZXP Liner Packer w/15'Tieback Extension 1 3 4,727' Flex Lock Liner Hanger 4 9,946' Landing Collar 5 10,028' Float Collar 6 10,071' Float Shoe PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 6,026' 6,036' 4,297' 4,306' 10' 9/22/2005 Open 6,068' 6,088' 4,335' 4,354' 20' 9/22/2005 Open 6,118' 6,136' 4,382' 4,398' 18' 10/6/2005 Open T-8 6,152' 6,186' 4,413' 4,445' 34' 9/22/2005 Open 6,299' 6,319' 4,549' 4,568' 20' 5/31/2008 Open e 6,354' 6,360' 4,600' 4,606' 6' 10/6/2005 Open 2 6,682' 6,702' 4,904' 4,924' 20' 10/6/2005 Open ..iT-12 6,738' 6,758' 4,958' 4,976' 20' 10/4/2005 Open I 'r T-20 6,948' 6,968' 5,154' 5,161' 20' 10/4/2005 Open 7,158' 7,198' 5,369' 5,409' 40' 10/4/2005 Open i*•.1. . 3 7,162' 7,182' 5,373' 5,393' 20' 3/15/2005 Open ' L T-30 7,198' 7,251' 5,409' 5,461' 53' 10/3/2005 Open Pr e. I 7,438' 7,458' 5,648' 5,668' 20' 3/15/2005 Open it 7,570' 7,588' 5,780' 5,798' 18' 10/3/2005 Open ■ - T-42 7,794' 7,814' 6,004' 6,024' 20' 2/25/2005 Open • 8,188' 8,208' 6,397' 6,417' 20' 10/3/2005 Open 8,188' 8,266' 6,397' 6,475' 78' 5/6/2004 Open T-50 8,234' 8,254' 6,443' 6,463' 20' 4/30/2004 Open 7„ 8,402' 8,437' 6,611' 6,646' 35' 5/7/2004 Open L T-65 8,784' 8,804' 6,993' 7,013' 20' 5/27/2004 Covered 1-83 8,916' 8,936' 7,125' 7,199' 20' 5/28/2004 Covered bf' 9,088' 9,142' 7,297' 7,351' 54' 5/28/2004 Covered 1-90 9,113' 9,133' 7,322' 7,242' 20' 4/21/2004 Covered ' 9,220' 9,256' 7,429' 7,465' 36' 5/7/2004 Covered T-130 9,542' 9,558' 7,750' 7,766' 16' 4/20/2004 Covered , OPEN HOLE/CEMENT DETAIL i• 9-5/8" 12-1/4" hole, Cmt w/515 sks(230 bbls)12 ppg Type 1 cmt.134 sks(60 bbls)to Surface R 7" 8-1/2" hole, Cmt w/180 sks(70 bbls)12.5 ppg Lead&110 sks(36 bbls)13.5 ppg Tail Cmt bumped plug. ..1% 4-1/2" 7"hole w/690sks(219 bbls)of 12.8 ppg class G cmt. / TOFtagged @8,744'ND i,>, -‘,,,r. on 4/13/2112 !*, Fracked Tyonek Perfs 8,188'-8,266' MD on 2/10/2005 48,553 lbs of 20/40 Ottawa including 12.5%12/20 Flex Sand y Lightning 1800 6%KCL based fluid ramped 1-8 ppg i a Frac Grad=0.75 psi/ft Max Surf Pressure=3,700 psig 4-1/2 5 G-Function 2-4 6 TD=10,115' PBTD=9,946' FISH: Expro 30.9'OVL:1-7/16"rope socket w/1"fishing neck(1.0'), 1-3/4"swivel(1.2'),1-11/16"tungsten wt bar(21'),3-1/8"CCL(2.5'),3"junk basket(5.0'),and 3.78"gauge ring(.17') Revised By:TDF 3-4-2013 Ninilchik Field PROPOSED Well: Paxton 01 Hilcorp Alaska,LLC Last Completed: 5/29/2004 CASING DETAIL Poaa MSL=153'/17'AGL Size Type Wt/Grade/Conn ID Top Btm jc ) i ''' J i 20" Conductor 133/K-55/PE 18.73 Surf 100' ° 9-5/8" Surface 47/L-80/ModButt 8.681 Surf 1,895' t' 7" Intermediate 29/L-80/BTC 6.184 Surf 4,950' 4-1/2" Liner 12.6/L-80/Hydril 521 3.958 4,703' 10,071' 20" ' " TUBING DETAIL fi, 4-1/2" Tubing 12.6#/L-80/Mod-Butt 3.958 Surf 4,703' 1, JEWELRY DETAIL r. No Depth ID OD Item a 1 2,517' 3.858 5.93 Baker Chemical Injection Nipple 35/s' 2 4,703' ZXP Liner Packer w/15'Tieback Extension 3 4,727' Flex Lock Liner Hanger 4 9,946' Landing Collar , 5 10,028' Float Collar f+ I 6 10,071' Float Shoe .4 PERFORATION DETAIL ,� Zone Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status E 7 T-6 ±5,859' ±5,886 ±4,144' ±4,169' 27 FUTURE FUTURE IA I i fix' 6,026' 6,036' 4,297' 4,306' 10' 9/22/2005 Open '. 6,068' 6,088' 4,335' 4,354' 20' 9/22/2005 Open Pe 6,118' 6,136' 4,382' 4,398' 18' 10/6/2005 Open T-8 " 6,152' 6,186' 4,413' 4,445' 34' 9/22/2005 Open : $ 6,299' 6,319' 4,549' 4,568' 20' 5/31/2008 Open i =4 6,354' 6,360' 4,600' 4,606' 6' 10/6/2005 Open ' 6,682' 6,702' 4,904' 4,924' 20' 10/6/2005 Open 2 1-12 6,738' 6,758' 4,958' 4,976' 20' 10/4/2005 Open l.• -r ,) 1-20 6,948' 6,968' 5,154' 5,161' 20' 10/4/2005 Open 1 7,158' 7,198' 5,369' 5,409' 40' 10/4/2005 Open ` 3 Ili 7,162' 7,182' 5,373' 5,393' 20' 3/15/2005 Open r J' T-30 7,198' 7,251' 5,409' 5,461' 53' 10/3/2005 Open e 7,438' 7,458' 5,648' 5,668' 20' 3/15/2005 Open t° 7,570' 7,588' 5,780' 5,798' 18' 10/3/2005 Open A T-42 7,794' 7,814' 6,004' 6,024' 20' 2/25/2005 Open 4.1 A' 8,188' 8,208' 6,397' 6,417' 20' 10/3/2005 Open 8,188' 8,266' 6,397' 6,475' 78' 5/6/2004 Open T-50 8,234' 8,254' 6,443' 6,463' 20' 4/30/2004 Open 8,402' 8,437' 6,611' 6,646' 35' 5/7/2004 Open r i . T-65 8,784' 8,804' 6,993' 7,013' 20' 5/27/2004 Covered 1-83 8,916' 8,936' 7,125' 7,199' 20' 5/28/2004 Covered Of, rc` 9,088' 9,142' 7,297' 7,351' 54' 5/28/2004 Covered ; T-90 9,113' 9,133' 7,322' 7,242' 20' 4/21/2004 Covered t 9,220' 9,256' 7,429' 7,465' 36' 5/7/2004 Covered T-130 9,542' 9,558' 7,750' 7,766' 16' 4/20/2004 Covered s.fi OPEN HOLE/CEMENT DETAIL f:', 02.‘ 9-5/8" _ 12-1/4" hole, Cmt w/515 sks(230 bbls)12 ppg Type 1 cmt.134 sks(60 bbls)to Surface 7" 8-1/2" hole, Cmt w/180 sks(70 bbls)12.5 ppg Lead&110 sks(36 bbls)13.5 ppg Tail Cmt bumped plug. t"r! 4-1/2" 7"hole w/690sks(219 bbls)of 12.8 ppg class G cmt. TOF tagged @ 8,744'MD I 0 on 4/13/2012 04, . , Fracked Tyonek Perfs 8,188'-8,266' MD on 2/10/2005 ',. .'!104-'4'1 x 48,553 lbs of 20/40 Ottawa including 12.5%12/20 Flex Sand 4' Lightning 1800 6%KCL based fluid ramped 1-8 ppg 4,, le* 4 Frac Grad=0.75 psi/ft Max SurfPressure=3,700 psig 41/2" § �5 G-Function 2-4 6 TD=10,115' PBTD=9,946 FISH: Expro 30.9'OVL:1-7/16"rope socket w/1"fishing neck(1.0'), 1-3/4"swivel(1.2'),1-11/16"tungsten wt bar(21'),3-1/8"CCL(2.5'),3"junk basket(5.0'),and 3.78"gauge ring(.17') Revised By:TDF 5-1-2013 1 • Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, May 06, 2014 12:32 PM To: 'David Duffy' Cc: Paul Chan;Tom Fouts; Chris Kanyer; David Buthman Subject: RE: Paxton 1: Proposed Perforations (Permit 201-010) David, Thank you for providing Hilcorp's justification, below. I concur that a spacing exception 1 is not required for Hilcorp's planned Tyonek perforation operations in Paxton after reviewing Hilcorp's justification, AOGCC's records for all nearby wells, and AOGCC's orders and regulations that govern those wells. Please let me know if you have any questions. Regards, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.daviesPalaska.gov. From: David Duffy [mailto:dduffy@hilcorp.com] Sent: Friday, May 02, 2014 6:59 PM To: Davies, Stephen F (DOA) Cc: Paul Chan; Tom Fouts; Chris Kanyer; David Buthman Subject: FW: Paxton 1: Proposed Perforations (Permit 201-010) Steve, The Pax-1 well is a shut-in Tyonek producer. Hilcorp is requesting permission add new perforations within the Tyonek reservoir or pool and therefore return the well to production. Hilcorp refers to this interval within the Tyonek as the "T-6" sand. Because the T-6 sands are part of the Tyonek reservoir or pool, no spacing exception issues are triggered by 20 AAC 25.055(a)(4). Any other conclusion would require a spacing exception for each new sand perfed within a common reservoir or pool. Such a wide interpretation is not in keeping with current AOGCC policy or applicable law. 20 AAC 25.990(59) gives the term "reservoir"the same meaning as the term "pool." AS 31.05.170(12) defines the term "pool" as"an underground reservoir containing, or appearing to contain, a common accumulation of oil or gas; each zone of a general structure which is completely separated from any other zone in the structure is covered by the term "pool." (emphasis added). Here,the T-6 is simply a zone within the general Tyonek structure, and therefore is covered by the term of art "pool." Moreover, Pax-1 was the "discovery" well for what became the Susan Dionne/Paxton Participating Area. Subsequent Tyonek development wells required spacing exceptions to produce less than 3000' apart from another well within the same pool/reservoir. Here,the nearest well (Pax-2)that also produces from the Tyonek Pool does so under the spacing exception granted by Conservation Order 592. • As shown on the map below, there is 2620' between the Pax-1 and Pax-2 wells (measured from the T-6 interval). CO 952 is relevant because it specifically authorized drilling, completion, testing and regular production of the Pax-2 well in the "Tyonek reservoirs"within 3000' of the Pax-1 well. See Finding No. 1, and Conclusions 1-3, CO 592. Given this specific wording, no separate action is required to allow Pax-1 to be produced from anywhere within the Tyonek within 3000' of Pax-2. Lastly, there is no change of ownership within 1500' of the proposed T-6 perfs. The Pax-1 wellbore extends off-shore - and the state is the sole owner. The nearest location where property ownership differs is+2800' away. See map below. As a result, no spacing exception is required per 20 AAC 25.055(a)(2). 15,20..sets 30J0 Dameer Lewd 'F �GN Lu un.pna. 1500'Radius re1 Cw... 3000'Diameter For the reasons stated above, a spacing exception is not required to produce the Pax-1 well from the Tyonek T-6 sands. Please give me a call if you have other questions or need any additional information. Have a great weekend. David Duffy, Landman Hilcorp Alaska, LLC Direct: 907-777-8414 Cell: 907-301-2629 dduffy@hilcorp.com This email may contain confidential and /or privileged information and is intended for the recipient(s) only. In the event you receive this message in error, please notify me and delete the message. 2 From: Davies, Stephen F (DOA) [mailto:steve.davies@@alaska.gov] Sent: Friday, May 02, 2014 11:48 AM To: Paul Chan Subject: Paxton 1: Proposed Perforations (Permit 201-010) Paul, Hilcorp proposes to perforate the Tyonek T-6 sands in Paxton 1. The Application for Sundry Approval for this operation states, in Box 7, that Conservation Order No. 592 (CO)governs spacing for Paxton 1. This is not correct: CO 592 clearly applies only to the Paxton 2 well. What is the distance from the proposed perforations in Paxton 1 to the nearest well that is open to the T-6 sand? What is the distance from the proposed perforations in Paxton 1 to the nearest property line where landownership or ownership change? Please justify why a spacing exception should not be required under 20 AAC 25.055. Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.daviesPalaska.gov. 3 • • ,„,41.-,1,7,-,v 9 THE STATE Alaska Oil and Gas �� °f 1 1 Conservation Commission L1 is ° A9-- GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Chris Kanyer SCANNED APR 0 3 2013 Reservoir Engineer o�b Hilcorp Alaska, LLC 3800 Centerpoint Drive Anchorage, AK 99503 Re: Ninilchik Field, Tyonek Undefined Gas Pool, Ninilchik Unit Paxton 1 Sundry Number: 313 -149 Dear Mr. Kanyer: 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, at y P Foerster Chair DATED this day of April, 2013. Encl. 4 1 la • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ' 17/5/-0' / x. 3 APPLICATION FOR SUNDRY APPROVALS AO ' “.. ,f (i 20 MC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate Pull Tubing i Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other:Clean -out/ Complete 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory le . Development ❑ 204 -010 3. Address: Stratigraphic ❑ Service ❑ 6. API Number. 3¢00 Centerpoint Drive, Anchorage AK, 99503 50 -133- 20535 -00 -00 - 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order govems well spacing in this pool? 592 Will planned perforations require a spacing exception? Yes ❑ No 0 Ninilchik Unit Paxton 1 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL03843721 ADL0359242 • Ninilchik Field/ SD Tyonek 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): 10,115 . 8,320 8,744' 6,953' N/A 8,744' (Fill) I Casing Length Size MD TVD Burst Collapse Structural Conductor 100' 20” 100' 100' 3,060psi 1,500psi Surface 1,895' 9 -5/8" 1,895' 1,682' 6,870psi 4,760psi Intermediate 4,950' 7" 4,950' 3,418 8,160psi 7,020psi Production Liner 5,368' I 4 -1/2" 10,071' 8,276' 8,430psi 7,500psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 4 -1/2" 12.6# / L -80 4,703 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): ZXP Liner Packer / N/A 4,703(MD) & 3,266(TVD) / N/A :?. Attachments: Description Summary of Proposal p 13. Well Class e��opos d work: �b 4 / , Detailed Operations Program ❑ BOP Sketch Ex plorato ry { . Strat ❑ Development Service ❑ 1 i. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/1/2013 Oil ❑ Gas © Development ❑ Suspended ❑ 116. Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ C: ommission Representative: N/A GSTOR ❑ SPLUG I: 7 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Shane Bennett Email sbennettsna.hilcorp.com Printed Name Chris Kanyer Title Reservoir Engineer 1 j ,/,„,„. Phone 907 - 777 -8377 Date 3/26/2013 c j COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 313 -119 Mug Integrity ❑ BOP Test � , Mechanical Integrity Test ❑ Location Clearance ❑ Other: Ae 3 00 6 ?5 � 8 6 P sf • 'Suacing Exception Required? Yes ❑ No P; Subsequent Form Required: / 0 — e L I ) APPROVED BY F.pproved by: 4` � � J )i COMMISSIONER THE COMMISSION Date: � _ 3 / 1•Z' /3 Submit Form and Q .� , 4 , Qf 1fIG. vi d 0 1 g ed application is valid a tl4's from the date of approval. Attachments, Duplicate ' 1�� OMS APR 0 I t� ... "'t . • • Well Prognosis Well: PAX -1 Hilcoro Alaska, Lb Date: 3/22/2013 Well Name: Ninilchik Unit Paxton 1 API Number: 50- 133 - 20535 -00 Current Status: SI Gas completion Leg: N/A Estimated Start Date: April 1 2013 Rig: Cloverleaf Rig 4 ✓ Reg. Approval Req'd? 10 -403 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777 -8398 Permit to Drill Number: 204 -010 First Call Engineer: Shane Bennett (907) 777 -8425 (0) (325) 203 -7487 (M) Second Call Engineer: Chris Myers (907) 777 -8333 (0) (907) 398 -9955 (M) Reg. Approval Req'd? 10 -403 Date Reg. Approval Rec'vd: Current Bottom Hole Pressure: —2,454 psi Maximum Expected BHP: —2,454 psi @ 6,032' TVD (Based on Static survey ran 2/5/2010) Max. Allowable Surface Pressure: —2,137 psi (Based on 0.0526 psi /ft gas gradient) Brief Well Summary This well was drilled and completed as a gas well in 2004. Subsequent perforations were added in 2005, followed by performing a coil tubing cleanout to 9,850', and running a velocity string in 2007. The velocity string was pulled in December 2011, where the velocity string was found flow -cut. A coil tubing cleanout was attempted, tagging at 9,208'. Attempts to RIH with a 3.80" mill to complete the cleanout were unsuccessful, tagging high at 6,080'. A casing caliper was run and discovered casing deformation in the 4 -1/2" liner. The velocity string was not rerun due to inability to clean out well. Well has remained shut. The proposed completion plans include pulling the 4.5" tubing from the sealbore in the ZXP liner top packer, cleaning out fill to the deepest Tyonek perfs (9,542'- 9,558'), and running a new 2 -7/8" tubing & packer y completion with blast joints across the suspected erosion area. The well will be returned to production to regain production and additional recovery of reserves from several Tyonek intervals. Summary Procedure 1. RU Cloverleaf Rig 4 2. Set two way check, ND Tree. 3. NU BOP and pressure test BOP to 250 psi low /3,000 psi high. 4. POOH with 4.5" tubing from sealbore in the ZXP liner top packer at 4,703'. 5. RIH with cleanout BHA and cleanout fill (possibly fish) in 4.5" liner to +/- 9,600'. 6. RIH with 2 -7/8" tubing, x nipple, blast joints, retrievable packer at +/- 4,650', tubing tail to +/- 8,750'. 7. Land tubing in hanger and set retrievable packer. p ` r) 110 Zap !S 8. ND BOP and NU tree. /cs 9. Turn well over to production & flow test well. Contingency 10. RU E -line and test lubricator to 250psi low /2,500psi high. 11. Perforate the Tyonek 130 sand at +/- 9,542' to +/- 9,558' 12. RD Eline. L-->" 4, - / por�. Attachments: 1. As -built Well Schematic 2. Proposed Well Schematic 3. BOP Schematic • • Ninilc Field SCHEMATIC Well: Paxton 01 Hikorp Alaska, LLC Last Completed: 5/29/2004 CASING DETAIL RKB: MSL =153' / 1T AGL Size Type Wt/ Grade/ Conn ID Top Btm f l ' 20" Conductor 133 / K -55 / PE 18.73 Surf 100' y 9 -5/8" Surface 47 / L -80 / Mod -Butt 8.681 Surf 1,895' 7" Intermediate 29 / L -80 / BTC 6.184 Surf 4,950' 4 -1/2" Liner 12.6 / L -80 / Hydril 521 3.958 4,703' 10,071' 20" TUBING DETAIL 4 -1/2" 1 Tubing 12.6 # /L -80 /Mod -Butt 3.958 Surf 4,703' t JEWELRY DETAIL No Depth ID OD Item 9-5/8" 1 2,517' 3.858 5.93 Baker Chemical Injection Nipple 2 4,703' ZXP Liner Packer w/ 15' Tieback Extension 1 3 4,727' Flex Lock Liner Hanger 4 9,946' Landing Collar 5 10,028' Float Collar 6 10,071' Float Shoe µ 4" PERFORATION DETAIL - 43 Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status 6,026' ' 6,036' 4,297' 4,306' 10' 9/22/2005 Open 6,068' 6,088' 4,335' 4,354' 20' 9/22/2005 Open 6,118' 6,136' 4,382' 4,398' 18' 10/6/2005 Open T -8 6,152' 6,186' 4,413' 4,445' 34' 9/22/2005 Open 6,299' 6,319' 4,549' 4,568' 20' 5/31/2008 Open s -A. 6,354' 6,360' 4,600' 4,606' 6' 10/6/2005 Open 2 6,682' 6,702' 4,904' 4,924' 20' 10/6/2005 Open T -12 6,738' - 6,758' 4,958' 4,976' 20' 10/4/2005 Open ,: T -20 6,948' 6,968' 5,154' 5,161' 20' 10/4/2005 Open 7,158' 7,198' 5,369' 5,409' 40' 10/4/2005 Open 7 1 RI ' 3 7,162' 7,182' 5,373' 5,393' 20' 3/15/2005 Open . T -30 7,198' 7,251' 5,409' 5,461' 53' 10/3/2005 Open t i ® 7,438' 7,458' 5,648' 5,668' 20' 3/15/2005 Open Pr 1 7,570' 7,588' 5,780' 5,798' 18' 10/3/2005 Open Its i T -42 7,794' \ 7,814' 6,004' 6,024' 20' 2/25/2005 Open 8,188' 8,208' 6,397' 6,417' 20' 10/3/2005 Open 8,188' . 8,266' 6,397' 6,475' 78' 5/6/2004 Open T -50 8,234' ' 8,254' 6,443' 6,463' 20' 4/30/2004 Open 7 " Z ` 8,402' . 8,437' 6,611' 6,646' 35' 5/7/2004 Open L T -65 8,784' . 8,804' 6,993' 7,013' 20' 5/27/2004 Covered T -83 8,916' 8,936' 7,125' 7,199' 20' 5/28/2004 Covered . 9,088' 9,142' 7,297' 7,351' 54' 5/28/2004 Covered T -90 9,113' 9,133' 7,322' 7,242' 20' 4/21/2004 Covered 9,220' 9,256' 7,429' 7,465' 36' 5/7/2004 Covered T -130 9,542' 9,558' 7,750' 7,766' 16' 4/20/2004 Covered OPEN HOLE / CEMENT DETAIL 9 -5/8" 12 -1/4" hole, Cmt w/ 515 sks (230 bbls) 12 ppg Type 1 cmt. 134 sks (60 bbls) to Surface 7" 8 -1/2" hole, Cmt w/ 180 sks (70 bbls) 12.5 ppg Lead & 110 sks (36 bbls) 13.5 ppg Tail Cmt bumped plug. TOF tagged MD 4 -1/2" 7" hole w/ 690sks (219 bbls) of 12.8 ppg class G cmt. on 4/13/2012 , , 4' Fracked Tyonek Perfs 8,188' - 8,266' MD on 2/10/2005 48,553 Ibs of 20/40 Ottawa including 12.5% 12/20 Flex Sand i Lightning 1800 6% KCL based fluid ramped 1 -8 ppg 4 Frac Grad =0.75 psi /ft Max Surf Pressure =3,700 psig 4 -1/2 , 5 G- Function 2 -4 6 TD =10,115' PBTD= 9,946' FISH: Expro 30.9' OVL: 1- 7/16" rope socket w /1" fishing neck (1.0'), 1 -3/4" swivel (1.2'), 1- 11/16" tungsten wt bar (21'), 3 -1/8" CCL (2.5'), 3" junk basket (5.0'), and 3.78" gauge ring (.17') Revised By: TDF 3 -4 -2013 • • Ninilchik Field PROPOSED Well: Paxton 01 Hilcorp Alaska, LLC Last Completed: 5/29/2004 CASING DETAIL RKII MSL =153' 11T AGL Size Type Wt/ Grade/ Conn ID Top Btm j ) . 20" Conductor 133 / K -55 / PE 18.73 Surf 100' 9 -5/8" Surface 47 / L -80/ Mod -Butt 8.681 Surf 1,895' k 7" Intermediate 29 / L -80 / BTC 6.184 Surf 4,950' 4 -1/2" Liner 12.6 / L -80 / Hydril 521 3.958 4,703' 10,071' 20" TUBING DETAIL 1 1 2-7/8" 1 Tubing 1 6.5 # /N -80 /Mod -Butt 2.441 I Surf 1 ±8,750' JEWELRY DETAIL k to ty No Depth ID OD Item r, 5 ) ' 1 ±300' SSSV 95o 2 ±4,600' 2.875 5.93 Production Packer 3 ±4,635' X- Profile Nipple C 4 4,703' ZXP Liner Packer w/ 15' Tieback Extension Ph 5 4,727' Flex Lock Liner Hanger ' , 2 6 ±6,006' Blast Joints x 10 @ 20' each li$ f' 7 ±8,748' X- Profile Nipple 'n � „ 8 ±8,750' WLEG 1 i 9 9,946' Landing Collar ( - 10 10,028' Float Collar y - 11 10,071' Float Shoe a b. PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status 6,026' 6,036' 4,297' 4,306' 10' 9/22/2005 Open ►1! y4 12 i 6,068' 6,088' 4,335' 4,354' 20' 9/22/2005 Open , 3 6,118' 6,136' 4,382' 4,398' 18' 10/6/2005 Open T 8 6,152' 6,186' 4,413' 4,445' 34' 9/22/2005 Open 6,299' 6,319' 4,549' 4,568' 20' 5/31/2008 Open , ,ti t p, 4 6,354' 6,360' 4,600' 4,606' 6' 10/6/2005 Open T -12 6,682' 6,702' 4,904' 4,924' 20' 10/6/2005 Open 10/4/2005 Open y 6,738' 6,758' 4,958' 4,976' 20' i c 5 T -20 6,948' 6,968' 5,154' 5,161' 20' 10/4/2005 Open Lt 7,158' 7,198' 5,369' 5,409' 40' 10/4/2005 Open c I • • 7,162' 7,182' 5,373' 5,393' 20' 3/15/2005 Open 1- T -30 7,198' 7,251' 5,409' 5,461' 53' 10/3/2005 Open 7,438' 7,458' 5,648' 5,668' 20' 3/15/2005 Open c r y 7,570' 7,588' 5,780' 5,798' 18' 10/3/2005 Open T -42 7,794' 7,814' 6,004' 6,024' 20' 2/25/2005 Open 8,188' 8,208' 6,397' 6,417' 20' 10/3/2005 Open 8,188' 8,266' 6,397' 6,475' 78' 5/6/2004 Open 7.' _ T -50 8,234' 8,254' 6,443' 6,463' 20' 4/30/2004 Open TOC @ 6,000, Expro Radial Bond Log ---IP, 8,402' 8,437' 6,611' 6,646' 35' 5/7/2004 Open T -65 8,784' 8,804' 6,993' 7,013' 20' 5/27/2004 Open 6e T -83 8,916' 8,936' 7,125' 7,199' 20' 5/28/2004 Open i`�r `` 9,088' 9,142' 7,297' 7,351' 54' 5/28/2004 Open T -90 9,113' 9,133' 7,322' 7,242' 20' 4/21/2004 Open k. „. 9,220' 9,256' 7,429' 7,465' 36' 5/7/2004 Open " T -130 9,542' 9,558' 7,750' 7,766' 16' 4/20/2004 Open ig OPEN HOLE / CEMENT DETAIL i 9 -5/8" 12 -1/4" hole, Cmt w/ 515 sks (230 bbls) 12 ppg Type 1 cmt. 134 sks (60 bbls) to Surface 7" 8 -1/2" hole, Cmt w/ 180 sks (70 bbls) 12.5 ppg Lead & 110 sks (36 bbls) 13.5 ppg Tail Cmt bumped plug. 7 !. *" 4 -1/2" 7" hole w/ 690sks (219 bbls) of 12.8 ppg class G cmt. Fracked Tvonek Perfs 8,188' - 8,266' MD on 2/10/2005 TOF±9600' 'u 48,553 lbs of 20/40 Ottawa including 12.5% 12/20 Flex Sand s Lightning 1800 6% KCL based fluid ramped 1 -8 ppg 4„..,; 9 Frac Grad =0.75 psi /ft Max Surf Pressure =3,700 psig 4-1 / 2 "k C 11" ° '10 G- Function 2 -4 TD =10,115' PBTD= 9,946' FISH: Expro 30.9' OVL: 1- 7/16" rope socket w /1" fishing neck (1.0'), 1 -3/4" swivel (1.2'), 1- 11/16" tungsten wt bar (21'), 3 -1/8" CCL (2.5'), 3" junk basket (5.0'), and 3.78" gauge ring (.17') Revised By: TDF 3 -26 -2013 . • m 20Ni13 BOP lchik Unit Stack Knight Oil Tools Rental Hilem -p o�i;er�ka, Td t 02/05/2013 Ninilchik Unit Paxton #1 Cloverleaf #4 BOP 3.98' • • Hydril GK 11" -5000 111 111 111111111 111 III I1I 111 III _ — clw -u 111111M/sv man 2 7/8 -5 variables 4.54' ��O ®® _ Blind 11 "- 5000 NEM - ® ®® I1I 111 111 111 111 Osg27i 1`1 Chok21 /161Kill 0Mvalves 27/76:70M O5P�11161 On One HCR M 1 1 11 1 111 I (I 11 2.00' e e � . i i 1/16 5M EFO,-. 11 111 11I 111 111 • 10K4o'kti Regg, James B (DOA) p 4 _010 From: Sulley, Michael B. (MRO) [msulley@marathonoil.com] Monday, December 12, 2011 7:46 AM �q 14111' 2 1 To: Regg, James B (DOA); doa .aogcc.phrudhoe.bay @alaska.gov Cc: Ellis, Michael (MRO); Skiba, Kevin J. (MRO) Subject: Reporting BOPE use to Prevent the Flow of Fluids from a Well Attachments: Reporting BOPE Use to Prevent the Flow of Fluids from a Well.docx Dear Mr. Regg: Attached please find a letter to serve as your AOGCC Guidance Bulletin No 10 -003. If you have any further questions, please do not hesitate to contact me. «Reporting BOPE Use to Prevent the Flow of Fluids from a Well.docx» Respectfully, Mike Sulley 907 394 -1334 msulley@ marathonoil .com �R -;1t • •p ( pm 26 4 -via Reporting BOPE Use to Prevent the Flow of Fluids from a Well Notification to the AOGCC Mike Sulley informed Jim Regg, AOGCC, of BOPE event via telephone at approx. 4:30 PM Friday, December 9, 2011. Reporting Details: p g Date, Time of BOPE use: 11:21 AM on December 9, 2011 Well /Location /PTD Number: Paxton #1 /Ninichik Gas Field, Paxton Pad/ 204 -010 Rig Name: Baker Coil J194 Operator Contact: Marathon, Mike Sulley 907 3941334 BOPE Used: TOT 4- 1/16" Dual Combi Unit Reason for BOPE Use: To prevent well from flowing Actions Taken /To Be Taken (including the date used BOPE was tested): BOPE tested 12/8/2011. Blind Shears actuated to cut coil tubing on 12/9/2011. Chronology of Events: Nov. 30: Set PX plug and prong in PXN profile at 8129 ft WLM. Vstring pressure 1600 psi, Vstring annulus pressure 1320 psi. Dec. 8: RU 4- 1/16" TOT BOPE, tested same. Dec. 9: 7:30: Operations bled Vstring /Vstring annulus to approx. 760 psi (pipeline pressure) 8:00: PU 3" GS ran into well, catch hanger, PU ^'15 ft. 11:00: Closed pipe /slip ram on 1 -3/4" coil. 11:04: Bleed off Vstring pressure to zero. Observe. 11:15: Dumped traction on chains. Walked injector up coil. 11:18: Slipping pipe, pull up 2 ft. 11:19: Pull up another 1 ft. Vv P)`6 11:20: Picking up lubricator stack to begin crossing over to a dimple on connector to enable spooling /recover of coil. Coil Hanger and GS tool was inside of lubricator. Flow was observed coming from the bottom of lubricator. Suspected barrier failure, subsequently pipe pulled and a hole is found in the vstring adjacent to a perfed interval. 11:21: Blind Shear ram actuated. Secured well. RU to kill well w/ 6% KCI. Dec 9 -12: Continue operations to recover coil. Found hole in coil at 2028' ft from end of coil tubing. • • Sifffirl -1 ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION CO1 J2I ISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Kevin J. Skiba Regulatory Compliance Representative © � b Marathon Alaska Production, LLC 01,0* P.O. Box 1949 Kenai, AK 99611 -1949 Re: Ninilchik Field, Tyonek Undefined Gas Pool, Paxton #1 Sundry Number: 311 -154 Dear Mr. Skiba: MAY 0 6 7.0 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. • cere y, Daniel T. Seamount, Jr. Chair DATED this 5 day of May, 2011. Encl. • Mara, Alaska Production LLC Alaska Asset Team M Marathon P.O. Box 1949 MARATHON Alaska Production LLC Kenai, AK 99611 ® Telephone 907/283 -1371 Fax 907/283 -1350 April 29, 2011 RECEIVED I Mr. Winton Aubert Alaska Oil & Gas Conservation Commission MAY i i : Ail 333 W 7 Ave Anchorage, Alaska 99501 kesk8 Oil & Gay Cans. Commission t;ncn, %rags Reference: 10 -403 Application for Sundry Approvals Field: Ninilchik Gas Field Well: Paxton #1 Dear Mr. Aubert: Submitted for your approval is the10 -403 Application for Sundry Approvals for PAX- 1well. Marathon proposes to pull the velocity string, clean out the wellbore, and reinstall the velocity string at a new target setting depth of 9,540' MD. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, S' 4 'W/jL6t1 Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -403 Application for Sundry Approvals cc: AOGCC Current Well Schematic Houston Well File Proposed Well Schematic Kenai Well File Detailed Operations Program KJS ' STATE OF ALASKA Oik .. // ALASKA •AND GAS CONSERVATION COMMISSION. 5 , APPLICATION FOR SUNDRY APPROVALS oS to oft 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair well ❑ Change approved program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Specify: Time Extension ❑ Operational shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter casing ❑ Other: Clean out & re -run V- String - el 2. Operator Name: Marathon Alaska Production LLC 4. Current Well Class: 5. Permit to Drill Number: Development El . Exploratory ❑ 204 -010- 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 -1949 50- 133 - 20535- 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 Paxton #1 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 359242' & ADL 384372- Ninilchik Unit / SD Tyonek 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): 10,115' - 8,320' - 9,946' - 8,152' - NA 9,606' Casing Length Size MD / TVD Burst Collapse Structural Conductor 79' 20" 100' 100' 3,060 psi 1,500 psi Surface 1,874' 9 -5/8" 1,895' 1,683' 6,870 psi 4,750 psi Intermediate 4,929' 7" 4,950' 3,418' 8,160 psi 8,160 psi Production Liner 5,368' 4 - 1/2" 10,071' 10,071' 8,430 psi 7,500 psi Perforati th MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): .2458 9,558' .5809' - 7,766' Velocity ' 4 -1/2" L -80 4,703' -G 4 104 j L 7 Packers and SSSV Type: SSSV: NA Packers and SSSV MD (ft) and TVD (ft): SSSV NA Packers: Baker ZXP Liner Packer pack 4,703' MD 3,266' TVD 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program Ig BOP Sketch ❑ Exploratory ❑ Development 0 - Service ❑ 14. Estimated Date for ■ 15. Well Status after proposed work: May 'A011 011 Commencing Operations: Oil ❑ Gas 0- 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 Kevin Skiba (907) 283 -1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature �Ph. Date �� • i I I (907) 283 - 1371 April 29, 2011 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 5t `-" ( ✓ -4' Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ RECEIVED Other: ;J;i j ,:' - ill Alaska Oil & Gas Cm's. Guns ission Subsequent Form Required: 10 —• ( p t{ . ; <,I c t?rag6 / APPROVED BY � ' Approved by: � / COMMISSIONER THE COMMISSION Date: 5/s RBDMS MAY 0 6 2011 '-- Form 10 -403 Revised 1/2010 ORIGINAL Submit in Duplicate Permit #: 204 -010 411 0 API #: 50- 133 - 20535 -00 -00 Paxton #1 Prop. Des: ADL- 359242 S, 384372 KB Elevation: 153' (17'AGL) Ninilchik Field (1%01 ARATMON (Nabor's Rig) 782' FNL, 2,905' FEL X: 206422 Sec. 13, T1S, R14W, S.M. Y: 2230579 Conductor Latitude: 60° 5'45.539" N _ 20" K - 55 133 ppf PE Longitude: 151° 36'30.592" W MD TO Bottom Spud: 02/16/2004 I L TVD o' 100' TD: 03/08/2004 Rig Released: 03/14/04 @ 00:00 hrs. Surface Casing r 9 -5/8" L -80 47 ppf Mod -Butt �- ; Tom Bottom i MD 0' 1,895' t�,,+ +�, +. -N TVD 0' 1,683' Build 2.0 de 00 from 350- 2,200 •••• •� • +�• 1 (230 ) ppg 12 -1/4" hole cmt w/ 516 sks 230 bbls of 12 9 ` �r •:,, Type-1 cmt. 134 sks bbls) to surface. • Hold 56 deg from 2,200 - 4,200' MD .i��•r'� � � +� �a T YP (60 bbl ( ) 9 Drop 2 de /100 to 7,800' Final angle of 5.5 deg • .:. Azimuth: 335 deg. @ 4,900' MD/270 dg• 1 @7,800' Baker Chemical Intermediate Casing 105 deg @ TD Injection Nipple 7" L -80 29 ppf BTC To Bottom +£ .92 510 MD ( 58" I � 5.930" OD / 3.858" ID MD 0' 4,950' 8,430 psi burst TVD 0' 3,418' Production Tubing 7,500 psi collapse 8.1/2" hole cmt w / 180 sks (70 bbls) 12.5 ppg Lead q & 110 sks (36 bbls) 13.5 ppg Tail cmt. Bumped plug. 4 -1/2" L -80 12.6 ppf Mod -Butt j Top Bottom MD 21' 4,703' I ) TVD 21' 3,266' Liner 7" hole w / 690 sks (219 bbls) of 12.8 ppg 4 -1/2" L -80 12.6 ppf Hydril 521 class G cmt. Top Bottom MD 4,703' 10,071' TVD 3,266' 8,276' { 7" hole w / 690 sks (219 bbls) of 12.8 ppg ZXP Liner Packer with 15' Tieback Extension class G cmt. @ 4,703' MD (Top) Flex -Lock Liner Hanger © 4,727 MD (Top) Landing Collar @ 9,946' MD (Top) Float Collar © 10,028' MD (Top) Existing Tyonek Perfs Float Shoe @ 10,071' MD (Bottom) MD TVD FT Date Perf Gun 6,026 - 6,036' 4,297 - 4,306' 10' 9/22/2005 3 -3/8" Owen 6 SPF 6,068 - 6,088' 4,335- 4,354' 20' 9/22/2005 3 -3/8" Owen 6 SPF Velocity String (installed on 1/25/2007) 6,118- 6,136' 4,382 - 4,398' 18' 10/6/2005 3 -3/8" Owen 6 SPF 1 -3/4" OD 6,152- 6,186' 4,413 - 4,445' 34' 9/22/2005 3-3/8" Owen 6 SPF Top Bottom 6,299- 6,319' 4,549- 4,568' 20' 10/6/2005 3 -3/8" Owen 6 SPF MD 21' 8,103' 6,354- 6,360' 4,600 - 4,606' 6' 10/6/2005 3 -3/8" Owen 6 SPF TVD 21' 6,312' Cement Top 6,682- 6,702' 4,904 - 4,924' 20' 10/4/2005 3 -3/8" Owen 6 SPF BHA includes: 2.50" OD X 1.50" ID CT grapple @ 6,000' 6,738-6,758' 4,958- 4,976' 20' 10/4/2005 3 -3/8" Owen 6 SPF Expro Radial 6,948- 6,968' 5,154 - 5,161' 20' 10/4/2005 3 -3/8" Owen 6 SPF connector, 2.50" OD X 1.50" ID X 10' long box by Bond Log ' 7,158- 7,198' 5,369 - 5,409' 40' 3/15/2005 3 -3/8" Owen 6 SPF box straight bar, 1.91" OD X 1.25" PXN (1.135" 7,198 - 7,251' 5,409 -5,461 53' 3/15/2005 3 -3/8" Owen 6 SPF no -go) profile nipple, and 3.50" OD x 2.50" OD 7,162- 7,182' 5,373-5,393' 20' 10/3/2005 3-3/8" Owen 6 SPF (Reperf) re -entry y top box x 2.0" ID bottom) wireline 7,438- 7,458' 5,648. 5,668' 20' 10/3/2005 3 -3/8" Owen 6 SPF re -entry quid 7,570- 7,588' 5,780- 5,798' 18' 2/25/2005 3 -3/8" Owen 6 SPF 7,794 - 7,814' 6,004- 6,024' 20' 10/3/2005 3 -3/8" Owen 6 SPF 8,188 - 8,266' 6,397 - 6,475' 78' 4/30/2004 PJ 2506 8,188- 8,208' 6,397- 6,417' 20' 5/6/2004 PJ 2506 (Reperf) Tagged fill at 9,341' w/ 1" bailer (2/4/2010) 8,234 - 8,254' 6,443- 6,463' 20' 5/7/2004 PJ 2506 (Reperf) Tagged metal or fish @ 9,331' w\ 1" bailer (3/16/2009) 8,402-8,437' 6,611- 6,646' 37' 5/27/2004 3 -3/8" Owen 6 SPF Cleaned fill to 9,850' (1/24/2007) 8,784 - 8,804' 6,993- 7,013' 20' 5/28/2004 3 -3/8" Owen 6 SPF Tagged fill @ 9,562' w\ Expro P -T tool (11/01/2005) ' 8,916- 8,936' 7,125- 7,199' 20' 5/28/2004 3 -3/8" Owen 6 SPF Tagged fill @ 9,606' w\ 2.25" GR (8/24/2005) 9,088- 9,142' 7,297- 7,351' 54' 4/21/2004 PJ 2506 Tagged PBTD @ 9,953' wl coil tubing & slickline (4/16/2004) L 9,113- 9,133' 7,322 - 7,242' 20' 5/7/2004 PJ 2506 (Reperf) 9,220-9,256' 7,429- 7,465' 36' 4/20/2004 PJ 2506 `- 9,542- 9,558' 7,750- 7,766' 16' 4/19/2004 PJ 2506 L 9,542- 9,558' 7,750 - 7,766' 16' 2/23/2005 3 -3/8" Owen 6 SPF (Reperf) FISH: Expro 30.9' OVL: 1- 7/16" rope socket w /1" fishing neck (1.0'), 1 -3/4" swivel (1.2'), 1- 11/16" tungsten wt bar (21'), 3 -1/8" CCL (2.5'), 3" junk basket (5.0'), and 3.78" gauge ring (.17') Fraced Tvonek Perfs 8,188' - 8,266' MD on 2/10/2005 Formation Tops 48,553 Ibs of 20/40 Ottawa including 12.5% 12/20 Flex Sand Formation Depth (MD) Depth (TVD) Sterling N/A N/A Lightning 1800 6% KCL based fluid ramped 1 -8 ppg Beluga 654' 652' TD PBTD Frac Grad =0.75 psi/ft Max Surf Pressure =3,700 psig Tyonek 4,751' 3,295' 10,115' MD 9,946' MD G- Function 2.4 TD 10,115' 8,320' 8,320' TVD 8,152' TVD Well Name & Number: Paxton #1 Lease: Ninilchik Unit I Paxton Pad Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 10,406' - 11,171' Perf (TVD): 6,821' - 7,585' Angle @ KOP & Depth: 3° / 100 ft @ 250' MD Angle @ Perfs: Date Completed: 5/28/2004 Ground Level: 136' (AMSL) RKB: 17' (AGL) Revised by: Kevin Skiba Revision Date: 2/11/2010 Permit #: 204 -010 P RO FS E D P 50-133-20535-00-00 Paxton #1 Prop. & 3 Des: ADL- 359242 & 384372 KB Elevation: 153' (17'AGL) Ninilchik Field MARATHON (Nabors Rig) X: 206422 782' FNL, 2,905' FEL Y: 2230579 Sec. 13, T1S, R14W, S.M. Latitude: 60° 5'45.539" N Conductor Longitude: 151° 36'30.592" W 20" K - 55 133 ppf PE Spud: 02/16/2004 �u - 1! LL Top Bottom TD: 03/08/2004 I $ MD 0' 100' Rig Released: 03/14/04 @ 00:00 hrs. J f TVD 0' 100' r i Surface Casing F 9 -5/8" L -80 47 ppf Mod -Butt S Top Bottom :ii MD 0' 1,895' KOP @ 350' MD/TVD ... TVD 0' 1,683' Build 2.0 deg /100 from 350 - 2,200' , 12 -1/4" hole cmt w/ 516 sks (230 bbls) of 12 ppg Hold 56 deg from 2,200- 4,200' MD ' +yg Type -1 cmt. 134 sks (60 bbls) to surface. Drop 2 deg /100 to 7,800'e" + • Final angle of 5.5 deg + :: • Azimuth: 335 d 04,900 MP /2704'. y +N: + + +� Baker Chemical Intermediate Casing Injection Nipple 7" L -80 29 PP f BTC 105 deg @ TD= + +� + +� + +� + +� + +� +r� • � • . @ 2.517' MD (Top) Top Bottom 5.93T OD / 3.858" ID MD 0' 4,950' 8,430 psi burst TVD 0' 3,418' Production Tubing 7,500 psi collapse & 110 sks (36 bbls) (70 bbls) cmt. Bumped Lea d 4 -1/2" L -80 12.6 ppf Mod -Butt ) 135 ppg PP9 Tail P ed P 9 Top Bottom MD 21' 4,703' TVD 21' 3,266' Liner 7" hole w / 690 sks (219 bbls) of 12.8 ppg 4 -1/2" L -80 12.6 ppf Hydril 521 class G cmt. Top Bottom MD 4,703' 10,071' TVD 3,266' 8,276' 7" hole w / 690 sks (219 bbls) of 12.8 ppg ZXP Liner Packer with 15' Tieback Extension :1 class G cmt. @ 4,703' MD (Top) l li Flex -Lock Liner Hanger @ 4,727' MD (Top) Landing Collar © 9,946' MD (Top) II Float Collar @ 10,028' MD (Top) Existing Tyonek Perfs Float Shoe © 10,071' MD (Bottom) i, MD TVD FT Date Perf Gun I 6,026 - 6,036' 4,297-4,306' 10' 9/22/2005 3 -3/8" Owen 6 SPF 6,068 - 6,088' 4,335-4,354' 20' 9/22/2005 3 -3/8" Owen 6 SPF 6,118-6,136' 4,382-4,398' 18' 10/6/2005 3-3/8" Owen 6 SPF t 6,152 - 6,186' 4,413 -4,445' 34' 9/22/2005 3 -3 /8" Owen 6 SPF Velocity String (installed on 1/25/2007) Cement Top 6,299- 6,319' 4,549 -4,568' 20' 10/6/2005 3 -3/8" Owen 6 SPF 1 -3/4" OD @ 6,000' - 6,354- 6,360' 4,600 -4,606' 6' 10/6/2005 3 -3/8" Owen 6 SPF Top Bottom Expro Radial 6,682- 6,702' 4,904 -4,924' 20' 10/4/2005 3 -3/8" Owen 6 SPF Bond Log 6,738 - 6,758' 4,958-4,976' 20' 10/4/2005 3 -3/8" Owen 6 SPF MD 21' 9,54 6,948 - 6,968' 5,154 - 5,161' 20' 10/4/2005 3 -3/8" Owen 6 SPF TVD 21 7'748 ' 7,158- 7,198' 5,369 - 5,409' 40' 3/15/2005 3-3/8" Owen 6 SPF BHA includes: 2.50" OD X 1.50" ID CT grapple 7,198- 7,251' 5,409 -5,461 53' 3/15/2005 3 -3/8" Owen 6 SPF connector, 2.50" OD X 1.50" ID X 10' long box by 7,162 - 7,182' 5,373 - 5,393' 20' 10/3/2005 3 -3/8" Owen 6 SPF (Reperf) box straight bar, 1.91" OD X 1.25" PXN (1.135" 7,438- 7,458' 5,648 - 5,668' 20' 10/3/2005 3 -3/8" Owen 6 SPF no -go) profile nipple, and 3.50" OD x 2.50" OD 7,570- 7,588' 5,780 - 5,798' 18' 2/25/2005 3 -3/8" Owen 6 SPF (1.50" ID top box x 2.0" ID bottom) wireline 7,794-7,814' 6,004 - 6,024' 20' 10/3/2005 3 -3/8" Owen 6 SPF re -entry guid 8,188 - 8,266' 6,397- 6,475' 78' 4/30/2004 PJ 2506 8,188 - 8,208' 6,397 - 6,417' 20' 5/6/2004 PJ 2506 (Reperf) 8,234 - 8,254' 6,443- 6,463' 20' 5/7/2004 PJ 2506 (Reperf) Tagged fill at 9,341' w/ 1" bailer ( 2 / 4 / 2010 ) 8,402- 8,437' 6,611- 6,646' 37' 5/27/2004 3 -3/8" Owen 6 SPF - Tagged metal or fish @ 9,331' w\ 1" bailer (3/16/2009) - _ 8,784 - 8,804' 6,993 - 7,013' 20' 5/28/2004 3 -3/8" Owen 6 SPF Cleaned fill to 9,850' (1/24/2007) 8,916-8,936' 7,125- 7,199' 20' 5/28/2004 3 -3/8" Owen 6 SPF Tagged fill @ 9,562' w\ Expro P -T tool (11/01/2005) 9,088-9,142' 7,297- 7,351' 54' 4/21/2004 PJ 2506 Tagged fill @ 9,606' w\ 2.25" GR ( 8 / 24 / 2005 ) 9,113- 9,133' 7,322- 7,242' 20' 5/7/2004 PJ 2506 (Reperf) Tagged PBTD @ 9,953' w \coil tubing & slickline (4/16/2004) 9,220- 9,256' 7,429 - 7,465' 36' 4/20/2004 PJ 2506 9,542- 9,558' 7,750- 7,766' 16' 4/19/2004 PJ 2506 L 9,542- 9,558' 7,750- 7,766' 16' 2/23/2005 3 -3/8" Owen 6 SPF (Reperf) FISH: @9910' (2/5/2005) Expro 30.9' OVL: 1- 7/16" rope socket w/1" fishing neck (1.0'), 1 -3/4" swivel (1.2'), 1- 11/16" tungsten wt bar (21'), 3 -1/8" CCL (2.5'), 3" junk basket (5.0'), and 3.78" gauge ring (.17') 4 Fraced Tyonek Perfs 8,188' - 8,266' MD on 2/10/2005 Formation Tops 48,553 Ibs of 20/40 Ottawa including 12.5% 12/20 Flex Sand Formation Depth (MD) Depth (TVD) Sterling N/A N/A - Lightning 1800 6% KCL based fluid ramped 1 -8 ppg Beluga 654' 652' TD PBTD Frac Grad =0.75 psi /ft Max Surf Pressure =3,700 psig Tyonek 4,751' 3,295' 10,115' MD 9,946' MD G- Function 2 -4 TO 10,115' 8,320' 8,320' TVD 8,152' TVD Well Name & Number: Paxton #1 Lease: Ninilchik Unit / Paxton Pad Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 10,406' - 11,171' Perf (TVD): 6,821' - 7,585' Angle @ KOP & Depth: 3° / 100 ft @ 250' MD Angle @ Perfs: Date Completed: 5/28/2004 Ground Level: 136' (AMSL) RKB: 17' (AGL) Revised by: Mike Sulley Revision Date: 4/11/2011 • MARATHON ARATH MARATHON ALASKA PRODUCTION LLC ALASKA ASSET TEAM Pax #1 Ninilchik Unit Paxton Pad Pull Velocity String /Clean out Fill/ Re -run V string Procedure WBS # W 0.11.XXXXX. CAP.001 APPROVALS: Mike SuIley (4/25/2011) Program Writer Mike Ellis Lyndon Ibele Latest Version Date: 4/25/11 Well Status: The well is currently not producing because perforations are covered with fill in the wellbore. Objectives: Clean out fill to capture more reserves and jet well in. Install a 1.75" CT V- string to prolong well life by reducing unload rate and will give operations greater production flexibility in the future. Resources: Coiled tubing set up with pump and N2 pump Approx 10,000 of 1.75" CT Arctic Iron and choke skid, gas buster, tank set up Manlift / 2 Light plants Vetco Crew for wellhead modifications /hang -off assembly install. Procedure: Disconnect power to wellhouse (call electrician). MI man lift. MI crane. Remove well house. Paperwork: Sundry Notice, WBD, Work Permit, Well Ops transfer sheet. Coiled Tubing Velocity String Hang -off Procedure 4/25/2011 - 1 - • • A. Install 1.25" PXN plug and prong MIRUPollard slick line unit. Install 1.25" PXN plug and prong in EO V string @ 8103' to provide a barrier to pull V string. B. MIRU MOC flowback equipment This includes open -top flowback tank, choke skid, gas buster, and flowback iron. MIRU fluid tank with 250 bbls 6% KCI. Lay liner and berm area around tank. C. Pull 1.75" CT 1. MIRU BJ coiled tubing unit. Verify 24 hour notification has been made to / AOGCC for BOP test. Rig up fluid and N2 pumps. RU pumping iron (BJ) and Arctic flow back iron (MOC). RU 2" iron for equalizing from BOP to top of lubricator. 2. Nipple up BJ CT wellhead assembly (WHA). Current WHA is 4- 1/16" 5M swab /cap. WHA to include 4- 1/16" - 5M X 4- 1/16" - 10M DSA, 4- 1/16" - 10M X 5" Flanged Riser, 4- 1/16" — 10M flow cross and 4- 1/16" - 10M Dual - Combi BOP (dressed for 1 -3/4" CT). Function test BOP. Install test bar. 3. Perform complete BOP test and complete AOGCC BOP Test Report (Correct form dated 01/25/2010). Pressure test pump iron (200 low /4500 high psi). Pressure test WHA and flow back iron to choke manifold i (200/4500 psi). Pressure test BOP rams (200/4500 psi). Note BOP test witness or waiver in WellView, including details. 4. Pressure test V string with N2 to 2000 psi. Release pressure upon completion of the test. 5. Nipple up iniector to WHA. Pressure test WHA using CT kill line (200/1500 psi). Bleed WHP to flow back tank. Prior to next step, ensure that flowback line from WHA through choke manifold to gas buster is ready and available to keep TP at or below 1500 psi while POOH to eliminate possible CT collapse. 6. MU BJ Coil BHA and Weatherford Hydraulic Release GS Running Tool. (Only hand filing OD of CT above BOP. HOT WORK PERMIT Coiled Tubing Velocity String Hang -off Procedure 4/25/2011 - 2 - • • REQUIRED for air grinder /carbide burr). GS running tool should be plugged to release on pressure, not rate. Swing Injector and lubricator away from WH. BJ CoilTech to connect Weatherford GS tool string assembly to coil on reel trailer. Dimple -on a 1 -3/4" CT connector. Pull test CT connector (25,000 lbs.) using 1.125" 10SA box X 1 -1/2" MT pin crossover and 1-1/2" MT box pull plate. Tool string will consist of 1 -3/4" slimline dimple -on, 1.125" 10SA box X 1 -1/2" MT pin X -over and a plugged 3" GS spear. PU or lay down 4" lubricator as needed to cover GS tool string and Vetco CT hanger. 7. RIH and latch Vetco CT hanger per Vetco procedures. PU string weight and verify string is latched. Release upper lock screws. PU string weight. Release lower lock screws. Pull coil hanger up into lubricator. 8. Set CT in BOP tubing /slip rams. Lock tubing /slip rams. Slack off injector chain traction and roll chains to verify slips are set. Release WHP above tubing rams to the flowback tank. Nipple injector off of WHA. Walk injector up CT. The chains should always be rotating "out of hole" and zero tension when -ever "walking" the injector.lnstall C plate above BOP and polish rod clamp on CT. 9. Release GS Running Tool. Mechanically release GS spear. Set down weight and then pick GS off of hanger. Cut weep hole. Cut CT above BOP high enough to install dimple -on CT connector. Prep tubing and install dimple -on connector. Pull test connector to string weight plus 5,000 lbs. Remove polish rod clamp and C -plate from top of BOP. Walk injector down CT and nipple injector /lubricator to top of BOP. The chains should always be rotating "out of hole" and zero tension when -ever "walking" the injector. Equalize WHP across tubing rams. Unlock tubing /slip rams. Open BOP tubing /slip rams. Pull coil out of hole. D. Clean out fill and jet well in 1. MU BJ Coil BHA and 2" jetting nozzle. (Only hand filing OD of CT above BOP. HOT WORK PERMIT REQUIRED for air grinder /carbide burr). Swing Injector and lubricator away from WH. BJ CoilTech to connect 2" jetting nozzle and tool string assembly to coil on reel trailer. Dimple -on a 1 -3/4" CT connector. Pull test CT connector (25,000 lbs.) using 1.125" 10SA box X 1 -1/2" MT pin crossover and 1 -1/2" MT box pull plate. Tool string will consist of 1 -3/4" slimline dimple -on, 1 -3/4" DF check valve, Coiled Tubing Velocity String Hang -off Procedure 4/25/2011 -3- • • 1.125' 10SA box X 1 -1/2" MT pin X -over and 2" jet nozzle. PU or lay down 4" lubricator as needed to cover tool string. 2. RIH(c , 60 fpm with coil tubing string and 2" jetting nozzle pumping 6% KCL at min rate. At 9000' increase fluid pump rate to 3/4 bpm and N2 at 750 scf /min. Penetration rate should be approximately 5 fpm. Cleanout fill from 9341' to 9850'. 3. Once 9850' is reached, slowly PUH @ 50 fpm to 5000'while circulating solids to surface. Circulate well clean. 4. After circulating solids out of hole, increase N2 rate to 700 scf /m and run back to bottom to "kick off' well. 5. Pooh while continuing to circulate N2 © 700 scf /m. Reduce N2 rate once water returns dry up. Continue POOH. Rerun 1.75" Coil Tubing String 6. Pig CT. Run end of CT with pig catcher onto Well head. Open valves on flow cross to flow back tank. Pump 5 bbls water, cleaning pig, and coil displacement +10% behind pig. 7. MU CT BHA. Nipple injector off WH. PU 10' of 4- 1/16" CQ lubricator. MU velocity string BHA to end of CT. Install dimple on connector. Pull test to 18K. Pressure test coil to 3000 psi. Blow down coil with approximately 10,000 scf of N2 to flow back tank. Continue installing BHA. BHA to include: a. 2.50" OD X 1.50" ID CT grapple connector, b. 2.50" OD X 1.50" ID X 10' long box x box straight bar, c. 1.91" OD X 1.25" PXN (1.135" no -go) pin x pin, d. 2.50" OD x 2.50" OD (1.50" ID top box x 2.0" ID bottom) wireline re- entry guide with 2.0 OD" x 2.50" OD 0-ring sealed aluminum pump - off plug. Strap and record velocity string BHA dimensions and lengths. Include record in WellView and on updated WBD. 8. Nipple up iniector to WHA. Pressure test WHA using CT kill line (200/1500 psi). Bleed WHP to flow back tank. Prior to next step, ensure Coiled Tubing Velocity String Hang -off Procedure 4/25/2011 -4- • • that flowback line from WHA through choke manifold to gas buster is ready and available to keep TP at or below 1500 psi while RIH to eliminate possible CT collapse. This would serve as a backup if flow through the production flow line was unexpectedly curtailed or ceased. 9. RIH with coil tubing velocity string and BHA with well flowing to sales up annulus (running v- strings into shut -in wells has been very unsuccessful). 10. Cut coil tubing. POH to span WHA for final landing depth, 9540'. Set CT in BOP tubing /slip rams. Lock tubing /slip rams. Slack off injector chain traction and roll chains to verify slips are set. Release WHP above tubing rams to the flowback tank. Nipple injector off of WHA. Walk injector up CT. The chains should always be rotating "out of hole" and zero tension when -ever "walking" the injector. Install C plate above BOP and polish rod clamp on CT. Cut weep hole. Cut CT above BOP high enough to allow Vetco to install CT connector and hanger mandrel assembly. 11. MU Vetco Coil Tubing Hanger and Weatherford Hydraulic Release GS Running Tool. (Only hand filing OD of CT above BOP. HOT WORK PERMIT REQUIRED for air grinder /carbide burr). GS running tool should be plugged to release on pressure, not rate. Swing Injector and lubricator away from WH. Vetco to connect VGCT Coil Tubing Hanger (4" Nom C/W 3" Weatherford Fishing neck with 2 -3/8" 8rd Box and 2" BPV) to hanging coil tubing with coil grapple. While Vetco is making up CT hanger, BJ CoilTech to connect Weatherford GS tool string assembly to coil on reel trailer. Dimple -on a 1 -3/4" CT connector. Pull test CT connector (25,000 lbs.) using 1.125" 10SA box X 1 -1/2" MT pin crossover and 1 -1/2" MT box pull plate. Tool string will consist of 1 -3/4" slimline dimple -on, 1 -3/4" DF check valve, 1.125' 10SA box X 1 -1/2" MT pin X- over and a plugged 3" GS spear. PU or lay down 4" lubricator as needed to cover GS tool string and Vetco CT hanger. 12. Latch GS spear to Vetco mandrel after PU injector. Remove polish rod clamp and C -plate from top of BOP. Accurately measure from hanger assembly to CT lock down screws. Walk injector down CT and nipple injector /lubricator to top of BOP. Pull test CT mandrel connection /GS spear assembly to CT string weight plus 5,000 lbs. Slack off weight to CT string weight. Measure and mark the exact distance that the CT has to move down to align the hanger. Make all measurements on the gooseneck with all rollers locked. Equalize WHP across tubing rams. Unlock tubing /slip rams. Open BOP tubing /slip rams. 13. RIH and land Vetco CT hanger per Vetco procedures. Stop hanger 1' high and run lower lockdown screws to their landing position. Lower Coiled Tubing Velocity String Hang -off Procedure 4/25/2011 -5- • • hanger onto the Iockdown screws and then lock upper screws. Verify string and hanger are landed and secured per Vetco procedures. Slack off string weight to neutral. Tighten lock screws. Pressure test hanger between slab seals to 5000 psig for 10 min. with hand pump pressure test unit (Vetco Supplied). 14. Release GS Running Tool. Start pumping N2 to pressure up CT to release GS spear. Set down weight and then pick GS off of hanger E. Pressure Up and Blow Pump -Off Plug Shut in sales and allow WHP pressure to build up to 1100 psi. Jumper gas from annulus to coil tubing until CT WHP is 1100 psi. While leaving CT shut in, open annulus to sales. The differential pressure between the coil tubing and annulus should blow off the pump out plug. If the situation dictates, pump off plug with N2. F. RD and release CT. RD equipment, clean location, and turn in work permit. G. Flow Test Well to Sales No more than a 60% drawdown with methane gas in wellbore is permitted for the lowest open interval. Obtain stabilized flow within the 60% drawdown limit. The unloading rate up 4 -1/2" casing and 1.75" coil tubing in a vertical well is 4.0 MMCFPD and 638 MCFPD, respectively, at 800 psig FCP. Flow well to sales observing recommended drawdown rates. H. Complete Well Ops Transfer Sheet and distribute. Complete Well Ops Transfer Sheet and distribute. Considerations, Instructions, and Planning: Coiled Tubing Velocity String Hang -off Procedure 4/25/2011 -6- • • A pre- meeting with the construction group is required. Talk with construction and make arrangements to complete instrumentation, electrical, logic, and FCO to minimize shut -in time. V- string candidates don't normally like shut -ins, and having a "rush" job adds considerably to the cost of the tree work. A hot work permit is necessary for grinding the top of the CT above the BOP to allow installation of the dimple on connector when the v- string is pulled. This permit requires special approval and must be obtained before the job. When running the v- string, only allow hand filing of the outside of the CT above the tree to avoid the necessity of the hot work permit. Hand filing the outside is sufficient to install the external connector. Pigging the coil is a good practice generally and required if we are running used pipe from BJ. The critical point in the job is spacing out to hang off the CT. If the space out and procedure is not correct the CT or hanger can easily be damaged costing significant extra time and money. Organize a job meeting before the injector is walked back down to the BOP to ensure everything is measured and correct. There are 2 kinds of CT hangers in the field. The new style hanger has seals that are energized by the lockdown screws. The old style hanger has o -rings and is a larger OD. If an old style hanger is pulled from the well it should be discarded and replaced with the new style with slab seals. A third hanger is in final design as of Sept -09. This design has shear screws to stop from prematurely energizing the seal while running through the lubricator or tree. It is necessary to use straight bars to align the hanger and GS. Use a 6' straight bar between the CT connector and the hanger and above the GS spear use 2 large centralizers separated with a 2' — 3' straight bar. If running a 4" hanger in 4- 1/16" lubricator (or 3" in 3 -1/8 ") it is necessary to install a pump in sub at the top of the lubricator and connect a hose from the top pump - in sub to the BOP to equalize around the hanger. Differential across the hanger can energize the seals and then they will be damaged running the hanger through the lubricator. Vetco is redesigning the 4" hanger to severely reduce this possibility (in final design stage in Sept09). It is safer to latch the hanger with the GS after the lubricator is reconnected to avoid walking the injector down the pipe. Either method works but with the straight bar below the hanger and the double centralizers above the GS it is easy to latch inside the lubricator. When running the 3" hanger latching the GS inside the lubricator is not an option unless you have 3 -1/8" lubricator and an equalizing system. Coiled Tubing Velocity String Hang -off Procedure 4/25/2011 -7- • • M Marathon MARATHON Oil Company February 29, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Ninilchik Gas Field Well: Paxton #1 Dear Mr. Maunder gl~ska 0i18~ Gas r",.Y ~ f ; ~~. ~ ~,, .,:., Ar~chor~,~+ ~R~r OID V We requested permission to vent gas from PAX-1 well while making the PAX-2 well surface facility tie-in. Plans were developed to construct a temporary by-pass around the surface facilities while completing the tie-in. There was no certainty that the operating variables, at the time of tie-in, would be conducive to maintaining gas flow from PAX-1 necessitating gas venting. The tie-in was completed during the week of February 18th without the need to vent gas. This report is being submitted as anon-venting event to close out Sundry# 308-045. If you have any questions or need further information please call me at (907) 283-1371. Sincerely, _ ~~ ..a~~~ Kevin J. Skiba Production Technician Enclosures: 10-404 Sundry Report Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~EV~~ V MAR o 4 2aag ~r~~ ~ ~D lYltitl ~ ~ L.U~t~ cc: AOGCC Houston Well File Kenai Well File MAM KJS ' \~5 6~ o~ ~~ 3~` lq,~ ~~~ STATE OF ALASKA ~ ~-~~~ ALA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Non-Venting ' Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number. Name: Marathon Oil Company Development Q Exploratory^ 204-010 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20535-00-00 7. KB Elevation (ft): 9. Well Name and Number: 153' ~ Paxton #1 ' 8. Property Designation: 10. Field/Pool(s): ADL-359242 7ADL-384372 Ninilchik Unit /Beluga 8~ Tyonek Pools 11. Present Well Condition Summary: Total Depth measured 10,115' ' feet Plugs (measured) NA true vertical 8,320' ~ feet Junk (measured) 9,606' Effective Depth measured 9,946' ~ feet true vertical 8,152' ~ feet Casing Length Size MD TVD Burst Collapse Structural 0 0 0 0 0 0 Conductor 79' 20" 100' 100' 3,060 psi 1,500 psi Surface 1,874' 9-5/8" 1,895' 1,683' 6,870 psi 4,750 psi Intermediate 4,929' 7" 4,950' 3,418' 8,160 psi 7,020 psi Production 0 0 0 0 0 0 Liner 5,368' 41/2" 10,071' 8,276' 8,430 psi 7,500 psi Perforation depth: Measured depth: 7,158' - 9,558' gross True Vertical depth: 5,369' - 7,766' gross Tubing: (size, grade, and measured depth) 4-1/2" L-80 4,703' Packers and SSSV (type and measured depth) Baker 2J(P Liner Packer 4,703' 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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: NA Subsequent to operation: NA 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ~ Service ^ Daily Report of Well Operations 16. Well Status after work: Oil ^ Gas^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 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: 308-045 Contact Kevin Skiba (907) 283-1371 Printed Name Michael A. Mullin Title Senior Production Engineer Signature Phone (907) 283-1337 Date February 29, 2008 Form 10-404 Revised 04/2006 `.?t ~jj,~~ ~~,' ~A~ ~ ~ ~Q~~' Submit Original Only • • rt~ ~.:.- - a~'? .~.; _ ,~.:.. ,_ :: MICROFILMED 03/01 /2008. DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_InsertstMicrofilm_Marker.doc r: • ( (~, , ~ I ~ ~ ~ d ~ p.~~'~ ~ w,:~ K' M try J r', %~ ~~ . ~ L~ ~ ~ SARAH PAL/N, GOVERNOR ALA58A OII, AI~TD rzA~S 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQATIOI~T COAil•'II55IO1Q ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Michael A. Mullin Senior Production Engineer Marathon Oil Company PO Box 1949 Kenai Alaska 99611-1949 ~'~ ~ ~~ ~ ~ 200 Re: Ninilchik Unit Field, Beluga & Tyonek Gas Pools, Paxton # 1 Sundry Number: 308-045 ©~ ~ Dear Mr. Mullin: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided iri 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 rehearing. A request for rehearing 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 ft the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this -~ day of February, 2008 Encl. • M Marathon MARATHON Oil Company February 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-403 Sundry Notice Field: Ninilchik Gas Field Well: Paxton #1 Dear Mr. Maunder ,oL° ~ti~ We are currently drilling Paxton #2 in Ninilchik. We plan to tie in the well to the production system on Feb. 19th which requires isolating the flowline on Paxton #1. We have concerns that Paxton #1 will be damaged if we shut in the well to perform this facilities work and are requesting permission to vent the well during the facilities work to preserve the existing production. We expect to complete this work in 24 hours. Anticipated vented volume should be about 1 MM. We are requesting permission to vent 2MM in case the tie in takes longer than anticipated. If you have any questions or need further information please call me at (907) 398-9954. Sincerely, Michael A. Mullin Senior Production Engineer Enclosures: 10-403 Sundry Notice Operations Summary cc: AOGCC Houston Well File Kenai Well File MAM KJS ORIGINAL Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~'~' ,~., ~~ ~ ~ ?~~~ ,, ~,1ask~ pit ~ has ~~st~. ~~~atris~~:~; Dg' 13~U"~' STATE OF ALASKA .~ p~ J ALA OIL AND GAS CONSERVATION COM SIO ~ ~ ~` EB ~ ~~ - Q APPLICATION FOR SUNDRY APPROV ~i ~~ ~-. ~~I~ I ~ ~ ~~, ~, t~a~ 20 AAC 25.280 .__~ _____. 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ aiver Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Vent Gas Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2.Operator Name: Marathon Oil Company 4. Current Well Class: 5. Permit to Drill Number: Development ^ Exploratory ^ 204-010 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20535-00-00 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 Q Paxton #1 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL-359242 7ADL-384372 153' ~ Ninilchik Unit !Beluga $ Tyonek Poots 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,115' 8,320' ~ 9,946' ~ 8,152' ' NA 9,606' Casing Length Size MD TVD Burst Collapse Structural Conductor 7g' 20" 100' 100' 3,060 psi 1,500 psi Surface 1,874' 9-5/8" 1,895' 1,683' 6,870 psi 4,750 psi Intermediate 4,929' 7" 4,950' 3,418' 8,160 psi 7,020 psi Production Liner 5,368' 4-1/2" 10,071' 8,276' 8,430 psi 7,500 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7,158' - 9,558' gross 5,369' - 7,766' gross 4-1/2" L-80 4,703' Packers and SSSV Type: Packers and SSSV MD (ft): Baker ZXP Liner Packer 4,703' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development^ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: February 19, 2008 pil ^ Gas 0 Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Michael A. Mullin Title Senior Production Engineer Signature hone Date (907) 283-1337 February 6, 2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~ ° lJT~ Plug Integrity ^ BOP Test ^ Mec nical Integrity Test ^ Location Clearance ^ ha l ry Other. ~~'h~~ v~~v4~E ~1~~~~ '~ ~~~~~ V~`~ ~~ ~~~ S ~F~ ~~~ ~ ~ 200 Subsequent Form Required: ~ L~r~ ~ ,~~~ v~ \V ~~ O ~~~~~ ~~ ~.~~©~ APPROVED BY roved b COMMISSIONER THE COMMISSION Date: 2' / s r A pp y Form 1 -403 Revised 06/ 6 ... ~ ~ ~ ~ ~\~ /1~ ~ Submit in Duplicate • r • • M MARATHON MARATHON OIL COMPANY ALASKA REGION Ninilchik Gas Field Paxton #1 Venting Objective: Maintain flow on Paxton #1 while performing facilities work to tie in Paxton #2 flowline to avoid losing some or all of the production from shutting in the well. OUTLINE PROCEDURE: ~. Determine flowing pressure at minimum unload rate of 800 MCF. 2. Open Paxton #1 to gas buster at minimum unload rate. 3. Close wing valve, SSV, and flowline valve. 4. Bleed pressure between wing valve and flowline valve. 5. Lock out wing valve and flowline valve. s. Perform Paxton #2 tie in in facility. 7. Unlock valves and turn over to production. s. Record all vented volumes for AOGCC recording. CONTACTS Mickey Mullin: 907-283-1337 (w) Ken Walsh: 907-283-1311 (w) 907-398-9954 (c) 907-394-3060 (c) Ninilchik Operators: 907-567- 3248 rage 1 ~~ ~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, February 08, 2008 12:18 PM To: 'Skiba, Kevin J.'; Mullin, Mickey Subject: Paxton #1 (204-010) Kevin and Mickey, I am reviewing the sundry submitted regarding venting on this well while tying in Paxton #2. Could you provide some examples of venting events while trying to unload water or run velocity strings. Such information wi{l support your request for Paxton #2. Thanks in advance. Tom Maunder, PE f AOGCC ' ~ <. lv Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent:. Wednesday, February 13, 2008 2:19 PM To: 'Ibele, Lyndon` Subject: RE: Paxton #1 (204-010) Lyndon, This is exactly what I needed. Thanks much. Tom Maunder, PE AOGCC From: Ibele, Lyndon [mailto:lcibele@marathonoil.com] Sent: Wednesday, February 13, 2008 2:14 PM To: Maunder, Thomas E (DOA) Subject: FW: Paxton #1 (204-010) Y' 1. V~ ~' ~~ ~~ ~ ~ ~ ~ ,~' ~y' i ~~ a: ~, -~I C,G ~' ~~ ~i ~ U ~~ < ~~ t~ mot! ~ i 7 .~ i '3' ~ ~. ~~ fi ~~ --~; .s ~, ~~ ~ ~ ~ ~ ~ ~ ~, ~! ~ ~ ..~± ~; ~- nJ ` ; v~ i ~~~ `~ : j ; c~ ~. ~~ ~; ~~ 4 y ~+ '~I ~! ' ?~ ~- Ik `~ J ~l s I ~ ~. .~ ~ ~ I ~.i i ~ ~~ ~ Tom-- You had questions about the necessity of venting Paxton #1 during facility work. We do not have any engineering proof that shutting in will do any harm, but on the contrary we requested permission to vent because we are very, very concerned that the well may not recover if it is shut in. As you can see on the attached plot, the well currently makes less than 1 mmcfd with a velocity string installed to assist in unloading water. If too much water accumulates during the shut in, we will be unable to unload it with the v-string and may loose the well altogether (and risk permanent loss of reserves}. {i2,t23~'2006 7:10:58 PM} 41 Deg F kgfrs944-2ary.kgf.moc.com:PX_7I_3006 [Delta] Tag Name i Description ~ Server ~ Color Uniks Maximum I IO Address `Time OFfset 1 Minimum j ^~ Li PX_FI_1173 _ PX Barton Pipeline Flow Rate kgfrs949.., MCF _ 0 3000 ~~ngFrs_kgFtVIEW~Tag.., 0:00:00,.,, ^~ i~'-1 PX_PI_3004 PX Well #1 Flowline Pressure Indicator kgfrs949.., psi 0 1500 1+,ngFrs_kgf~VIEW~Tag... 0:00:00,... ^~ ,.: pX_TI_3006 PX Well #1 Flow Line Temperature Indicator kgFrs949... Deg F 0 60 ~~ngFrs_kgF~VIEW~Tag... 0:00:00.... 11:37:58 AM 6:01:58 AM 2:25;58 AM 4:49:58 PM 4:13:se F~rvi u;si:sn AM Summary by Month: Individual Well Production Well Name: NINILCHIK UNIT PAXTON 1 API: 50-133-20535-00-00 Permit to Drill: 2040100 Operator: MARATHON OIL CO Field/Pool: NINILCHIK, SD TYONEK UNDEF GAS Sales Cd: Acct Grp: Final Status: 1-GAS Current Status: 1-GAS 2005 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Days 4 28 31 28 31 30 3l 31 30 31 30 31 Oil 0 0 0 0 0 0 0 0 0 0 0 0 Wtr 0 0 0 137 110 68 0 75 156 354 170 122 Gas 7,428 20,576 67,235 59,129 55,423 50,620 48,585 46,953 58,966 82,233 52,859 44,879 2005 Totals: Oil 0 Water 1,192 Gas 594,886 Cum Oil 0 Cum Wtr 1,192 Cum Gas 594,886 2006 Jan__ _ Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Days 30 28 31 30 31 30 31 31 27 31 30 31 Oil 0 0 0 0 0 0 0 0 0 0 0 0 Wtr 20 447 329 220 120 100 249 142 116 94 24 25 Gas 38,804 42,904 49,745 46,256 52,676 37,208 38,157 35,396 29,746 32,654 27,813 27,446 2006 Totals: Oil 0 Water 1,886 Gas 458,805 Cum Oil 0 Cum Wtr 3,078 Cum Gas 1,053,691 2007 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Days 31 28 31 30 31 30 31 31 30 31 30 31 Oil 0 0 0 0 0 0 0 0 0 0 0 0 Wtr 280 243 74 74 99 40 76 59 95 62 48 61 Gas 26,782 39,651 42,097 40,424 40,928 38,142 38,050 37,102 34,491 34,551 32,442 30,965 2007 Totals: Oil 0 Water 1,211 Gas 435,625 Cum Oil 0 Cum Wtr 4,289 Cum Gas 1,489,316 Thursday, February 07, 2008 Page 1 Maratln Oil Company - Alaska Asset Team Northern Business Unit P.O. Box 3128 Houston, TX 77253 Telephone 713-296-2384 Fax 713-499-8504 July 12, 2006 Attention: Howard Oakland Alaska Oil & Gas Conservation Commission 333 W. 7tb Avenue, Suite 100 Anchorage, AK 9950 I FEDERAL EXPRESS RE: Marathon Paxton #1 Well Data CONFIDENTIAL Enclosed are the following CONFIDENTIAL digital data for the above referenced well: Epoch Mud Log Data ~ ID j paxton_# LIas r . Paxtonl_DD.pdf £OJ Paxtonl_ML.pdf ¡i;j Paxton l_ML TVD.pdf Please indicate your receipt of this data by signing below and returning one copy to me at the LETTERHEAD address or fax to me at 713-499-8504. Thank you, K~ Kaynell Zeman Geological Technician Enclosures Received by: ê-ß /í,,-----" Date: '"+ I r1-/i~~ I .. DC;L(-Ct 6 /? r3cì1Jt ~ 9 J~ À ~ \t. DATA SUBMITTAL COMPLIANCE REPORT 5/25/2006 Permit to Drill 2040100 Well Name/No. NINILCHIK UNIT, PAXTON 1 Operator MARATHON OIL CO hh S rt-...J_ I. 7y'~ '-{ API ..so. 5õ-133-20535-00-00 MD 10115 t" TVD 8320 r Completion Date 5/29/2004 /' Completion Status 1-GAS Current Status 1-GAS UIC N REQUIRED INFORMATION Mud Log Yes Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: Reeves Quad Combo: GR/CaIlDen/Neutron/SoniclRes Well Log Information: Electr Dataset Number Name 12681 Induction/Resistivity (data taken from Logs Portion of Master Well Data Maint Digital Med/Frmt C Las Log Log Scale Media Run No Interval OH / Start Stop CH Received Comments 150 10067 Open 4/19/2004 Induction/Res Dens Poro Dt (.Ias) Mud Log (.Ias) Dir Svy (.dat) 4/19/2004 Final Well Report (.doc) o 10115 4/19/2004 . C Wrd 12681 Report: Final Well R Directional Survey Rpt Well Cores/Samples Information: 4/22/2004 Sample Set Number Comments 1134 Cores and/or Samples are required to be ~I submitted. This record automatically created I from Permit to Drill Module on: 1/29/2004. ~ Interval Start Stop 1905 10115 Sent Received Name Cuttings ADDITIONAL INFORMATION Well Cored? Y / N Daily History Received? Y/N . Chips Received? Y / N Formation Tops ~N Analysis Y / N Received? Comments: tIt u¿ ~ p) ~4.? . \. ~ ... ct, ..v.....r .-l~ )j4;) ~ ~W\.J--~~ Compliance Reviewed By: Date: Addendum to request for Paxton # 1 mudlog graphics . . Kaynell, As I was releasing Paxton # 1, I took a look at the mud log las file. The header information is for KBU 23-7 (API 50-133-20532-00). The data stops at 10114' MD so it could be for Paxton # 1, but I don't know for sure. Please send to me the correct mud log las file. TNX Howard Sunny and warm the last few days. 1 of 1 6/29/2006 8:20 AM Paxton 1 . . Kaynel/, The CD that you sent to us with Paxton 1 (API 50-133-20535-00) digital data did not have any mud log graphics (.pdf) files. It did have the .LAS file, though. Please send the graphics file(s) of the mud log. TNX Howard Been partly cloudy and cool with passing rain showers. Typical summer. 1 of 1 6/20/20063:40 PM . N\) Marathon '..MARATHON Oil Company . Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 February 24, 2006 RECE\VED FEE 2 1 2006 comn~ßßíGí'I A1tska Oi\ & Gas Cons. Anchorage Winton Aubert Alaska Oil & Gas Conservation Commission 333 West yth Ave, Suite 100 Anchorage, AK 99501 Reference: Report of Sundry Well Operations 10-404 for permit 204-010 Field: Ninilchik Unit- Beluga / Tyonek Well: Paxton No.1 Dear Mr. Aubert, Enclosed please find the Report of Sundry Well Operations with associated attachments for Ninilchik Unit well Paxton No.1. This well was completed cased hole with a 4.5" monobore production string to surface. The Report indicates results from fracture stimulating the perforations from 8188'-8266' MD. Please accept my apology for being late with this report. Should you require further information, I can be reached at 713-296-2730, or bye-mail at JRThompson@MarathonOil.com. Sincerely, a::.~~ Sr. Completions Engineer Enclosures: Well bore Diagram Frac Operations Summary STATE OF ALASKA ALiA OIL AND GAS CONSERVATION COMrA/ON REPcMT OF SUNDRY WELL OPE~IONS RECEIVED 1. Operations Abandon U Performed: Alter Casing 0 Change Approved Program 0 2. Operator Name: Marathon Oil Company 3. Address: Repair Well U Pull Tubing 0 Operat. Shutdown 0 Plug Perforations U Perforate New Pool 0 Perforate 0 4. Current Well Class: Development [] Stratigraphic 0 Stimulatel:0 Other GO 2 7 2006 WaiverO Timef{.!~psi'W[J. Gas Cons. Cormissii-n Re-enter Suspe~§ %eil'tf 5. Permit to Drill Numb~\thOrage Exploratory 0 204-010 Service 0 6. API Number: 50-133-20535-00-00 P.O. Box 1949, Kenai, AK 99611-1949 7. KB Elevation (ft): 167' 9. Well Name and Number: Ninilchik Unit, Paxton #1 8. Property Designation: 10. Field/Pool(s): ADL-359242 & 384372 11. Present Well Condition Summary: Ninilchik - Beluga / Tyonek Total Depth measured 10,115 feet true vertical 8,320 feet Effective Depth measured 9946 feet true vertical 8152 feet Casing Length Size MD Structural Conductor 100' 20" 100' Surface 1895' 9-518" 1895' Intermediate 4950' 7" 4950' Production Liner 5368' 4-1/2" 10071' Perforation depth: Measured depth: See Well Schematic Plugs (measured) NA Junk (measured) 9915' TVD Burst Collapse 100' 3060 1500 1683' 6870 4750 3418' 8160 7020 8276' 8430 7500 True Vertical depth: See Well Schematic Tubing: (size, grade, and measured depth) 4-1/2" L-80 4703' Packers and SSSV (type and measured depth) Baker ZXP Liner 4703' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Fracture stimulated Tyonek Perfs at 8188'-8266' MD RBDMS BFL FEB 2 7 2006 Treatment descriptions including volumes used and final pressure: Placed 48,553 Ibs ot 20/40 Ottawa including 12.5% 12/20 Flex Sand Lightning 18006% KCL based fluid ramped 1-8 ppg. Frac Grad=0.75 psi/ft. Max Surf Pressure = 3700 psig. Gc-Function 2-4. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure NA 2916 0 0 NA 2149 50 0 15. Well Class after proposed work: Exploratory 0 Development [] 16. Well Status after proposed work: Oil 0 Gas [] WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Tubing Pressure 718 780 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Well Schematic Only Daily Report of Well Operations Frac Op Summary Service 0 GINJ 0 WINJ 0 WDSPL 0 SUndry Number or N/A if C.O. Exempt: 305-023 Contact James R. Thompson Printed Name James R. Thompson Title Sr. Completions Engineer ;2~ Phone 713-296-2730 ORIG¡r~AL Date 2124/2006 Submit Original Only -.;., Conductor 20" 133 ppf PE 10. !VID TVD Ism.. 0' 0' 100' !VID TVI) 47 ppf Ism.. 0' O· BTC 12·114" hole with 7" L·80 Bottom O· 4950· 0' 3418· ppg Lead'" 8-112'· hole with HYdrìl 521 TD: 10,115' MD 1 8320' TVI) .... ~ Formation Tops: Formation Depth IMD) Depth ITVD) Sterling N/A N/A Beluga 654' 652' Tyonek 4751' TD 10,115' 4703' 10071' 8276· 7" hole with +1. 690 sks 12.8 ppg - Legal Well Name: Common Well Name: PAXTON 1 PAXTON 1 2/16/2004 2/612005 08:00 - 08:30 08:30 - 10:30 0.50 SAFETY MTG_ CMPSTM 2.00 RURD_ ELEC CMPSTM 10:30 - 11:30 11 :30 - 13:30 1.00 RUNPU SLlK 2.00 RUNPUL SLlK CMPSTM CMPSTM 13:30 - 14:30 1.00 RUNPUL SLlK CMPSTM 14:30 - 16:30 2.00 RURD_ ELEC CMPSTM 16:30 - 19:00 2.50 RUNPU SLlK CMPSTM 19:00 - 20:00 1.00 RUNPU SLlK CMPSTM 20:00 - 21 :30 1.50 RURD_ ELEC CMPSTM 2/9/2005 06:00 - 18:00 12.00 RURD - STlM CMPSTM 2/10/2005 106:00 - 18:00 12.00 RURD_ STIM CMPSTM 2/11/2005 06:00 - 08:00 2.00 RURD_ STIM CMPSTM 08:00 - 08:30 0.50 SAFETY MTG_ CMPSTM 08:30 - 10:00 1.50 TEST_ EQIP CMPSTM 10:00 - 12:00 2.00 PUMP_ WTR_ CMPSTM 12:00 - 14:00 2.00 MIX_ FLD_ CMPSTM 14:00 - 15:00 1.00 PUMP_ FRAC CMPSTM 15:00 - 15:30 0.50 SAFETY MTG - CMPSTM 15:30 - 18:30 3.00 RURD_ STIM CMPSTM 18:30 - 19:30 1.00 RURD_ STIM CMPSTM plan to fish Expro wireline tool string and set Baker retrievable bridge plug. MIRU Pollard slickline. Airport Rental delivered 45/25 gas man lift. PWS and ASRC on location at 9 AM to continue rigging up test equipment for the frac. Perform twist test on slickline. MU skirted JDC fishing tool, spang jars, hydraulic jars, and two 5' weight stem to rope socket. Pulled slickline tool string into 3-1/2" Pollard lubricator. MU slickline BOP to top of 10' Expro 4-1/2" lubricator and BOP. MU 3-1/2" lubricator to top of slickline BOP. Had to replace two O-ring seals on Pollard lubricator to achieve good pressure test with 2600 psi WHP. RIH with fishing tool string on slickline and tagged top of fish at 9910' MD (below all perforations). Latched onto fish and worked spang and oil jars repeatedly. Tools moved about 1-2' which was probably the jar stroke on the junk basket fish. Fish did not move any more. Continued to jar without movement. Pulled a bind on the fish and held for 15 minutes without fish movement. Called Anchorage to discuss options. Decided to abandon fishing operations and proceed with running the retrievable bridge plug. Jarred down to release JDC pulling tool. . Fish is 30.9' overall length and includes from the top down: 1-7/16" OD Rope socket with 1" fishing neck (1.0'), 1-3/4" Swivel (1.2'), 1-11/16" tungsten weight bars (21'), 3-1/8" CCL (2.5'), 3" Junk Basket (5.0'), and 3.78" Gauge Ring (0.17'). POOH with slickline fishing tools. LD lubricator and tool string. Retied Expro rope socket while POOH. RDMO Pollard slickline. Baker Oil Tool delivered and MU a Baker 43B Wireline set retrievable BP (3.771" OD gauge and 3.97" OAL with 5K differential pressure rating) to #10 setting sleeve. Went to radio silence and armed slow-set charge. Pulled tool string into lubricator. Took lubricator to wellhead and pressure tested to 2600 psi WHP. RIH with retrievable bridge plug and correlated depth with liner top and casing collars on Expro CBL log. Set retrievable BP with center of element at 8300' MD. POOH with BP setting tool string. RDMO Expro wireline. Left well shut in overnight. Will blow down well to -700 psi line pressure in about 2 hours tomorrow morning to perform negative test on BP. Will then leave well open to SPIDR to monitor surface pressure buildup. OH --1-- Continue to RU frac truck lines and equipment. Move in Coil tubing unit and spot same. Continue to RU flowback iron and well testers lines. Mixed up two tanks of 6% KCL, heating same. SDFN . OH --1-- Completed RU of frac truck lines and equiment. Finished spotting CT equipment. Completed RU of flow back and well tester lines. Function tested tree saver and stabbed same into well. Connected frac lines to tree saver. Continued to heat KCL. Run all trucks to confirm operational. SDFN OH --1-- Start up trucks. Clean location of snow. Perform pre frac equipment checks. Hold pre job safety meeting. Discussed high pressure pumping and testing. Slips trips and falls. Emergency response. Snow. Near misses. Spills. Change out valve and Test well test flowback iron to 4000 psig. Good test. Test frac lines to 9500 psig. Good test. Load 7x4-1/2 annulus and pressure to 1000 psig (Annulus was full). Load 4-1/2" tubing with bbl 6% KCL. Perform injection test and monitor falloff to determine G function closure time. GOHFER analysis indicates an ISIP of 1935 for Frac Grad = 0.75 psi/ft. G function closure between 2 and 4 using two different test start times. Gel up frac tank for frac job. Line froze up requiring fluid transfer from on tank. Pumped frac into upper perfs at 8188'-8266' using Lightning 1800 system. Placed total of 48,553 Ibs of 20/24 ottawa (12.5% 12/20 Flex Sand) ramping from 1.0 ppg - 8.0 ppg at 25 BPM. Max Surface Pressure = 3700 psig. Tolalload volume = 430 bbls. Placed 100% of design. Hold RD safety meeting RD frac truck lines and valves. Mix up additional 6% KCL for CT work. Stroke tree saver into up postion and close master valves. Remove tree saver from well. Printed: 2/24/2006 9:58:19 AM MIRU CT pump van, nitrogen pump truck and transport. RU lines. Install BOPs and injector head. Test lines to 200/4500 psig. Good test. Pump pig through coil tubing. Trouble shoot CT counter. Replace same with new one. Test BOPs 200/4500 psig. Good test. Remove injector head. Recover pig. Install dimple on tool and BHA consisting of dimple on connector, straight bar, double check valve, dual circ sub, and bull nose nozzle. RIH with CT at min fluid rate of 1-1.5 bpm t07500' CTM. Take test pull. Continue RIH to 8000' CTM. Increase fluid rate to 2 bpm and RIH to 8150' CTM. Wash down through perforations and tag plug at 8286' CTM. Tag was solid with no washoff. PU to 8250' CTM and wash back down tagging plug again at 8286' CTM. PU to 8284' CTM Start circulating bottoms up. OH --1-- Finish CBU at 8284' CTM above plug at 8286' CTM PU above perfs and shut in well while vac trucks transfer KCL from returns tank to suction tank. Open well and establish circulation. RIH and tag plug at 8286 CTM. Drop ball and seat same in dual circ sub and POOH reverse washing to 2000' CTM Finish colling down N2 pump. Shutdown fluid pump and start N2 at 650 scfm. Start RIH with CT displacing KCL wih N2. Follow back pressure chart as fluid is displaced to increase wellhead backpressure while RIH to plug at 8286' CTM. Tag plug at 8286' CTM. Verified proper fluid recovery from tubing. Ran out of N2. POOH with CT. Close swab and master valves. Final SITP = 2250 psig N2 equaling 2810 psig BHP at plug. Blowdown CT. Remove injector head and secure same. Ensure all lines blown dry. Install tree cap and SDFN. OH --1-- Arrive on location. Start up trucks. Get work permit from operator. Spot N2 transport. Hold prejob safety meeting. Discuss cold weaqther ops. Slips, trips, and falls. Emergency 1 escape plans. Crane signals and working around loads. Radio communications. Well work plan and Baker retrieving tool and jar operation. Continue RU CT equipment. Remove snow from work area. Heat up KCL tank pipng manifold and lubricator sections. Make up 20' of CT lubricator for plug retrieving BHA. Cut CT and make up Baker slip type connector. Test pull same to 15,OOOlbs. Good test. Conitnue making up plug retrieval Baker BHA consisting of retrieving overshot, XO, disconnect sub, XO, jars, XO, double check flapper, slip type CT connector. Install lubricator on injector head and pick BHA. Stab lubricator and injector head on well. Pressure test all surface CT lines, valves, and equipment to 3000 psig with N2. Attempt to RIH with CT. Counld not get past well's upper master valve. Pick up into lubricator and work vlave closed and open. Could only get 28 of 29.5 turns. Rih with CT and hung up in valve but then fell through. Pick back up into lubricator. Discuss valve problem. Suspect fluid from prio circulating got into valve body and froze overnight with cold temps. Put heat on upper mvaster valve and let get warm. Operate valve after heating full 29.5 turns close and open. RIH with CT and plug retrieving BHA. (No problems going through tree valves) RIH to 8000' CTM and start N2 at 500 scfm and get PU wt. of 10000 Ibs.. RIH and tag bridge at 8255' CTM. Could not work past. PU to 8230' CTM and pump 20 bbls of 6% KCL followed by N@ at 2500 scfm (2 BPM). RIH and wash past 8255' CTM down to plug at 8286' CTM. Set down over fish neck with 2000 Ibs. and wash top of plug with remaining fluid in CT. Set down total of 5000 Ibs to equalize plug. Wait 10 min and then PU and shear plug with 5000 Ibs pull. PU to 8270' CTM with 2-4000 Ib drag. Wait another 10 min to allow packing elements to relax. Drop back down to 8320' CTM Plug latched and free. 1.50 RUNPUL COIL CMPSTM POOH with CT and plug with 1-3000 Ibs drag. Maintaining WHP of +1-2300 psig and N2 at 1900 scfm to 4701' CTM where plug became stuck. 1.50 WORK PIPE CMPSTM Work CT at 4701'. Break free going down to 4713' CTM. PU. Plug stuck at 4701' CTM. Break free down and go to 4753' CTM. PU and plug stuck at 4721' CTM. Break free down and got to 4753' CTM. PU and plug stuck at 4733' CTM. Losing ground andn running low on N2. Shut off N2 and start fluid in hole. Break free down and go to 4900' CTM. PU and plug stuck at 4835' CTM. Could not break free down. Plug stuck at 4835' CTM. Work CT, jars not working. Continue to work Printed: 2/24/2006 9:58:19 AM Legal Well Name: Common Well Name: PAXTON 1 PAXTON 1 19:30 - 02:30 02:30 - 05:30 CMPSTM 05:30 - 06:00 0.50 CIRC_ CFLD CMPSTM 2/12/2005 06:00 - 06:30 0.50 CIRC_ CFLD CMPSTM 06:30 - 08:30 2.00 MIX_ FLD_ CMPSTM 08:30 - 11 :00 I 2.50 RUNPUL COIL CMPSTM 11 :00 - 11 :30 0.50 RURD_ COIL CMPSTM 11:30 -14:30 3.00 RUNPUL COIL CMPSTM 14:30 - 15:30 1.00 RUNPUL COIL CMPSTM 15:30 - 17:00 1.50 RURD_ COIL CMPSTM 2/13/2005 08:00 - 08:45 0.75 RURD_ COIL CMPSTM 08:45 - 09:30 0.75 SAFETY MTG - CMPSTM 09:30 - 14:00 4.50 RURD - COIL CMPSTM 14:00 - 14:30 0.50 RUNPUL COIL CMPSTM 14:30 - 15:30 1.00 INSPCT WLHD CMPSTM 15:30 - 18:30 3.00 RUNPUL COIL CMPSTM 18:30 - 20:00 20:00 - 21 :30 Spud Date: 2/16/2004 . . Legal Well Name: PAXTON 1 Common Well Name: PAXTON 1 20:00 - 21 :30 1.50 WORK PIPE CMPSTM 21 :30 - 23:30 2.00 RUNPUL COIL CMPSTM 23:30 - 01 :30 2.00 RURD_ COIL CMPSTM 01 :30 - 06:00 4.50 FLOW_ TEST CMPSTM 2/14/2005 13:00 - 16:30 3.50 RURD_ COIL CMPSTM 16:30 - 19:30 19:30 - 20:30 I I I 20:30 - 22:00 22:00 - 23:00 23:00 - 01 :30 2/15/2005 01 :30 - 06:00 06:00 - 15:00 15:00 - 06:00 2/17/2005 08:00 - 08:30 08:30 - 10:00 10:00 - 11:00 11 :00 - 11 :30 11:30-18:00 CT and jars starting hitting. Got fluid to surface. PU and pulled to 17000 Ibs and jars hit freeing plug. POOH with CT. No further sticking problems. Closed swab and upper master valves. Pump 10 bbls methanol and chased same with N2 to blow dry all CT and lines. Remove injector head and lubricator off BOPs. Lower CT. Recovered 100% of plug. Break down BHA and lubricator. Secure injector head and install night cap. Secure CT equipment. Release CT crews. Monitor well for production. Production had to trouble shoot ESD system leak prior to opening well. Open well up at 0130 abd FTP rapicidly decreased from 1300 psig to 0 psig in 30 min. Well dead at 0200. As of 0600 well still dead. OH --1-- Arrive location and start trucks to warm up. Obtain work permit. Hold PJSM. RU injector head and make up Jet in BHA consisting of chisel point jet nozzle, dual check valve straight bar and dimple on connector. Stab injector head and pressure test lines and equipment to 3000 psig. Open swab valve and attempt to openup upper master valve. Upper maste valve only turning 28 turns. Apply heat to valve and let warm up. Operate valve and get all 29.5 turns. 3.00 RUNPU COIL CMPSTM RIH with CT Start N2 at min rate of 400 scfm at 1500' CTM. Increase N2 to 750 scfm at 6250' CTM. Tag up at 9377' CTM w/10001bs. PU and had 2000 Ibs over PU wt to get free. Set back down and try to wash. No success put 2000 Ibs down wt. PU and pulled 4000 Ibs over PU wt to get free. 1.00 JET _ N2_ CMPSTM PU to 9340' CTM and jet well with N2 at 750 scfm Increase N2 to 1000 scfm and ease down attempting to wash fill. No wash off. Put 4000 Ibs down wt and PU and get free with 8000 Ibs pull over PU wt. Discuss counter problem and agree that counter is off and that actual tag depth is 9934' CTM and that CT was going alongside wireline fish. Total fluid recovered = 150 bbls. Getting no more fluid out of well and no signs of any gas. PU to 8147' CTM (counter depth = 7603') nad decrease N2 to 400 scfm. Allowed wellhead pressure to decrrease to 60 psig. No signs of gas of fluid. RIH to 9934' CTM (9377' counter depth) and increase N2 to 750 scfm to see if any fluid had entered wellbore. No evidence of any fluid. POOH with CT to surface. Confirm that counter was off 547'. RD injector head and secure location. Release CT crews and turn well over to PWS. Open well to atmoshpere and monitor same. FTP gradually increased to 160 psig flowing gas as of 0600 hrs 2/14/2005. OH --1-- Unload well through open choke to atmoshpere. Well unloading about 34 bwpd with FTP = 140 psig. Put well into test separator with separator pressure 50-60 psig and test well. As of 0530 hrs 2/15/05 well making 1.7 mmcfd, 42 bwpd, on an open choke with a 188 psig FTP. OH --1-- Held PJSM with Pollard, PWS, and MOC personnell to review potential hazards and operational plan. Reviewed work permit. Well flowing 2.0 MMscfd at 210 psi FTP. Hauled in and layed out plywood around wellhead to reduce slip hazard. 1.50 JET_ N2_ CMPSTM 1.00 JET_ N2_ CMPSTM 2.50 RUNPU COIL CMPSTM 4.50 FLOW_ TEST CMPSTM 9.00 FLOW_ TEST CMPSTM 15.00 FLOW_ TEST CMPSTM 0.50 SAFETY MTG_ CMPSTM 1.50 RURD_ SLlK CMPSTM 1.00 RUNPU SLlK 0.50 RUNPUL SLlK 6.50 RUNPUL SLlK CMPSTM I CMPSTM CMPSTM Spud Date: 2/16/2004 . . Rain-for-Rent hauled off two 500-bbl tanks. Veco hauled off about 190 bbls 6% KCL water to KGF. Airport Rental picked up air compressor and light plant. McLane's on pad surveying. BJ Services hauled off fluid van. Veco roustabouts broke out and racked some chicksan. MIRU Pollard slickline to run flowing gauge ring and flowing pressure-temperature gradient across alii perforated intervals. MU pump-in tee and WL valve to tree cap. PU 2.30" OD gauge ring, jars, anti-blowup tool, and lead stem into lubricator. Took lubricator to wellhead and pressure tested with 210 psi WHP. RIH with 2.30" gauge ring to 9660' MD while well flowing to PWS testers. POOH and LD gauge ring. MU tandem pressureltemperature gauges to tool string. I RIH at 60 fpm to 100' above top perf at 8188' MD while well flowing at 2.1 MMscfd and 210 psi FTP. Took 5 minute bench at 8088' MD. Continued RIH at 30 fpm through all perf intervals to 9658' MD (100' below bottom perf). Tagged up lightly Printed: 2/24/2006 9:58:19 AM Legal Well Name: PAXTON 1 Common Well Name: PAXTON 1 11 :30 - 18:00 6.50 RUNPUL SLlK CMPSTM 18:00 - 19:00 1.00 RURD_ SLlK CMPSTM 2/22/2005 08:00 - 08:30 0.50 SAFETY MTG_ CMPSTM 08:30 - 10:30 2.00 RURD_ ELEC CMPSTM 10:30 - 11 :00 0.50 RUNPU ELEC CMPPRF 11 :00 - 12:00 1.00 REPAIR EQIP CMPPRF 12:00 - 13:00 1.00 RUNPUL ELEC CMPPRF 13:30 - 14:00 0.50 RURD - ELEC CMPPRF 2/24/2005 08:00 - 08:30 0.50 SAFETY MTG_ CMPSTM 08:30 - 09:30 1.00 RUNPU ELEC CMPPRF Spud Date: 2/16/2004 09:30 - 13:00 I 3.50 RUNPUL ELEC CMPPRF 13:00 - 14:00 1.00 PERF _ CSG_ CMPPRF 2/26/2005 14:00 - 08:00 - 08:30 I RURD ELEC 0.50 SAFETY MTG_ 0.50 RURD_ ELEC CMPSTM CMPPRF CMPSTM 08:30 - 09:00 09:00 - 16:30 7.50 WAlTON EalP I CMPSTM 16:30 - 17:00 0.50 I RUNPUL ELEC I CMPPRF and worked through 9123' MD. Took 5 minute bench at 9658' MD. PUH at 30 fpm and took 5 minute bench at 8088' MD. POOH at 60 fpm. Note: Pulled tight and worked through 8225' MD (might have been small fluid slug activating anti-blowup tool while passing perfs). RDMO Pollard slickline. Downloaded data is good. Will continue to flow test. OH --1-- Held PJSM with Expro wireline, PWS, and MOC personnel to discuss potential hazards and operational plan to reperforate Tyonek interval. PWS flowed well at 2.1 MMscfd and 10-15 BWPD at 188-195 psi FTP since 2/16/2005. Choked well back to 1250 psi FTP at 0700 hrs to achieve 60% underbalance for perforating with methane in wellbore. MIRU Expro wireline to reperforate Tyonek interval, 9542'-9558' MD. Armed firing head for PX-1. RIH with 17' long 3.375" OD perforating gun loaded 16' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF on CCL. Flowed at 1250 psi while running in the hole. At 11 :00 hrs diverted flow from vent stack to sales maintaining 1250 psi FTP and about 1.7 MMscfd. Expro correlated depth with liner top packer at 4703' and RIH to 7200' MD. Noticed oil leaking from greasehead pump. Spent 0.5 hrs trying to pinpoint source of leak and repair the grease pump. Could not repair pump. Leak contained to bed of crane truck-no spill. POOH with guns to repair grease pump. LD and disarmed perforating guns. RD Expro. Took Expro crane truck in for grease injector repair. Left wireline unit and lubricator on location. Left well flowing to sales through PWS equipment at 1250 psi FTP and 1.8 MMscfd. OH --1-- Held PJSM with Expro wireline, PWS, and MOC personnel to discuss potential hazards and operational plan to reperforate Tyonek interval. PWS flowed well to sales at 1.7 MMscfd and 0 BWPD at 1200 psi FTP since 2/21/2005. Armed firing head for PX-1. RIH with 17' long 3.375" OD perforating gun loaded 16' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF on CCL. Flowed to sales at 1200 psi while running in the hole. Took lubricator to wellhead and pressure tested to 1200 psi with WHP. Expro grease injector still leaking oil but at a manageable rate. RIH with 3.375" OD perforating gun loaded 16' with SDP-3125-311NT3, 25 gm. charges, 6 SPF on CCL. Flowed at 1200 psi while running in the hole. Correlated depth with liner top packer. RIH to tie in again at short joint around 8500' MD and CCL began working sporadically. Decided to continue RIH to try to correlate depth while Expro went to their shop to get a Gun-GR. CCL working again. Correlated depth with Reeves Array Induction open hole log run Mar-09-2004 and Expro CBL run Apr-09-2004. Shut well in and reperforated 9542-9558' KB with 1200 psi WHP. POOH for 10 minutes with well shut in. Pressure built from 1200 to 1360 psi in 10 minutes. Began flowing well again at 1200 psi and 1.7 MMscfd. Finished POOH with gun - all shots fired and round. RDMO Expro perforators. Plan to flow well to sales maintaining 1200 psi FTP overnight. OH --1-- Held PJSM with Expro wireline, PWS, and MOC personnel to discuss potential hazards and operational plan to perforate Tyonek interval. PWS flowed well to sales at 1.7 MMscfd and 0 BWPD at 1200 psi FTP since 2/23/2005. Spotted crane truck with repaired grease injector (leaking less oil but has engine blowby trouble). Warmed up wireline unit. Began laying out GR-CCL when alternator siezed on Expro crane truck engine. Serpentine belt melted and broke. Removed battery leads and then disconnected and removed alternator on Expro crane truck engine. Waited for Expro to pickup and install a replacement alternator and fan belt. . . While waiting on Expro, began reducing FTP to 950 psi to achieve 60% underbalance when perforating new Tyonek interval, 7570-7588' MD. Recovered 1 bbl water almost immediately. Production somewhat stabile at 2.1 MMscfd and 950 psi FTP after about 5 hours. Armed firing head for PX-1 to 20' perf gun. Took lubricator to wellhead and pressure tested to 950 psi with WHP. Printed: 2/24/2006 9:58:19 AM . . Alaska Region Domestic Production Nt MARATHON , Marathon I Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/564-6305 Fax 907/564-6489 February 21, 2006 Winton Aubert AOGCC 333 West ih Ave Suite 100 Anchorage, AK 99501 Dear Mr. Aubert: Attached and submitted for your records is the Form 10-404 to add Tyonek perforations in the Paxton #1 well. Also attached for your records is the current well schematic and operational history of the work performed. The well is currently an active Tyonek formation producer. If you would like any other information, please contact me at 394-3060 or kdwalsh@marathonoil.com. Sincerely, lÚM-b.\AJ~. Ken D. Walsh Senior Production Engineer Enclosures Ir '....v....f V ..:;U . STATE OF ALASKA A FEB 2 1 2006 ALA Oil AND GAS CONSERVATION COM~ON REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commission Anchorage 1. Operations Abandon U RepairWell U Plug Perforations U StimulateU Other U Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. Shutdown D Perforate 0 Re-enter Suspended Well D 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: Marathon Oil Company Development 0 ExploratoryD 204-010 3. Address: P. O. Box 1949, Kenai, AI( 99611-1949 StratigraphicD ServiceD 6. API Number: 50-133-20535-00 7. KB Elevation (ft): 153' 9. Well Name and Number: Ninilchik Unit, Paxton #1 8. Property Designation: 10. Field/Pool(s): ADL-359242 + 384372 11. Present Well Condition Summary: Ninilch ik/Beluga- Tyonek Total Depth measured 10115' MD feet true vertical 8320' TVD feet Effective Depth measured 9946' feet true vertical 8152' feet Casing Length Size MD Structural Conductor 100' 20" 100' Surface 1895' 9-5/8" 1895' Intermediate 4950' 7" 4950' Production Liner 5368' 4-1/2" 10071' Plugs (measured) 0 Junk (measured) 0 TVD Burst Collapse NIA NIA 100' 3060 psi 1500 psi 1683' 6870 psi 4750 psi 3418' 8160 psi 7020 psi 8276' 8430 psi 7500 psi Perforation depth: Measured depth: 6026-6036',6068-6088',6118-6136', 6152-6186', 6299-6319', 6354-6360', 6682-6702', 6738-6758', 6948-6968' 7162-7182',7438-7458',7794-7814' True Vertical depth: 4297-4306',4335-4354',4382-4398', 4413-4445', 4549-4568', 4600-4606', 4904-4924', 4958-4976', 5154-5161' 5373-5393',5648-5668', 6004-6024' Tubing: (size, grade, and measured depth) 4-1/2" L-80 4703' Packers and SSSV (type and measured depth) Baker ZXP Liner Packer@ 4703' 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft FEB 22 2006 Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: 0 Subsequent to operation: 0 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 1317 3 NIA 1785 5 NIA 15. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: oilD Gas 0 WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl Tubing Pressure 813 785 Service D Attached Contact Ken D. Walsh GINJ D WINJ D WDSPL D Isunëò;e: ~~ Exempt: Jlau ~/.uJ,/óÞ Printed Name Ken D. Walsh f\ n Signature {~b~ W ~ Title Senior Production Engineer Phone 907-394-3060 Date 2/21/2006 Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only Wildcat Field 686' & 2921' FEL Sec. 13-T1S-R14W Ai TD: 10,115' MD / 8320' TVD Formation Tops: Formation Depth (MD) Depth (TVD) Sterling N/A N/A Beluga 654' 652· Tyonek 4751' 3295' TO 10,115' 8320' ..... Conductor 20" K-55 133 ppf PE I2rL Bottom MD 0' 100' TVD 0' 100' JII '10. Surface Casinq 9-5/8" 47 ppf I2rL MD 0' TVD 0' L·ao Bottom 1895' 1683' BTC 12-1/4" hole with +/. 516sks 12 ppgcement Intermediate Casinq 7" 29 ppf L-80 I2rL §Q!!Q!!l MD 0' 4950' TVD 0' 3418· 8-1/2" hole with +/- 180 sks 12.5 ppg Lead + 110 sks 13.5 ppgTail .... ~ ::¡¡ Tagged Fill at 9606' with 2.25" 8/24/2005. Ý Tagged Fill at 9562' with Expm P·T too! on 11/01/2005. ~V j Li ney 4-1/2" 12.6 ppf I2rL MD 4703· TVD 3266· 7" hole with +/- 690 sks 12.8 ppg L-80 Hydril 521 §Q!!Q!!l 10071' 8276' . . Marathon Oil Company Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date PAXTON 1 PAXTON 1 RECOMPLETION NABORS DRILLING NABORS DRILLING Sub Code Phase 8/25/2005 8/26/2005 9/22/2005 9/23/2005 07:45 - 08:20 08:20 - 09:30 09:30 - 11 :00 11 :00 - 12:30 12:30 - 14:00 14:00 - 14:30 0.58 SAFETY MTG_ WRLN 1.17 RURD_ ELEC WRLN 1.50 RURD_ ELEC WRLN 1.50 RUNPUL ELEC WRLN 1.50 RUNPUL ELEC WRLN 0.50 RURD_ ELEC WRLN Start: Rig Release: Rig Number: 8/25/2005 3/14/2004 129 Spud Date: 2/16/2004 End: Group: 08:00 - 08:20 0.33 SAFETY MTG - WRLN 08:20 - 09:00 0.67 RURD - ELEC WRLN 09:00 - 11 :45 2.75 RUNPUL ELEC WRLN 11 :45 - 13:20 1.58 RUNPUL ELEC WRLN 13:20 - 14:30 1.17 RURD_ ELEC WRLN 08:00 - 08:30 0.50 SAFETY MTG_ WRLN 08:30 - 10:20 1.83 RURD_ ELEC WRLN 10:20 - 11 :30 1.17 RUNPUL ELEC WRLN 11 :30 - 12:30 1.00 RUNPUL ELEC WRLN 12:30 - 13:30 1.00 RUNPUL ELEC WRLN 13:30 - 14:30 1.00 RURD_ ELEC WRLN 07:30 - 08:00 0.50 SAFETY MTG - WRLN 08:00 - 08:45 0.75 RURD - ELEC WRLN 08:45 - 09:10 0.42 RURD - ELEC WRLN 09:10 - 10:10 1.00 RUNPUL ELEC WRLN 10:10 - 10:50 0.67 RUNPUL ELEC WRLN 10:50 - 10:55 0.08 RURD_ ELEC WRLN 10:55 - 11 :30 0.58 RUNPUL ELEC WRLN 11 :30 - 12:30 1.00 RUNPUL ELEC WRLN 12:30 - 12:45 0.25 RURD - ELEC WRLN 12:45 - 13:40 0.92 RUNPUL ELEC WRLN 13:40 - 14:15 0.58 RUNPUL ELEC WRLN 14:15 - 14:25 0.17 RURD_ ELEC WRLN 14:25 - 15:05 0.67 RUNPUL ELEC WRLN 15:05 - 15:45 0.67 RUNPUL ELEC WRLN 15:45 - 15:55 0.17 RURD_ ELEC WRLN 15:55 - 16:35 0.67 RUNPUL ELEC WRLN 16:35 - 17:05 0.50 RUNPUL ELEC WRLN x' DescriptiQn of Operations . . ". ',. .,'.. ~,' '. ; ',.. '.. ',' . . '. ".. Filled out Work Permit and Held PJSM. Arrive location and RU Expro eline. Call Vetco to grease leaking swab. Continue RU. RIH 2.25" drift. Tag TO at 9606. POH drift. Well shut in 2 times slugging water. Produced 17 Bbls water from swabbing with drift. PLC locked up and wouild not allow reopening sales line. Abort PIT log to repair PLC and allow well to stabilize. Filled out Work Permit and Held PJSM. Arrive location and RU Expro eline. RIH with SRO PIT tools. Log PIT from 9600' - 7150'. POH. Record gradient at 7000' and every 1000' out of hole. RD Expro and release. Filled out Work Permit and Held PJSM. Arrive location and RU Expro eline. RIH with SRO PIT tools. record gradient every 100'. Fluid level at 146'. Log PIT from 7000' to 9600'. POH. RD Expro and release. Filled out Work Permit and Held PJSM. Arrive location and RU Expro eline. Arm 3-3/8", 20' gun #1. RIH Gun #1. Tie in to ZXP packer and shoot 6166 - 6186' KB (CBL 4' off open hole depth). Log off. POH. Arm 3-3/8", 14' gun #2. RIH Gun #2. Tie in to ZXP packer and position gun. Gun misfired. POH. Change out CCL and PX-1 Safe det system RIH Gun #2. Tie in to ZXP packer and shoot 6152 - 6166' KB (CBL 4' off open hole depth). Log off. POH. Arm 3-3/8", 20' gun #3. RIH Gun #3. Tie in to ZXP packer and shoot 6068 - 6088' (CBL 4' off open hole depth). Log off. POH. Arm 3-3/8", 10' gun #4. RIH Gun #4. Tie in to ZXP packer and shoot 6026 - 6036' (CBL 5' off open hole depth). Log off. POH. NOTE: Gun Runs #1 through #3 increased the production rate by about 200 Mcfd above the 1.5 MMscfd initial rate before today's perforating. The bulk of the production rate increase, about 2.1 MMscfd incremental, was noted after perforating 6026'-6036' MD. It is not apparent as to which new perf interval(s) increased the water rate by 12 BWPD. RD Expro and release. Expro Wireline on location. Obtain a work permit, held PJSM and discussed operational plan and hazards. Well produced 3.426 MMscfd and 15 BWPD yesterday at 823 psig FTP. MIRU Expro perforators. MU lubricator and grease head. Install WL valve and pump-in tee on top of swab valve. Pressure tested lubricator with WHP. Armed 21' 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD 17:05 - 18:00 0.92 RURD ELEC WRLN 10/4/2005 07:00 - 07:30 0.50 SAFETY MTG_ CMPPRF 07:30 - 09:00 1.50 RURD - ELEC CMPPRF 09:00 - 10:30 1.50 RUNPUL ELEC CMPFLW Printed: 2/20/2006 7:15:38 AM . . Marathon Oil Company . Operations Summary Report 1.50 RUNPUL ELEC CMPFLW perforating gun loaded 20' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. 0.50 PERF _ CSG_ CMPFLW Correlated depth with CBL and Array Induction logs (8 ft correction to open hole logs). SWI and perforated 7794-7814' MD with 1000 psi surface WHP. 1.00 RUNPUL ELEC CMPFLW POOH with guns for 10 minutes and SICP increased to 1220 psi. Opened well to sales while continuing to POOH with gun. Bled pressure off of lubricator. LD perf gun. All shots fired and round. Swabbed about 4 bbls. water to surface with gun. Production at 3.836 MMscfd at 830 psig FTP. 0.50 RUNPUL ELEC CMPFLW Vetco on location to grease leaking swab valve. Armed 21' 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 20' with SDP-3125-311NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. 0.50 PERF _ CSG_ CMPFLW Correlated depth with CBL and Array Induction logs (6 ft correction to openhole logs). SWI and perforated 7438-7458' MD with 1000 psi surface WHP. 1.00 RUNPUL ELEC CMPFLW POOH with guns for 10 minutes and SICP increased to 1225 psi. Opened well to sales while continuing to POOH with gun. Bled pressure off of lubricator. LD perf gun. All shots fired and round. Swabbed no water to surface with gun. Production at 3.8 MMscfd at 830 psig FTP. 1.00 RUNPUL ELEC CMPFLW Armed 21' 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 20' with SDP-3125-311NT3, 25 gm. charges, 6 SPF, and PX-1 firing head on CCL. 0.50 PERF _ CSG_ CMPFLW Correlated depth with CBL and Array Induction logs (4 ft correction to openhole logs). SWI and Reperforated 7162-7182' MD with 950 psi surface WHP. 0.50 RUNPUL ELEC CMPFLW POOH with guns for 10 minutes and SICP increased to 1175 psi. Opened well to sales while continuing to POOH with gun. Bled pressure off of lubricator. LD perf gun and lubricator. All shots fired and round. Swabbed about 2 bbls. water to surface with gun. Production at 3.9 MMscfd at 830 psig FTP. LD WL valve and flow tee. Install tree cap. Rig back Expro wireline. Left well flowing to sales at 820 psi LP. Plan to continue perforating tomorrow. Expro Wireline on location. Obtained a work permit, held PJSM and discussed operational plan and hazards. Well produced 3.55 MMscfd and 13 BWPD yesterday at 820 psig FTP. MIRU Expro perforators. MU lubricator and grease head. Install WL valve and pump-in tee on top of swab valve. Pressure tested lubricator with WHP. Armed 21' 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 20' with SDP-3125-311NT3, 25 gm. charges, 6 SPF, and 008 firing head on CCL. Correlated depth with CBL and Array Induction logs (2 ft correction to open hole logs). SWI and perforated 6948-6968' MD with 900 psi surface WHP. POOH with guns for 10 minutes and SICP increased from 900 to 1150 psi. Opened well to sales while continuing to POOH with gun. Bled pressure off of lubricator. LD perf gun. All shots fired and round. Swabbed about 2 bbls. water to surface with gun. Production at 3.74 MMscfd at 820 psig FTP. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PAXTON 1 PAXTON 1 RECOMPLETION NABORS DRILLING NABORS DRILLING Hour~i..Code ·î6~be Phase From - To 10/4/2005 09:00 - 10:30 10:30 - 11 :00 11 :00 - 12:00 12:00 - 12:30 12:30 - 13:00 13:00 - 14:00 14:00 - 15:00 15:00 - 15:30 15:30 - 16:00 16:00 - 17:00 1.00 RURD - CMPFLW 10/5/2005 08:00 - 08:30 0.50 SAFETY MTG_ CMPPRF 08:30 - 09:30 1.00 RURD - ELEC CMPPRF 09:30 - 10:00 0.50 RUNPUL ELEC CMPFLW 10:00 - 10:30 0.50 PERF _ CSG_ CMPFLW 10:30 - 11 :00 0.50 RUNPUL ELEC CMPFLW of4 Start: Rig Release: Rig Number: Spud Date: 2/16/2004 End: Group: 8/25/2005 3/14/2004 129 Description of Operations Printed: 2/20/2006 7:15:38 AM . . Marathon Oil Company . Operations Summary Report legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - 10/5/2005 11 :00 - 11 :30 11 :30 - 12:00 12:00 - 13:00 13:00 - 14:00 14:00 - 14:30 14:30 - 15:00 15:00 - 16:30 10/6/2005 08:00 - 08:30 PAXTON 1 PAXTON 1 RECOMPlETION NABORS DRilLING NABORS DRilLING C Sub Hours ;;~de Cqqe Start: Rig Release: Rig Number: 8/25/2005 3/14/2004 129 Spud Date: 2/16/2004 End: Group: Phase 0.50 RUNPUL ELEC CMPFLW Armed 21' 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 20' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF, and 008 firing head on CCL. 0.50 PERF _ CSG_ CMPFLW Correlated depth with CBL and Array Induction logs (no correction to open hole logs). Unable to shut well in completely because choke appeared to be partially plugged. Perforated 6738-6758' MD with 900 psi FTP (rate at about 1 MMscfd). 1.00 RUNPUL ELEC CMPFLW POOH with guns for 10 minutes and FTP increased from 900 to 975 psi. Opened well to sales while continuing to POOH with gun. Bled pressure off of lubricator. LD perf gun. All shots fired and round. Swabbed about 10 bbls. water to surface with gun. Production at 3.97 MMscfd at 820 psig FTP. 1.00 RUNPUL ELEC CMPFLW Armed 21' 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 20' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF, and 008 firing head on CCL. 0.50 PERF _ CSG_ CMPFLW Correlated depth with CBL and Array Induction logs (1ft correction to openhole logs). SWI (choke cleared of debris). Perforated 6682-6702' MD with 850 psi FTP. 0.50 RUNPUL ELEC CMPFLW POOH with guns for 10 minutes and FTP increased from 850 to 1150 psi (1st 200 psi gain appeared to occur much more quickly than those of the last two days). Opened well to sales while continuing to POOH with gun. Bled pressure off of lubricator. LD perf gun. All shots fired and round. Swabbed no bbls. water to surface with gun. Production at 4.03 MMscfd at 820 psig FTP. 1.50 RURD_ ELEC CMPFLW LD WL valve and flow tee. Install tree cap. Rig back Expro wireline. Left well flowing to sales at 820 psi LP. Plan to continue perforating tomorrow. 0.50 SAFETY MTG_ CMPPRF Expro Wireline on location. Obtained a work permit, held PJSM and discussed operational plan and hazards. Well produced 3.64 MMscfd and 14 BWPD yesterday at 825 psig FTP. Discussed safety concems with high winds in AM. Decided to rehead wireline while monitoring wind strength. Reheaded wireline. Cancelled job for today due to high gusty winds. Will try again tomorrow. Wait on Expro wireline. Crew delayed due to waiting on highway construction. Expro Wireline on location. Obtained a work permit, held PJSM and discussed operational plan and hazards. Well produced 3.56 MMscfd and 11.3 BWPD yesterday at 821 psig FTP. MIRU Expro perforators. MU lubricator and grease head. Install WL valve and pump-in tee on top of swab valve. Pressure tested lubricator with WHP. Armed 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 6' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF, and 008 firing head on CCL. Correlated depth with CBL and Array Induction logs (2 ft correction to open hole logs). SWI and perforated 6354-6360' MD with 850 psi surface WHP. POOH with guns for 10 minutes and SICP increased from 850 to 1150 psi. Opened well to sales while continuing to POOH with gun. All shots fired and round. Swabbed no water to surface with gun. Production at 3.51 MMscfd at 820 psig FTP. 0.75 RUNPUL ELEC CMPFLW Armed 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD 08:30 - 09:30 1.00 RURD - ELEC CMPPRF 1017/2005 08:00 - 09:00 1.00 WAlTON EQIP CMPPRF 09:00 - 09:30 0.50 SAFETY MTG_ CMPPRF 09:30 - 10:00 0.50 RURD - ELEC CMPPRF 10:00 - 10:30 0.50 RUNPUL ELEC CMPFLW 10:30 - 10:45 0.25 PERF - CSG_ CMPFLW 10:45 -11:15 0.50 RUNPUL ELEC CMPFLW 11:15-12:00 Printed: 2/20/2006 7:15:38 AM . . . Marathon Oil Company Operations Summary Report 0.75 RUNPUL ELEC CMPFLW perforating gun loaded 18' with SDP-3125-311NT3, 25 gm. charges, 6 SPF, and 008 firing head on CCL. 0.50 PERF _ CSG_ CMPFLW Correlated depth with CBL and Array Induction logs (2 ft correction to openhole logs). SWI and perforated 6299-6319' MD with 850 psi surface WHP. 0.50 RUNPUL ELEC CMPFLW POOH with guns for 10 minutes and SICP increased from 850 to 1150 psi. Opened well to sales while continuing to POOH with gun. All shots fired and round. Swabbed about 4 bbls. water to surface with gun. Production at 3.55 MMscfd at 830 psig FTP. 0.50 RUNPUL ELEC CMPFLW Armed 3-3/8" carrier and took lubricator to tree. RIH with 3.375" OD perforating gun loaded 20' with SDP-3125-311NT3, 25 gm. charges, 6 SPF, and 008 firing head on CCL. 0.25 PERF _ CSG_ CMPFLW Correlated depth with CBL and Array Induction logs (3 ft correction to openhole logs). SWI and perforated 6118-6136' MD with 850 psi surface WHP. 0.75 RUNPUL ELEC CMPFLW POOH with guns for 10 minutes and SICP increased from 850 to 1150 psi. Opened well to sales while continuing to POOH with gun. All shots fired and round. Swabbed no water to surface with gun. Production at 3.76 MMscfd at 830 psig FTP. RDMO Expro perforators. Left well to sales. Project is complete. MI Equipment spot up. Held PJSM and discussed procedure with operator. Obtained a work permit and safety issues. Spot up equipment, shut in swab valve. Continue with rigging up wireline unit. Make up tool string and rig up the wireline BOP's. WHP= 793 psig, 1, 700 MCFP day rate. Open well up to lubricator, no leaks on lub. RIH with tool string. Capacidence tool showed water at 1000' KBD, no real changes on the temperature and pressure tool till it reached the bottom set of perforations. Tool string set down at 9562' KBD, which is around the bottom set of perforations. PUH to 5300' KBD, tool stopped working dropped down to 5500' KBD, PU hole tool back working. Continue with temperature survey. PU tool to 5300' make 5 minute stop, WHP= 1218 psig, 96 deg. F., PUH to next stop at 5000' KBD, WHP = 1193 psig @ 93 deg. F. PUH to 4000' KBD, WHP = 1116 psig @ 83 psig. After 5 minutes PUH to 3000' KBD, 1040 psig @ 75 deg F Wire at 2000' KBD, WHP =955 psig, 67 deg. F., POOH PU to 1000' KBD, WHP= 851 psig 53 deg. F. OOH with tool string, WHP= 802 psig, , Lay down tools. RD wireline unit. Clean up around wellhead. Finished RD Expro wireline unit, left lease. legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date PAXTON 1 PAXTON 1 RECOMPlETION NABORS DRilLING NABORS DRilLING Cd<fe¡· StlbPhase ./ ¡Code 1017/2005 11:15-12:00 12:00 - 12:30 12:30 - 13:00 13:00 - 13:30 13:30 - 13:45 13:45 - 14:30 14:30 - 16:00 1.50 RURD - ELEC CMPFLW 11/1/2005 07:00 - 08:00 1.00 08:00 - 10:30 2.50 10:30 - 11 :45 1.25 11 :45 - 12:45 1.00 12:45 - 13:00 0.25 13:00 - 13:40 0.67 13:40 - 14:15 0.58 14:15 - 14:30 0.25 14:30 - 14:45 0.25 14:45 - 14:55 0.17 14:55 - 15:15 0.33 15:15 -16:45 1.50 16:45 - 18:30 1.75 Spud Date: 2/16/2004 End: Group: Start: 8/25/2005 Rig Release: 3/14/2004 Rig Number: 129 Descriptibl1of Qperatiqns Printed: 2/20/2006 7:15:38 AM e ~ ~!Æ8" ~ rF' [ill Or? ~,ið: n ' ¡! ,. t! .. ," _ ¡ ~ _ Al ï,' I' II ,,!," ¡, \' q : f _, - r; 1 " i , ;.' - ; ~ , " U", lJ L6 ,! Lr nJ~ \ ~æ!Æ -- / / / FRANK H. MURKOWSKI, GOVERNOR Ali~'i11iA OIL AlWD GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 F~ (907)276-7542 Ken D. Walsh Senior Production Engineer Marathon Oil Company P.O. Box 1949 Kenai, AK 99611-1949 J. ô 4-'" ~'Q,~Ð· Re: Nini1chikjTyonek Paxton # 1 Sundry Number: 305-258 Dear Walsh: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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 01 day or weekend. A person may not appeal a Commission decisio to S perior Court unless rehearing has been requested. DATED this~ day of September, 2005 Encl. e e Alaska Business Unit M MARATHON \- ~ Marathon Oil Company P.O. Box 1949 Kenai, AK 99611-1949 Telephone 907/283-1311 Fax 907/283-6175 August 29, 2005 Winton Aubert AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Dear Mr. Aubert: Attached and submitted for your approval is the Form 10-403 to add new Tyonek perforations in the Paxton #1 wellbore. Also, included with this submission are a procedure and a well bore diagram. This well is currently a Tyonek gas producer. If you would like any other information, please contact me at 283-1311 or kdwalsh(â¿marathonoil.com. Sincerely, ~\). uJ~ Ken D. Walsh Senior Production Engineer Enclosures C{I:f q,~ -05 W G/\- '( { , 1¡j~-2: .. STATE OF ALASKA .. b~.s 1/ I"' ALA_ Oil AND GAS CONSERVATION COMM_ON 'J~ b APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate ~ Waiver U othérU Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: MARATHON OIL COMPANY 3. Address: P. O. Box 1949, Kenai, AK 99611-1949 7. KB Elevation (ft): 153' 8. Property Designation: ADL-359242 + 384372 11. Total Depth MD (ft): 10115' MD Casing Structural Conductor Surface Intermediate Production Liner Perforation Degth MD (ft): -Jd2~i90îl~¿rgss ~4Æ ITotal Depth TVD (ft): 8320' TVD Length 100' 1895' 4950' Development 0 Stratigraphic 0 Exploratory 0 204-010.- Service 0 6. API Number: 50-133-20535-00 ./ 9. Well Name and Number: Ninilchik Unit, Paxton #1 / 10. Field/Pools(s): Ninilchik/Beluga-Tyonek /' PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 9946' 8152' Size MD TVD Plugs (measured): Burst JUnk (measured): Collapse NIA 1500 psi 4750 psi 7020 psi 20" 9-5/8" NIA 3060 psi 6870 psi 8160 psi 100' 1895' 4950' 100' 1683' 3418' 7" ~k'. ~~to /Tubing Grade: L-80 Packers and SSSV MD (ft): 4283' 8430 psi 7500 psi ¡Tubing MD (ft): 4703' ~ 4-1/2" ~ fellS I Perforation Depth TVD (ft): Tubing Size: (:,¡~~1~17Jr~s~ \&JGA- 4-1/2" BOP Test 0 Form 10-403 Revised 07/2005 Packers and SSSV Type: Baker 9-5/8" Cement Retainer 12. Attachments: Description Summary of Proposal U Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for 9/6/2005 13. Well Class after proposed work: Exploratory 0 Development 0 Service 0 15. Well Status after proposed work: Oil 0 Gas 0 Plugged 0 Abandoned 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact :;"~::.me I ~~I:huJ il Phaoo 907::3060 Se"~' Prod"cl;'~:t·" COMMISSION USE ONLY Date: 8/25/2005 Conditions of approval: Notify Commission so that a representative may witness SUndry Numbe~d ~ ¡¡- Plug Integrity 0 Other: Approve Mechanical Integrity Test 0 Location Clearance 0 RBDMS 8FL SEP 0 7 2005 COMMISSIONER APPROVED BY THE COMMISSION ~/£ Date: ~ \ ¡L\ L Submit in Duplicate e e MARATHON OIL COMPANY ALASKA REGION Ninilchik Field Paxton #1 Recompletion Procedure WBS# Tvonek Recompletion Procedure (08-29-2005) ALL DATA RELATIVE TO THE TESTING OF THIS WELL IS CONFIDENTIAL. Note: This procedure covers work to obtain a flowing temperature-pressure survey and add new Tyonek perforations. 1. Obtain Real-time Flowina Temperature-Pressure Survey. Hold Safety and environmental awareness meeting. MIRU Expro wireline. Roundtrip a 2.25" OD gauge ring to 9600' KB. RIH with CCl and 1-11/16" real time Spartec pressure-tem perature tool and GR with weight bars on wireline observing tool response for indication of producing fluid level. RIH to 9660' MD (about 100' below bottom perf at 9558' MD). Correlate depth and POOH logging to about 100' above fluid level. POOH taking 5 min benches every 1000'. RDMO Expro Wireline. NOTE: Wireline fish in bottom of hole last taaaed at 9953' with coil tubina. 2. Add New Tvonek Perforations. Measured Depth TVD SBHP (0.469 psilft) Surface Wellhead Pressure 50% DD 60% DD 0.96 N2 0.57 2;as 6152-6186', 6068-6088' 6026-6036' 34 ft 20 ft 10 ft 4413-4445' 4335-4354 ' 4297-4306' 2084 psi 2042 psi 2020 psi 805 psi 795 psi 790 psi 755 psi 740 psi 735 psi Perfs intervals below are to be added if additional rate is required. 7960-7992' , 32 ft 6169-6201' 2908 psi 965 psi 1010 psi 7794-7868' , 74 ft 6004-6077' 2850 psi 955 psi 995 psi 7424-7467' , 43 ft 5634-5677' 2662 psi 925 psi 935 psi 6941-6968' , 27 ft 5154-5181 ' 2430 psi 880 psi 865 psi 6732-6760' , 28 ft 4952-4979' 2335 psi 860 psi 835 psi 6677-6702', 25 ft 4900-4924' 2309 psi 855 psi 830 psi 6354-6360' , 6ft 4600-4606' 2160 psi 825 psi 780 psi 6299-6319' , 20 ft 4549-4568' 2142 psi 820 psi 775 psi 6118-6136' , 18 ft 4382-4398' 2063 psi 800 psi 750 psi PERFORATE TYONEK: RU Expro wireline service with full lubricator (pump in sub and flow tubes), and pressure control equipment. Hold safety and environmental awareness meeting. Flow well at line pressure (about 800 psi) while running in the hole with the first perforating gun. PU and RIH with CCl and 3.375" HSD guns loaded 6 SPF 60 degree-phased with SDP-3125-311 NT3 charges and PX-1 firing head (if Pad activities warrant, use conventional firing head). Consider running shooting GRlCCl to log strip and ensure all casing e e Page 2 of2 collars are identified on first run. API target performance is 0.36" entrance hole and 40.25" penetration. Max gun swell in air is 3.625" 00. Correlate depth to Expro CBLlGR/CCL log. Perforate 6152-6168' MO with 775-800 psi WHP. Continue perforating Tyonek intervals from the bottom of the well up as outlined in Step #2 observing v perforating drawdown limits. Flow test open perf interval(s) to sales. Add perforations as needed to exceed minimum flow rate necessary to unload fluids from the wellbore and meet gas sales objective. At Houston Geology and Reservoir recommendation, stop and evaluate (flow and possible PBU) an interval that shows prominent response after it is perforated. ROMO Expro wireline. 3. FLOW TEST WELL TO SALES. No more than a 50% drawdown with nitrogen in the well bore or 60% drawdown with methane gas in well bore is permitted for the lowest open interval. Obtain stabilized flow within the 60% drawdown limit. The unloading rate up 4-1/2" casing in a vertical well is 4.0 MMCFGPO @ 800 psig FCP. Establish deliverability and obtain gas samples to determine gas analysis flowing well as per direction of onsite production engineer. Contact Houston Reservoir Engineering with transient test questions - Clyde Scott 713-296-2336. Following clean up and constant gas rate, prepare for pressure transient work, if requested. 4. PRESSURE TRANSIENT MEASUREMENT (CONTINGENCY): MIRU Pollard Wireline to run tandem :/' pressure gauges on slickline. Install SPIOR or Data Trap gauge on tree cap flange. Houston Reservoir Engineering to provide gauge data collection sampling rate. Hold PJSM. RIH and set gauges on AO stop with bottom of gauges at the depth to be specified by Clyde Scott with Houston Reservoir Engineering. Flow and then shut-in well per Houston Reservoir Engineering direction. 5. FLOW WELL TO SALES: Release rental equipment and return to vendors. Flow well to sales observing recommended drawdown rates. CONTACTS Ken Walsh: 907-283-1311 (w) 907-394-3060 (c) David Brimberry: 713-296-2265 (w) 713- 408-0703 (c) Ben Schoffmann: 907-565-3035 (w) 907-268-0122 (P) Clyde Scott: 713-296-2336 (w) Ninilchik Operators: 907-260-7660 or 907-567-3248 (Susan Dionne Pad) KGF Operators: 907-283-1305 Paxton #1 Tyonek Completion Procedure KDW - 8/29/2005 4:01 :23 PM Paxton #1 Wildca.t Field 686' FNL & 2921' FEL Sec. 13-T1S-R14W ......1 Proposed Tyonek Perfs: MD Net ft 34ft 20 ft 10 ft 32ft 43ft 28ft 25ft 6 ft 20ft 18 ft 74ft 27 ft TD: 10,115' MD 1 8320' TVD Formation Tops: Formation Depth (MDI Depth (TVDI Sterling NIA NIA Beluga 654' 652' Tyonek 4751' 3295' TD 10,115' 8320' -.:... Conductor 20" K·55 133 ppf PE I.Q.e. .!!2.lli!!!1 MD 0' 100' TVD 0' 100' ,jj .. Surface Casinq 9-5/8" 47 ppf I.Q.e. MD 0' TVD 0' L·SO .!!2.lli!!!1 1895' 1683' BTC 12·114" hole with +1- 516 sks 12 ppg cement Intermediate Casinq 7" 29 ppf L-SO I.Q.e. .!!2.lli!!!1 MD 0' 4950' TVD 0' 341S· 8·112" hole with +1·1S0 sks 12,5 ppg Lead + 110 sks 13,5 ppg Tail BTC ~ Tagged PBTD at 9953' with coil tubing and slickline ~ ~ .bi.!:!!!! ... ..... L·80 Hydríí 521 .!!2.lli!!!1 10071' 8276' 4-112" 12.6 ppf I.Q.e. MD 4703' TVD 3266' 7" hole with +1- 690 sks 12,8 ppg . . Worldwide Drilling North America Marathon Oil Company P.O. Box 3128 Houston, TX 77253-3128 Telephone 713-629-6600 Fax 713-499-6737 May 12, 2005 I?f:., (]P-/i .114.\ . ,,~ ~/~D· 4' r 1 ":' . .~.~ ¡,r¡;~Ir¡; n·. / 20(/5 hi & A '''on", ("I fllt!;!).'!: .~' '-'0h1/'l),' lJllQ. .. ~'$¡() 11 Steve Davies Petroleum Geologist State of Alaska Alaska Oil & Gas Conservation Commission 333 West th Ave, Suite 100 Anchorage, AK 99501 Reference: Sundry Notice - Surface Location Change Field: Ninilchik Well: Ninilchik Unit - Paxton #1 Permit Number: 204-010 Dear Mr. Davies Enclosed please find the REPORT OF SUNDRY WELL OPERATIONS, along with a current as-built survey plat for the above referenced well. When this well was permitted for drilling, a different site was being looked at for the drilling pad. This site was not used and the pad was placed in a different location and drilling commenced. During drilling operations it was discovered that the surface coordinates being used were based on the original PERMIT TO DRILL, not the actual coordinates. A directional change was made to hit the original bottom hole target circles, but a SUNDRY notice was not submitted at that time for the correct surface coordinates. The attached SUNDRY is provided to resolve this and Marathon apologizes for the delay. If you require further information, I can be reached at 713-296-3273 or bye-mail at wjtank@marathonoil.com. Sincerely, -t1~~ Advanced Senior Drilling Engineer Enclosures r !- a STATE OF ALASKA . AL~ OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPERATIONS RECEI\/ED MAY 1 7 2005 1. Operations Abandon U Performed: Alter Casing D Change Approved Program 0 2. Operator Name: Repair Well U Pull Tubing D Ope rat. Shutdown D Marathon Oil Company 3. Address: P. O. Box 1949, Kenai, AI< 99611-1949 7. KB Elevation (ft): 153 8. Property Designation: ADL-359242 + 384372 11. Present Well Condition Summary: Total Depth measured 10,115' true vertical 8,320' Effective Depth measured 9,946' true vertical 8,152' Casing Length Size Structural Conductor 100' 20" Surface 1,895' 9-5/8" Intermediate 4,950' 7" Production Liner 5,368' 4-1/2" Perforation depth: Measured depth: 8,188' - 8,266' True Vertical depth: 6,397' - 6,475' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Plug Perforations U Perforate New Pool D Perforate D 4. Current Well Class: Development 0 Stratigraphic D Sti::::~ TIm~:~Æ: Y::h;~:~ Comm;";·" Re-enter Suspended Well D 5. Permit to Drill Number: ExploratoryD 204-010 Service D 6. API Number: 50-133-20535-00 9. Well Name and Number: Ninilchik Unit, Paxton #1 10. Field/Pool(s): NinilchiklBeluga- Tyonek feet feet Plugs (measured) Junk (measured) o o feet feet MD TVD Burst Collapse 100' 3,060 psi 1,500 psi 1,683' 6,870 psi 4,750 psi 3,418' 8,160 psi 7,020 psi 8,276' 8,430 psi 7,500 psi 8,916' - 8,936' 9,088' - 9,142' 9,220' - 9,256' 9,542' - 9,558' 7,125' - 7,145' 7,297' -7,351' 7,429' -7,465' 7,750' - 7,766' L-80 4,703' 4,703' 100' 1,895' 4,950' 10,071' 8,784' - 8,804' 6,993' -7,013' 4-1/2" 4-1/2" x 7" Baker ZXP Treatment descriptions including volumes used and final pressure: RBDMS BFL MAY 2 5 2005 15. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: OiID Gas 0 WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Contact Printed Name Willard J. Tank Signature ~~~ Form 10-404 Revised 04/2004 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Service D GINJ D WINJ D WDSPL D ISUndry Number or NIA if C.O. Exempt: Title Advanced Senior Drilling Engineer o RTGrt~rj;L Date 5/12/2005 Submit Original Only 1( 1'7 "', ,/ /'/"""" '. MA!N ~ /ï Ctf -;.>~::ºAI~ (" ,,/ ¡C"! ," " ¡!,! \/~ '"", "- /:// !II \; ELECTRICAL &:' "- I (' COMMUNICATiON '~"" '\ ",<:5 /¡." /. ¡ BUILDING DQ~ ~"'.., I ,/l., ,1'/ COMMUNICATiON OJ> þ::;:':~ ""- ¡J TOWER .,t) ,,~ !/¡ I BASE \)' DIA -....;:'(;: - / --~ßL~_____SECT!9NLlNE ,~ --¡ ,II -~ NOTE: SEcfioN UNE - - - - - " / ~ "iJ<ð,;// ¡j I NOT TO SCALe / ~.¡$'~~:i:.?-ð /!~ NINILCHICK, PAXTON #fif" I ~r ~ I / v /,I$' / 1J1Ft):j /f CHAINLlN0\ 14§ ? FENCE ' l.~ , L-.'f-,~ _'/./ 'lilt / "'18 . I 'iii / 1/ /, kliJ¡ IQ.~ !J ~I Itf . 1:." I!{.¡ , /!i 1;)0 J I(j) I J '" I I' CONTROL PT. CP-1 ~ : 1..--;7 N " 2230681,929 ,~ ~_.-_. E " 206'293.550 i EÚ,V. " 148.75' )1 MAIN (L.....¿>/ GATE \ \ \ i' ) i, 1. BASIS OF COORDINATES IS KEN1 CORS STATION, NA027 ALASKA STATE PLANE ZONE 4, 2. BASIS OF VERTICAL CONTROL IS NGS BENCH MARK MONUMENT V 62. ELEVATION: 269.42 FEET (NGVD 68), . / 1 I J 1 I, II ';'1 I ,'( I rr NINILCHIK PAXTON PAD WELL NO.1 ASP ZONE 4 NAD27 N: 2230S78.S13 E: 206422.237 . LAT: SooS'4S.S39M N LONG: 151 °3S'30.592M W FEL = 2905' FNL = 782' ELEV = 149.830' (MSL) SECTION 13, TOWNSHIP 1S O^I\I~t: 1A\^, QU ^~ NOTES ~ ~ . MARATHON OIL COMPANY IUÆA ltBJDI ~ Consulting Group ~ Testing . .' ("", ~---- ?~ '/ .~ h~ //lè.$' Ò' lfr r¡1.t~ '.'. Ii! ¡----.. <'9 . ~ ~ ~ 12'DIA,/1 ¡,fjif/¡!:IU¡---:'-:'? ,,'.:.r , '1/; (..., I( ........--.... fff TANK \ ; i '"",,,,,,blJ\fQ!'b . !' '.- ¡¡Î ""~'s.~..,/þ' h /1 EXPOSED, /f í/I PlfE - I ì;,----~",.. )~ VI ;/ '-- è(¡1L, ~\'( ;. r¡ /I ..........."'DIIvQ· Î. j, ¡ 1&.....____<'6./9.ô':-.......J::y'" i/j !¡ "......, l; J' I", 411 /';0} "'Y.i PIPE 1, 'I SUPPORT /,~/ (riP¡ -'(¡ï /, /Ij 1.4 SECTION / It / ~/fj 13 ",,1:1../ / o· f I ALDERS & /If; / BRUSH 4;'1 ï I @J / 2905' FEL PAXTON NO. 1----1- ~) ~l~~: /1 METHANOL 1-, 0~ ~ SKID I,' I ø ¡;: /i? I / #' if /t,'1 Ò' I ';l!f! I.t~ / ï¡':) &~I I /' , ....- §/ ò/; Iff i~ ! ~ o z z o I- ~ Q.. -' Z u. N CO ,.... / / ! / '" ~ SCALE o I 60 t FEET ~ PROJECT NINILCHIK, PAXTON PAD WELL # 1 AS-BUILT LOCATION SURFACE LOCATION DIAGRAM ENGINEERING f MAPPING I SURVEYING I TESTING P.O. BOX 468 SOlDOTNA. AK. 99669 VOICE: (907) 283-4218 FAX: (907) 28":3..3265 EMAll: SAMCLANE@MCLANECG.COM S13 T1S R14W SEWARD MERIDIAN, ALASKA LOCATION w z !.:ï I~ \ Ii I \ /12: 7 1-1-3=+1 ã - ) I I I 3:1~ ..,./(") ..... ..... 0::,0:: I w ¡z ¡:::; ¡~ It !~ '0 lit !L I I IW I~ I~ ,I- ,ß r> / I 120 I REVJSION: DATE: 1/27105 DRAWN By: DME SCALE: 1H::: 60' PROJECT NO. D53OO1 BOOK NO. 04-15 SHEET 1 OF 1 . M' ~MARATHON Oil Company,Slot #1 Paxton Pad, tMARATHON Ninilchik Field,Kenai Peninsula, Alaska . SURVEY LISTING Page 1 Wellbore: Paxton#1 Wellpath: MWD<0-10115> Date Printed: 22-Feb-2005 d¡)cf~{) 10 ... IAKIR HUGilli' INTEQ tIii; ., Name Paxton#1 Wellbore Created 27-Feb-2004 Last Revised 22-Apr-2004 Name Paxton#1 Well Government ID Last Revised 27-Feb-2004 Name Slot #1 Grid Northing I 2230578.5130 ~ Slot Latitude N60 5 45.5384 LonQitude W151 36 30.5915 North 691.91 S Grid Easting I 206422.2370 ' Name Paxton Pad Installation NorthinQ I Coord System Name I 2231200.1560 AK-4 on NORTH AMERICAN DATUM 1927 datum Easting 209346.0570 Name Ninilchik Field Field Northing 2252005.1188 I Coord System Name I AK-4 on NORTH AMERICAN DATUM 1927 datum EastinQ 226657.8482 Craate&iv C.mêì1ts All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nabors 129 167.0ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 327.66 degrees Bottom hole distance is 3861.84 Feet on azimuth 327.66 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated East 2908.01W North AIiQnment True North Alignment True , M MARATHON j . MARATHON Oil Company,Slot #1 Paxton Pad, Ninilchik Field,Kenai Peninsula, Alaska . SURVEY LISTING Page 2 Well bore: Paxton#1 Wellpath: MWD<0-10115> Date Printed: 22-Feb-2005 rei. BADR HUGI_ INTEQ .. ~, Wellpath (Grid) Re Jort MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Easting Northing Idea/100ftl Sectionlftl 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 206422.24 2230578.51 110.00 0.10 274.40 110.00 0.01N 0.10W 0.09 0.06 206422.14 2230578.52 195.00 1.00 274.40 195.00 0.07N 0.91W 1.06 0.55 206421.33 2230578.61 286.00 1.90 307.10 285.97 1.04N 2.90W 1.31 2.43 206419.36 2230579.62 376.00 4.40 325.50 375.82 4.79N 6.05W 2.96 7.28 206416.31 2230583.45 466.00 7.10 339.10 465.37 12.83N 9.99W 3.34 16.18 206412.56 2230591.58 555.00 7.20 340.00 553.68 23.21 N 13.86W 0.17 27.02 206408.95 2230602.05 645.00 8.00 339.60 642.88 34.38N 17.97W 0.89 38.66 206405.11 2230613.32 735.00 10.10 339.50 731.76 47.64N 22.92W 2.33 52.51 206400.48 2230626.70 833.00 14.20 335.90 827.54 66.67N 30.84W 4.25 72.83 206393.03 2230645.92 929.00 18.90 337.30 919.54 91.78N 41.66W 4.91 99.83 206382.83 2230671.28 1024.00 23.10 334.70 1008.22 122.84N 55.56W 4.53 133.51 206369.68 2230702.66 1120.00 26.80 334.80 1095.24 159.46N 72.83W 3.85 173.69 206353.31 2230739.69 1216.00 30.40 334.20 1179.51 200.92N 92.63W 3.76 219.31 206334.53 2230781.63 1311.00 33.90 334.70 1259.93 246.53N 114.42W 3.69 269.50 206313.86 2230827.75 1406.00 35.60 335.00 1337.99 295.54N 137.43W 1.80 323.22 206292.05 2230877.31 1502.00 38.80 334.30 1414.44 347.98N 162.28W 3.36 380.82 206268.47 2230930.34 1598.00 42.70 334.20 1487.16 404.41 N 189.50W 4.06 443.06 206242.63 2230987.42 1693.00 47.30 334.60 1554.31 464.98N 218.51W 4.85 509.75 206215.10 2231048.67 1789.00 50.80 334.80 1617.22 530.52N 249.49W 3.65 581.70 206185.73 2231114.95 1850.00 52.30 333.90 1655.15 573.59N 270.17W 2.72 629.15 206166.10 2231158.50 1981.00 53.60 334.10 1734.08 667.55N 316.00W 1.00 733.06 206122.57 2231253.56 2072.00 54.70 334.40 1787.38 733.99N 348.05W 1.24 806.33 206092.16 2231320.75 2168.00 55.90 334.90 1842.03 805.32N 381.84W 1.32 884.67 206060.11 2231392.88 2263.00 56.90 334.90 1894.60 876.97N 415.40W 1.05 963.17 206028.30 2231465.33 2358.00 56.20 335.30 1946.96 948.87N 448.77W 0.82 1041.77 205996.69 2231538.02 2454.00 56.40 335.30 2000.23 1021.43N 482.15W 0.21 1120.93 205965.09 2231611.37 2550.00 56.40 335.60 2053.35 1094.16N 515.37W 0.26 1200.15 205933.65 2231684.88 2645.00 55.70 335.00 2106.41 1165.75N 548.30W 0.90 1278.25 205902.47 2231757.26 2741.00 56.60 334.90 2159.88 1237.98N 582.06W 0.94 1357.34 205870.48 2231830.29 2837.00 57.00 334.00 2212.45 1310.45N 616.70W 0.89 1437.10 205837.61 2231903.58 2933.00 55.90 334.20 2265.50 1382.42N 651.65W 1.16 1516.60 205804.42 2231976.38 3028.00 56.40 333.60 2318.42 1453.27N 686.36W 0.74 1595.03 205771.45 2232048.05 3123.00 56.90 333.70 2370.65 1524.38N 721.58W 0.53 1673.96 205737.97 2232120.00 3219.00 56.00 333.80 2423.70 1596.14N 756.97W 0.94 1753.51 205704.34 2232192.59 3314.00 56.30 333.90 2476.62 1666.96N 791.74W 0.33 1831.95 205671.30 2232264.24 3410.00 55.60 334.10 2530.37 1738.45N 826.61W 0.75 1911.00 205638.18 2232336.56 3506.00 55.80 334.90 2584.47 1810.03N 860.75W 0.72 1989.75 205605.79 2232408.95 3602.00 55.00 334.90 2638.98 1881.59N 894.27W 0.83 2068.14 205574.02 2232481.30 3697.00 54.80 335.00 2693.61 1952.00N 927.18W 0.23 2145.23 205542.84 2232552.49 3793.00 56.40 335.10 2747.84 2023.82N 960.59W 1.67 2223.78 205511.18 2232625.10 3888.00 56.70 335.10 2800.21 2095.71 N 993.97W 0.32 2302.38 205479.57 2232697.79 3984.00 55.40 335.70 2853.82 2168.12N 1027.12W 1.45 2381.29 205448.19 2232770.97 4080.00 55.70 335.60 2908.13 2240.24N 1059.76W 0.32 2459.69 205417.31 2232843.87 4176.00 56.20 336.00 2961.88 2312.79N 1092.36W 0.62 2538.43 205386.48 2232917.19 4271.00 55.10 335.30 3015.48 2384.24N 1124.70W 1.31 2616.10 205355.90 2232989.41 4366.00 55.10 335.60 3069.83 2455.11 N 1157.07W 0.26 2693.29 205325.26 2233061.05 4463.00 55.50 335.40 3125.05 2527.68N 1190.14W 0.45 2772.30 205293.96 2233134.40 4559.00 54.40 334.80 3180.18 2598.97N 1223.23W 1.25 2850.22 205262.62 2233206.47 4654.00 53.40 335.50 3236.16 2668.62N 1255.49W 1.21 2926.33 205232.07 2233276.88 4749.00 52.60 335.50 3293.33 2737.65N 1286.95W 0.84 3001.49 205202.29 2233346.66 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Nabors 129 167.0ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 327.66 degrees Bottom hole distance is 3861.84 Feet on azimuth 327.66 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated , M MARATHON ~ . MARATHON Oil Company,Slot #1 Paxton Pad, Ninilchik Field,Kenai Peninsula, Alaska . SURVEY LISTING Page 3 Wellbore: Paxton#1 Wellpath: MWD<0-10115> Date Printed: 22-Feb-2005 _i. ... INTEQ ... ( . " Well path (Grid) Re 30rt MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Easting Northing Idea/100ftl Sectionlftl 4827.00 52.00 335.40 3341.03 2793.79N 1312.59W 0.78 3062.63 205178.03 2233403.41 4868.00 51.60 334.80 3366.38 2823.01 N 1326.16W 1.51 3094.58 205165.18 2233432.95 4899.00 51.60 335.00 3385.64 2845.02N 1336.46W 0.51 3118.68 205155.41 2233455.20 5028.00 49.00 332.40 3468.04 2933.99N 1380.39W 2.54 3217.36 205113.66 2233545.22 5124.00 46.30 329.80 3532.71 2996.11N 1414.64W 3.45 3288.16 205080.93 2233608.14 5217.00 42.40 325.80 3599.22 3051.13N 1449.19W 5.16 3353.13 205047.73 2233663.99 5312.00 39.10 324.00 3671.18 3101.87N 1484.82W 3.69 3415.06 205013.35 2233715.58 5408.00 35.80 319.80 3747.39 3147.82N 1520.75W 4.35 3473.11 204978.55 2233762.40 5504.00 31.40 314.80 3827.35 3186.92N 1556.64W 5.41 3525.34 204943.62 2233802.36 5600.00 28.00 305.50 3910.77 3217.65N 1592.76W 5.96 3570.63 204908.25 2233833.96 5696.00 26.30 294.30 3996.25 3239.51 N 1630.52W 5.60 3609.29 204871.04 2233856.73 5788.00 24.90 284.90 4079.25 3252.88N 1667.83W 4.66 3640.54 204834.07 2233871.00 5885.00 24.00 274.10 4167.59 3259.54N 1707.26W 4.69 3667.26 204794.81 2233878.63 5980.00 23.70 272.70 4254.48 3261.82N 1745.60W 0.67 3689.70 204756.54 2233881.84 6076.00 22.40 266.00 4342.83 3261.46N 1783.13W 3.05 3709.46 204719.01 2233882.38 6171.00 22.50 264.10 4430.63 3258.33N 1819.27W 0.77 3726.14 204682.81 2233880.13 6266.00 22.20 263.60 4518.49 3254.46N 1855.18W 0.37 3742.09 204646.81 2233877 .14 6361.00 22.10 265.40 4606.48 3251.02N 1890.83W 0.72 3758.25 204611.08 2233874.57 6456.00 21.90 268.50 4694.57 3249.13N 1926.36W 1.24 3775.65 204575.52 2233873.54 6553.00 21.90 267.80 4784.57 3247.96N 1962.52W 0.27 3794.00 204539.35 2233873.26 6649.00 21.20 267.70 4873.86 3246.57N 1997.75W 0.73 3811.68 204504.09 2233872.73 6745.00 18.10 268.80 4964.26 3245.57N 2030.01W 3.25 3828.08 204471.81 2233872.51 6842.00 14.30 270.50 5057.39 3245.36N 2057.07W 3.95 3842.38 204444.76 2233872.95 6936.00 10.60 272.50 5149.16 3245.83N 2077.32W 3.96 3853.61 204424.53 2233873.92 7032.00 8.80 277.50 5243.79 3247.18N 2093.43W 2.07 3863.36 204408.46 2233875.66 7128.00 6.30 277 .80 5338.95 3248.85N 2105.93W 2.60 3871.46 204396.00 2233877.64 7223.00 4.60 276.30 5433.52 3249.98N 2114.88W 1.80 3877.20 204387.08 2233878.98 7319.00 4.10 272.10 5529.24 3250.52N 2122.13W 0.62 3881.55 204379.84 2233879.70 7414.00 3.60 272.80 5624.02 3250.80N 2128.51W 0.53 3885.18 204373.48 2233880.13 7510.00 3.10 265.00 5719.86 3250.72N 2134.10W 0.70 3888.11 204367.88 2233880.19 7605.00 3.00 268.90 5814.73 3250.44N 2139.15W 0.24 3890.58 204362.83 2233880.04 7701.00 2.70 271.70 5910.61 3250.46N 2143.92W 0.34 3893.15 204358.06 2233880.17 7796.00 2.30 270.60 6005.52 3250.55N 2148.06W 0.42 3895.43 204353.92 2233880.36 7893.00 2.30 268.30 6102.44 3250.51 N 2151.95W 0.10 3897.48 204350.03 2233880.42 7989.00 1.90 273.40 6198.37 3250.55N 2155.47W 0.46 3899.40 204346.52 2233880.54 8084.00 1.40 276.10 6293.34 3250.77N 2158.19W 0.53 3901.04 204343.80 2233880.82 8180.00 1.20 287.60 6389.31 3251.19N 2160.32W 0.34 3902.53 204341.69 2233881.30 8274.00 1.50 299.20 6483.28 3252.09N 2162.33W 0.43 3904.37 204339.70 2233882.25 8370.00 1.20 283.90 6579.26 3252.95N 2164.40W 0.49 3906.20 204337.64 2233883.15 8466.00 0.80 310.30 6675.24 3253.62N 2165.89W 0.63 3907.57 204336.17 2233883.87 8562.00 0.40 354.90 6771.24 3254.39N 2166.43W 0.61 3908.50 204335.65 2233884.65 8657.00 0.80 82.70 6866.23 3254.80N 2165.80W 0.93 3908.52 204336.29 2233885.04 8753.00 1.50 89.90 6962.22 3254.89N 2163.88W 0.74 3907.56 204338.21 2233885.09 8848.00 2.00 81.70 7057.17 3255.13N 2161.00W 0.59 3906.23 204341.10 2233885.26 8942.00 2.60 80.30 7151.09 3255.73N 2157.27W 0.64 3904.74 204344.84 2233885.76 9039.00 3.00 85.90 7247.98 3256.28N 2152.57W 0.50 3902.69 204349.55 2233886.20 9135.00 3.40 76.70 7343.83 3257.11N 2147.30W 0.68 3900.57 204354.85 2233886.91 9229.00 3.40 76.70 7437.66 3258.40N 2141.87W 0.00 3898.75 204360.30 2233888.06 9325.00 3.90 79.30 7533.4 7 3259.66N 2135.89W 0.55 3896.62 204366.31 2233889.17 9421.00 4.10 78.20 7629.23 3260.97N 2129.32W 0.22 3894.21 204372.91 2233890.32 9517.00 5.10 81.1 0 7724.92 3262.33N 2121.75W 1.07 3891.31 204380.51 2233891.50 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Nabors 129167.0ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 327.66 degrees Bottom hole distance is 3861.84 Feet on azimuth 327.66 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . ~ . . SURVEY LISTING Page 4 Wellbore: Paxton#1 Well path: MWD<O-10115> Date Printed: 22-Feb-2005 .i. BAD. IIUGIIIS INTEQ M MARATHON 4 MARATHON Oil Company,Slot #1 Paxton Pad, Ninilchik Field,Kenai Peninsula, Alaska Well path (Grid) Re :>ort MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Easting Northing fdeQ/100ftl Sectionfftl 9613.00 5.10 83.00 7820.54 3263.51 N 2113.30W 0.18 3887.79 204388.99 2233892.47 9709.00 5.10 87.40 7916.17 3264.22N 2104.80W 0.41 3883.85 204397.50 2233892.98 9804.00 5.60 83.60 8010.75 3264.93N 2095.98W 0.64 3879.73 204406.34 2233893.47 9900.00 5.70 89.80 8106.28 3265.47N 2086.55W 0.64 3875.14 204415.77 2233893.78 9995.00 5.90 91.00 8200.80 3265.40N 2076.95W 0.25 3869.95 204425.37 2233893.48 10045.00 5.50 105.00 8250.55 3264.74N 2072.07W 2.89 3866.78 204430.24 2233892.69 10115.00 5.50 105.00 8320.23 ' 3263.00N 2065.59W 0.00 3861.84 204436.67 2233890.80 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Nabors 129 167.0ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 327.66 degrees Bottom hole distance is 3861.84 Feet on azimuth 327.66 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . MARATHON OIL COMPANY ALASKA ASSET TEAr...1 DRILUNG REPORT SUMMARY . Alaska Asset Team IPaxton #1 'j 2-Feb-04 RID load out. 13-Feb-04 R/U rig. 14-Feb-04 RlU rig. 1 S-F eb-04 RlU rig. 16..Feb··04 Install 20 1/8" starting head. N/U 21 1/4" diverter and 16" diverter line. Test diverter. P/U 4" DP and 5" HWDP. P/U BHA. RECEIVED APR 11 2005 Alaska Oil & Gas Cons. Commission Anchorage . . MARATHON Oil COMPANY ALASKA ASSET TEAM DRJLUNG REPORT SUMMARY Alaska Asset Team IPaxton #1 1l-F eb-04 Clean 20" conductor 37' to 100'. Drill from 100' to 790'. Wiper trip. Change out save sub. RIH. Drill from 790' to 850', ·18-F eb-04 Drill from 850' to 1905', Circ clean. Wiper trip. 19··Feb..04 Circ. clean. Continue POOH. Service rig. RIH. Circ clean. POOH. LD BHA. Run and cement 9 5/8" casing. WC prep to ND. 20.. Feb··03 Empty and clean pits whil WOC. ND diverter. Remove starter head. Install 11" 5M wellhead. NU 13 5/8" BOPE. Prep to test BOPE. 2'1-Feb-03 Test BOPE. Test casing. PU 4" drillppe. PU BHA. RIH. Drill shoe. Drill 20" new hole to 1925'. Perform LOT. Drill from 1925' to 2036'. 22..Feb··04 Drill from 2036' to 2993', Circ clean. Wiper trip to shoe. Drill from 293' to 3677'. 23-F eb-04 Drill from 3677' to 4045'. Wiper trip to shoe. Drill from 4045' to 4677'. >. RECEIVED APR 11 2005 Alaska Oil & Gas Cons. Commission Anchorage . . MARATHON OIL COMPANY ALASKA ASSET TEAr'll DRILUNG REPORT SUMMARY Alaska Asset Team ¡Paxton #1 24-Feb-04 Drill F/4667' to 4959'. Circ clean. Wiper trip to the shoe. Circ clean at TO. Wiper trip to 3300'. Circ. clean @ TO. POOH to run logs. 26+ eb-04 POOH wI directional BHA. RIH wI Reeves DP conveyed logs. POOH logging. LID logging tools. RIU and run 7" CSG. 26.. Feb..04 Ran & cemented 7" casing. Install & test packoff. LD HWDP. Clean pits, mix mud. LOOP. 21-FE!b-04 Finish LID 4" DP. P/U 3 1/2" DP. 28-Ff)b-04 P/U DP & HWDP. Test BOPE. Mix mud. P/U BHA. TIH. 29-Feb-04 Test casing. Drill shoe track & 20' new hole. LOT to 16.42 ppg EMW. C/O mud. Drill f/4979' to 5339' MD. i-Mar - 2004 Drill f/5339' to 5574'. CBU. WT. Drill f/5574' to 5772' MD. RECEIVED APR 11 2005 Alaska Oil & Gas Cons. Commission Anchorage . MARATHON OIL COMPANY ALASKA ASSET TEAj\¡1 DRlLUNG REPORT SUMMARY . Alaska Asset Team ¡Paxton #1 02-M81'-04 Drill f/5772' to 6146'. CBU. WI. Drill f/6146' to 6387' MD. 03-Mar-04 Drill f/6387' to 7017' MD. 04-Mar -04 Drill f/7017' to 7198'. CBU. WT. Drill f/7198' to 7655'. 05-Mar-04 Drill f/7655' to 8441'. CBU. WT Drill f/8441, to 8504'. 06-~<t1ar -04 Drill f/8504' to 9512'. CBU for trip. 07 -Mar-04 CBU for trip. TFNB. Test BOPE. TIH to 7" shoe. CBU. Slip/cut drilling line. SR. TIH. W/R 8823' to 9109' CBU. 8-f\1!ar - 200A CBU. W/R f/9109' to 9513' MD. Drill f/9513' to 9993' MD. Circulate. Drill f/9993' to 10115' MD. CBU. RECEIVED APR 11 2005 Alaska Oil & Gas Cons. Commission Anchorage . . MARATHON ŒL COMPANY ALASKA ASSET TEAM DR!LLlNG REPORT SUMMARY Alaska Asset Team IPaxton #1 09-rv1ar-04 CBU. WT. CBU. POOH to log. RIU loggers. Could not get below 7920' w/W/L, log f/7920' to csg shoe. R/D loggers. TIH w/bitlHWDP. Drop drift, POOH. 10-Mar-04 M/U shuttle BHA. P/U logging tools. TIH on DP. Pump out logging tools. POOH logging, LID logging tools. 1 "1-Mar-04 RIU and run 41/2" liner to 10, 070'. 12-Mar -04 CBU. Cement 4 1/2" liner. Set ZXP liner top packer. Circ. out. POOH LID DP and DC. RIH and dress liner top. Test liner to 1500 psi. Displace above liner to 6% KCL brine. POOH. "13-Mar-04 POOH LID DP. Pull wear bushing. Run 4.5" Production TBG. Land TBG on hanger and test seals. 14..Maf··04 N/D BOPE. N/U & test tree. Clean pits. Rig released to Nabors Alaska drilling 00:00 hrs 3/14/04 RECEIVED APR 11 2005 Alaska Oil & Gas Cons. CÐnmission Anchorage ~. '\ . . 10f2 Marathon Oil Company Operations Summary Report RIU Weatherford CSG tools. P/U and Bakerlok 4 1/2" 12.6ppf L-80 Hydril 521 shoe tract. Run 41/2" 12.6ppf L-80 Hydril 521 liner (total 134joints) CIO joint #50 w/joint#159. Joint#50 was bent. M/U Baker 4.5" rotatable liner hanger ZXP liner top packer assy. P/U and rabbit 3-4 3/4" DC and RIH. Get string parameters(S/O 50K, P/U 58K, ROT 54K TQ 3-4K 2.2BPM @ 500psi). Cont. P/U total 28-4 3/4" DC. M/U Baker plug dropping assy and UD. Cont. RIH with liner on 3 1/2" DP. Circ. last stand of DP down. Tag @ 10,101'. Attempt to circ. to bottom(1 0, 115). Could not circ. down. Attempt to rotate wI max torque 12,000ft-lb. Could not rotate. Stuck liner @ 10,098'. Worked liner free. Circ. liner and condition mud for cement(2.2BPM@950psi start 4BPM 1100psi end). PRIM PR1CSG MIU Baker plug dropping assy to DP. PRIM PR1CSG Cont to M/U Baker plug dropping assy. PRIM PR1CSG Drop setting ball. Circ. 2BPM 850psi. Set hanger w/1800psi. Verify hanger has set. Release from hanger w/3000psi. Verify release. Stack 15K on liner and blow ball seat out w/4000psi. Liner shoe @ 10,071', LC@ 9946', and TOL@ 4703' CBU(B/U gas 1450units). 2.0BPM 850psi and increase to 5BPM 1970psi. PJSM prior to cementing operation(reduce Yp to below 20). Rotate liner w/12K ft-Ib. Rotate and CBU. 12RPM 8-11 K ft-Ib. 5BPM 2000psi. PJSM prior to cementing liner. Pump 5bbls water ahead. Test cement lines to 3500psi. Bleed off pressure. Pump 40bbls 10.5ppg MCS-4D spacer. Mix and pump 690sx Class"G" cementw/2%KCL, 22%LW-6, 5%MPA-1, .6%CD-32, .25%R-3, .9%BA-10, .15%SMS and 19phs FP-6L to yield 219bbls 12.8ppg slurry. Avg rate 5BPM. Could not rotate liner after 20bbls of spacer came around shoe(torque greater tan 12K ft-Ib). PRIM PR1CSG Wash out cement lines to slop tank. Drop DP dart. Displace w/80bbls 6% KCL w/2ppb flovis(observed liner wiper plug shear out@30bbls) finish displacement w/31 bbls 9.5ppg mud. Bumped plug w/5000psi 1500psi over displacement pressure. Avg rate 4BPM. Bleed off pressure and check floats held. CIP@11:30hrs. Lost 20bbls mud during cement job. Pressure up to 400psi. P/U and engage pumps when pressure bled down. Circ. and set ZXP liner top packer with rotating dog sub. CBUX2. 25bbls spacer to surface. Break down plug dropping assy. POOH UD 3 1/2" DP. Service rig. Cont. POOH LID 3 1/2" DP (total 123jnts). Rack back 6-4 3/4" collars. UD 22-4 3/4" collars. Inspect and LID liner hanger running tool. P/U 4.85" pollish mill and 6" dress mill. RIH(SLM) tag TOL @ 4703'. Polish seal bore and dress TOL wldress mills. CBU. Test liner to 1500psi/30min. Mix 6% KCL brine. Displace to 6%KCL brine. Flow check well. Test liner to 1500psi/10min. Clean shakers. Pump dry job(heavy brine). POOH LID DP. Legal Well Name: PAXTON 1 Common Well Name: PAXTON 1 Event Name: ORIGINAL COMPLETION Contractor Name: NABORS DRILLING Rig Name: NABORS DRILLING Date To Hours Code Sub Phase Code 3/11/2004 06:00 - 08:00 2.00 EQUIP RURD PR1CSG 08:00 - 09:00 1.00 CSG RUN PR1CSG 09:00 - 17:30 8.50 CSG RUN PR1CSG 17:30 - 18:30 1.00 CSG RUN PR1CSG 18:30 - 22:30 4.00 TRIP PUDP PR1CSG 22:30 - 00:00 1.50 CSG RUN PR1CSG 00:00 - 03:00 3.00 CSG RUN PR1CSG 03:00 - 05:30 2.50 CSG RUN PR1CSG 3/12/2004 05:30 - 06:00 06:00 - 06:30 06:30 - 07:00 0.50 CEMT 0.50 CEMT 0.50 CEMT 07:00 - 08:00 1.00 CEMT PRIM PR1CSG 08:00 - 09:30 1.50 CEMT PRIM PR1CSG 09:30 - 10:30 1.00 CEMT PRIM PR1CSG 10:30 - 11:30 1.00 CEMT 11 :30 - 12:00 0.50 PKRPLG SET PR1CSG 12:00 - 13:00 1.00 CIRC CLN PR1CSG 13:00 - 14:00 1.00 EQUIP RURD PR1CSG 14:00 - 15:30 1.50 TRIP BHA PR1CSG 15:30 - 16:00 0.50 RIG SERV PR1CSG 16:00 - 19:00 3.00 TRIP BHA PR1CSG 19:00 - 21 :30 2.50 TRIP BBHD PR1CSG 21 :30 - 22:00 0.50 TRIP BHA PR1CSG 22:00 - 01 :00 3.00 TRIP BHA PR1CSG 01 :00 - 02:00 1.00 DRILL CEMT PR1CSG 02:00 - 02:30 0.50 TEST CSG PR1CSG 02:30 - 04:00 1.50 MUD CHNG PR1CSG 04:00 - 04:30 0.50 MUD CHNG PR1CSG 04:30 - 06:00 1.50 TRIP LDDP PR1CSG Start: Rig Release: Rig Number: Spud Date: 2/16/2004 End: 3/14/2004 Group: 3/10/2004 3/14/2004 129 Description Printed: 2/18/2005 4:53:38 PM . . .'~ .. Marathon Oil Company Operations Summary Report Cont. POOH LID 3 1/2" DP(totaI128jnts) and 6- 4 3/4"DC. Inspect Polish/Dress mill. Pull wear bushing. Rack, strap and drift 4 1/2" TBG. RlU Weatherford TBG running tools. Organize rig floor. PJSM prior to running TBG. P/U Baker 4.5"seal assy. RIH w/4.5" 12.6PPF L-80 Butt-modTBG(52 joints ). M/U injection mandrel. RlU Pollard wireline to run control line. Connect control line and test line to 1000psi. Bleed to 500psi. PJSM prior to running TBG w/controlline. Cont. RIH wI 4.5" TBG(totaI111jnts). M/U joint 112 and eirc. head. Circ. down. M/U joint 113 and circ. head. Circ. down and find TOL ZXP @ 4607 TBG tally. LID joint 113 and 112. Mouse hole joint 111. MIU pups 7.8',12.10' and 12.14'. M/U joint 111. M/U Vetco 11" X 4 1/2" TBG hanger assy. M/U landing joint. 0.50 PLRNRP PTBG CMPRUN Run control line through Vetco TBG hanger. 1.00 CIRC CLN CMPRUN Spot 6% KCL brine w/corrosion inhibitor 303A in annulus circulating the long way. Land hanger(top of no go 2' above ZXP@4705'(TBG tally). Injection mandrel top @ 2517'. 0.50 TEST CSG CMPRUN Set lockdowns on TBG hanger. Test TBG seals to 750psi/10min. Legal Well Name: PAXTON 1 Common Well Name: PAXTON 1 Event Name: ORIGINAL COMPLETION Contractor Name: NABORS DRILLING Rig Name: NABORS DRILLING Date From - To Hours Code Sub Phase Code 3/13/2004 06:00 - 12:30 6.50 TRIP BHA PR1CSG 12:30 - 13:30 1.00 TRIP WEAR CMPRUN 13:30 - 16:00 2.50 TRIP PUDP CMPRUN 16:00 - 17:30 1.50 EQUIP RURD CMPRUN 17:30 - 20:30 3.00 PLRNRP PTBG CMPRUN 20:30 - 22:00 1.50 PLRNRP PTBG CMPRUN 22:00 - 01 :30 3.50 PLRNRP PTBG CMPRUN 01 :30 - 04:00 2.50 PLRNRP PTBG CMPRUN 04:00 - 04:30 04:30 - 05:30 05:30 - 06:00 Start: Rig Release: Rig Number: Spud Date: 2/16/2004 End: 3/14/2004 Group: 3/10/2004 3/14/2004 129 Note: Pressure on 9 5/8" X 7" annulus bled to zero and build up to 150psi in 18hrs. 3/14/2004 06:00 - 06:30 0.50 TEST EQUI CMPRUN LID landing joint. Test hanger seals to 5000psi/10min. Install BPV. 06:30 - 07:30 1.00 NUND DBOP CMPRUN Flush mud pumps, top drive, mud lines and blow down same. N/D choke and kill lines. Prep stack to N/D. 07:30 - 12:00 4.50 NUND DBOP CMPRUN Flush Hydril. LID beaver slide. Move catwalk. N/D hydril. 12:00 - 15:00 3.00 NUND DBOP CMPRUN Remove rams and flush BOP. N/D double gate, mud cross and adaptor spool. Clean pits. 15:00 - 18:30 3.50 NUND UTRE CMPRUN Run chemical injection line through wellhead. N/U Vetco 4 1/8" 5000psi tree w/11" 5000psi X 41/8" 5000psi adaptor. Test tree void to 5000psi/10min. 18:30 - 19:30 1.00 TEST EQUI CMPRUN Pull BPV and install TWC. Test tree to 5000psi/10min w/methanol/water mix. Pull TWC and set BPV. 19:30 - 00:00 4.50 CLEAN PIT RDMO Clean pits. Clear floor of tools. Prep to RID top dive. Note: Pressure on 9 5/8" X 7" annulus 200psi. Rig released to Nabors Drilling Alaska OO:OOhrs 03/14/2004. Printed: 2/18/2005 4:53:38 PM . . page 1 of 11 Marathon Oil Company Op.erations Summary Report Decided to set back injector head and commence dispacement in AM. Held Pre-job Safety Meeting to discuss hazards and operational plan. Started equipment. MU injector head to wellhead. Pressure tested stripper and Bowen connection to 250/2000 psi with methanol water. Displaced methanol water to tank with fresh water. Run in Hole with Coiled Tubing pumping fresh water at 0.75 BPM. Tagged PBTD at 9953' KB. Reprimed fluid pump. Spotted 60 bbls of 6% KCL water on bottom. Jetted well dry with nitrogen at 1500 SCFM while POOH from 9953' KB. Trapped 1590 psi nitrogen surface pressure in well. RD Coiled Tubing Equipment. Left well shut in and locked master valves closed. Weaver Bros. delivered Halliburton separator, cement barrels, and MOC vent stack. APC delivered diesel fuel storage tank, dunnage, felt, and liner. 0.50 PERF RURD CMPPRF MIRU Schlumberger wireline to perforate Tyonek. Spotted equipment. 0.50 SAFETY SMTG CMPPRF Held Pre-job Safety Meeting to discuss hazards and operational plan. Filled out work permit form, including hot work. 2.00 PERF RURD CMPPRF Left well shut in while ASRC welder cut off mouse hole casing to ground level. Covered mouse hole with plywood and cordoned off area with caution tape. Schlumberger layed out and made up lubricator. MU flow tee and WL valve. Udelhoven electricians wired camp and separator to rental generator. Vetco greased all tree valves. Could not blow down tree cap above both masters and swab valve. Valves holding pressure after grease injected. MU flow tee and WL valve to Otis connection. Armed perforating gun and picked up into lubricator. MU lubricator to WL valve. Pressure tested lubricator and Halliburton test line from wing valve to separator to 250/3500 psi. RIH with 20' of 2.875" OD perforating gun (16' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, Gun GR-CCL, adapter head, and rope socket on 0.23" wireline. Perf data: 15 gram charge, 27.7" penetration, and 0.36" entrance hole. Halliburton bled nitrogen pressure down to 1325 psi while running in the hole with perf gun. Legal Well Name: PAXTON 1 Common Well Name: PAXTON 1 Event Name: ORIGINAL COMPLETION Contractor Name: NABORS DRILLING Rig Name: NABORS DRILLING Date From... To Hours Code Sub Phase Code 4/8/2004 06:30 - 08:30 2.00 RURD_ SLlK WBPREP 08:30 - 11 :00 2.50 TAG_ BOTM WBPREP 11 :00 - 12:30 1.50 TRIP - TOOL WBPREP 4/10/2004 07:00 - 08:30 1.50 RURD - ELEC WBPREP 08:30 - 10:20 1.83 LOG_ CSG_ WBPREP 10:20 - 14:30 4.17 RURD ELEC WBPREP 4/16/2004 07:00 - 07:30 0.50 CL TBG RURD CMPPRF 07:30 - 12:00 4.50 CL TBG RURD CMPPRF 12:00 - 13:00 1.00 CL TBG RURD CMPPRF 13:00 - 15:30 2.50 CL TBG RURD CMPPRF 4/17/2004 07:00 - 07:30 0.50 SAFETY SMTG CMPPRF 07:30 - 08:00 0.50 CLTBG RURD CMPPRF 08:00 - 08:30 0.50 CL TBG RURD CMPPRF 08:30 - 11 :30 3.00 CL TBG RICT CMPPRF 11 :30 - 12:00 0.50 CL TBG RICT CMPPRF 12:00 - 12:30 0.50 CL TBG JETw CMPPRF 12:30 - 14:30 2.00 CL TBG N2LT CMPPRF 14:30 - 18:00 3.50 CL TBG RURD CMPPRF 4/20/2004 07:00 - 07:30 07:30 - 08:00 08:00 - 10:00 10:00 -11:00 1.00 RMOPS GRSE CMPPRF 11 :00 - 12:00 1.00 PERF RURD CMPPRF 12:00 - 13:00 1.00 PERF RURD CMPPRF 13:00 - 16:30 3.50 PERF WLNC CMPPRF Spud Date: 2/16/2004 End: Group: Start: 4/11/2004 Rig Release: 3/14/2004 Rig Number: 129 Description of Operations MI RU wire line unit on well. Held safety and environmental meeting and discussed procedure. MU 1 11/16" tool string with 3.8" GR. RIH tag fill at 9953' KBD. POOH with tools. OOH with tools RD unit. Secured well, Wire line unit left pad. Note: AB Vetco pulled back pressure valve prior to rigging up on well. Move equipment from Kenai to location. MIRU E-line unit. Set up tool 1 11/16" tool string to run radio sonic bond log. RIH correlate back to CML MD array induction log dated 3-9-2004. Made correlation pass. RIH to 9952' KBD, PU hole logging at 35 FPM. OOH with logging tool. RD unit, clean up lease and secure well. BJ CoilTech arrive location. PJSM. Start RU operations. Function test BOPs. Stab CT. Take injector to wellhead. Prime pump and fill CT with 50/50 methanol. Pressure test shell, blind rams, tubing rams 250 psi low and 4500 psi high. Printed: 2/18/2005 4:48:33 PM . . MarathqniQifCompany Operations Summary Page 2 of Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PAXTON 1 PAXTON 1 ORIGINAL COMPLETION NABORS DRILLING NABORS DRILLING To Hours Code $Ú'b Phase Code Start: 4/11/2004 Rig Release: 3/14/2004 Rig Number: 129 Description of.Operations Spud Date: 2/16/2004 End: Group: 4/20/2004 16:30 - 17:00 0.50 PERF 17:00 - 18:00 18:00 - 19:00 1.00 PERF 1.00 PERF WLNC CMPPRF Correlated depth with Reeves Neutron/Density log run 9-Mar-2004. Openhole log run on 1 :240 scale did not match 1 :200 scale. Correlated depth at perforation interval. Perforated Tyonek interval 9542-9558'. Could not log GR/CCL strip due to tool failure from perforating event. Initial pressure was 1325 psi nitrogen. Pressure after 15 minutes was 1400 psi and after 30 minutes was 1540 psi. WLNC CMPPRF POOH with perforating assembly. RURD CMPPRF Bled off pressure in lubricator. LD guns. All shots fired and round. Heavy layer of grease on tool string. LD lubricator and installed tree cap. Opened well to Halliburton well testers for pressure monitoring overnight. ¡./ 4/21/2004 07:00 - 07:30 0.50 PERF RURD CMPPRF Started and warmed up equipment. 07:30 - 08:00 0.50 SAFETY SMTG CMPPRF Held Pre-job Safety Meeting to discuss hazards and operational plan. Filled out work permit form, including hot work. 08:00 - 09:00 1.00 PERF RURD CMPPRF Left well shut in while ASRC welded steel plate on top of open mouse hole casing. Schlumberger layed out and made up lubricator. MU flow tee and WL valve. 09:00 - 09:30 0.50 PERF WLNC CMPPRF Armed perforating gun and picked up into lubricator. MU lubricator to WL valve. Initial shut in pressure of 2725 psi with nitrogen trapped in well. 09:30 - 10:30 1.00 PERF WLNC CMPPRF RIH with 20' of 2.875" OD perforating gun (18' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, Gun GR-CCL, adapter head, and rope socket on 0.23" wireline. Perf data: 15 gram charge, 27.7" penetration, and 0.36" entrance hole. Halliburton bled nitrogen pressure down to 1750 psi while running in the hole with perf gun. Gas gravitometer indicated methane specific gravity when pressure reached 1750 psi. Trapped 800 psi methane in Halliburton separator to heat glycollwater bath. 10:30 - 11 :00 0.50 PERF WLNC CMPPRF Correlated depth with Reeves Neutron/Density log run 9-Mar-2004. Correlated depth with GR at perforation interval. Perforated Tyonek ¡/ interval 9238-9256'. Initial pressure was 1900 psi methane gas. Pressure after 15 minutes was 1970 psi and after 30 minutes was 2000 psi. 11 :00 - 12:00 1.00 PERF WLNC CMPPRF POOH with perforating assembly. All shots fired and round. Armed and MU new gun to perforating assembly. 12:00 - 13:00 1.00 PERF WLNC CMPPRF RIH with 20' of 2.875" OD perforating gun (18' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, Gun GR-CCL, adapter head, and rope socket on 0.23" wireline. Perf data: 15 gram charge, 27.7" penetration, and 0.36" entrance hole. Halliburton bled gas pressure down from 2550 to 1700 psi while running in the hole with perf gun. 13:00 - 13:30 0.50 PERF WLNC CMPPRF Correlated depth with Reeves Neutron/Density log run 9-Mar-2004. Correlated depth with GR at perforation interval. Perforated Tyonek interval 9220-9238'. Initial pressure was 1790. Pressure after 15 minutes was 2000 psi and after 30 minutes was 2160 psi. 13:30 - 14:30 1.00 PERF WLNC CMPPRF POOH with perforating assembly. All shots fired and round. LD perforating assembly. 14:30 - 17:00 2.50 PERF RURD CMPPRF Rig down Perforating Equipment from the wellhead and spotted on edge of pad. 17:00 - 19:30 2.50 TEST TPBU CMPFLW Put well on test through Halliburton with SICP at 2840 psi on a 14/64 choke. Pressure bled down to 1500 psi maximum drawdown limit in two hours. Final rate at 1.225 MMscfd on a 12/64 choke. 19:30 - 21 :00 1.50 TEST TPBU CMPFLW Shut well in to build pressure to 2000 psi Printed: 2/18/2005 4:48:33 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . ",,"";',, Mara thonO,.·'ICom pany ,i'Yr,'.';i).'·:',· .' .··).......·.:···..m}>..·.,;.;;.:·.....· . ." ...)..:....... Operations Summary Report PAXTON 1 PAXTON 1 ORIGINAL COMPLETION NABORS DRILLING NABORS DRILLING 4/21/2004 21 :00 - 23:00 From ·To Hours 4/22/2004 23:00 - 06:00 07:00 - 07:30 07:30 - 08:00 08:00 - 09:00 09:00 - 09:30 09:30 - 10:30 10:30 -11:30 11 :30 - 12:30 12:30 - 13:00 13:00 - 13:30 13:30 - 14:30 14:30 - 15:00 15:00 - 16:00 Phase 30f 11 Spud Date: 2/16/2004 End: Group: Start: 4/11/2004 Rig Release: 3/14/2004 Rig Number: 129 Description of Operations 2.00 TEST TPBU CMPFLW Flowed well on a 12/64 choke and shut in for buildup. Final rate at 1.307 MMscfd. Shut well in to build pressure. Started and warmed up equipment. Held Pre-job Safety Meeting to discuss hazards and operational plan. Filled out work permit form. RU Schlumberger. Layed out and made up lubricator. MU flow tee and WL valve to swab valve. Armed perforating gun and picked up into lubricator. MU lubricator to WL valve. Pressure tested WL valve, flow tee, and lubricator to 250/3500 psi with methanol. Initial shut in pressure of 2800 psi with methane gas in well. 1.00 PERF WLNC CMPPRF RIH with 20' of 2.875" OD perforating gun (18' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, Gun GR-CCL, adapter head, and rope socket on 0.23" wireline. Halliburton bled nitrogen pressure down to 1800 psi while running in the hole with perf gun. 1.00 PERF WLNC CMPPRF Correlated depth with Reeves Neutron/Density log run 9-Mar-2004. Correlated depth with GR at perforation interval. Perforated Tyonek interval 9124-9142'. Initial pressure was 1890 psi methane gas. Pressure after 15 minutes was 2075 psi and after 30 minutes was 2190 psi. 1.00 PERF WLNC CMPPRF POOH with perforating assembly. All shots fired and round. Armed and MU new gun to perforating assembly. 0.50 PERF WLNC CMPPRF RIH with 20' of 2.875" OD perforating gun (18' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, Gun GR-CCL, adapter head, and rope socket on 0.23" wireline. Halliburton bled gas pressure down from 2425 to 1800 psi while running in the hole with perf gun. 0.50 PERF WLNC CMPPRF Correlated depth with Reeves Neutron/Density log run 9-Mar-2004. Correlated depth with GR at perforation interval. Perforated Tyonek interval 9106-9124'. Initial pressure was 1800. Pressure after 15 minutes was 2010 psi and after 30 minutes was 2100 psi. 1.00 PERF WLNC CMPPRF POOH with perforating assembly. All shots fired and round. Armed and MU new gun to perforating assembly. 0.50 PERF WLNC CMPPRF RIH with 20' of 2.875" OD perforating gun (18'loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, Gun GR-CCL, adapter head, and rope socket on 0.23" wireline. Halliburton bled gas pressure down from 2425 to 1800 psi while running in the hole with perf gun. 1.00 PERF WLNC CMPPRF Correlated depth with Reeves Neutron/Density log run 9-Mar-2004. Correlated depth with GR at perforation interval. Perforated Tyonek interval 9088-9106'. Initial pressure was 1760. Pressure after 15 minutes was 1925 psi and after 30 minutes was 2075 psi. Rig down Perforating Equipment from the wellhead and spotted on edge of pad. Put well on test through Halliburton with SICP at 2590 psi on a 14/64 choke. Pressure bled down to 1510 psi maximum drawdown limit and stabilized at 1.3 MMscfd on a 12/64 choke. Move in Pollard slickline unit and mast truck. Spotted equipment and filled out work permit. Held Pre-job Safety Meeting with Pollard and Halliburton tester to discuss operational plan and potential hazards. Closed master and swab valve and bled off pressure. PU and MU Pollard 1.25" OD tandem quartz gauge to 1.75" OD tool string consisting of shock absorber, XO, oil jars, knuckle joint, two 5' 7.00 TEST TPBU CMPFLW 0.50 PERF RURD CMPPRF 0.50 SAFETY SMTG CMPPRF 1.00 PERF RURD CMPPRF 0.50 PERF WLNC CMPPRF 16:00 - 17:00 1.00 PERF RURD CMPPRF 17:00 - 06:00 13.00 TEST TPBU CMPFLW 4/29/2004 07:00 - 07:30 0.50 SLICK MUTL CMPFLW 07:30 - 08:00 0.50 SAFETY SMTG CMPFLW 08:00 - 08:30 0.50 SLICK MUTL CMPFLW Printed: 2/18/2005 4:48:33 PM . . Marathon Oil Company Operations Summary Report . stem, knuckle joint, and rope socket on 0.125" OD slickline. MU lubricator and flow tee to tree Otis connection. Set 17' KB Attempt to pressure test lubricator failed. LD lubricator and replaced nicked O-ring. MU lubricator to Otis connection and successfully pressure tested to 2500 psi. RIH recording pressure and temperature gradient in memory mode to 9700' KB at 120 FPM without difficulty. Measured static stops as follows while POOH: 11' - 10 minutes (top of swab valve) 9700' - 10 minutes 9600' - 5 min. 8000' - 5 min. 9542' - 5 min. 7500' - 5 min. 9400' - 5 min. 5000' - 5 min. 9220' - 5 min. 2500' - 5 min. 9088' - 5 min. 11' - 10 min. 8500' - 5 min. 1.00 SLICK RURD CMPFLW Rig Down Slick line Equipment. Download gauges to verify data quality. Upper gauge showed good data but lower gauge does not. Will have Johnnie Butler with Pollard try to downloadlrecover the data on the lower gauge. Finished respotting Schlumberger perforating equipment. Held Pre-job Safety Meeting with Schlumberger and Halliburton tester to discuss operational plan and potential hazards. Closed master and swab valve and bled off pressure. MU flow tee and WL valve to swab valve. PU lubricator and checked fire on tools. Armed perforating gun and picked up into lubricator. MU lubricator to WL valve. Pressure tested WL valve, flow tee, and lubricator to 250/3000 psi with diesel. Opened well and dropped diesel down well to cut wireline grease. Initial shut in pressure of 2510 psi with methane gas in well. 1.00 PERF WLNC CMPPRF RIH with 20' of 2.875" OD perforating gun (20' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, Gun GR-CCL, adapter head, and rope socket on 0.23" wireline. Halliburton bled nitrogen pressure down to 1850 psi while running in the hole with perf gun. 0.50 PERF WLNC CMPPRF Correlated depth with Reeves Array Induction log run 9-Mar-2004. Correlated depth with GR at perforation interval. Perforated Tyonek interval 8246-8266'. Initial pressure was 1850 psi methane gas. Pressure after 15 minutes was 1990 psi and after 30 minutes was 2070 psi. 0.50 PERF WLNC CMPPRF POOH with perforating assembly. All shots fired and round. Armed and MU new gun to perforating assembly. 0.50 PERF WLNC CMPPRF RIH with 20' of 2.875" OD perforating gun (20' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, Gun GR-CCL, adapter head, and rope socket on 0.23" wireline. Halliburton bled gas pressure down from 2240 to 1900 psi while running in the hole with perf gun. 0.50 PERF WLNC CMPPRF Correlated depth with Reeves Array Induction log run 9-Mar-2004. Correlated depth with GR at perforation interval. Perforated Tyonek interval 8226-8246'. Initial pressure was 1900 psi methane gas. Pressure after 15 minutes was 2100 psi and after 30 minutes was 2140 psi. 1.00 PERF WLNC CMPPRF POOH with perforating assembly. All shots fired and round. Armed and MU new gun to perforating assembly. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PAXTON 1 PAXTON 1 ORIGINAL COMPLETION NABORS DRILLING NABORS DRILLING Sub Hours Code Code 4/29/2004 08:00 - 08:30 0.50 SLICK MUTL CMPFLW 08:30 - 09:00 0.50 SLICK MUTL CMPFLW 09:00 - 10:30 1.50 SLICK RPTL CMPFLW 10:30 - 13:00 2.50 SLICK RPTL CMPFLW 13:00 - 14:00 5/1/2004 06:30 - 07:00 0.50 PERF RURD CMPPRF 07:00 - 07:30 0.50 SAFETY SMTG CMPPRF 07:30 - 08:00 0.50 PERF RURD CMPPRF 08:00 - 09:00 1.00 PERF WLNC CMPPRF 09:00 - 10:00 10:00 - 10:30 10:30 - 11 :00 11 :00 - 11 :30 11 :30 - 12:00 12:00 - 13:00 Start: Rig Release: Rig Number: 4/11/2004 3/14/2004 129 Spud Date: 2/16/2004 End: Group: De$~iption Printed: 2/18/2005 4:48:33 PM . . Marathon Oil Operations Summary Report legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date PAXTON 1 PAXTON 1 ORIGINAL COMPLETION NABORS DRilLING NABORS DRilLING Spud Date: 2/16/2004 End: Group: Start: 4/11/2004 Rig Release: 3/14/2004 Rig Number: 129 Ø~çriptioº9fOperations 5/112004 13:00 - 13:30 0.50 PERF WLNC CMPPRF RIH with 20' of 2.875" OD perforating gun (20' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, Gun GR-CCL, adapter head, and rope socket on 0.23" wireline. Halliburton bled gas pressure down from 2310 to 1710 psi while running in the hole with perf gun. 0.50 PERF WLNC CMPPRF Correlated depth with Reeves Array Induction log run 9-Mar-2004. Correlated depth with GR at perforation interval. Perforated Tyonek interval 8206-8226'. Initial pressure was 1710 psi methane gas. Pressure after 15 minutes was 1900 psi and after 30 minutes was 2050 psi. 0.50 PERF WLNC CMPPRF POOH with perforating assembly. All shots fired and round. Armed and MU new gun to perforating assembly. 0.50 PERF WLNC CMPPRF RIH with 20' of 2.875" OD perforating gun (18' loaded HSDPJ, 60 deg phased, 6 JSPF), SAFE Head, Gun GR-CCL, adapter head, and rope socket on 0.23" wireline. Halliburton bled gas pressure down from 2235 to 1760 psi while running in the hole with perf gun. 0.50 PERF WLNC CMPPRF Correlated depth with Reeves Array Induction log run 9-Mar-2004. Correlated depth with GR at perforation interval. Perforated Tyonek interval 8188-8206'. Initial pressure was 1760 psi methane gas. Pressure after 15 minutes was 1930 psi and after 30 minutes was 2080 psi. POOH with perforating assembly. All shots fired and round. LD perforating assembly. Rig down Perforating Equipment from the wellhead and loaded onto flatbed. Weaver Bros. will haul from location tomorrow AM. Put well on test through Halliburton with SICP at 2440 psi on a 14/64 choke. Refer to Halliburton flow test data sheet for more detail. Held Pre-job Safety Meeting with Schlumberger and Halliburton testers to discuss operational plan and potential hazards. Closed master and swab valve and bled off pressure. MIRU Schlumberger perforators. Shut well in. MU flow tee and WL valve to swab valve. Layout and PU lubricator. Checked fire on Gun-GR tools. Finished RU and armed 3.5" OD 3406, 6 SPF perforating gun. Took lubricator to WHo Pressure tested WL valve, flow tee, and lubricator to 250/3000 psi with methanol. Bled methanol back to tank. PU and RIH with a 10' loaded 3.5" OD 3406,6 SPF perforating gun on Gun-GR to 9250' to reperforate 9118'-9128' MD. Might have detected fluid level around 8350' MD while running in the hole monitoring tension. Bled pressure down to 1500 psi while running in the hole to accomplish underbalance. 0.50 PERF WLNC CMPPRF PUH logging to correlate depth and became stuck at 9088' MD. Pulled successively harder on wireline until reached maximum safe pull of 3200 Ibs. surface. Tools came free after leaving tension on wireline for 5 minutes. PUH immediately and logged to 8000' without problems. Called Anchorage for orders. Directed to abort perforating and POOH. POOH and disarmed perforating gun. Stood back perforators and put well on test overnight. Started Schlumberger wireline equipment. Held Pre-job Safety Meeting with Schlumberger and Halliburton testers to discuss operational plan and potential hazards. Closed master and swab valve and bled off pressure. 13:30 - 14:00 14:00 - 14:30 14:30 - 15:00 15:00 - 15:30 15:30 - 16:00 0.50 PERF WLNC CMPPRF 16:00 - 17:30 1.50 PERF RURD CMPPRF 17:30 - 00:00 6.50 FLOW BACK CMPFLW 5/7/2004 08:30 - 09:00 0.50 SAFETY SMTG CMPPRF 09:00 - 10:00 1.00 PERF RURD CMPPRF 10:00 - 10:30 0.50 PERF RURD CMPPRF 10:30 - 12:30 2.00 PERF RURD CMPPRF 12:30 - 13:00 0.50 PERF RURD CMPPRF 13:00 - 14:00 1.00 PERF WLNC CMPPRF 14:00 - 14:30 14:30 - 15:00 0.50 PERF WLNC CMPPRF 15:00 - 16:00 1.00 PERF WLNC CMPPRF 16:00 - 17:00 1.00 PERF RURD CMPPRF 5/8/2004 07:00 - 07:30 0.50 PERF RURD CMPPRF 07:30 - 08:00 0.50 SAFETY SMTG CMPPRF Printed: 2/18/2005 4:48:33 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . MarathohOil Company Operations SUmmary Report PAXTON 1 PAXTON 1 ORIGINAL COMPLETION NABORS DRILLING NABORS DRILLING Spud Date: 2/16/2004 End: Group: Start: 4/11/2004 Rig Release: 3/14/2004 Rig Number: 129 Description of Operations Date From - To Hours Phase 5/812004 08:00 - 09:00 1.00 PERF RURD CMPPRF 09:00 - 11 :30 2.50 PERF WLNC CMPPRF 11 :30 - 13:30 13:30 - 15:00 15:00 - 17:00 17:00 - 19:30 Shut well in. MU flow tee and WL valve to swab valve. PU lubricator. Checked fire on Gun-GR tools. RIH with 20' loaded 2.875" OD 2906, 6 SPF perforating gun on Gun-GR. Correlated depth and reperforated 9113-9133' MD with 1500 psi WHP. POOH with gun - all shots fired and round. Reloaded new guns. Flowed well at 1000 psi while running in and out of hole. 2.00 FLOW BACK CMPPRF Flow tested well at 1000 psi for 2 hours with fairly stable rate of 1.9 MMscfd (past stabilized rate at 1000 psi was 1.7 MMscfd). 1.50 PERF WLNC CMPPRF RIH with 20' loaded 2.875" OD 2906, 6 SPF perforating guns on Gun-GR. Correlated depth and reperforated 8234-8254' MD with 1500 psi WHP. POOH and reloaded new guns. Flowed well at 1000 psi while running in and out of hole. 2.00 FLOW BACK CMPFLW Flow tested well at 1000 psi for 2 hours with fairly stable rate of 2.1 MMscfd. 2.50 PERF WLNC CMPFLW RIH with 20' loaded 2.875" OD 2906, 6 SPF perforating guns on Gun-GR. Correlated depth and reperforated 8188-8208' MD with 1300 psi WHP. POOH and LD perforating assembly. Stood back Schlumberger. Flowed well at 1000 psi while running in and out of hole. 19:30 - 21 :30 2.00 FLOW BACK CMPFLW Flow tested well at 1000 psi for 2 hours with fairly stable rate of 1.9 MMscfd. 21 :30 - 06:00 8.50 FLOW BACK CMPFLW Opened choke and flowed well at around 500 psi FTP overnight with 2.1 MMscfd average rate. 5/11/2004 05:00 - 08:30 3.50 RURD - SLlK CMPFLW Pollard moved equipment down to Paxton. Set around well head with unit. Contacted Schlumberger to see if we could use their boom truck. It was spotted around well head. They agreed. Held PJSM discussed procedure. WHP= 500 psig, well flowing at 2.1 MMCFPD, 0 BPD water. 08:30 - 09:45 1.25 TEST_ EQIP CMPFLW Swab valve was leaking had to shut in well for 5 minutes to stab on lubricator. PT lubricator with WHP, good test. Had to stabilize well prior to starting survey. WHP built to 690 PSIG when shut in for 5 minutes. Haliburton tester flowed well to stabalize. Well made 1/2 bbl fluid when well brought back on line. 09:45 - 14:00 4.25 LOG - CSG_ CMPFLW Well stabilized RIH with gauges. Made 5 minute stops per stop sheeet. Well flowing stable during gradient survey. Bottom stop at 9700' KBD. POOH with gauges 14:00 - 15:00 1.00 RURD - SLlK CMPFLW OOH with gauges. Check data, good data. RD wire line unit move to Falls Creek. 5/22/2004 11 :30 - 21 :30 5/23/2004 09:00 - 11 :30 11 :30 - 12:00 Field results:FBHP = 896 psig at 9700' KBD, 9542' KBD gas gradient. 10.00 NUND DTRE CMPFLW ABB Vetco and Pollard crane truck on location to change out leaking swab valve and inspect master valves. RU Vetco lubricator on tree and set two -way check valve. Two-way check valve not sealing properly. Discovered cracked weld on Vetco lubricator running tool. Pumped silicon sealant into bottom master valve but could not get it to hold pressure. Shut in tree. Took lubricator to be rewelded. Arrive location and pulled two-way check and installed back pressure valve. Replaced swab valve with new valve. Pulled BPV. SWIFN. 2.50 WIRELN RURD CMPFLW MIRU Expro wireline to set a retrievable bridge plug in the production tubing in order to change out leaking christmas tree valves. Layed out and made up 5" lubricator and grease control head. Weatherford and ABB Vetco personnel on location. 0.50 SAFETY SMTG CMPFLW Held Pre-job safety meeting with all personnel on location to discuss Printed: 2/18/2005 4:48:33 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . Marathon Oil Company Qperations Syrnmary Report PAXTON 1 PAXTON 1 ORIGINAL COMPLETION NABORS DRILLING NABORS DRILLING From-To Hours cOde<îg~e Phase 5/23/2004 11 :30 - 12:00 12:00 - 13:00 13:00 - 14:00 14:00 - 14:30 14:30 - 15:00 15:00 - 16:30 16:30 - 17:30 17:30 - 18:00 5/24/2004 09:30 - 11 :00 11 :00 - 11 :30 11 :30 - 13:30 13:30 - 14:00 14:00 - 15:00 Start: 4/11/2004 Rig Release: 3/14/2004 Rig Number: 129 Spud Date: 2/16/2004 End: Group: of Operations 0.50 SAFETY SMTG CMPFLW hazards and operational plan. 1.00 WIRELN RURD CMPFLW Flanged up Expro flow tee and wireline valve to top of swab valve. MU CCL, Weatherford WRP setting tool with Baker #10 and Weatherford 4-1/2" WRP with 4-1/2" GS or GR fishing neck. 1.00 WIRELN RURD CMPFLW INCIDENT: Began preparing methanol skid to pressure test lubricator. Discovered pressure on 12,000 WP line from methanol skid to control line connected to injection mandrel in production tubing string. Closed needle valve in line and began bleeding back methanol to skid to relieve trapped pressure in HP test line. While bleeding back pressure, obtained unexpected well gas and heard a loud "pop" sound near needle valve. Quickly shut bleeder valve, secured area, and inspected HP hose. Hose covering was ruptured near quick connect and had small bulges in hose covering (hose is not rated for gas). No discernable break in interior wire-wrapped line. All gas had been bled off of hose. Closed needle valve at wellhead and replaced hose with a new one. No injuries or spills. Appears that double check valves in injection mandrel did not hold which allowed the methanol in control line to be displaced with gas. 0.50 WIRELN RURD CMPFLW Connected new methanol line to Expro lubricator. MU Weatherford WRP tool. Armed Baker #1 0 firing head. Took tool string and lubricator to wellhead. 0.50 WIRELN RURD CMPFLW Pressure tested lubricator to 250/3000 psi with methanol. 1.50 WIRELN RPTL CMPFLW RIH and set Weatherford wireline retrievable bridge plug at 1030'. Good indication of set. PUH logging three collars and RIH tagging WRP at correct depth. POOH to place tool string in lubricator. 1.00 WIRELN RPTL CMPFLW Attempted to bleed off SITP of 2775 psi but could only draw down to 25 psi. Shut well in and immediately began to build pressure. WRP not holding pressure-most likely cut O-ring on the inside of the tool. Released Vetco personnel. 0.50 WIRELN RPTL CMPFLW Closed master valves and bled pressure down. Shut wing, SSV, and swab valve. Bled off minimal pressure from lubricator through flow tee valve. RD Expro lubricator and broke out tools. Installed night cap on Expro WL valve. SWIFN. 1.50 WIRELN RURD CMPFLW MIRU Pollard wireline to pull a leaking retrievable bridge plug in the production tubing. Late start for Pollard crew was due to only crew available today and they worked until midnight last night. Began spotting and RU equipment. 0.50 SAFETY SMTG CMPFLW Held Pre-job safety meeting with all personnel on location to discuss hazards and operational plan. 2.00 WIRELN RURD CMPFLW Connected Weatherford WRP pulling sleeve and Pollard 4-1/2" GR pulling tool to slickline spang jars. NU Pollard lubricator to top of Expro WL valve and pressure tested to 500 psi. Bled off pressure and replaced O-ring on lubricator Bowen connection. Pressure tested lubricator to 500/2775 psi. 0.50 WIRELN RPTL CMPFLW RIH and attempted to release 4-1/2" WRP at 1030' KB. Spang jar action "mushy". Could not get plug to equalize. POOH to check tools. Cleaned off tools which were covered with grease and silicone sealant. Pumped 10 gals of diesel into lubricator and RIH again. Jarred down on WRP to equalized pressure. PUH 20' and allow elements to relax. Drug WRP uphole pulling tight in tubing collars to 620' KB. Worked tool until sheared off of GR pulling tool. 1.00 WIRELN RPTL CMPFLW POOH and MU 4-1/2" GS pulling tool. RIH and latched onto WRP fish. Jarred on fish and came free. POOH and LD fishing assembly and Printed: 2/18/2005 4:48:33 PM PAXTON 1 PAXTON 1 ORIGINAL COMPLETION NABORS DRilLING NABORS DRilLING C Sub From-To Hours.>pde Codê Phase legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 5/24/2004 14:00 - 15:00 15:00 - 16:00 16:00 - 16:30 16:30 - 17:00 17:00 - 18:00 . . .... Marathon Oil Company Operations Summary Report Page 8 of 11 Spud Date: 2/16/2004 End: Group: Start: 4/11/2004 Rig Release: 3/14/2004 Rig Number: 129 Description of Op~,.ation~ 1.00 WIRELN RPTL CMPFLW WRP. WRP elements in place and unmarked. No marks on WRP. Suspect that slips did not fully retract until plug jarred free. 1.00 WIRELN RPTL CMPFLW PU and RIH with a 3.75" OD gauge ring on slickline to 9949' KB. POOH with GR. Noted fluid level around 9370' while RIH and POOH. RD Pollard slickline lubricator and tools. 0.50 SAFETY SMTG CMPFLW Held Pre-job safety meeting with all personnel on location to discuss hazards and operational plan to set WRP and replace tree. 0.50 RURD_ SLlK CMPFLW RU Expro to set WRP in tubing for tree replacement. MU Weatherford 4-1/2" WRP and setting tool to Expro firing head and CCL after arming Baker #10 slow set. 1.00 TRIP _ TOOL CMPFLW RIH with WRP and set middle element between collars at 910' KB. PUH and RIH to tag at proper depth. POOH with setting tools. Bled 2500 psi pressure off tubing above WRP. LD Expro lubricator and setting tools. Vetco dry-rodded a BPV into tubing hanger. ND Christmas tree and NU new tree including masters, tee, wing, and swab valves. NU same SSV valve as originally installed on tree. Pulled BPV and installed two-way check valve. Pressure tested tree body to 5000 psi with methanol successfully. Bled off pressure. Pulled two-way check valve. SWIFN. Pollard slickline on location to pull Weatherford retrievable bridge plug (WRP). Held Pre-job safety meeting with all personnel on location to discuss hazards and operational plan. PU lubricator and MU Weatherford retrieving tool and Pollard 4-1/2" GR pulling tool to spang and oil jars on slickline. Took lubricator to wellhead. Pressure tested lubricator to 300/1800 psi with methanol. Bled off pressure. Opened well with 0 psi SITP. 1.00 SETREL PKR_ CMPFLW RIH to 910' KB and lightly tagged up on top ofWRP. Manually manipulated slickline to tap down on top of WRP to equalize pressure. Pressure jumped to 1350 psi and the slickline became slack for about 10-15 seconds and then became tight again. Pressure continued to climb slowly until it reached 1500 psi. Attempted to move tool without success. No spang or oil jar action. Tried holding a steady pull of 875 Ibs. but did not move tools. Apparent that slickline tools were blown uphole and have become stuck. It appears unlikely that the WRP was released and was blown uphole with slickline tool string since the wellhead pressure has stabilized at 1500 psi (should be about 2775 psi) and the relatively long time it took the line to become taut. 4.50 WAIT EQIP CMPFLW Waited on Pollard to gather, build, and deliver slickline severing and fishing tools. Held safety meeting while waiting to discuss plan forward and potential hazards. 1.50 TRIP _ TOOL CMPFLW Closed wireline valve (slickline BOP). Bled off pressure from lubricator. Attached a 3' long 1-1/2" OD Flat bottom Go-Devil to slickline and dropped it downhole. Did not cut slickline. Attached a 5' long 1-1/2" cutter bar and dropped it downhole. Cut slickline. POOH with slickline recovering all but 180' of 0.125" OD line. 1.50 NUND EQIP CMPFLW Shut well in. ND Expro's wireline valve, pump-in tee, and crossover from top of tree. Pressure tested Halliburton's 3" test line from well to separator with 100 psi of air. Pressure tested same line to 300/3500 psi with methanol. NU MOC 4-1/8", 5K tree cap flange with 6-1/2" Otis top connection. 18:00 - 19:30 1.50 NUND DTRE CMPFLW 19:30 - 22:00 2.50 NUND DTRE CMPFLW 5/25/2004 07:00 - 07:30 0.50 RURD - SLlK CMPFLW 07:30 - 08:00 0.50 SAFETY MTG - CMPFLW 08:00 - 08:30 0.50 RURD - SLlK CMPFLW 08:30 - 09:30 09:30 - 14:00 14:00 - 15:30 15:30 - 17:00 Printed: 2/18/2005 4:48:33 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . Page 9 of 11 MarathónOil Company Operations S....mmaryRep0r1 PAXTON 1 PAXTON 1 ORIGINAL COMPLETION NABORS DRILLING NABORS DRILLING Sub From - To Hours Code Code Phase 5/25/2004 15:30 - 17:00 5/26/2004 07:00 - 07:30 07:30 - 08:00 08:00 - 10:30 10:30 - 11 :30 11 :30 - 12:30 12:30 - 13:30 13:30 - 14:30 14:30 - 17:00 1.50 NUND EQIP CMPFLW 0.50 RURD_ SLlK CMPPRF 0.50 SAFETY MTG_ CMPPRF 2.50 RURD_ SLlK CMPPRF 1.00 TEST _ EQIP CMPPRF 1.00 TRIP _ TOOL CMPPRF 1.00 WORK_SLlK CMPPRF 1.00 WAlTON EQIP 2.50 PUMP _ N2_ CMPPRF CMPPRF 17:00 - SECURE WELL CMPPRF 5/27/2004 07:00 - 07:30 0.50 SAFETY MTG_ CMPPRF 07:30 - 09:00 1.50 ENGAGE FISH CMPPRF 09:00 - 10:00 10:00 -11:00 1.00 ENGAGEFISH CMPPRF 1.00 ENGAGE FISH CMPPRF Start: 4/11/2004 Rig Release: 3/14/2004 Rig Number: 129 Description Spud Date: 2/16/2004 End: Group: NOTE: Fish is about 180' of 0.125" slickline and 1.75" OD tool string each with 1.75" fishing neck consisting of Rope Socket (0.5'), Knuckle Jt.(0.75'), Stem (10'), Oil Jars (3.5'), Spang Jars (5'), and Quick Connect (1.0'). Attached to Quick Connect is a 4-1/2" GR Pulling Tool with a 2.313" fishing neck (1.5') and a 3.75" OD Overshot (2.0'). Pollard slickline, Toloff boom truck, and Halliburton on location to fish slickline tools. Spotted boom truck and layed out lubricator. Halliburton pressure tested 3" 1502 line from wellhead to separator to 3500 psi with methanol. Held Pre-job safety meeting with all personnel on location to discuss hazards and operational plan. Layout and MU Pollard 4" lubricator. Perform twist test on slickline (20 turns). Note: had cut off all slickline retrieved from drum after POOH yesterday. Pull slickline through 3" lubricator and tied rope socket. MU slickline tools. PU lubricator. MU 4" lubricator to bottom of 3" lubricator to swallow fish. MU lubricator to tree. Pressure tested lubricator to 300/3000 psi with methanol using Haskel pump. Replaced failed double diaphram pump. Opened well with 1500 psi SITP. RIH with a 3.75" bell guide and GR pulling tool with spang and oil jars on slickline. Tagged up at 659' KB and worked bell guide down 8' to catch top of cutter bar. POOH and LD cutter bar. Bell guide and cutter bar showed indications of wire around them. PU and RIH with baited wire grab on tool string while waiting for nitrogen unit to balance pressure across the plug. Tagged up at 653' and worked down to 661'. Pull 50# over string weight and shut down until nitrogen pressure could be applied. Wait on BJ nitrogen unit and personnel. MIRU BJ Coiltech nitrogen unit to balance pressure across WRP before continuing fishing operations. Held safety meeting to discuss hazards. MU pump lines and cooled down nitrogen unit. PT lines to closed ball valve on Pollard lubricator to 3500 psi. Opened ball valve and pressured up wellbore to 3200 psi. Closed ball valve and bled down nitrogen line. Broke nitrogen line connection at ground level and installed tapped bull plug with needle valve. Pollard lubricator O-ring began leaking nitrogen. Pulled off fish and POOH. Shut in top master. Bled off lubricator pressure. Shut all valves and LD lubricator. No fish on wire grab. Replaced O-ring. SDFN. Left BJ nitrogen unit rigged up on pad. Held Pre-job safety meeting with all personnel on location to discuss hazards and operational plan. PU internal wire grab spear. MU and PT lubricator. Opened well with 2700 psi SITP. RIH and work fish down to 669' KB. POOH recovering Go-Devil bar (indications of rope socket and wire cuts on bottom of Go-Devil). RIH with 3.85" fingered wire grab to push and ball wire. Tagged up at 624'. Could not work downhole. POOH and straighted bent finger on wire grab. RIH to 658' with fingered wire grab. POOH and found two fingers 180 deg apart had bent inward (setting down on tubing collars). SITP at 2200 psi. RIH to 673' with same internal wire grab spear used previously. Pick up with 200# overpull. Waited for oil jar action. PUH slowly with minimal drag to 300'. Slacked off 5' moving tool string and fish downhole easily. Printed: 2/18/2005 4:48:33 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 5/27/2004 10:00 -11:00 11 :00 - 12:30 12:30 - 14:00 14:00 - 15:00 15:00 - 15:30 15:30 - 16:30 PAXTON 1 PAXTON 1 ORIGINAL COMPLETION NABORS DRILLING NABORS DRILLING S.yb >Phase Cœ.e Start: 4/11/2004 Rig Release: 3/14/2004 Rig Number: 129 Spud Date: 2/16/2004 End: Group: of Operations 1.00 ENGAGE FISH CMPPRF POOH and shut tree valves. Recovered slickline tool string fish including Weatherford WRP retrieving tools and about 12' of wire. 1.50 ENGAGE FISH CMPPRF RIH with fingered wire grab balling up wire from 675' to 691'. POOH without recovering any wire. RIH with internal wire grab spear and worked down from 685' to 690". Pick up with 100# overpull. POOH slowly. Can not close tree valves completely (24 out of 29-1/2 turns). Close WL valve on wire and bleed off pressure. 1.50 TRIP _ TOOL CMPPRF Remove lubricator and shortened tool string. Tie wire fish to tool string and strip wire through wireline valve connected to lubricator three times. Recovered an estimated total wire fish of 190'. LD two sections of 4" lubricator. 1.00 TRIP _ TOOL CMPPRF MU and RIH with 3.5" OD lead impression block (LIB) and tag up on top of fish at 895' KB. POOH and LD LIB. Solid impression of fishing neck in middle of LIB with no indication of wire. MU Weatherford WRP retrieving tool with 4-1/2" GR, spang, and oil jars. Cooled down BJ Coiltech nitrogen unit and pressure tested lines to 3500 psi. 0.50 PUMP _ N2_ CMPPRF Pressured up lubricator and wellbore to 910' to 3000 psi with nitrogen to balance pressure across WRP. 1.00 ENGAGE FISH CMPPRF RIH with WRP retrieving tools on slickline. Jarred on bridge plug and it came loose. Allowed packer elements to relax for 15 minutes. POOH with WRP having to work through collars. LD WRP fish. Top and bottom element were swelled. All of the elements, slips, and tool were recovered. RDMO Pollard Wireline. Secured and chained tree valves. Released Toloff boom truck. Held Pre-job safety meeting with all personnel on location to discuss hazards and operational plan. Expro and Halliburton. MU flow tee and WL valve to swab valve. Checked fire on Gun-GR tools. PU lubricator. Went to radio silence. Armed perforating gun and pulled into lubricator. Took lubricator and perforating assembly to wellhead. Pressure tested lubricator to 400/3000 psi with methanol. Bled back methanol to pump skid and Halliburton flow line. Attempted to RIH with perforating assembly but could not get gun to fall. Broke off lubricator and worked location sand out of packoff. SITP was 2750 psi. RIH with 3.375" OD perforating gun loaded 20' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF on Gun-GR. Correlated depth with Reeves Array Induction open hole log run Mar-09-2004. Flowed well pressure down to 1200 psi while running in and out of hole. Ran GRlCCL strip from 9100'-8200'. NOTE: Gun temporarily stuck at 9088' KB 1.50 PERF _ TBG_ CMPPRF Perforated 8417-8437' KB with 1250 psi WHP. POOH with gun - all shots fired and round. Pressure builtfrom 1250 to 1295 psi in 10 minutes. Reloaded new guns. 1.00 PERF _ TBG_ CMPPRF RIH with 3.375" OD perforating gun loaded 15' with SDP-3125-311NT3, 25 gm. charges, 6 SPF on Gun-GR. Correlated depth with Reeves Array Induction open hole log run Mar-09-2004. Flowed well pressure down to 1200 psi while running in and out of hole. 1.00 PERF _ TBG_ CMPPRF Perforated 8402-8417' KB with 1240 psi WHP. POOH with gun - all shots fired and round. Pressure built from 1240 to 1440 psi in 10 minutes. 13.50 FLOW_ TEST CMPFLW LD Expro lubricator and installed night cap on wireline valve. Did not shut in the well during or following perforating runs. Instruction for well 16:30 - 17:30 1.00 RURD - SLlK CMPPRF 5/28/2004 07:00 - 07:30 0.50 SAFETY MTG - CMPPRF 07:30 - 09:30 2.00 RURD - ELEC CMPPRF 09:30 - 10:00 0.50 RUNPUL ELEC CMPPRF 10:00 - 10:30 0.50 TEST_ TREE CMPPRF 10:30 - 11 :30 1.00 RUNPUL ELEC CMPPRF 11 :30 - 13:00 1.50 PERF - TBG_ CMPPRF 13:00 - 14:30 14:30 - 15:30 15:30 - 16:30 16:30 - 06:00 "" Printed: 2/18/2005 4:48:33 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 5/28/2004 5/29/2004 . . Marathon Oil Company ; Operations Summary Report 11 of 11 ,.\ y..'. PAXTON 1 PAXTON 1 ORIGINAL COMPLETION NABORS DRILLING NABORS DRILLING ;>Sub . From -To HoursC~dê; COdeP;t);¡ise 16:30 - 06:00 08:00 - 08:30 08:30 - 09:00 09:00 - 10:30 10:30 -11:00 11 :00 - 12:00 12:00 - 13:00 13:00 - 14:30 14:30 - 16:00 Start: 4/11/2004 Rig Release: 3/14/2004 Rig Number: 129 Spud Date: 2/16/2004 End: Group: of Operations 13.50 FLOW_ TEST CMPFLW testers is to flow the well at 1000 psi until 2100 hrs and then draw the FTP down to 500 psi in 30 minutes. They are to hold the pressure at 500 psi overnight and only shut the well in for safety reasons. 0.50 SAFETY MTG_ CMPPRF Held Pre-job safety meeting with Expro perforators and Halliburton well testers to discuss hazards and operational plan. 0.50 WAlTON ORDR CMPPRF Wait on orders. 1.50 RURD_ ELEC CMPPRF MU perforating gun and armed conventional firing head after observing radio silence. PU 5" OD lubricator and pulled Gun-GR and perforating gun into lubricator. Took lubricator to wellhead. PT lubricator assembly with well gas to 100/1200 psi. 0.50 TRIP _ TOOL CMPPRF RIH with 3.375" OD perforating gun loaded 20' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF on Gun-GR. Correlated depth with Reeves Array Induction openhole log run Mar-09-2004. Flowed at 1200 psi while running in the hole. 1.00 PERF _ TBG_ CMPPRF Perforated 8916-8936' KB with 1250 psi WHP. POOH with gun - all shots fired and round. Pressure built from 1140 to 1370 psi in 10 minutes. Flowed at 1100 psi while pulling out of the hole. Reloaded new guns. 1.00 PERF _ TBG_ CMPPRF RIH with 3.375" OD perforating gun loaded 20' with SDP-3125-311 NT3, 25 gm. charges, 6 SPF on Gun-GR. Correlated depth with Reeves Array Induction openhole log run Mar-09-2004. Flowed at 1100 psi while running in the hole. 1.50 PERF _ TBG_ CMPPRF Perforated 8784-8804' KB with 1200 psi WHP. POOH with gun - all shots fired and round. Pressure built from 1200 to 1400 psi in 10 minutes. Flowed at 1300 psi while pulling out of the hole. 1.50 RURD_ ELEC CMPFLW RDMO Expro perforators. Flowed well to test. Plan to flow at 1000 psi FTP until 2100 hrs and then drop FTP to 500 psi and hold constant overnight. / / (; Printed: 2/18/2005 4:48:33 PM Paxton # 1 . . «SUM Paxton #1 031404.xls» «SUM Paxton #1 021604.xls» «SUM Paxton #1 022304.xls» «SUM Paxton #1 030104.xls» «SUM Paxton #1 030804.xls» Betty J. Veldhuis Marathon Oil Company Alaska Asset Team Phone: 907.565.3070 Fax: 907.565.3076 Content-Description: SUM Paxton #1 031404.xls SUM Paxton #1 031404.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: SUM Paxton #1 021604.xls Paxton #1 021604.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: SUM Paxton #1 022304.xls SUM Paxton #1 022304.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: SUM Paxton #1 030104.xls SUM Paxton #1 030104.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: SUM Paxton #1 030804.xls SUM Paxton #1 030804.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 4/11/2005 9:48 AM RE: [Fwd: Paxton 1 Operations Summary Incomplete, BH Coordinates Need ConfIrmation] Steve, I apologize for the delay in answering your first inquiry. I went on vacation shortly after receiving the initial inquiry. After my return, I had been waiting on a response from another individual as to the proper X and Y coordinates for the TO for this wellbore. The answers are embedded with your questions below. Please let me know how you would like me to correct the incorrect entries on the Form-407. . Regards, Ken D. Walsh Senior Production Engineer Marathon Oil Company-Alaska Asset Team 907-283-1311 (office) 907 ·394·3060 (cell) From: Stephen Davies [mailto:steve_davies@admin.state.ak.us] Sent: Monday, April 04, 2005 11:42 AM To: Walsh, Ken Subject: [Fwd: Paxton 1 Operations Summary Incomplete, BH Coordinates Need Confirmation] Ken, . Did you get a chance to look into this? Thanks, Steve Davies AOGCC -------- Original Message -------- Subject:Paxton I Operations Summary Incomplete, BH Coordinates Need ConfIrmation Date: Wed, 23 Mar 2005 11 :24: 10 -0900 From:Stephen Davies <steve davies(ã}admin.state.akus> Organization:State of Alaska To:kdwalsh(ã}marathonoil.com lof2 4/11/2005 11 :51 AM RE: [Fwd: Paxton 1 Operations Summary Incomplete, BH Coordinates Need Continuation] Ken, After review of the file for Paxton #1, I have the following comments: 1) The operational history for the well is incomplete. AOGCC has no information on any activities before March 11, 2004. Could you please supply it? Our records show that our Drilling Department has submitted copies of our rig-related drilling and completion activities for this well to the AOGCC which include all activities before March 11, 2004, Our records also indicate that an abbreviated report for these activities was also submitted on a weekly basis. 2) The completion report you submitted indicated 'I'D of the well was reached on March 18, 2004. The incomplete operations summary that you supplied indicates that the 4-1/2" liner was being run to 'I'D on March 11th, and that the Nabors Rig was released on March 14th. I need the complete operations history to correct this error and to verify the supd date for the well. I have reviewed the filed completion report and find that the TD date was entered incorrectly. The correct date should have been March 08, 2004. Sorry for the mistake. 3) The state base plane coordinates that you supplied on the Completion Report for the 'I'D of the are different from those listed on the Baker-Hughes survey report. The difference is about 83' in the X-coordinate and about 49' in the Y-coordinate. Which coordinates are correct? The correct X and Y coordinates for the Paxton #1 'I'D are those reported on the Baker Hughes Integ directional survey. Those figures should be X: 204436.67 and Y: 2233890.80. Again, sorry for the mistake. Thanks, Steve Davies AOGCC 20f2 . . 4/11/2005 11:51 AM [Fwd: Paxton 1 Operations Summary Incomplete, BH Coordinates ... . . 2-D cj- D/ð Ken, Did you get a chance to look into this? Thanks, Steve Davies AOGCC -------- Original Message -------- Subject:Paxton I Operations Summary Incomplete, BH Coordinates Need Confirmation Date: Wed, 23 Mar 2005 11 :24: 10 -0900 From:Stephen Davies <steve davies(atadmin.state.ak.us> Organization:State of Alaska To:kdwalsh(¿~marathonoil.com Ken, After review of the file for Paxton #1, I have the following comments: 1) The operational history for the well is incomplete. AOGCC has no information on any activities before March 11, 2004. Could you please supply it? 2) The completion report you submitted indicated TD of the well was reached on March 18, 2004. The incomplete operations summary that you supplied indicates that the 4-1/2" liner was being run to TD on March 11th, and that the Nabors Rig was released on March 14th. I need the complete operations history to correct this error and to verify the supd date for the well. 3) The state base plane coordinates that you supplied on the Completion Repor~ for the TD of the are different from those listed on the Baker-Hughes survey report. The difference is about 83' in the X-coordinate and about 49' in the Y-coordinate. Which coordinates are correct? . Thanks, Steve Davies AOGCC -.;. 1 of 1 4/4/2005 11 :42 AM Paxton 1 Operations Summary Incomplete, BH Coordinates Need Co... . . 2óé.(~ð/Ô Ken, After review of the file for Paxton #1, I have the following comments: 1) The operational history for the well is incomplete. AOGCC has no information on any activities before March 11, 2004. Could you please supply it? 2) The completion report you submitted indicated TD of the well was reached on March 18, 2004. The incomplete operations summary that you supplied indicates that the 4-1/2" liner was being run to TD on March 11th, and that the Nabors Rig was released on March 14th. I need the complete operations history to correct this error and to verify the supd date for the well. 3) The state base plane coordinates that you supplied on the Completion Report for the TD of the are different from those listed on the Baker-Hughes survey report. The difference is about 83' in the X-coordinate and about 49' in the Y-coordinate. Which coordinates are correct? Thanks, Steve Davies AOGCC 1 of 1 3/23/2005 11 :25 AM RE: Paxton 1 Completion Information Steve, I forgot to submit the operational history. It is my understanding that Marathon's Drilling Dept. has submitted the directional. However, I will include the survey with the history. I will send both to your attention. Ken Walsh Advanced Production Engineer Marathon Oil Company-Alaska Asset Team 907-283-1311 (office) 907-394-3060 (cell) -----Original Message----- From: Stephen Davies [mailto:steve davies@admin.state.ak.us] Sent: Wednesday, February 16, 2005 3:36 PM To: Walsh, Ken Subject: Paxton 1 Completion Information Ken, While reviewing the completion report you submitted for Paxton 1, I noticed that we only have the 10-407 form and completion diagram. We do not have any directional information or operational history information in the well file. Did you submit these items to the Commission? Thanks, Steve Davies Petroleum Geologist Alaska Oil and Gas Conservation Commission Telephone: (907) 793-1224 1 of 1 2/23/20054:18 PM . . Alaska Business Unit Nt MARATHON . , Marathon Oil Company P.O. Box 1949 Kenai, AK 99611-1949 Telephone 907/283-1311 Fax 907/283-6175 February 22, 2005 Steve Davies Petroleum Geologist AOGCC 333 West ¡th Ave Suite 100 Anchorage, AK 99501 ~ Dear Mr. Davies: Attached and submitted for your records are the Operations Summaries for the original completion activities at the Paxton #1. Also, included with this submission are the directional survey data and a revised well bore diagram. If you would like any other information, please contact me at 283-1311 or kdwalsh@marathonoil.com. Sincerely, \ÚM- b. LAJ~ Ken D. Walsh Advanced Production Engineer Enclosures .Paxton #1 Wildcat field 686' fNl & 2921'fEl Sec. 13-T1S-R14W 4IA .¡ FQrmation Tops: Formation Sterling Eleiuga Tyonek TD Depth (MD) Depth (TVD) NIA NIA 654· 652' 4751' 3295' 10,115' 8320' TO: 10,115' MD I 8320' TVD ¿¡, L Conductor 20" K-55 133 PE MD 100' TVD 0' 100' io. Surface Casinq 9·5IS" 47 ppf IillL MD 0' TVD 0' BTC 16S3' 12·114" hole with +1- 516 sks 12 ppgcement Intermediate Casinq 7" 29 ppf IillL 0' 0' L-80 Bottom 4950' 3418' MD TVD S.112" hole with ...1- 180 sks 12.5ppg Lead + 110 Tyonek Perfs: 818B-B266',1Bft, pJ 2506 413012004- 8402-8431', 31 n, 3-31S" Owen 512112004 8184-8804',20 ft, 3·318" Owen 5/2812004 8916-8936', 20 n, 3-318" Owen 512812004 9088-9142, 54 ft, PJ 2506 4/21/2004 9220-9256, 36 ft, PJ 2506 412012004 9542-9558, 16 ft, PJ 2506 4/19/2004 Reperf: 9113-33; 8234-54'; 8188-8208' MD PJ 2506 510112004 Tagged PBTD at 9953' with cQiI tubingandslickline FISH: Expro 30.9' OVL: 1-7/16" rope 1-314" swivel (1.2'),1-11116" tungsten wt bar (21'),3.118" 3" junk basket (5.0'),and 3.78"gauge ring (.17') Liner 4-112" 12.6 ppf IillL 4703' 3266' L·80 Hydril 521 Bottom 10011' 8276' MD TVD 1" hole with +1- 690 sks 12.8 ppg Æe-O(O ./.J3-~oS.35-oð-oO MARATHON OIL COMPANY Page 1 of 1 WELL NAME PAXTON 1 SUPERVISOR Gene Anderson FJELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS@6AM Prep to move rig. OPERATION COMMENTS Prep to move rig. 124 HR PROG TMD 100 AUTH MD WBS 9,793 MOC WI NRI 9072831315 60.0000 60.0000 COUNTY/OTHER I LAST CASING I NEXT CASING í~:Oi~~ 1l0NFlõ~~tiÃl IGL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 TVD 100 1 DFSO 1 DOLO 1 RPT # I DATE 1 11-Feb-2004 SAPIWBS COST dx0309781 capdrl ! DA!L Y WELL COST CUM ""JELL COST KB R!G PHONE I LEAKOFF MANHRS WORKED I ACCIDENT TYPE 217.00 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: RID and load out equipment. LAST SAFETY MTG SAPEh¥.sOMIÌIIARY BOP PSI TEST I LAST STOP CARD AUDIT RNEGULATORY INSP? 2/11/2004 LAST RIG INSPECTION 2/11/2004 12:00 15:00 3.00 OPERATreNSfSUMMARY . ~H;ð.~,". . . . OP SUBOP . TRéL 100 AF RDMO RIG RDMO Release rig from Falls Creek 4 @ 12:00hrs 02/10/04. 100 RID pits. Prep rig floor and derrick to UD. 15:00 15:30 0.50 100 100 AF RDMO RIG RDMO UD derrick. 15:30 00:00 8.50 100 100 AF RDMO RIG RDMO Coil up lines and RID derrick. Move pits. RID pump room and move change room. Move boiler room. Wash matting boards. Work on#2 mud pump. Blow down rig. 00:00 06:00 6.00 100 100 AF RDMO RIG RDMO Unstring blocks. Raise derrick board. Tie up board hanging lines. Attach line to pull A-legs. COMMENTS Accept rig from FC 4 @ 12:00hrs 02/10/04. PERS:ONNEL DATA NO.\; !HPllRS COMPANY 14 175.00 R&K Industrial 1 18.00 POB @ 06;00: ~NO: . HOURS . 2 24.00 LAST BOP TEST: SIZE (in) liD (in)ISHOE TEST (ppg~ 20.000 18.730 I . ·iCASINGStJMfIÍllARY LAST CASING TEST: MAX sìcÞ I MD (ft) I (psi) @ (ppg) 100 . TVD (ft) 100 NEXT BOP TEST: WT Ob/ft) ·1 GRADE 133.00 X-56 I BURSt (psi) Printed: 4/8/2004 10:00:23 . . OIL COMPANY Page 1 of 1 WELL NAME PAXTON 1 SUPERVISOR R.C. Lawson FJELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS @ 6AM RlU rig. OPERATION COMMENTS RID load out. 124 HR PROG TMD TVD I DFSO 1 DOLO I RPT # I DATE 100 100 2 :~~~~~~~~~~ AUTH MD WBS 9,793 dx0309781capdrl RIG PHONE P...10C \"11 NRI I nAil V'.'I""'I' ,..,.."'.. I ..... ... ...-.. ~ --- 9072831315 60.0000 I 60.0000 I . , COUNTY/OTHER I LAST CASING I NEXT CASING 20.000 (in) @ 100 (ft) 9.625 (in) @ 1,900 (ft) 124 HR FORECAST Move rig and begin RlU. IGL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 KB I LEA~~;~ ' .' . 'SAEETY SUMMARY ", '.'.,,' . '.. BOP PSI TEST I LAST STOP CARD AUDIT I REGULATORY INSP? 2/12/2004 N MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG 274.00 2/12/2004 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Rig move and pad safety. I LAST RIG INSPECTION ¡!":¡'-'., STEP FROM 06:00 12:00 6.00 OPERATIONS SUMMARY· " TO. SUB PHASe .Of> $UBOP TRBLi 100 100 AF RDMO RIG RDMO CIO Pod on #2 mud pump. UD A-legs. Pull pump sheds anc generator shed. Load out trucks. 100 100 AF RDMO RIG RDMO Un-pin derrick. RID and split derrick. RID water tank and do~ house. RID sub and pull A-leg feet. Load drawworks. P/U pad. Load out 13 loads. Release crew early to go to days off 100 100 AF RDMO RIG RDMO Wait for crew comming on @ midnight. 100 100 AF RDMO RIG MIRU Set rig matting boards. Complete CIO of pod on#2 mud pump. 12:00 20:30 8.50 20:30 00:00 3.50 00:00 06:00 6.00 PERSONNEL DAtA NO. HOliR'S COMPANY 15 190.00 R&K Industrial 1 24.00 Peak Oilfield Service Co. PÔB,@;'q6:00: NO.' HOURS' 2 24.00 3 36.00 LAST BOP TEST: SIZE (ih) ". .\. :iO;(in>!SA0E:TEST (ppg~ 20.000 18.730 I " CASINGSUMM~RY, / LAST CASING TEST: MAX slCP .j MD(ft) I (psi) @ (ppg) 100 NEXT BOP TEST: . ~~¿ft) 'f ~~~~¿~> \ G~~E :.;. r B.UR5T (psi) Printed: 4/8/2004 10:00:25 . . OIL COMPANY Page 1 of 1 KB lling Report .Exploitation Gas GL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 IRPT# I DATE 3 13~~.e_b~:~~~ WELL NAME PAXTON 1 SUPERVISOR R.C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS @ 6AM RlU rig. OPERATION COMMENTS RlU rig. 124 HR PROG TMD TVD I DFSO I DOL1 100 100 AUTH MD WBS 9,793 dx0309781 capdrl MOC WI NR! II DA!L v WELL COST 9072831315 60.0000 60.0000 COUNTY/OTHER I LAST CASING I NEXT CASING 20.000 (in) @ 100 (ft) 9.625 (in) @ 1,900 (ft) 124 HR FORECAST Move rig and begin RlU. RIG PHONE CUM WELL COST I LEAKOFF LAST SAFETY MTG 2/13/2004 SAFEtFY SUMMARY I BOP PSI TEST I LAST STOP CARD AUDIT MANHRS WORKED I ACCIDENT TYPE 327.00 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: RlU rig. REGULATORY INSP? N I LAST RIG INSPECTION sq'ß: . PHASE..' 06:00 12:00 6.00 100 100 AF MIRU RIG MIRU 12:00 00:00 12.00 100 100 AF MIRU RIG MIRU 00:00 06:00 6.00 100 100 AF MIRU RIG MIRU Move loads to Paxton location. Set sub base. Unload trailers Set doghouse, drawworks, stage derrick trailers. Put pins in derrick feet. Set pump house generator house, boiler, connex, prep to P/U derrick. Set pits. Hook up lines and fire up boiler. Install windwalls on pits. Raise A-legs. Hook up and check out derrick lights. Hook up electrical lines and steam hoses. Nabors Alaska Drilling Marathon R&K Industrial P'ËRSONNELDAl'Ä' NO.. HOURS CQIÌl\PANY .' . 19 237.00 Peak Oilfield Service Co. 1 24.00 Weaver Brothers (WBI) 2 24.00 SERV{GE . ·p,9á@ 06:Q{): .' .... . NO. HQO~S 3 36.00 1 6.00 LAST BOP TEST: SIZE (in)! .1.D(¡¡,œlsHOE TEST· (þþgX 20.000 18.730 I LAST CASING TEST: . . MAX SICP I MD (ft) ·1 (psi) @ (ppg) 100 TVP(ft) . 100 NEXT BOP TEST: WT(!blft) I ØRAPE ····I:S.LJRST(PSi). 133.00 X-56 Printed: 4/8/2004 10:00:26 · . ON OIL COMPANY Page 1 of 1 WELL NAME PAXTON 1 SUPERVISOR R.C. Lawson F!ELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS @ 6AM RIU rig. OPERATION COMMENTS RIU rig. 124 HR PROG TMD TVD I DFSO 1 DOL2 1 RPT # I DATE 100 100 4 14-Feb-2004 AUTH MD WBS SAPIWBS COST 9,793 dx0309781capdrl R!G PHONE MOC W! MDI I ~AII V \AII::I I rnC:T 9072831315 60.0000 "~~.OOOO I un.. COUNTY/OTHER 1 LAST CASING I NEXT CASING 20.000 (in) @ 100 (ft) 9.625 (in) @ 1,900 (ft) 124 HR FORECAST RIU rig. IGL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 KB CUM WELL COST I LEAKOFF I ACCIDENT TYPE 315.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: RIU rig. . SAFETYiSUMMARY BOP PSI TEST LAST STOP CARD AUDIT < "~ i,"\:';H,j':; \;-<,><:¿(..~~;::: ;:;:j:<;' '~6SÙB 100 AF oÞe~TIONS-S.OM· 'r#JARY " PHASE oÞ SUBOP TRBl " , - - --- ---- -- - --- ~ -- -^ , ,¡ ,..>0" ,," MIRU RIG MIRU :à;~>?'/~t.:-):!r;;;;:':»:-i;,'.'-- STEP 'FRÒM, .'TO 06:00 12:00 HRS, FROM' 6.00 100 12:00 00:00 12.00 100 100 AF MIRU RIG MIRU Install Top Drive torque guide beam. Check bushings in tugger sheaves. Prep derrick to P/U. Move camp. Pin derrick to floor. Extend and pin A-legs. Set camp. Clean out rig water tank. Connect steam to pits. Spool drilling line. 00:00 06:00 6.00 100 100 AF MIRU RIG MIRU Tighten Deadman. Pull tension on blocks. Remove slings and chain from blocks. Remove chains from derrick. Pull derrick climber pole. Dress and set same. Inspect derrick. PJSM. Raise derrrick. RIU tuggers. Remove tieback lines from service loop. Hang lines. Prep to bridle down. "" PERSONNEL DATA , . :HQ~RS CQ\VPANY 18 225.00 Peak Oilfield Service Co. 1 24.00 Weaver Brothers (WBI) 2 12.00 CASING SUMMARY LAST CASING TEST: (:~ :I~;g) I M~O~ft) I ,POB@ 06:ÒQ: , NO, HOURS; ',' 3 36.00 2 18.00 COlVlPÄf\lY Nabors Alaska Drilling Marathon R&K Industrial LAST BOP TEST: SIZE (ili) liD (in) '[SHOE TEST (ppg~ 20.000 18.730 I TVD (ft) 100 NEXT BOP TEST: WT (Ib/ft) I GRADE 133.00 X-56 I BURST (psi). Printed: 4/8/2004 10:00:28 WELL NAME PAXTON 1 SUPERVISOR R.C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS @ 6AM Prep to install starter head. OPERATION COMMENTS RIU rig. . . Page 1 of 1 KB 124 HR PROG TMD TVD 1 DFSO I DOL3 I RPT # I DATE AUT~O~D WB;OO 5 ~:~~~~~~~~ 9,793 dx0309781 capdrl MOC WI NR! II DAILY WELL COST 60.0000 60.0000 I LAST CASING 1 NEXT CASING 20.000 (in) @ 100 (ft) 9.625 (in) @ 1,900 (ft) 124 HR FORECAST Install starter head. N/U diverter. P/U DP. Spud. IGL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 !>JG PHONE CUM WELL COST 9072831315 COUNTY/OTHER I LEAKOFF I LAST SAFETY MTG 2/15/2004 LAST BOP TEST: SIZE (in) 110 (in) ISHOE TEST (Ppg) 20.000 18.730 MANHRS WORKED I ACCIDENT TYPE 314.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: RIU top drive. ~'i .'-:-.:'-: :: ,-" STEP FROM TO HRS 06:00 08:30 2.50 08:30 12:00 3.50 FRO)ì,; 100 100 12:00 00:00 12.00 00:00 06:00 6.00 COMPANY Nabors Alaska Drilling Marathon R&K Industrial Weaver Brothers (WBI) SAFETY SUmMARY IBOP PSI TEST LAST STOP CARD AUDIT 2/15/2004 TO: SUB 100 AF 100 AF /Òì::tERATIONS SUMMARY::';;;' PHASÈ.OP SiJ~OP1RBL' MIRU RIG MIRU Install yoke to PIU top drive. Install standpipe manifold. MIRU RIG MIRU P/U top drive. Install 3 guide plates. Pin and hang TD. RID hanging apparatus. Set grasshoper. Hook up hydraulic hoses. Extend and pin tensioning cables. Work on water well. Begin to fill pits. Set centrifudge and control panel. Adjust pump house. Set lift station for DD camp. MIRU RIG MIRU RlU top drive. Streach out slide. Pin blocks to TD. Hook up water well. Repair leaks on hydraulic pump in substructure. Fill pits with water and prep to mix mud. Weld braces back under floor to doghouse. RlU kelly hose. Secure standpipe. RIU communication. CIO savor sub to 4 1/2 IF. MIRU RIG MIRU Accept rig @OO:OOhrs 2I15/04(due to time taken to modify dog house landing from last well). 100 100 AF 100 100 AF Clamp on TD saver sub. Install bales. Function test. Hang tongs. Hook up bleeder line. Organize floor. RlU gauges. Stage diverter spool and hydrill in sub. Set gas buster. DresE mud pumps w/6" liners. Mix mud. SERVICE PÒB @ 06:00: NO. HOURS 4 32.00 2 18.00 1 4.00 PERSÐNNEL DATA NO~ HOURS COMPANY 18 212.00 Alaska Petroleum Contra 1 24.00 Epoch Well Services 1 12.00 Baker Hughes Inteq 1 12.00 CASING SUMMARY LAST CASING TEST: MAX SICP I MD (ft) (psi) @ (ppg) 100 NEXT BOP TEST: WT (Ib/ft) GRADE 133.00 X-56 I BURST (psi) TVD (ft) 100 Printed: 4/8/2004 10:00:30 . . Page 1 of 2 WELL NAME PAXTON 1 SUPERVISOR R.C. Lawson FIELD NA.'IIE WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS @ 6AM PIU BHA. OPERATION COMMENTS Install 20 1/8" starting head. N/U 21 1/4" diverter and 16" diverter line. Test diverter. P/U 4" DP and 5" HWDP. P/U BHA. 124 HR PROG TMD100 TVD 100 I DFS 0 I DOL4 I RPT #6 AUTH MD WBS 9,793 dx0309781capdrl MOC WI NRI II DAILY WELL COST 9072831315 60.0000 60.0000 COUNTY/OTHER I LAST CASING I NEXT CASING 20.000 (in) @ 100 (ft) 9.625 (in) @ 1,900 (ft) 124 HR FORECAST Spud well. Drill ahead. IGL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 DATE 16-Feb-2004 SAPIWBS COST KB R!G PHONE CUM WELL (;0:>1 I LEAKOFF . SA;ETY SUMMARY I BOP PSI TEST I LAST STOP CARD AUDIT 2/15/2004 r LAST RIG INSPECTION MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG 338.00 None 2/15/2004 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: General safety(weekly safety meeting). 06:00 08:30 2.50 100 100 AF DRLSUR NUND UwLH Cut and bevel 20" conductor. 08:30 12:00 3.50 100 100 AF DRLSUR NUND UwLH Install Vetco 20 1/8" slip on starting head. Test to 600psi/5min. Pull test to 10K. N/U 2 1/4" diverter spool. 12:00 22:00 10.00 100 100 AF DRLSUR NUND UBOP N/U 21 1/4" Diverter and 16" diverter line. N/U bell nipple and flowline. Hook up koomey lines. PIU 1 joint 4" DP. Test diverter. RIU Geronimo line. Dress mud pumps w/6" liners. 22:00 00:00 2.00 100 100 AF DRLSUR EQUIP RSEQ Prep to P/U 4" DP. Move service loop to back of derrick. Repair hydraulic leak in pipe spinner line. 00:00 01:30 1.50 100 100 AF DRLSUR TRIP PUDP P/U 42 joints 4" 15.7ppf DP and rack back in derrick. 01:30 03:00 1.50 100 100 AF DRLSUR TRIP PUDP Stap and P/U 23jnts 5"50PPF HWDP and 6 3/4" jars and rack back. 03:00 06:00 3.00 100 100 AF DRLSUR TRIP BBHD P/U 8" navidrill motor and M/U 12 1/4" bit. P/U 12 1/8" stab and monel collar. Tag @ 37'. UD stab and monel. DENSITY(ppgl I FV\ PVlYP I 60 16/41 8.70 . GÊ4S 18/32 I PP I ';è WUHTHP .\ 12.41 I ÈCD; IMi!JDD~1~I;;ÞÀl~~<~QS1ol F:'~:'~L I ~7 1~;:~Brr~~~~:;lo~;~61 elTs JÉTS ORTFA 18/18/18/16111111 'CI/Ca' 700/40 I iCO' 'êÓST .; M";H ICaCí2(wt%iH2S LÌME I ESii:l' 6~~M BIT/RON SIZE 1 11 12.250 BIT/RUNI WOB 0 12-2-WT-A-E- 1-NO-TD 24Hr ROPO ¡CUM HRsl CUM DEPTH!) I CUM ROPO RPM FloRtO PRESSO PBITO HRS I . 24Hr DISTO BHA NO. LEN.(ft) 1 792.3 BHA DESCRIPTION BHA I EFF WTO I P/UO I S/OO I ROT WTO I TORÓUE(~axlmin) 0 I BHA hrs I JAR hrs I MWD hrs I MTR hrs I 58 hrs 121/4" HTC MX C1 bit, 8" M1C/1.4AKO/12 1/8" UBHS , 121/8" IBS , 8" MWD , 8" HANG OFF SUB, 6 5/8" H-90-P X 4 1/2"IF-B , 5" 49.5PPF HWDP (4), 6 1/4" DAILEY HYDRAULlC-MECH JARS, 5" 49.5PPF HWDP (19), 4 1/2" IF-P X HT-40-B ,4" 15.7PPF S-135 HT40 DP COMPANY Nabors Alaska Drilling Marathon Weaver Brothers (WBI) SERVICE PERSONNEL DATA NO. HOURS COMPANY 19 210.00 Alaska Petroleum Contra 1 24.00 Baker Hughes Inteq 1 12.00 Epoch Well Services SERVICE POB @ 06:00: NO. HOURS 4 32.00 2 24.00 2 24.00 Pr; nted: 4/8/2004 1 0 :00 :31 . WELL NAME PAXTON 1 SERVICE M-I Drilling Fluids LAST BOP TEST: MARATHON OIL COMPANY 17.0 144.00 124 HR PROGTMD 100 . ITVD 100 IDFSO IRPT# 1 DATE 6 16-Feb-2004 PERSONNEL DATA NO. I HOURSII COMPANY 1 12.00 DOL 4 LAST CASING TEST: NEXT BOP TEST: Printed: 4/8/2004 10:00:31 . . MARATHON OIL COMPANY Page 1 of 2 D WELL NAME PAXTON 1 SUPERVISOR R.C. Lawson FIELD NAME 124 HR PROG TMD TVD 1 DFS1 1 DOL5 1 RPT # I DATE 750.0 850 845 7 17-Feb-2004 AUTH MD WBS SAPIWBS COST 9,793 dx0309781capdrl MOC WI NRI 1 CAlLY WELL COST 9072831315 60.0000 60.0000 COUNTY/OTHER IL;~~o~~;~:) @ 100 (ft) INEX19~~~'(¡n) @ 1,900 (ft) I. 24 HR FORECAST Drill ahead. GL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 KB RIG PHONE CUM WELL COST WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS@ 6AM Drilling ahead @ 850'. OPERATION COMMENTS Clean 20" conductor 37' to 100'. Drill F/100' to 790'. Wiper trip. CIO saver sub. RIH. Drill F1790' to 850'. _o-ho"_.' SAFETY SUMMARY BOP PSI TEST LAST STOP CARD AUDIT I REGULATORY INSP? I LAST RIG INSPECTION 2/16/2004 N MANHRS WORKED I ACCIDENT TYPE 399.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Making connections. 06:00 09:00 . .' OPERATJONS,SUMMA'R¥ SUB . PHASE' "OP SUBOP TRBL' 211 AF DRLSUR DRILL DOHD ÓÉSCRIPll0N . RIH tag @ 37'. Clean 20" condutor to 100'. Dir drill and survey F/100' to 211'(ART=1.69hrs). POOH. P/U MWD. Scribe motor and MWD. Service top drive brake. RIH. Tag @ 140'. Wash to bottom. Dir drill and survey F/211' to 250'(ART=.3hrs). CIO top stand of 5" HWDP to stand w/6 1/4" jars. Pump a high vis sweep. Flowline plugged with gravel. Clean flowline and possum belly. Dir drill and survey F/250' to 790'(getting overpull picking up off slips at connections(ART=2Ahrs AST=2.6hrs). Pump a high vis sweep and circ. clean(CBUX3)(Iarge volume of gravel across shakers). Pump out to 610'. Tight @ connection. Wash to bottom. Pump 2 high vis sweeps and circ. clean(CBUX3)(large volume of gravel across shakers). 790 AF DRLSUR TRIP WTRP POOH to 68'(hole slick). 790 AF DRLSUR RIG SERV Service rig and adjust brakes. CIO saver sub to HT-40. 790 AF DRLSUR TRIP WTRP RIH tag @ 780'(10' fill). Wash to 790'. 850 AF DRLSUR DRILL DOHD Dir drill and survey F1790' to 850'(AST=.7hrs). IECDI IMUD DATAl DAILY COST I I CUM COST FCIT.SOL OIWI %Sand/MBT Ph/pM PflMf I CIICa ICaCI2(wt%~ H2S LlME 2.014.5 196 0.75/15.0 9.001004 0.310.8 800/20 I 100 09:00 10:30 1.50 211 211 AF DRLSUR TRIP BBHD 10:30 12:00 1.50 211 211 AF DRLSUR TRIP BHA 12:00 13:30 1.50 211 250 AF DRLSUR DRILL DOHD 13:30 15:00 1.50 250 250 AF DRLSUR CIRC CLN 15:00 22:00 7.00 250 790 AF DRLSUR DRILL DOHD 22:00 23:00 1.00 790 790 AF DRLSUR CIRC CLN 23:00 00:30 1.50 790 790 AF DRLSUR TRIP WSHR 00:30 01 :30 01 :30 03:30 03:30 04:30 04:30 06:00 1.00 2.00 1.00 1.50 790 790 790 790 DENSITY(ppg) I FV I pV/YP I 77 17/28 9.00 GELS I 17/36 I pp I WUHTHP 11.61 ES 16~;M BITS BIT/RUN SIZE MANUF. TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE IN I I·O-D~L-B.G·O-R 1 11 12.250 HTC MXC1 6021539 18/18/18/161111I1 100.0 2/1612004 2-2-WT-A-E- 1-NO-TD BIT/RUN WOB (kip) RPM GPM PRESS(psi) I P BIT(psi) HRS I 24Hr DIST(ft) j24Hr ROP(ft/hr) ICUM HRSI CUM DEPTH(ft) I CUM ROP(ft/hr) 1/1 1/5 80/100 630 1,300 371 7.70 750.0 97040 7.70 750.0 97.40 BHA N0'1 LEN.(ft) 1 792.3 BHA DESCRIPTION BHA I EFF WT(lb) I P/U(lb) I S/O(lb) I ROT WT(lb) I TORQUE(max/min) (ft-Ibf) BHA hrs I JAR hrs I MWD hrs MTR hrs I SS hrs 48,000 65,000 62,000 62,000 2,500/2,000 7.70 121/4" HTC MX C1 bit, 8" M1C/1AAKO/12 1/8" UBHS , 12 1/8"IBS, 8" MWD, 8" HANG OFF SUB, 65/8" H-90-P X 4 Printed: 4/8/2004 10:00:33 . . MA Page 2 of 2 WELL NAME PAXTON 1 IKB 17.0 124 HR PROGTMD 750.0 850 TVD 845 IDFS1 I DOL5 IRPT# 1 DATE 7 17-Feb-2004 BHA BHA DESCRIPTION 1/2"!F-B , 5" 49.5PPF HWDP (4),61/4" DAILEY HYDRAUL!C-MECH JARS, 5" 49.5PPF HIJIJDP (19), 4 1/2" IF-P X HT-40-B , 4" 15.7PPF S-135 HT40 DP NO. 1 2 MAKE OF PUMP GARDNER-DENVER GARDNER-DENVER PUMP/ HYDRAULIC DATA STROKE (in) , LINER (in) SPM Q (gpm) 9.000 6.000 100 317.26 9.000 6.000 100 317.26 PRESS. (psi) TOTAL Q 1,300 634.52 1,300 634.52 KILL SPM I PRESSURE AVG. CONN: MAX. CONN: ,MUD GAS AVG. TRIP: MAX. TRIP: UNITS 10 80 ~~úf¥1ìDlê>~¡¡;,~~ 0.0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 466.0 7.10 339.10 465.37 15.85 12.83 -9.99 3.34 110.0 0.10 274.40 110.00 0.05 0.01 -0.10 0.09 555.0 7.20 340.00 553.68 26.89 23.21 -13.86 0.17 195.0 1.00 274.40 195.00 0.45 0.07 -0.91 1.06 645.0 8.00 339.60 642.88 38.75 34.38 -17.97 0.89 286.0 1.90 307.10 285.97 2.17 1.04 -2.90 1.31 735.0 10.10 339.50 731.76 52.87 47.64 -22.92 2.33 376.0 4.40 325.50 375.83 6.90 4.79 -6.05 2.96 Nabors Alaska Drilling , N~\f\ ~9 210.00 Epoch Well Services Marathon , ~t\t\t' t\\L 24.00 M-I Drilling Fluids Weaver Brothers (WBI) ( ,'\1 ~{\ \J \.... 1 5.00 R&K Industrial Alaska Petroleum Contr ._~ 4 32.00 Quadco Baker Hughes Inteq 2 48.00 S&R Enterprises 2 1 2 1 2 24.00 24.00 20.00 10.00 2.00 CASING SUMMARY LAST CASING TEST: , , , MAX SICP 1 MD (ft) 'I (psi) @ (ppg) 100 LAST BOP TEST: ,Sl2:E (in) 1: ,10.: (in) ,SHOE JEST (pþgi'" 20.000 18.730 I TVD (ft) 100 NEXT BOP TEST: ~~~~~:)I G~~E EiURS'I:!(/)Si). Printed: 4/8/2004 10:00:33 MANHRS WORKED ACCIDENT TYPE I LAST SAFETY MTG 367.00 None 2/18/2004 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Tripping pipe pinch points. .0 SUB PHÂSE 01;' Só-ŠOP 19:00 13.00 850 1,653 AF DRLSUR DRILL DOHD 19:00 20:00 1.00 1,653 1,653 AF DRLSUR CIRC CLN 20:00 02:30 6.50 1,653 1,905 AF DRLSUR DRILL DOHD 02:30 04:30 2.00 1,905 1,905 AF DRLSUR CIRC CLN 04:30 05:30 1.00 1,905 1,905 AF DRLSUR TRIP WTRP Dir drill and survey F/850' to 1653'(AST=5.59hrs ART=3.89hrs). 600 units gas Circ. out gas. Simulate a connection. Conn gas 10 units. Dir drill and survey F/1653' to 1905'(AST=3.58hrs ART=.78hrs). Circ clean(CBUX5)(pump hi vis sweep, 100-120RPM, 630gpm). POOH(tight @ 1100', 950', 920'(pulled 20kover) WIR 920' to 880' 0.50 1,905 1,905 AF DRLSUR CIRC CLN Circ. shakers clean(100RPM 635GPM). I ECp 19.51 I MUD:;¡DATA DAILY COST I I CUM COST F~~;~L 1';:1 ~:~~.:TI~~~~0~4' I 0~;;::1' 4~~;~"" [Qa,CJ2(wt%1 H2S WELL NAME PAXTON 1 SUPERVISOR R.C. Lawson F!ELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS@ 6AM POOH. OPERATION COMMENTS Drill F/850' to 1905'. Circ. clean. Wiper trip. 05:30 06:00 DENSITY(ppg) I 9.40 i:: l~~7: I ~~~S I l·ppl w~~tíP I . . MARATHON OIL Page 1 of 2 Daily Drilli ort Exploitation Gas IGL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 RIG PHONE KB 124 HR PROG TMD TVD I DFS2 I DOL6 I RPT # I DATE 1,055.0 1,905 1,688 8 18-Feb-2004 AUTH MD WBS SAPIWBS COST 9,793 dx0309781capdrl MaC WI NR! II CAlLY WELL COST 60.0000 60.0000 I LAST CASING 1 NEXT "A::ïINü I LEAKOFF 20.000 (in) @ 100 (ft) 9.625 (in) @ 1,900 (ft) 124 HR FORECAST Condo hole. Run CSG. Cement. CUM WELL COST 9072831315 COUNTY/OTHER SA~ETYSUMMARY. ¡BOP PSI TEST I LAST STOP CARD AUDIT RNEGULATORY INSP? 2/18/2004 I LAST RIG INSPECTION - LIME IES 16R;M BIT/RUNI WOB (kip) I RPM I GPM I PRESS(psi) I P BIT(psi) 1 11 5 I 9 100 1120 630 1,750 387 HRS I 24Hr DIST(ft) 124Hr ROP(ftlhr)ICUM HRSICUM DEPTH(ft)ICUM ROP(ftIhr) 13.90 1,055.0 75.90 21.60 1,805.0 83.56 BHA I EFF WT(lb)I. P/U(lb) S/O(lb) ROT WT(lb) TORQUE(maxlmin) (ft-1bfJ BHA hrs I JAR hrs I MWD hrs I MTR hrs I S8 hrs 48,000 68,000 68,000 68,000 3,500/3,000 22.00 121/4" HTC MX C1 bit, 8" M1C/1.4AKO/12 1/8" UBHS , 121/8" IBS , 8" MWD , 8" HANG OFF SUB, 6 5/8" H-90-P X 4 1/2"IF-B , 5" 49.5PPF HWDP (4), 6 1/4" DAILEY HYDRAULlC-MECH JARS, 5" 49.5PPF HWDP (19), 41/2" IF-P X HT-40-B ,4" 15.7PPF S-135 HT40 DP . BHA NO. \ LÈN.(ft) 1 792.3 BHA DESCRIPTION NO. 1 2 MAKE OF PUMP GARDNER-DENVER GARDNER-DENVER AVG. CONN: MAX. CONN: PUMP 1 HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) 9.000 6.000 100 317.26 9.000 6.000 100 317.26 PRESS. (psi) TOTAL Q 1,750 634.52 1,750 634.52 KILL SPM / PRESSURE 8 MUD GAS AVG. TRIP: MAX. TRIP: 40 725 UNITS AVG. BKGRD: MAX. DRL: Printed: 4/8/2004 10:00:35 . . Page 2 of 2 WELL NAME IKB IGL 124 HR PROGITMD ITVD IDFS2 1 DOL6 RPT# 8 I DATE PAXTON 1 17.0 144.00 1,055.0 1,905 1,688 18-Feb-2004 SI.JR~ES¥Ð~l'A MD INGb AZIMUTH TVD VS NfS GUM EIVV GUMDOGbEG MD INGb AZIMUTH ND VS NfSGUM ElW CUMDOGŒG 833.0 14.20 335.90 827.55 73.46 66.67 -30.84 4.25 1,406.0 35.60 335.00 1,337.99 325.93 295.54 -137.42 1.80 929.0 18.90 337.30 919.54 100.78 91.78 -41.65 4.91 1,502.0 38.80 334.30 1,414.44 383.96 347.98 -162.28 3.36 1,024.0 23.10 334.70 1,008.21 134.81 122.84 -55.56 4.53 1,598.0 42.70 334.20 1,487.16 446.61 404.41 -189.50 4.06 1,120.0 26.80 334.80 1,095.24 175.30 159.46 -72.83 3.85 1,693.0 47.30 334.60 1,554.31 513.76 464.98 -218.51 4.85 1,216.0 30.40 334.20 1,179.51 221.24 200.92 -92.63 3.76 1,789.0 50.80 334.80 1,617.22 586.26 530.52 -249.49 3.65 1,311.0 33.90 334.70 1,259.93 271.78 246.53 -114.42 3.69 1,850.0 52.30 333.90 1.655.15 634.03 573.59 -270.17 2.72 , SERVICE PESRSONNESL ÐÅ1tA' , 'liío.' HOIJRS COMPANY 19 210.00 Epoch Well Services 1 24.00 M-I Drilling Fluids 1 5.00 R&K Industrial 2 48.00 Swaco ,~OB @ 06:00: .' eNO. í-IþURS' 2 24.00 1 24.00 4 24.00 1 8.00 LAST BOP TEST: stzE(irì)' ID (iÒ> [SHQE TeST (ppg~ ," 20.000 18.730 I GASING'SUIllÍMARY LAST CASING TEST: (~~:I~;g) "" "l i~~~obft)'; ' , NEXT BOP TEST: ~~~ft) 1 :~~~~~;) I"G~~e .-.[ BURST (p$i) Printed: 4/8/2004 10:00:35 · . MARATHO~ OIL COMPANY Page 1 of2 D WELL NAME PAXTON 1 SUPERVISOR R.C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS@ 6AM WOC. Prep to N/D. Empty and clean pits. OPERATION COMMENTS Circ. clean. Cont. POOH. Service rig. RIH. GL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 RIG PHONE 124 HR PROG TMD TVD 1 DFS3 DOL7 I RPT # I DATE 1,905 1,688 9 19-Feb-2004 AUTH MD WBS SAPIWBS COST 9,793 dx0309781 capdrl MOC W! NR! II DAILY WELL COST 60.0000 60.0000 1 lAST CASING 1 NEXT CASING . - .- 9.625 (in) @ 1,895 (ft) 7.000 (in) @ 4,950 (ft) 124 HR FORECAST WOC. N/D diverter. N/U BOP and test. P/U DP. rill.. \A'~I' ,..,..-- KB 9072831315 COUNTY/OTHER " . i I LEAKOFF Circ. clean. POOH. UD BHA. Run and cement 9 5/8" CSG. WOC prep to N/D. : ,I, -,',:",,', " 0,'/,.,/ ',:,: MANHRS WORKED I ACCIDENT TYPE I lAST SAFETY MTG 459.00 None 2/19/2004 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: High pressure lines. " . . .SAFET¥SUMMARY IBOP PSI TEST I lAST STOP CARD AUDIT I REGULATORY INSP? 2/18/2004 N I lAST RIG INSPECTION 06:00 06:30 0.50 1,905 1,905 AF DRLSUR CIRC CLN Circ. clean(100RPM, 635GPM). 06:30 07:00 0.50 1,905 1,905 AF DRLSUR TRIP WTRP Cont. POOH. Tight @ 839'(W/R to 790'). Clean off BHA and Bit. 07:00 08:00 1.00 1,905 1,905 AF DRLSUR TRIP WTRP CIO elevators. POOH(SLM). Clean BHA and bit. 08:00 09:00 1.00 1,905 1,905 AF DRLSUR RIG SERV Service rig. 09:00 11:00 2.00 1,905 1,905 AF DRLSUR TRIP WTRP RIH to 1905'(tag bridge @ 1677 W/R bridge). 11:00 13:00 2.00 1,905 1,905 AF DRLSUR CIRC CLN Circ. shakers clean (pump high vis sweep CBUX3, 330 units trip gas, 630gpm 120RPM). Observe well no static losses. Pump dry job. 13:00 15:00 2.00 1,905 1,905 AF DRLSUR TRIP BHA POOH(hole slick). 15:00 16:00 1.00 1,905 1,905 AF DRLSUR TRIP BBHD B/O bit UD MWD and motor. 16:00 19:00 3.00 1,905 1,905 AF CSGSUR EQUIP RURD RlU Weatherford CSG tools. Prep to P/U CSG. 19:00 19:30 0.50 1,905 1,905 AF CSGSUR CSG RUN PJSM prior to running CSG. 19:30 23:00 3.50 1,905 1,905 AF CSGSUR CSG RUN Bakerlok and M/U shoe tract. Run 46jnts 9 5/8" 47PPF L-80 Mod-Butt CSG. Shoe @ 1895', FC @ 1811'. 23:00 00:30 1.50 1,905 1,905 AF CSGSUR EQUIP RURD RD spider slips and fill up tool. RlU BJ cement head and cement lines. 00:30 02:00 1.50 1,905 1,905 AF CSGSUR CIRC MUD Circ. 1.5XCSG volume(200bbls)(6.5BPM 100psi, 118units gas@B/U). PJSM prior to cementing CSG. 02:00 03:00 1.00 1,905 1,905 AF CSGSUR CEMT PRIM Pump 5bbls water ahead. Test lines to 3000psi. Drop bottorr plug. Pump 30bbls 8.4ppg spacer ahead wlrig pumps. Mix and pump 515sxs Type 1 cement w/18%LW-6, 20%MPA-1, 1%SMS, .3%CD-32, 19phs FP-6L to yield 230bbls 12.0ppg slurry. 03:00 03:30 0.50 1,905 1,905 AF CSGSUR CEMT PRIM Drop top plug and kick out w/5bbls water from BJ. Displace w/128bbls 9.5ppg mud. Bump plug w/1800psi, 1500psi over displacement pressure. Bleed off pressure and check floats hold. CIP@03:30hrs. 60bbls cement to surface. 03:30 06:00 2.50 1,905 1,905 AF CSGSUR CEMT PRIM RID cement lines. UD cement head. Flush stack. Prep to N/D diverter. Empty pits. DeNSITY(ppg) 9.50 I PP I I ECD 19.51 IMIlD DAmA I DAILY COST I I CUM COST FV I PVJYP GELS WLlHTHP FCrLSOL I OIW I %Sand/MBT I Ph/pM I Pf/Mf I \:;olIva I CaCI;2(Wt%1 H2S LIME I ES '6R;M 52 18/12 5112 7.61 2.0/8.0 192 0.75/20.0 9.50/0.5 0.3/0.9 400/20 Printed: 4/8/2004 10:00:37 . . MARA1HON 0 D ANY Page 2 of 2 BIT/RUN SiZe: 1 11 12.250 1RR1/212.250 BIT/RUN WOB (kip) I 1RR1/~ I MANUF. HTC HTC KB IGL 124 HR PROGTMD ITVD IDFS3 IDO~ RPT# DATE 17.0 144.00 1,905 1,688 9 19-Feb-2004 BITS TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE I!\! I-O-D-L-B-G-O-R MXC1 6021539 18/18/18/16111/11 100.0 2/1612004 2-2-WT-A-E- 1-NO-TD MXC1 6021539 18/18/18/16111111 1,905.0 2/18/2004 2-2-WT-A-E- 1-NO-TD WELL NAME PAXTON 1 RPM GPM I PRESS(psi) I P BIT(psi) HRS I 24Hr DIST(ft) 24Hr ROP(ftlhr)\CUM HRS\CUM DEPTH(ft)CUM ROP(ftlhr) BHA NO.. LEN:(ft). 2 792.3 BHA DESCRIPTION ;BHA c·. I EFF VVT(fb>.¡ P/U(lb)! S/O(l!:i) ROT WT(lb)! TQRQUE(ma~min)(ft-lbf) I BHA hrs) JAR h~I·' MWO.hrs!· cMTR hrs 48.000 68,000 68,000 68,000 / 22.00 12 1/4" HTC MX C1 bit, 8" M1C/1.4AK0/12 1/8" UBHS , 12 1/8" IBS , 8" MWD , 8" HANG OFF SUB, 65/8" H-90-P X 4 1/2"IF-B , 5" 49.5PPF HWDP (4), 6 1/4" DAILEY HYDRAULlC-MECH JARS, 5" 49.5PPF HWDP (19), 41/2" IF-P X HT-40-B, 4" 15.7PPF S-135 HT40 DP Nabors Alaska Drilling Marathon Baker Hughes Inteq Epoch Well Services M-I Drilling Fluids 18 225.00 R&K Industrial 3 24.00 1 24.00 Weatherford 3 30.00 2 48.00 BJ Services 3 24.00 4 48.00 S&R Enterprises 2 2.00 1 24.00 Peak Oilfield Service Co. 2 10.00 LAST BOP TEST: SIZE (i~) ID (jO) SH<D.E TEST (ppg) 20.000 18.730 9.625 8.681 LAST CASING TEST: . . MAX SICP M[)(ft) (psi) @ (ppg) 100 (psi) @ (ppg) 1,895 TVD (ft) 100 1,682 NEXT BOP TEST: WT (Ib/ft) . GRADE· 133.00 X-56 47.00 L-80 BURST (psi) 6,870 Printed: 4/8/2004 10:00:37 WELL NAME PAXTON 1 SUPERVISOR R.C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS @ 6AM Prep to test BOPE. OPERATION COMMENTS Empty and clean pits while WOC. MANHRS WORKED I ACCIDENT TYPE 461.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: N/U BOPE. . . Oil COMPANY Page 1 of 1 iIIin9 Report Exploitation Gas IGL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 KB 124 HR PROG TMD TVD 1 DFS4 I DOL8 1 RPT # I DATE 1,905 1,688 10 20-Feb-2004 AUTH MD WBS "'ADIWR.C: r:OST 9,793 dx0309781 capdrl MOC WI NRI I ....n v \Ill'" I r:OST 60.0000 60.0000 I 1 LAST CASING I NEXT CASING I LEAKOFF 9.625 (in) @ 1,895 (ft) 7.000 (in) @ 4,950 (ft) 124 HR FORECAST Test BOP. P/U DP. Drill out. RIG PHONE CUM "¡YELL COST 9072831315 COUNTY/OTHER N/D diverter. Remove starter head. Install 11" 5M wellhead. N/U 135/8" BOPE. Prep to test BOPE. I LAST SAFETY MTG 2/19/2004 SAFETY SUMMARY BOP PSI TEST I LAST STOP CARD AUDIT I REGULATORY INSP? 2/18/2004 N 06:00 11:30 5.50 1,905 1,905 RURD While WOC. Empty and clean pits. Clean and organise rig. Prep to N/D diverter. 11:30 12:00 0.50 1,905 1,905 AF CSGSUR NUND DBOP NID 16" diverter line and knife valve. N/Ddiverter and P/U. 12:00 14:30 2.50 1,905 1,905 AF CSGSUR NUND DBOP Rough cut 9 5/8" CSG and UD cut JNT. RID flow nipple. RID diverter. NID diverter spool. 14:30 17:00 2.50 1,905 1,905 AF CSGSUR NUND DWLD Release slips on starter head. Remove starter head. Cut 20". Final cut and dress 9 5/8" CSG. 17:00 18:00 1.00 1,905 1,905 AF CSGSUR NUND UwLH Install 11" 3M X 11" 5M vetco wellhead. Test seals to 1500psi/10min. Pull test to 10K. 18:00 00:00 6.00 1,905 1,905 AF CSGSUR NUND UBOP PJSM prior to N/U. N/U 11"5M X 13 5/8" 5M adaptor spool. N/U 135/8" 5M S,Rd,A BOP stack. 00:00 05:30 5.50 1,905 1,905 AF CSGSUR NUND UBOP N/U choke and gas buster lines. Function test BOPE. Spot choke house and beaver slide. Set pipe racks. Layout DP. 05:30 06:00 0.50 1,905 1,905 AF CSGSUR TEST BOP M/U test JNT. Set test plug. COMMENTS Mix new flopro mud. DENSI"P(I\!Rflt I :: I ~:~;I 9.50 :~~S I I PP I W;~~~P I COMPANY Nabors Alaska Drilling Marathon Baker Hughes Inteq Epoch Well Services M-I Drilling Fluids LAST BOP TEST: SIZE (in) ID (in) SHOE TEST (ppg) 20.000 18.730 9.625 8.681 IEèbl FCIT :SOL '\ 2.0/8.0 IMUDDATAI DAlLYr;Q~T I Ofw 'I ofoSand/MBTI Ph/pM ''PflMf\ 192 0;5/20.0 9.50/0.4 0.311.3 I cuMèoST CaCI2(Wt%1 H2S LIME 1 ES 16R;M pOß @ 06:00: NQ, HOURS 3 36.00 4 20.00 4 20.00 2 8.00 Cl/Ca 400/20 SERVICE PERSONNEL DATA NO. HOliRSCOMPANY 19 233.00 R&K Industrial 1 24.00 Peak Oilfield Service Co. 2 48.00 Alaska Petroleum Contra 4 48.00 Weaver Brothers (WBI) 1 24.00 SERVICE CASING SUMMARY LAST CASING TEST: MAX SICP MD (ft) (psi) @ (ppg) 100 (psi) @ (ppg) 1,895 NEXT BOP TEST: WT (Ib/ft) GRADE 133.00 X-56 47.00 L-80 TVD (ft) 100 1,682 BURST (psi) 6,870 Printed: 4/8/2004 10:00:39 WELL NAME PAXTON 1 SUPERVISOR R.C. Lawson F!ELD NAME . . MARATrHON OIL COMPANY Page 1 of 2 Drilling Report loitation Gas 124 HR PROG TMD TVD I DFS5 1 DOL9 I RPT # I DATE 131.0 2,036 1,764 11 21-Feb-2004 AUTH MD WBS SAPIWBS COST 9,793 dx0309781 capdrl MOC WI NRI I CAlLY WELL COST 60.0000 60.0000 1 NEXT CA:>ullü - - - I LEAKOFF 1,895 (ft) 7.000 (in) @ 4,950 (ft) 16.87 IGL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 RIG PHONE KB CUM "'¡ELL COoS. WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS @ 6AM Drilling ahead @ 2036'. OPERATION COMMENTS Test BOPE. Test CSG. P/U 4" DP. P/U BHA. RIH. Drill shoe tract and shoe. Drill 20' new hole to 1925'. Perform LOT. Drill F/1925' to 2036'. 9072831315 COUNTY/OTHER I LAST CASING 9.625 (in) @ 124 HR FORECAST Drill ahead. , SAFETYSUIlAMARY IBOP PSI TEST I LAST STOP CARD AUDIT I REGULATORY INSP? 2/20/2004 2/19/2004 N I LAST RIG INSPECTION 2/16/2004 MANHRS WORKED I ACCIDENT TYPE ' LAST SAFETY MTG 442.00 None 2/20/2004 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: High pressure lines. 06:00 07:30 07:30 10:00 10:00 13:00 1.50 2.50 3.00 1,905 1,905 1,905 Ji,ø, , ,SOB PHASI::' .'(jp 1,905 AF CSGSUR TEST 1,905 AF CSGSUR LOC 1,905 AF CSGSUR TEST SÒBOÞ BOP LCLN BOP 13:00 14:00 1.00 1,905 1,905 AF CSGSUR EQUIP RURD 14:00 14:30 0.50 1,905 1,905 AF CSGSUR TRIP WEAR 14:30 15:30 1.00 1,905 1,905 AF CSGSUR TEST CSG 15:30 16:00 0.50 1,905 1,905 AF CSGSUR RIG SERV 16:00 20:00 4.00 1,905 1,905 AF CSGSUR TRIP PUDP 20:00 22:30 2.50 1,905 1,905 AF CSGSUR TRIP BBHD 22:30 23:00 0.50 1,905 1,905 AF CSGSURMwdLwd MwDU 23:00 00:30 1.50 1,905 1,905 AF CSGSUR TRIP PUDP 00:30 01:30 1.00 1,905 1,905 AF CSGSUR DRILL CEMT 01:30 02:00 0.50 1,905 1,925 AF CSGSUR DRILL DOHD 02:00 02:30 0.50 1,925 1,925 AF CSGSUR MUD CHNG 02:30 03:00 0.50 1,925 1,925 AF CSGSUR TEST LOT 03:00 03:30 0.50 1,925 1,925 AF CSGSUR TEST LOT 03:30 06:00 2.50 1,925 2,036 AF DRLlN1 DRILL DOHD COMMENTS BOP test witnessed by Lou Grimaldi AOGCC. DENSITY(ppg) FV I PVNP 109 15/28 9.15 I PP I I ECD I GELS I WUHTHP I Fcrr.SOL I 6/14 7.21 1.0/6.0 IMUD DATAl DAILY COST I Olw I %Sand/MBT I Ph/pM I Pf/Mf I 194 /1.0 9.7010.9 0.612.0 Cl/Ca 28,000/20 I CUM COST I CaCI2(wt°1 H2S LIME I ES ¡ 6~~M BIT/RUN SIZE I MANUF. 2 13 8.500 HTC BIT/RUNI WOB (kip) I RPM I 2 I 3 110 120 1120 Shell test BOP to 250/3000psi. Clean location. Strap DP on rack. Test Hydril, inside and outside kill valves, HCR valve, TIW valve, IBOP valve, upper and lower TD valves, CMV 1-18 to 250/3000psi 5min. Perform Koomey test. Test Blind rams and inside choke to 250/3000psi 5min. P/U 7" hanger assy and landing joint and M/U. Test run hanger assy and UD. Set wear bushing. Test 9 5/8" CSG against blind rams 3000psi/30min. Service rig. Install safety clamp on kelly hose. P/U 69jnts of 4" DP and rack back in derrick. PIU 8.5" bit and directional BHA. RIH w/5" HWDP. Test MWD. P/U 30 jnts 4" DP while RIH. Tag cement @ 1806'. Drill float collar @ 1811'. Drill cement and shoe to 1895'. Clean old hole to 1905'. Dir drill and survey F/1905' to 1925'(ART=.25hrs). Displace well to new 9.15ppg flopro mud. R/U BJ. PJSM prior to LOT. Perform LOT to 16.8ppg EMW(9.15ppg MW, 670psi). Dir drill and survey F/1925' to 2036'(ART=.65hrs AST=1.26hrs) BITS JETS OR TFA 15/15/15/15/1511111 TYPE I SERIAL N°'1 HCM605 7103535 GPM I PRESS(psi) I P BIT(psi) 539 1,200 329 DEPTH IN DATE IN 1,905.0 2/20/2004 I-O-D-L-B-G·O-R O-O-NO-A-D- I-NO-TD HRS I 24Hr DIST(ft) 124Hr ROP(ftIhr) [CUM HRSI CUM DEPTH(ft) I CUM ROP(ftIhr) 2.16 131.0 60.65 2.16 131.0 60.65 Printed: 4/8/2004 10:00:41 · . MARATHON OIL COMPANY Page20f2 iUin'g Report loitation Gas WELL NAME PAXTON 1 IKB 17.0 IGL 144.00 124 HR PROGITMD 131.0 2,036 ITVD IDFS 1,764 5 I DOL9 IRPT# I DATE 11 21-Feb-2004 I\iIAKE qF PUMP GARDNER-DENVER GARDNER-DENVER BHA II EFF WT(lb) II P/U{lb) S/O(lb) ROT WT{lb) TORQUE{ma"Jmin) (ft-!bf) II BHA hrs II JAR hrs I MWD hrs II MTR hrs I SS hrs 43,000 70,000 62,000 62,000 4,200/3,900 24.00 8-1/2" HTC HCM605 PDC Bit, 63/4" M1XU.8AKO/8 3/8" UBHS , 8-3/8" NMWBS ,65/16" MWD , 6 1/2" HOS ,41/2" H-90-P X 41/2" IF-B , 5" 49.5 ppf HWDP (4), 6-1/4" DAILEY HYDRAULlC-MECH JARS, 5" 49.5 ppf HWDP (19), 4 1/2" IF-P X HT-40-B, 4" 16.7PPF S-135 HT-40DP PUMP IH'YDAAUlICDÃTA STROKE (in) LINER (in) SPM Q (gpm) 9.000 6.000 85 269.67 9.000 6.000 85 269.67 BHA NO. II LEN.{ft) 3 793.1 BHA DESCRIPTION PRESS. (psi) TOTAL Q 1,200 539.34 1,200 539.34 KI':;l'S~M I PRESSURE 48 230 46 220 Nabors Alaska Drilling 19 232.00 R&K Industrial 3 36.00 Marathon 1 24.00 S&R Enterprises 2 2.00 Baker Hughes Inteq 2 48.00 Alaska Petroleum Contra 4 20.00 Epoch Well Services 4 48.00 Weaver Brothers (WBI) 1 2.00 M-I Drilling Fluids 1 24.00 AOGCC 1 6.00 LAST BOP TEST: 2/20/2004 SIZe (in) 10 (in) SHOE TEST(ppg) 20.000 18.730 9.625 8.681 16.87 LAST CASING TEST: 2/20/2004 MAXSICP MD (ft) . TVD (ft) (psi) @ (ppg) 100 100 670 (psi) @ 9.20 (ppg) 1,895 1,682 NEXT BOP TEST: WT(lblft) 133.00 X-56 47.00 L-80 2/27/2004 BURST (psi) 6,870 CONHD£N1\Al Printed: 4/8/2004 10:00:41 . . Page 1 of 2 WELL NAME PAXTON 1 SUPERVISOR R.C. Lawson FIELD NA.IIIIE 124 HR PROG TMD TVD 1 DFS6 1,641.0 3,677 2,679 AUTH MD WBS 9,793 dx0309781capdrl MOC WI NR! II DAILY WELL COST 9072831315 60.0000 60.0000 COUNTY/OTHER I LAST CASING I NEXT CASING 9.625 (in) @ 1,895 (ft) 7.000 (in) @ 4,950 (ft) 124 HR FORECAST Drill ahead. IGL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 IDOL IRPT# DATE 10 12 22-Feb-2004 SAPIWBS COST KB RIG PHONE CUM WELL COST WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS@ 6AM Dilling ahead @ 3677'. OPERATION COMMENTS Drill F/2036' to 2993'. Circ. clean. Wiper trip to the shoe. Drill F/2993' to 3677'. I LEAKOFF 16.87 SAFETY SUMMARY I BOP PSI TEST I LAST STOP CARD AUDIT 2/20/2004 2/21/2004 :;~O~ WORKED I~~~:ENT'~PEI~~~/~::Y MTG ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Tripping pipe and good housekeeping. 06:00 17:30 11.50 2,036 2,993 AF DRLlN1 DRILL DOHD Dir drill and survey F/2036' to 2993'(ART=3.69hrs AST=3.8hrs). 17:30 19:00 1.50 2,993 2,993 AF DRLlN1 CIRC CLN Circ. clean (CBUX6 510GPM, 120RPM). 19:00 21:00 2.00 2,993 2,993 AF DRLlN1 TRIP WTRP POOH(tight10-20K over @ 2757', 2745', 2555', 2484', 2472', 2421',2415',2398',2350',2377',2261',2165',2075'). 21:00 21:30 0.50 2,993 2,993 AF DRLlN1 RIG SERV Service the rig. 21:30 22:30 1.00 2,993 2,993 AF DRLlN1 TRIP WTRP RIH. Wash last 95' to bottom. Wiper gas 410units. 22:30 06:00 7.50 2,993 3,677 AF DRLlN1 DRILL DOHD Dir drill and survey F/2993' to 3677'(ART=3.08hrs AST=2.06hrs). D~NSI1Y(ppg) I 9.30 Þv ·1·' PVNP I GELS 70 14/25 11/15 I ppl WUHTHP ·1 6.01 I ECD I 9.97 MÚ[).DATA DAILY COST I FCn:.SOL OIW t %SånM~BTI Ph/pM I Pf/Mfl cí/Ca 1.0/6.5 194 I 0.25/3.0 9.90/1.1 1.0/3.4 27,000/20 I CUM COST. ICi(l9~(wt%1 H2S LIME !OS 16~~1II! BIT/RUN WOB (kip) RPM I GPM PRESS(psi) P BIT(psi) 2/3 4/5120/120508 1,530 296 HRS 24Hr DIST(ft) 124Hr ROP(ftlhr) ICUM HRS CUM DEPTH{ft) I CUM ROP(ftfhr) 12.63 1,641.0 129.93 14.79 1,772.0 119.81 BHA NO. LEN.(ft) 3 793.1 BHA DESCRIPTION BHA I EFF WT(lb) P/U(lb) I S/O(lb) ROT WT(lb)! TORQUE(max/min) (ft-Ibf) BHA hrsl JAR hrsl MWD hrs I MTR hrsl SS hrs 43,000 80,000 70,000 70,000 4,400/3,800 37.00 8-1/2" HTC HCM605 PDC Bit, 63/4" M1XU.8AKO/8 3/8" UBHS , 8-3/8" NMWBS ,65/16" MWD , 6 1/2" HOS ,41/2" H-90-P X 41/2" IF-B , 5" 49.5 ppf HWDP (4), 6-1/4" DAILEY HYDRAULlC-MECH JARS, 5" 49.5 ppf HWDP (19), 41/2" IF-P X HT-40-B , 4" 16.7PPF S-135 HT-40DP NO. 1 2 MAKE OF PUMP GARDNER-DENVER GARDNER-DENVER PUMP 1 HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) 9.000 6.000 80 253.81 9.000 6.000 80 253.81 PRESS. (psi) TOTAL Q 1,530 507.62 1,530 507.62 KILL SPM 1 PRESSURE 46 315 44 300 AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: UNITS 410 AVG. BKGRD: MAX. DRL: 150 1,777 Printed: 4/8/2004 10.00:43 WELL NAME PAXTON 1 MD 2.072.0 2,168.0 2.263.0 2.358.0 2,454.0 2,550.0 2,645.0 2,741.0 2.837.0 INCL 54.70 55.90 56.90 56.20 56.40 56.40 55.70 56.60 57.00 AZIMUTH 334.40 334.90 334.90 335.30 335.30 335.60 335.00 334.90 334.00 COMPANY";; Nabors Alaska Drilling Marathon Baker Hughes Inteq Epoch Well Services . MARATHON OIL D IKB 17.0 IGL 144.00 124 HR PROGITMD ITVD I DFS 1.641.0 3.677 2,679 6 IDOL RPT# I DATE 10 12 22-Feb-2004 SURVEY DATA TVD VS NIS CUM EJW CUM DOGLEG MD 1.787.38 812.31 733.99 -348.05 1.24 2,933.0 1.842.03 891.24 805.32 -381.84 1.32 3.028.0 1.894.60 970.36 876.97 -415.40 1.05 3,123.0 1.946.96 1,049.63 948.87 -448.78 0.82 3,219.0 2,000.23 1,129.49 1.021.43 -482.15 0.21 3,314.0 2.053.35 1.209.45 1.094.16 -515.37 0.26 3,410.0 2,106.41 1.288.25 1.165.75 -548.30 0.90 3.506.0 2,159.88 1.367.98 1.237.98 -582.06 0.94 3.602.0 2,212.45 1,448.30 1,310.45 -616.70 0.89 INCL 55.90 56.40 56.90 56.00 56.30 55.60 55.80 55.00 AZIMUTH 334.20 333.60 333.70 333.80 333.90 334.10 334.90 334.90 . Page 2 of 2 TVD VS NIS CUM EJW CUMDOGLEG 2.265.50 1.528.30 1,382.42 -651.65 1.16 2.318.42 1,607.18 1,453.27 -686.36 0.74 2.370.65 1,686.52 1.524.38 -721.58 0.53 2,423.70 1,766.50 1.596.14 -756.97 0.94 2.476.62 1,845.38 1.666.96 -791.74 0.33 2.530.37 1,924.91 1.738.45 -826.61 0.75 2.584.472,004.21 1.810.03 -860.75 0.72 2.638.982,083.23 1.881.59 -894.27 0.83 . PERSONNEL DATA' No.'HðµRS. . COMPANY 17 213.00 M-I Drilling Fluids 1 24.00 R&K Industrial 2 48.00 Weaver Brothers (WBI) 4 48.00 " ;:(¡':" SÈRVICÊ . . LAST BOP TEST: 2/20/2004 'SI:ZE (in> ·.IP· (in) . SHOE T:fEST (ppg) 20.000 18.730 9.625 8.681 16.87 CASING;SUMMARY LAST CASING TEST: 2/20/2004 MD'(ft) TvD (ft) 100 100 1,895 1,682 (psi) @ (ppg) 670 (psi) @ 9.20 (ppg) 1 3 2 24.00 36.00 4.00 NEXT BOP TEST: 2/27/2004 . BIJR&Tl(psi)· 133.00 X-56 47.00 L-80 6,870 Printed: 4/8/2004 10:00:43 . . Page 1 of 2 WELL NAME PAXTON 1 SUPERVISOR R.C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS@ 6AM Drilling ahead @ 4677 OPERATION COMMENTS Drill F/3677' to 4045'. Wiper trip to the shoe. IGL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 RIG PHONE 124 HR PROG TMD TVD I DFS7 I DOL I RPT # I DATE 1,000.0 4,677 3,237 11 13 23-Feb-2004 AUTH MD WBS '::APIWRS COST 9,793 dx0309781 capdrl MOC WI NR! I CAlLY WELL COST 60.0000 60.0000 I LAST CASING I NEXT '''''''N<> I LEAKOFF 9.625 (in) @ 1,895 (ft) 7.000 (in) @ 4,950 (ft) 16.87 124 HR FORECAST Drill ahead to CSG point. Wiper trip POOH. Log. CUM WELL COST KB 9072831315 COUNTY/OTHER Drill F/4045' to 4677'. MANHRS WORKED I ACCIDENT TYPE 411.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Short trip. LAST SAFETY MTG 2/22/2004 SAFE1'Y SUMMAR¥ I BOP PSI TEST 1 LAST STOP CARD AUDrr 2/20/2004 2/22/2004 06:00 10:00 4.00 3,677 4,045 AF DRLlN1 DRILL DOHD Dir drill and survey F/3677' to 4045'(ART=1.67hrsAST=1.47hrs). 10:00 11:30 1.50 4,045 4,045 AF DRLlN1 CIRC CLN CBUX4(515gpm, 120rpm) large quantity of cuttings. 11 :30 13:00 1.50 4,045 4,045 AF DRLlN1 TRIP WTRP POOH(tight 10-20k over @ 3793', 3700', 3621', 3603', 3583', 3526',3522',3505', B/R F/3558' to 3468', tight @ 3351', 3348', B/R 3370' to 3260'). 13:00 14:00 1.00 4,045 4,045 AF DRLlN1 CIRC CLN CBUX4(500gpm 120rpm). Large quantity of cuttings. 14:00 15:00 1.00 4,045 4,045 AF DRLlN1 TRIP WTRP POOH (tight 10-20K over @ 3169'. B/R 3181' to 2990'. Tight @ 2900',2885') 15:00 16:00 1.00 4,045 4,045 AF DRLlN1 CIRC CLN CBUX3 @ 2900'(500gpm,120rpm). Large quantity of cuttings. 16:00 18:00 2.00 4,045 4,045 AF DRLlN1 TRIP WTRP B/R to the shoe @ 1895'. 18:00 19:00 1.00 4,045 4,045 AF DRLlN1 CIRC CLN Circ. clean @ shoe(120rpm, 600gpm). Large quantity of cuttings. 19:00 20:00 1.00 4,045 4,045 AF DRLlN1 RIG SERV Service rig. 20:00 21:00 1.00 4,045 4,045 AF DRLlN1 TRIP WTRP RIH wash last 90' to bottom. Wiper gas 256units. 21:00 06:00 9.00 4,045 4,677 AF DRLlN1 DRILL DOHD Dir drill and survey F/4045' to 4677'(ART=3.09hrs AST=2.18hrs). COMMENTS Weekly safety meeting. DENSITY(ppg) I FVI PVNP I 70 14/30 9.35 I PP I GELS I W!!"'THÞj 12/20 5.81 I·Eèb10.14IMUD DATAl DAILY COST I FCfT.SOL OIW I· %Sa.ndìMBT Ph/PM Pf/Mf I 1.017.5 193 0.25/4.0 9.1010.4 0.312.6 Cllèa 28,000/20 I CUM CPST I CaCI2(wt%1' .H2S LIME I ESI6~;M BI~~~NI :::0 I M~~F. BIT/RUNI WOB (kip) I RPM I 2 I 3 6 I 8 120 1120 H~;:05 IS~~~:~::'I GPM I PRESS(psi) I P BIT(psi) 530 1,950 325 BITS JETS OR TFA DEPTH IN DATE IN I-O-D-L-B·G·O-R 15/15/15/15/1511111 1,905.0 2/20/2004 O-O-NO-A-D-I-NO-TD HRS I 24Hr DIST(ft) 124Hr ROP(ftlhr) ICUM HRSI CUM DEPTH(ft) I CUM ROP(ftlhr) 8.41 1,000.0 118.91 23.20 2,772.0 119.48 BHA N0'1 LEN.(ft) 3 793.1 BHA DESCRIPTION BHA I EFF WT(IO) I'· P/U(lO) 1 8/0(115) I ROT WT(IO) 1 TORQUE(maXlmin) (tHOt) 1 BHA hrs I JAR hrs I MWD hrs I MTR hrs I 8$ hrs 43,000 90,000 78,000 78,000 5,000/4,600 45.50 8-1/2" HTC HCM605 PDC Bit, 6 3/4" M1XU.8AKO/8 3/8" UBHS ,8-3/8" NMWBS , 65/16" MWD , 6 1/2" HOS ,41/2" H-90-P X 41/2" IF-B , 5" 49.5 ppf HWDP (4), 6-1/4" DAILEY HYDRAULlC-MECH JARS, 5" 49.5 ppf HWDP (19), 4 1/2" IF-P X HT-40-B , 4" 16.7PPF S-135 HT-40DP Printed: 4/8/2004 10:00:45 . . MARAT NY Page 2 of 2 WELL NAME PAXTON 1 IKB 17.0 124 HR PROG I TMD 1 TVD 1 DFS7 1,000.0 4,677 3,237 IDOL 11 IRPT# 1 DATE 13 23-Feb-2004 NO. 1 2 MAKE OF PUMP GARDNER-DENVER GARDNER-DENVER PUMP 1 HYDRAULIC DATA STROKE {in} LINER (in) SPM Q (gpm) 9.000 6.000 85 269.67 9.000 6.000 85 269.67 PRESS. (psi) TOTAL Q 1,950 539.34 1,950 539.34 KILL SPM ! PRESSURE 44 400 42 380 30 MUD GAS AVG. TRIP: MAX. TRIP: UNITS AVG. CONN: MAX. CONN: 256 AVG. BKGRD: MAX. DRL: 130 816 SURVEY DATA·· N/S CUM Ef:/'I C!-,M DOGLË,G MD 2,693.61 2,160.96 1,952.00 -927.18 0.23 4,176.0 2,747.84 2,240.17 2,023.82 -960.59 1.67 4,271.0 2.800.21 2,319.43 2,095.71 -993.97 0.32 4,366.0 2,853.82 2,399.06 2,168.12 -1,027.12 1.45 4,463.0 2,908.122,478.222,240.24 -1,059.76 0.32 4,559.0 3,697.0 3,793.0 3,888.0 3,984.0 4,080.0 54.80 56.40 56.70 55.40 55.70 AZIMU1H 335.00 335.10 335.10 335.70 335.60 56.20 55.10 55.10 55.50 54.40 336.00 335.30 335.60 335.40 334.80 2,961.88 2,557.75 2,312.79 -1.092.36 3,015.48 2,636.18 2,384.24 -1,124.70 3.069.832,714.092,455.11 -1,157.07 3,125.052.793.83 2,527.68 -1,190.14 3,180.192,872.422,598.97 -1,223.23 0.62 1.31 0.26 0.45 1.25 Nabors Alaska Drilling Marathon Baker Hughes Inteq Epoch Well Services PERSONNEt DATA ; NO. . HOUij~coNÍPANY 17 230.00 M-I Drilling Fluids 1 24.00 R&K Industrial 2 48.00 S&R Enterprises 4 48.00 1 3 1 24.00 36.00 1.00 LAST BOP TEST: 2/20/2004 SIZE (in) ID(in) SHOE TEST (ppg} 20.000 18.730 9.625 8.681 16.87 LAST CASING TEST: 2/20/2004 .. . MAX SICP . MD (ft) TVD (ft) (psi) @ (ppg) 100 100 670 (psi) @ 9.20 (ppg) 1,895 1,682 NEXT BOP TEST: WT(lblft)GRÀDE. 133.00 X-56 47.00 L-80 2/27/2004 BURST:(psî) 6,870 Printed: 4/8/2004 10:00:45 WELL NAME PAXTON 1 SUPERVISOR R.C. Lawson FIELD NAME . . MARATHON OIL COMPANY Page 1 of2 124 HR PROG TMD TVD I DFS8 I DOL 1 RPT # I DATE 282.0 4,959 3,423 12 14 24-Feb-2004 AUTH MD WBS SAPIWBS COST 9,793 dx0309781capdr1 I MOC WI NRI I - ... "'..e, , rn<::T CUM WELL COST 60.0000 60.0000! . 1 LAST CASING I NEXT CASING I LEAK OFF 9.625 (in) @ 1,895 (ft) 7.000 (in) @ 4,950 (ft) 16.87 124 HR FORECAST Run logs on DP. Run and cement 7" CSG. IGL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 KB RIG PHONE WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS@ 6AM POOH @ 790'. OPERATION COMMENTS Drill F/4667' to 4959'. Circ. clean. Wiper trip to the shoe. 9072831315 COUNTY/OTHER Circ. clean at TD. Wiper trip to 3300'. Circ. clean @ TD. POOH to run logs. MANHRS WORKED I ACCIDENT TYPE \ LAST SAFETY MTG 412.00 None 2/23/2004 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Short trip and cut drilling line. s~¡i~~smMMiR~ \:= 1~;;''''AU(~8NfíDÉ'NfÄ':'=ro" Dir drill and survey F/4677' to 4887'(ART=1.37hrs) Circ. shakers clean (CBUX3, 120rpm, 600gpm) Dir drill and survey F/4887' to 4928'(ART=.30hrs). Circ. shakers clean and wait to find out final CSG point from Geologist(CBUX5, 120rpm, 600gpm) Dir drill and survey F/4928' to 4959'(ART=.27hrs). Circ. shakers clean and wait to hear from Geologist(CBUX3,120rpm,600gpm) POOH. Tight(20K over)@ 4531', 4495', 4411', 4387', 4379'. B/R 4380' to 4297'. POOH tight @ 4248', 4129', 4110', 4107', 4104'. B/R 4105' to 4009'. POOH tight @ 3895',3827', 3820',3798',. B/R 3812' to 3721'. POOH tight @ 3450',3344',3323', slick to the shoe above 3323'. Clean and organize rig floor. PJSM. Cut 124' Dr1g line. Adjust brake and equalizer bar. Service rig. RIH. Wash last 80' to botom(no fill). Circ. clean(CBUX5, 120rpm,530gpm). Wiper gas 335units. POOH to 3300'(hole slick). RIH. Wash last 80' to bottom(no fill). Circ clean(CBUX3,120rpm,530gpm). Wiper gas 98units. Observe well (static). Pump dry job. 03:00 06:00 3.00 4,959 4,959 AF DRLlN1 TRIP BHA Drop 2 3/8" rabbit. POOH(SLM). Hole slick. 9.45 I PP I IECDI10.33IMWÐÐ~m~1 DÀIL'{C(¡)ST I I CUM COST GELS I WIdHTI'iI\' I FCftLSOL I om l'I'oSånd/MBT! Ph/pM I PJ/Mf I CIICa ICaCI2(wt%~ ¡'2S LIME I ES 6RPM 12/20 5.9/· 1.0/8.5 192 ·013/7.5·8.5010.3 0.313.4 26,000/60 I 13 06:00 08:00 09:30 10:00 08:00 09:30 10:00 12:00 12:00 12:30 12:30 14:00 14:00 18:30 18:30 19:00 20:00 20:30 22:30 00:00 01:00 02:00 19:00 20:00 20:30 22:30 00:00 01:00 02:00 03:00 DENSITY(ppg) I FV I PVNP I 72 14/30 2.00 1.50 0.50 2.00 4,677 4,887 4,887 4,928 4,887 4,887 4,928 4,928 AF DRLlN1 AF DRLlN1 AF DRLlN1 AF DRLlN1 DRILL CIRC DRILL CIRC DOHD CLN DOHD CLN 0.50 4,928 4,959 AF DRLlN1 DRILL DOHD 1.50 4,959 4,959 AF DRLlN1 CIRC CLN 4.50 4,959 4,959 AF DRLlN1 0.50 1.00 0.50 2.00 1.50 1.00 1.00 1.00 4,959 4,959 4,959 4,959 4,959 4,959 4,959 4,959 BIT/~UNI SIZE I MANUF. 2 13 8.500 HTC BIT/RUN I WOB (kip) I RPM I 2/3 5/7 120/120 4,959 4,959 4,959 4,959 4,959 4,959 4,959 4,959 AF DRLlN1 AF DRLlN1 AF DRLlN1 AF DRLlN1 AF DRLlN1 AF DRLlN1 AF DRLlN1 AF DRLlN1 TYPE I SE~IAL N°·1 HCM605 7103535 GPM I PRESS(psi) I P BIT(psi) 530 1,950 325 TRIP WTRP RIG RIG RIG TRIP CIRC TRIP TRIP CIRC SERV SCDL SERV WTRP CLN WTRP WTRP CLN Blms JETS OR TFA 15/15/15/15/1511111 HRS I 24Hr DIST(ft) 1.94 282.0 DEPTH IN DAtE IN I I-O-D-L-B-G-O-R 1,905.0 2/20/2004 O-O-NO-A-D- I-NO- TD 124Hr ROP(ftlhr) [CUM HRSI CUM DEPTH(ft) I CUM ROP(ftlhr) 145.36 25.14 3,054.0 121.48 Printed: 4/8/2004 10:00:47 · . MARATHON OIL COMPANY Page 2 of2 WELL NAME PAXTON 1 IKB 17.0 IGL 144.00 124 HR PROG I TMD 282.0 4,959 ITVD IDFS 3,423 8 IDOL RPT# I DATE 12 14 24-Feb-2004 BHA NO. II LEN.(ft) 3 793.1 BHA DESCRIPTION BHA II EFF WT(lb) II P/U(!b)II S/O(lb) II ROT WT(lb) I TORQUE(maxlmin) (ft·lbf) I BHA hrs I JAR hrs II MWD hrs II MTR hrs I SS hrs 43,000 100,000 81,000 81,000 5,000/4,600 47.50 8-1/2" HTC HCM605 PDC Bit, 63/4" M1XU.8AKO/8 3/8" UBHS , 8-3/8" NMWBS , 65/16" MWD , 6 1/2" HOS ,41/2" H-90-P X 41/2" IF-B , 5" 49.5 ppf HWDP (4),6-1/4" DAILEY HYDRAULlC-MECH JARS, 5" 49.5 ppf HWDP (19), 41/2" I F-P X HT -40-B , 4" 16.7PPF S-135 HT -40DP AVG. CONN: MAX. CONN: .MUD GAS AVG. TRIP: MAX. TRIP: UNITS 98 AVG. BKGRD: MAX. DRL: 1,310 .TVD 3,366.38 3,118.98 2,823.02 -1,326.16 1.51 3,385.64 3,143.27 2,845.02 -1,336.46 0.51 MD 4,654.0 4,749.0 4,827.0 INCl 53.40 52.60 52.00 SÚRvÈ~¡¡DATA . AZIMUTH .TVDVS;. ~/S.'þUMÈIW CUMb()GLEG .nMD INCL. 335.50 3,236.162,949.182,668.62 -1,255.49 1.21 4,868.0 51.60 335.50 3,293.33 3,025.05 2,737.65 -1,286.95 0.84 4,899.0 51.60 335.40 3,341.033,086.762,793.79 -1,312.59 0.78 Nabors Alaska Drilling Marathon Baker Hughes Inteq Epoch Well Services .l7!aRSONNEl;;:ÐÄ'ri~ '. '0 .NO.' )¡:¡~U~SCOMijÅNY 17 230.00 M-I Drilling Fluids 1 24.00 R&K Industrial 2 48.00 S&R Enterprises 4 48.00 1 3 2 24.00 36.00 2.00 LAST BOP TEST: 2/20/2004 SIZE.(in) ID(in) SHOETI;ST (ppg) 20.000 18.730 9.625 8.681 16.87 LAST CASING TEST: 2/20/2004 MAX SICP . MÒ(ft): TVD (ft) . (psi) @ (ppg) 100 100 670 (psi) @ 9.20 (ppg) 1,895 1,682 NEXT BOP TEST: WT (Jb/ft)C3AADE' . 133.00 X-56 47.00 L-80 2/27/2004 ..BURST (þSi)" 6,870 Printed: 4/8/2004 10:00:47 . . MARATHON OIL COMPANY D Page 1 of 2 i ngR,e:J:).ort Ex~IQitatiQ 1 Gl 124 HR PROG TMD TVD I DFS9 IDOL 17.0 144.00 4,959 3,423 13 RIG NAME & NO. AUTH MD WBS NABORS DRILLING 129 9,793 dx0309781capdrl R!G PHONE 907283 1315 M~~.~OO N=~.OOOO I Mil VWFIL r.mn COUNTY/OTHER 1 lAST CASING I NEXT CASING 9.625 (in) @ 1,895 (ft) 7.000 (in) @ 4,950 (ft) 124 HR FORECAST Run and cement CSG. UD 4" DP. P/U 3.5" DP. Drill out. WEll NAME PAXTON 1 SUPERVISOR R.C. Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS@ 6AM Investigate near miss incident. OPERATION COMMENTS POOH w/directional BHA. RIH wlReeves DP conveyed logs. KB IRPT# I DATE 15 ;~~~~~;~~; r.:1 ,._" W5=1 I ~nC::T IlEAKOFF 16.87 POOH logging. UD logging tools. RIU and run 7" CSG. S~RÊ~stLJM'M~R!¥ MANHRS WORKED [ACCIDENT TYPE [lAST SAFETY MTG IBOP PSI TEST I lAST STOP CARD AUDIT 473.00 Near Miss 2/25/2004 2/20/2004 2/2412004 ACCIDENT DESCRIPTION: Dropped 1joint of 7" CSG. Appears no injuries. SAFETY MTG TOPICS: Running CSG. STEP ~RO~ 1:0 06:00 08:00 08:00 09:30 09:30 10:30 10:30 11 :30 11 :30 14:00 14:00 15:00 15:00 16:00 16:00 20:00 20:00 21 :30 21 :30 22:00 22:00 00:00 00:00 01 :00 01 :00 02:30 02:30 04:00 04:00 05:30 05:30 06:00 DENSITY(ppg) FV I PVNP 78 14/28 BIT/RUN! SIZE I 2 13 8.500 BIT/RUNI WOB () I ""-~'<::;¡',<::)-}, HRS 2.00 1.50 . 'FROM 4,959 4,959 ¡lAST RIG INSPECTION 2/16/2004 REGULATORY INSP? N '! ,';' - ;~" ~ .TO· SOB 4,959 AF 4,959 CS ., " ...OPERÄ1'íOtiS:·StJMMAR!¥ . 'PHASE oF> "'SUBOI', t~BL. DRLlN1 TRIP BHA EVAL1 LOG OTHR 1.00 4,959 4,959 CS EVAL 1 1.00 4,959 4,959 CS EV AL 1 2.50 4,959 4,959 CS EVAL 1 LOG OTHR LOG OTHR LOG OTHR 1.00 4,959 4,959 CS EV AL 1 1.00 4,959 4,959 CS EVAL1 LOG OTHR LOG OTHR 4.00 4,959 4,959 CS EVAL 1 1.50 4,959 4,959 CS EVAL 1 LOG OTHR LOG OTHR 0.50 4,959 4,959 AF CSGIN1 RIG SERV 2.00 4,959 4,959 AF CSGIN1 TEST WEAR 1.00 4,959 4,959 AF CSGIN1 TEST BOP 1.50 4,959 4,959 AF CSGIN1 EQUIP RURD 1.50 4,959 4,959 AF CSGIN1 CSG RUN 1.50 4,959 0.50 4,959 9.50 GELS I 13/20 I PP I WUHTHP I 6.11 MANUF. HTC RPM 4,959 AF CSGIN1 CSG RUN 4,959 TA CSGIN1 SAFETY HAZC IECDI FCIT.SOL I 1.0/9.0 POOH(SLM). UD bit and directional tools. UO and strap 6jnts 31/2" DP. RIU and prep to run Reeves DP conveyed logs. PJSM prior to running logs. P/U 3 1/2" BHA. MIU Reeves logging tools and house inside the 3 1/2" DP. Cant. M/U BHA. RIH w/5" HWDP. MIU first stand of 4" DP. Flow test logging tools. RIH wash last 80' to bottom(no fill). CBU. Trip gas 50units. Pull up off of bottom. Drop Reeves messenger, pump down and deploy logging tools. POOH logging to surface. UD BHA. PJSM prior to removing nuclear sources. UD logging tools. Service rig. Pull wear bushing. Set test plug. CIO pipe rams to 7". Fill stack with water for test. Test door seals to 250/300psi 3min. R/U Weatherford CSG tools. PJSM prior to running CSG. Bakerlok shoe tractOnts1-4). Circulate shoe tract with fillup tool. Run 7" 26ppf L-80 Mod-Butt CSG(23joint run@0600hrs). HESA Investigate near miss incident. ¡MUD DATAl DAlLYCOST I Ofw I 'IoSand/MBT I Ph/pM ! Pf/Mf! 191 0.25/80 9.6010.6 0.513.8 CIICa 27,500/80 I CUM COST I CaCI2(wt%1 H2S LIME! ES 1-6~;M H~:6E05 I S~~~~~;:.! FloRt() I PRESS() P BIT() BITS ..!ErS OR TFA 15/15/15/15/1511111 DEPTH IN DATE IN 1,905.0 2/20/2004 I-O-D-L·B-G-O-R O-O-NO-A-D- I-NO-TD HRS I 24Hr DIST() I 24Hr ROP() ICUM HRSI CUM DEPTH() I CUM ROP() Printed: 4/8/2004 10:00:49 . . Page 2 of 2 WELL NAME PAXTON 1 M~RA T Dail ort Exploitation Gas IGL 124 HR PROGITMD 144.00 4,959 TVD ·)DFS 3,423 9 IDOL IRPT# I DATE 13 15 25-Feb-2004 IKB 17.0 BHA I EFF WTO I P/UO I 8/00 I ROT WTO I TO~QLJE(~axlmin) () I BHA hrs I JAR hrs I MWD hrs I MTR hrs I SS hrs 83/8" Reamer shoe, Circ. Landing sub, 3.5" 13.30PPF S-135 31/2" IFDP , 8 3/8" Stab, 3.5" 13.30PPF S-135 31/2" IFDP (3), Lower Latch, Upper Latch, 3.5" 13.30PPF S-135 31/2" IFDP , Float sub, 3.5" 13.30PPF S-135 31/2" IFDP, Float Sub, 3 1/2" IF-P X 4 1/2"IF-B , 5" 49.5 ppf HWDP (24), 4 1/2" IF-P X HT-40-B ,4" 16.7PPF S-135 HT -40DP . PCB @ 06:00: NO. H()Û~S 3 36.00 4 54.00 3 9.00 2 32.00 qOMPANY 17 230.00 R&K Industrial 1 24.00 Weatherford 2 16.00 BJ Services 4 48.00 Reeves Wireline 1 24.00 BHA N0'1 LEN.(ft) 4 941.9 BHA DESCRIPTION Nabors Alaska Drilling Marathon Baker Hughes 'nteq Epoch Well Services M-I Drilling Fluids LAST BOP TEST: 2/20/2004 SIZE (ifi) ... 'Ib (in) SHOE TEST (þpg} 20.000 18.730 9.625 8.681 16.87 LAST CASING TEST: 2/20/2004 ",:".., ',~ .'. MAXSICP (psi) @ (ppg) 670 (psi) @ 9.20 (ppg) 100 1,895 100 1,682 NEXT BOP TEST: WT (Ib/ft)', .ßRAD,E 133.00 X-56 47.00 L-80 2/27/2004 ....,; BURST(P~i); 6,870 Printed: 4/6/2004 10:00:49 WELL NAME PAXTON 1 SUPERVISOR Gene Anderson FIELD NAME . . 124 HR PROG TMD TVD 1 DFS IDOL I RPT # 4,959 3,423 10 14 16 AUTH MD WBS 9,793 dx0309781capdrl MOC WI NRI I 9072831315 60.0000 60.0000 ¡ !..'~ COUNTY/OTHER I LAST CASING I NEXT CASING 7.000 (in) @ 4,950 (ft) 4.500 (in) @ 9,757 (ft) 124 HR FORECAST LDDP. PU DP. Test BOP's. IGL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 RIG PHONE KB Page 1 of 2 I DATE 26-Feb-2004 I' '-"---~~T WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS@ 6AM LDDP. OPERATION COMMENTS Ran & cemented 7" casing. Install & test packoff. LD HWDP. Clean pits, mix mud. LDDP. .~ I L=KuFF . SAFE\T'Y SUfJÎM'ARY 1 BOP PSI TEST LAST STOP CARD AUDIT 2/20/2004 2/2412004 REGULATORY INSP? N 1 LAST RIG INSPECTION 2/25/2004 MANHRS WORKED 1 ACCIDENT TY~E "I' LAST SAFETY MTG 497.00 None 2/25/2004 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Run csg, Fall support, Cement csg. STEP FROM 06:00 07:00 07:00 09:30 09:30 18:00 18:00 19:00 19:00 20:30 20:30 21 :00 21 :00 22:30 22:30 23:00 23:00 01 :00 01 :00 03:00 03:00 03:30 03:30 06:00 DENSITY(ppg) FV I PVNP 70 15/28 HRS 1.00 2.50 FROM 4,959 4,959 '!?HhiSE St1BOf!l'RBL CSGIN1 SAFETY HAZC HESA Continue safety investigation of near miss incident. CSGIN1 SAFETY HAZC HESA PJSM. RID fill-up tool. RlU side door elevators, fill-up line. RlU fall restraint device at V-door while P/U casing. Finish running 120 jts, OAL 4957.89',7",26 ppf, L-80- BTC casing including float shoe, float collar, casing hanger & landing joint. Bottom of float shoe @ 4950', top of float collar @ 4865' MD. M/U landing joint & casing hanger. Land casing on load shoulder wI 82,000 Ibs. Install XO & cementing head. RlU cementing lines. Circulate casing @ 6 bpm & 570 psi. PJSM. Cement 7" casing as follows: Pump 5 bbls water, test lines to 3000 psi. Drop bottom plug. Mix & pump 40 bbls of 10.5 ppg weighted spacer. Mix & pump 180 sx (70 bbls) Lead cement + additives mixed @ 12.5 ppg & 2.17 cf/sk yield followed by 110 sx (36 bbls) Tail cement + addtives mixed @ 13.5 ppg & 1.84 cf/sk yield. Drop top plug, chase wI 5 bbls water. Displace cement wI 181 bbls 9.5 ppg mud. Bump plug wI 1200 psi. CIP @ 20:15 hrs, 2/25/04. Bleed pressure, floats held ok. Full circulation throughout job. RID cementers. UD cementing head, landing joint & elevators. UwLH Install & test secondary packoff to 5000 psi for 10 mins. RURD Change out long bales to short. UBOP Change 7" rams to VBR's. Install wear bushing. LDDP UD 5" HWDP in mousehole. REQP TOPS Repair leak in T/D. LDDP TlH wI 4" DP. POOH LDDP. SUB 4,959 TA 4,959 TA 8.50 4,959 4,959 AF CSGIN1 CSG RUN 1.00 4,959 4,959 AF CSGIN1 CIRC HOLE 1.50 4,959 4,959 AF CSGIN1 CEMT PRIM 0.50 4,959 4,959 AF CSGIN1 1.50 0.50 2.00 2.00 0.50 2.50 4,959 4,959 4,959 4,959 4,959 4,959 CSG RUN 4,959 AF 4,959 AF 4,959 AF 4,959 AF 4,959 TA 4,959 AF CSGIN1 CSGIN1 CSGIN1 CSGIN1 CSGIN1 CSGIN1 NUND EQUIP NUND TRIP EQUIP TRIP 9.50 GELS I 11/19 I pp I WLlHl'HP I 6.41 IECDI Fcrr.SOL I 1.0/8.5 IMUD DATAl DAILYCOSl' I OIW I %Sand/MBT I Ph/pM I Pf/Mf I I 0.25/9.0 9.5010.6 0.5/3.7 LIME 1 t::s I \)1'(....'111 I CUM COST Cl/Ca I CaCI2(wt%~ H2S 26,000/80 I BHA NO. 4 L:4~·~t) I EFF WTO 1 P/UO I S/OO I ROT WTO 1 BHÀ TORQUE(max/min) () I 1 BHA hrs I JAR hrs I MWD hrs 1 MTR hrs I SS hrs Printed: 4/8/2004 10:00:51 . M WELL NAME PAXTON 1 IKB 17.0 IGL 144.00 124HRPROGITMD ITVD IDFS IDOL RPT# I DATE 4,959 3,423 10 14 16 26-Feb-2004 . Pag~ 2 of 2 BHA BHA DESCRIPTION 83/8" Reamer shoe, Cire. Landing sub, 3.5" 13.30PPF S-135 31/2" !FDP , 83/8" Stab, 3.5" 13.30PPF S-135 31/2" IFDP (3), Lower Latch, Upper Latch, 3.5" 13.30PPF S-135 3 1/2"IFDP , Float sub, 3.5" 13.30PPF S-135 31/2" IFDP , Float Sub, 3 1/2" IF-P X 4 1/2"'F-B , 5" 49.5 ppf HWDP (24), 4 1/2" IF-P X HT-40-B ,4" 16.7PPF S-135 HT-40DP MUD GAS AVG. TRIP: MAX. TRIP: AVG. BKGRD: MAX. DRL: AVG. CONN: MAX. CONN: 94 PERSONNEL DA17A· HOURS. 264.00 24.00 48.00 48.00 24.00 32.00 COMP~V: . Weatherford BJ Services Wildflowers and Resin Airport Rentals Lynden Transport Weaver Brothers (WBI) Nabors Alaska Drilling Marathon Baker Hughes Inteq Epoch Well Services M-I Drilling Fluids R&K Industrial LAST BOP TEST: 2/20/2004 'Ib:'(in) SHOE;;TEST (þpg) .' 18.730 8.681 6.276 CASINtSUMMÄR¥: LAST CASING TEST: 2/20/2004 20.000 9.625 7.000 (psi) @ (ppg) 670 (psi) @ 9.20 (ppg) (psi) @ 9.20 (ppg) 100 1,895 4,950 100 1,682 3,417 16.87 UNI~S units POB @ Q~iQ,Q:' NO. '. :HÔl!R~.... 4 20.00 4 20.00 1 4.00 2 6.00 1 3.00 1 4.00 NEXT BOP TEST: .; WT (Ib/tt) .... '. ,GAAJ¡)E 133.00 X-56 47.00 L-80 26.00 L-80 2/27/2004 BURS'¡+/(þsl), 6,870 7,240 Printed: 4/6/2004 10:00:51 . . Page 1 of 1 WELL NAME PAXTON 1 SUPERVISOR Gene Anderson ]GL 17.0 144.00 RIG NAME & NO. KB 124 HR PROG TMD TVD I DFS IDOL 1 RPT # I DATE 4,959 3,423 11 15 17 27 -Feb-2004 AUTH MD was "APMlRS COST 9,793 dx0309781capdrl M~~.~~OO t~=~.OOOO 1 ['"n v w"" ~n~T 1 LAST CASING I NEXT CASING I LEAKOFF 7.000 (in) @ 4,950 (ft) 4.500 (in) (ã19,757 (ft) \24 HR FORECAST P/U DP & HWDP. Test BOPE. TIH wI BHA. ~UM WELL COST F!ElD NAME NABORS DRILLING 129 RIG PHONE WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS@ 6AM P/U 3-1/2' DP. OPERATION COMMENTS Finish UD 4" DP. P/U 3-1/2" DP. 9072831315 COUNTY/OTHER MANHRS WORKED I ACCIDENT TYPE 450.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: UD & P/U DP. I LAST SAFETY MTG 2/26/2004 "S~FETYSUMMARY'. " BOP PSI TEST I LAST STOP CARD AUDIT 2/20/2004 2/24/2004 N 06:00 13:00 7.00 4,959 4,959 AF CSGIN1 TRIP LDDP POOH UD 4" DP. 13:00 15:30 2.50 4,959 4,959 AF CSGIN1 EQUIP RURD UD 4" handling tools. PIU 3-1/2" handling tools. Strap & prep 3-1/2" DP. 15:30 22:00 6.50 4,959 4,959 AF CSGIN1 TRIP PUDP P/U 150 jts of 3-1/2",15.50 ppf, S-135, HT-38 DP. Rabbit pipe while P/U. 22:00 00:00 2.00 4,959 4,959 AF CSGIN1 TRIP PUDP POOH, rack back DP. 00:00 06:00 6.00 4,959 4,959 AF CSGIN1 TRIP PUDP Strap & prep 3-1/2" DP. P/U 3-1/2" DP as before. 91 jts in hole out of 150 jts P/U @ rpt time. Will have 100 stds 3-1/2" DP in derrrick when finished. DE~SITY(PP9) I Fvl PVNP I 55 11/23 9.30 G,ELS 7/13 I PP I WUHTHP! 6.81 ¡ECD FCIT.SOL I 1.017.5 I'MUP DÂ'TAjDAILYCOST I Olw I o/oSand/MBTj Ph/pM I Pf/Mf 'I I 0.25/5.0 9.5010.6 0.4/3.1 I CUM COST CIICa caCI~(wt%1 H2S 25,000/80 LII\II!O I ËS :6RPM units CÒMPANY Nabors Alaska Drilling Marathon Baker Hughes Inteq Epoch Well Services . M-I Drilling Fluids , f'"ERSONI,JE.L DATA' NO. H6:URS COMPANY 20 264.00 R&K Industrial 1 24.00 Weaver Brothers (WBI) 2 48.00 Swaco 4 48.00 Artie Slope Regional Cor 1 24.00 F'OÈ!~@ 06:00: . NO.' HØURS 2 24.00 1 3.00 1 2.00 2 13.00 LAST BOP TEST: 2/20/2004 SIZE (in) ID (in) SHOE TEST (ppg) 20.000 18.730 9.625 8.681 16.87 7.000 6.276 CASING SUMMARY LAST CASING TEST: 2/20/2004 MAX SICP MD (ft) TVD (ft) (psi) @ (ppg) 100 100 670 (psi) @ 9.20 (ppg) 1,895 1,682 (psi) @ 9.20 (ppg) 4,950 3,417 NEXT BOP TEST: WT (Ib/ft) GRADE 133.00 X-56 47.00 L-80 26.00 L-80 2/27/2004 BURST (psi) 6,870 7,240 Printed: 4/8/2004 10:00:53 . . MARATHON OIL COMPANY Page 1 of 2 124 HR PROG TMD TVD 1 DFS I DOL 1 RPT # DATE 4,959 3,423 12 16 18 28-Feb-2004 AUTH MD WBS 9,793 dx0309781capdrl MOC WI NRI I DAILY WELL COST 60.0000 60.0000 I I LAST CASING I NEX, .-A::;INI,; 7.000 (in) @ 4,950 (ft) 4.500 (in) @ 9,757 (ft) 124 HR FORECAST Test csg. Drill shoelnew fmn. LOT. CIO mud. Drill ahead WELL NAME PAXTON 1 SUPERVISOR Gene Anderson FIELD NAME IGL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 KB RIG PHONE WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS @ 6AM TIH wI new BHA. OPERATION COMMENTS P/U DP & HWDP. Test BOPE. Mix mud. P/U BHA. TIH. 9072831315 COUNTY/OTHER SÞ.PIWBS COST CUM WELL COST I LEAKOFF SAFETvSUMMARY I BOP PSI TEST I LAST STOP CARD AUDIT 2/27/2004 2/24/2004 REGULATORY INSP? N I LAST RIG INSPECTION 2/25/2004 " ' " ~' :~;; WORKED I ~~~:ENT TYPE· I ~;/~:~ MTG ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: P/U DP & HWDP, Test BOPE. /ro :ì:I.RS . >HASE 01' . 06:00 08:00 2.00 4,959 4,959 AF CSGIN1 TRIP PUDP 08:00 10:00 2.00 4,959 4,959 AF CSGIN1 TRIP PUDP 10:00 12:00 2.00 4,959 4,959 AF CSGIN1 TRIP PUDP 12:00 12:30 0.50 4,959 4,959 AF CSGIN1 TRIP PUDP 12:30 15:00 2.50 4,959 4,959 AF CSGIN1 EQUIP CHAN 15:00 16:00 1.00 4,959 4,959 AF CSGIN1 TEST BOP 16:00 20:00 4.00 4,959 4,959 AF CSGIN1 TEST BOP 20:00 02:30 6.50 4,959 4,959 AF CSGIN1 MUD RURD 02:30 03:30 1.00 4,959 4,959 AF CSGIN1 TRIP BBHD 03:30 04:30 1.00 4,959 4,959 AF CSGIN1 TRIP BIT 04:30 06:00 1.50 4,959 4,959 AF CSGIN1 TRIP BIT COMMENTS Witness of BOP test waived by Jim Regg, AOGCC, 14:00 hrs, 2/25/04. DENSITY(ppg) I Fvl >VN> I 54 12/20 I >P I WUHTHP I 6.61 IECD[ FCfT.SOL ! 1.017.0 [MUD DATA [ DAILY COST I OIW ! %Sand/MBT I >h/pM I >f/Mf I I 0.2516.0 9.60/0.7 0.613.2 Cl/Ca 25,000/40 [ CUM COST I CaCl2(wt%1 H2S LIME I ES /6R>M- 9.30 GELS I 8/15 Finish P/U total of 300 jts 3-1/2" DP. Mix new Flopro mud. POOH, rack back DP. Strap & P/U 3-1/2" HWDP & jars. POOH, rack back HWDP. CIO saver sub, grabber heads to HT-38. Pull wear bushing. UD 1 std 3-1/2" DP fl use as test joint. Run test plug. RlU to test BOPE. Test annular, inside choke & kill line valves, hydraulic IBOP, pipe rams, HCR, outside kill valve, manuallBOP, TIW, choke manifold valves 1 - 20 including hydraulic & manual choke to 250 psi low/3000 psi high. Pull test jt, test blind rams & dart valve to 250 psi low/3000 psi high. Test accumulator. Pull test plug. RID. Change liners in mud pumps to 5-1/2". Mix new Flopro mud. Clean store rooms & housekeeping. Blow down choke. Prep BHA on floor & catwalk. Test pumps. Install wear bushing. M/U 6" x 7" DOSRWD bit, motor & MWD. Orient motor, install probe in MWD. TIH wI BHA & HWDP. Flow check MWD. TIH to 4700' MD. TY>E DOSRWD I SERIAL N°·1 7103745 BITS JETS OR TFA 13/13/13/13/13/131111 HRS [ 24Hr DIST() DE>TH IN DATE IN I I·O-D-L-B-G-O-R 4,959.0 2/28/2004 6-8-BT-A-D- 1-RO-PR 24Hr ROP() [CUM HRSI CUM DEPTH() I CUM RO>() BIT/RUN! SIZE ! 3/4 7.000 BIT/RUN WOB () [ MANUF. Hughes R>M FloRtO PRESSO PBITO BH~ N0'1 L~~~) I EFF WTO I P/UO I S/OO I ROT WTn I BHA TORQUE(maxlmin) 0 I I BHA hrs I JAR hrs I MWD hrs I MTR hrs I SS hrs Printed: 4/8/2004 10:00:55 . . Page 2 of 2 WELL NAME PAXTON 1 KB 17.0 Daily Dri Exploitation IGL 124 HR PROGTMD 144.00 4,959 ITVD DFS IDOL RPT# I DATE 3,423 12 16 18 28-Feb-2004 BHA BHA DESCRIPTION 4-3/4" HCM 404 PDC Pilot Bit, 7" DOSRWD Bi-Center Tool, 4-7/8" M1XL w! 1.6AKO , SDC , 6" NMWBS , 5" MWD NMDP, HOS , Crossover, 3-1/2", 25 ppf HWDP (4), 4-3/4" DAILEY HYDRAULlC-MECH JARS, 3-1/2", 25 ppf HWDP (19), Crossover MUD GAS AVG. TRIP: MAX. TRIP: UNITS units AVG. CONN: MAX. CONN: AVG. BKGRD: MAX. DRL: PERSONNEL DATA, . Nabors Alaska Drilling Marathon Baker Hughes Inteq Epoch Well Services M-I Drilling Fluids NO. 20 1 2 4 1 ;1:'°lJ~S 264.00 24.00 48.00 48.00 24.00 COMPANY: ",,·"h -''';',',,' 'i','- Weaver Brothers (WBI) Oilfield Hot Shot Service Wildflowers and Resin Rigsafe . S~~VICE PÖB @ 06:00: .NO. HOURS ". 1 3.00 1 4.00 1 3.00 1 3.00 , CASINGi1SUIIIIMARY . LAST CASING TEST: 2/20/2004 MÀXSìep.~·' ..' (psi) @ (ppg) 670 (psi) @ 9.20 (ppg) (psi) @ 9.20 (ppg) LAST BOP TEST: 2/27/2004 SIZE~hì): ID (in) sl;J!D,E: TEST (ppg): 20.000 18.730 9.625 8.681 16.87 7.000 6.276 NEXT BOP TEST: 3/5/2004 100 1,895 4,950 100 1,682 3,417 133.00 X-56 47.00 L-80 26.00 L-80 6,870 7,240 Printed: 4/8/2004 10:00:55 . . 24HRPROG TMD TVD IDFS IDOL IRPT# I DATE 380.0 5,339 3,681 13 17 19 29-Feb-2004 AUTH MD WBS SAPIWBS COST 9,793 dx0309781capdrl M~~.~~OO N=~.OOOO 1 ".,~' yw",! ~"'~T I lAST CASING 1 NEXT CASING I LEAKOFF 7.000 (in) @ 4,950 (ft) 4.500 (in) @ 9,757 (ft) 16.42 124 HR FORECAST Drill ahead. WT. Drill ahead. WELL NAME PAXTON 1 SUPERVISOR Gene Anderson F!ELD NAME IGL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 KB RIG PHONE WILDCAT-FOR UNNAMED FIELD STATE./PROV Alaska CURRENT STATUS@ 6AM Drilling ahead. OPERATION COMMENTS Test casing. Drill shoe track & 20' new hole. 9072831315 COUNTY/OTHER Page 1 of 2 CUM WEll COST LOT to 16.42 ppg EMW. CIO mud. Drill f/4979' to 5339' MD. MANHRS WORKED I ACCIDENT TYPE I lAST SAFETY MTG 470.00 None 2/28/2004 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Housekeeping, Drilling shoe track, Drilling ahead. SAFÈ~Y SUMMARY IBOP PSI TEST I lAST STOP CARD AUDIT 2/27/2004 2/28/2004 06:00 07:00 1.00 4,959 4,959 AF CSGIN1 TEST CSG 07:00 07:30 0.50 4,959 4,959 AF CSGIN1 TRIP BIT 07:30 08:30 1.00 4,959 4,959 AF CSGIN1 DRILL CEMT 08:30 09:30 1.00 4,959 4,979 AF CSGIN1 DRILL DOH 09:30 10:00 0.50 4,979 4,979 AF CSGIN1 CIRC CLN 10:00 11:00 1.00 4,979 4,979 AF CSGIN1 TEST LOT 11:00 12:00 1.00 4,979 4,979 AF DRLPR MUD CHNG 12:00 06:00 18.00 4,979 5,339 AF DRLPR DRILL DOHD DEN~ITY(ppg) I · :: I'~~~:l I PP I I W~~~þ 1 I ECD 110.56 ,FCIT.SOll' OIW 1.0/5.5 I 9.20 ~E(,S 12/17 Obtain drill string data @ 4700' MD. P/U Wt 86,000#, SIO WI 56,000#, Rot Wt 68,000#, Torque 5000 ft Ibs. Close rams, test 7" casing to 3000 psi for 30 minutes, ok. Finish TIH. Tag top plug @ 4863' MD. Drill shoe track fl 4863' to 4950' MD. CIO previous hole to 4959' MD. Drill 20' of new hole fl 4959' to 4979' MD. ART 0.10 hrs. CBU. B/U gas 1430 units. Perform LOT to 16.42 ppg EMW. MW in/out 9.4 ppg, 1253 psi surface pressure @ 4950' MD, 3417' TVD. Change out old mud in hole to new 9.2 ppg Flopro mud system. Directional drill & survey fl 4979' to 5339' MD. ART 2.27 hrs. AST 11.37 hrs. 26,000/80 I CUM CÓST ' ur~êI2(\ÌIit'Yo1H2~ LIMe I ,ES 16RPM! BIT/RUNI SIZE 3/4 7.000 BIT/RUNI WOB (kip) I 3/4 2/4 RPM 1100 I SERIAL N°·1 7103745 GPM I PRESS(psi) I P BIT(psi) 299 1,900 125 BITS 131/3~~~/~:~~31111 I 6-8~'~;~~~:--~~~~PR HRS I 24Hr DIST(ft) 124Hr ROP(ftIhr) ¡CUM HRSI CUM DEPTH(ft) I CUM ROP(ftIhr) 13.74 380.0 27.66 13.74 380.0 27.66 BHA I EFF WT(lb) I P/U(lb) I S/O(lb) I ROT WT(lb) I TORQUE(maxlmin) (ft-Ibf) I BHA hrs I JAR hrs I MWD hrs I MTR hrs I S5 hrs 20,000 82,000 75,000 75,000 5,000/4,000 4-3/4" HCM 404 PDC Pilot Bit, 7" DOSRWD Bi-Center Tool, 4-7/8" M1XL w/1.6AKO , SDC , 6" NMWBS , 5" MWD NMDP, HOS , Crossover, 3-1/2", 25 ppf HWDP (4), 4-3/4" DAILEY HYDRAULlC-MECH JARS, 3_1/2", 25 ppf HWDP (19), Crossover BHA N0'1 LEN.(ft) 5 809.6 BHA DESCRIPTION NO. 1 2 MAKE OF PUMP GARDNER-DENVER GARDNER-DENVER PUMP 1 HYDRAULIC DATA STROKE (in) LINER (in) SRM Q (gpm) 9.000 5.500 112 298.58 9.000 KILL SPM 1 PRESSURE 42 600 40 600 PRESS. (psi) TOTAL Q 1,900 298.58 298.58 Printed. 4/8/2004 10:00:56 . . WELL NAME PAXTON 1 MARATHON OIL Daily Drilli Exploitati IGL 124 HR PROGITMD 144.00 380.0 5,339 Page 2 of 2 IKB 17.0 ITVD I DFS IDOL 3,681 13 17 IRPT# I DATE 19 29-Feb-2004 MUD GAS UNITS units 14 1 ,430 AVG. CONN: MAX. CONN: AVG. TRIP: MAX. TRIP: AVG. BKGRD: MAX. DRL: MD 5,028.0 5,124.0 INGL 49.00 46.30 AZIMUTH 332.40 329.80 SURVEY DATA TVD VS N/S GUM EIW GUM DOGLEG MD INGL 3,468.04 3,242.48 2,933.99 -1,380.39 2.54 5,217.0 42.40 3,532.71 3,313.25 2,996.10 -1,414.64 3.45 AZIMUTH 325.80 TVD VS N/S GUM EIW GUM DQGLEG 3,599.223,377.71 3,051.13 -1,449.19 5.16 SERVICE . . RERSONNEL DATA . NO."HOURSCOMPANÝ 20 264.00 R&K Industrial 1 24.00 BJ Services 2 48.00 Lynden Transport 4 48.00 S&R Enterprises 1 24.00 p,OB.'@06:00: . 'NO, HOIJR$ ., 4 48.00 2 10.00 1 1.00 2 3.00 Nabors Alaska Drilling Marathon Baker Hughes Inteq Epoch Well Services M-I Drilling Fluids 16.87 16.42 (psi) @ (ppg) 670 (psi) @ 9.20 (ppg) 1,289 (psi) @ 9.20 (ppg) · . CASiNG SUMMARY· LAST CASING TEST: 2/28/2004 MD (ft) TVD (ft) 100 100 1,895 1,682 4,950 3,417 LAST BOP TEST: 2/27/2004 .c$I:2:e;(iHj:i' ". ID (in) -SHOE¡TES:t:;(ppg) 20.000 18.730 9.625 8.681 7.000 6.276 NEXT BOP TEST: " ,.,-.",.:,,,,,,,., WT (Ib/tt).·, , GRADE 133.00 X-56 47.00 L-80 26.00 L-80 3/5/2004 . slJRST (psi); 6,870 7,240 (OMH\)f}n\~\. Printed: 41812004 10:00:56 WELL NAME PAXTON 1 SUPERVISOR Gene Anderson F!ELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS @ 6AM Drilling ahead. OPERATION COMMENTS Drill f/5339' to 5574'. CBU. WT. . . MARATHON OIL COMPANY D Page 1 of 2 rilling Report Exploitation Gas IGL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 RIG PHONE KB 124 HR PROG TMD TVD I DFS IDOL IRPT# I DATE 433.0 5,772 4,056 14 18 20 01-Mar-2004 AUTH MD WBS !':APIWBS COST 9,793 dx0309781capdrl MOC \'VI NRI I CAlLY \-¡ELL COST 60.0000 60.0000 I I LAST CASING I NEXT CASING I LEAKOFF 7.000 (in) @ 4,950 (ft) 4.500 (in) @ 9,757 (ft) 16.42 124 HR FORECAST Drill ahead. WT. Drill ahead. cur1l~ \AIElL COST 9072831315 COUNTY/OTHER Drill f/5574' to 5772' MD. S:AFETYSWMIIIIAR¥, IBOP PSI TEST I LAST STOP CARD AUDIT ! RNEGULATORY INSP? 2/27/2004 2/2812004 MANHRS WORKED ! ACCIDENT TYPE I LAST SAFETY MTG 446.00 None 2/29/2004 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Drilling ahead, Housekeeping, WT. ! LAST RIG INSPECTION 2/25/2004 06:00 15:30 9.50 5,339 5,574 AF DRLPR DRILL DOHD Directional drill & survey fl 5339' to 5574' MD. ART 1.31 hrs. AST 7.25 hrs. 15:30 16:00 0.50 5,574 5,574 AF DRLPR TRIP CIRT CBU forWT. 16:00 17:00 1.00 5,574 5,574 AF DRLPR TRIP WTRP Wipe hole to 7" casing shoe. Hole slick, no drag. 17:00 18:00 1.00 5,574 5,574 AF DRLPR RIG SERV Service TID, drwks, crown, blocks. Clean floor. 18:00 18:30 0.50 5,574 5,574 AF DRLPR TRIP WTRP TIH. Wash last std to btm for safety, no fill. 18:30 06:00 11.50 5,574 5,772 AF DRLPR DRILL DOHD Directional drill & survey f/5574' to 5772' MD. ART 0.70 hrs. AST 7.95 hrs. "OENSITY(ppg) I '0 FV 'I PVNP I 56 12/30 9.20 GEI.,S 13/17 pp I I' W~~;HP ¡ ECD10.71MUD [)~"~I DAILY COST 1 . " FCtr.SOL I om I ,olóS,and/MBT \ Ph/PMf pf/Mf\ CI/Ca 1.0/5.0 I 0.25/1.0 10.0010.6 0.512.4 28,000/40 I~I:IM COST I CaCI2(wt%1 H2S LIME I ES f 6RPM' BIT/RUNI WOB (kip) I 3/4 2/4 RPM 1100 GPM \ PRESS(psi) I P BIT(psi) 299 2,050 125 HRS \ 17.31 4,959.0 2/28/2004 6-8-BT-A-D- 1-RO-PR 24Hr DIST(ft) 24Hr ROP(ftlhr) ¡CUM HRS\ CUM DEPTH(ft) I CUM ROP(ftIhr) 433.0 25.01 31.05 813.0 26.18 BHA NO, LEN.(ft) 5 809.6 BHA DESCRIPTION I EF S/O(lb)! ROTWT(lbJ TO (ft-Ibf) ! BHAhrsl JARhrS MWDhts! MTRhrsl SShrs 30,000 86,000 80,000 80,000 4,000/4,000 4-3/4" HCM 404 PDC Pilot Bit, 7" DOSRWD Bi-Center Tool, 4-7/8" M1XL w/1.6AKO , SDC , 6" NMWBS , 5" MWD NMDP , HOS , Crossover, 3-1/2", 25 ppf HWDP (4), 4-3/4" DAILEY HYDRAULlC-MECH JARS, 3-1/2", 25 ppf HWDP (19), Crossover NO. 1 2 MAKE OF PUMP GARDNER-DENVER GARDNER-DENVER AVG. CONN: MAX. CONN: PUMP 1 HYDRAULIC DATA STROKE (in) LINER (in) SPiV! Q (gpm) 9.000 5.500 112 298.58 9.000 PRESS. (psi) TOTAL Q 2,050 298.58 298.58 KILL SPM / PRESSURE 42 650 42 650 42 MUD GAS AVG. TRIP: MAX. TRIP: 72 UNITS units 14 49 l AVG. BKGRD: MAX. DRL: Printed: 4/8/2004 10:00:58 WELL NAME PAXTON 1 MD 5,312.0 5,408.0 5,504.0 INCL 39.10 35.80 31.40 AZIMUTH 324.00 319.80 314.80 . . MARATHON OIL COMPANY Page 2 òf 2 Daily Drilling Report Exploitation IKB 17.0 IGL 144.00 124 HR PROG I TMD 433.0 5,772 SURVEY DATA TVD VS N/S CUM EIW CUM DOGLEG MD 3,671.183,438.763,101.87 -1,484.82 3.69 5,600.0 3,747.393,495.593,147.82 -1,520.75 4.35 5,696.0 3,827.353,546.193,186.92 -1,556.64 5.41 INCL 28.00 26.30 .C~MPANY Nabors Alaska Drilling Marathon Baker Hughes Inteq Epoch Well Services ITVD IDFS IDOL IRPT# ¡DATE 4,056 14 18 20 01-Mar-2004 AZIMUTH 305.50 294.30 PERSONNEt DÀ.tA NO. HOURS COMPANY 20 264.00 M-I Drilling Fluids 1 24.00 R&K Industrial 2 48.00 S&R Enterprises 4 48.00 ·CASING;SLlMM~Ry· . LAST CASING TEST: 2/28/2004 MAX SICPMD (ft) .ìV[){fty. (psi) @ (ppg) 100 100 670 (psi) @ 9.20 (ppg) 1,895 1,682 1,289 (psi) @ 9.20 (ppg) 4,950 3,417 20.000 9.625 7.000 LAST BOP TEST: 2/27/2004 ID (in)' SHÒ.ETEST (ppg) 18.730 8.681 6.276 16.87 16.42 TVD VS N/S CUMEIW GUM DOGLEG 3,910.77 3,589.31 3,217.65 -1,592.76 5.96 3,996.253,625.08 3,239.51 -1,630.52 5.60 " >:./\, ' J';t>ç;::·\-·" :';::<-I·,, NEXT BOP TEST: .. WT (Iblft) GRADE 133.00 X-56 47.00 L-80 26.00 L-80 POB @ 06:00: . NO. HOt.iRS· 1 24.00 4 36.00 2 2.00 3/5/2004 eÚRST(psi} 6,870 7,240 Printed: 4/8/2004 10:00:58 WELL NAME PAXTON 1 SUPERVISOR Gene Anderson FIELD NA.IJIE . . Page 1 of 2 KB I GL 124 HR PROG TMD TVD I DFS IDOL I RPT # I DATE RIGN;:~O&NO. 144.00 615.0 AU~~3~~ WB;626 15 19 21 ~:~~:~;~~~ NABORS DRILLING 129 9,793 dx0309781capdrl RIG PHONE MOC WI NRI II DAILY WELL COST 907283 1315 60.0000 60.0000 COUNTY/OTHER 1 LAST CASING I NEXT CASING I LEAKOFF 7.000 (in) @ 4,950 (ft) 4.500 (in> @ 9,757 (ft) 16.42 124 HR FORECAST Drill ahead. WT. Drill ahead. CUM WELL COST WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS @ 6AM Drilling ahead. OPERATION COMMENTS Drill f/5772' to 6146'. CBU. WT. Drill f/6146' to 6387' MD. SAFETY SUMMARY IBOP PSI TEST I LAST STOP CARD AUDIT I RNEGULATORY INSP? 2/27/2004 2/28/2004 MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG 433.00 None 3/1/2004 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Preventative maintenance, Slick/icy conditions I LAST RIG INSPECTION 2/25/2004 19:00 13.00 5,772 6,146 AF DRLPR DRILL DOHD Directional drill & survey f/5772' to 6146' MD. AST 6.90 hrs. ART 2.82 hrs. 19:00 19:30 0.50 6,146 6,146 AF DRLPR TRIP CIRT CBU forWT. 19:30 20:00 0.50 6,146 6,146 AF DRLPR TRIP WTRP Wipe hole 7 stds to 5480'. Hole slick, no drag. 20:00 20:30 0.50 6,146 6,146 AF DRLPR RIG SERV Service TID, drwks. Clean suction screens on mud pumps. 20:30 21:30 1.00 6,146 6,146 AF DRLPR TRIP WTRP TIH. Wash last std to btm for safety. Tighten leaky suction screen gasket. 21:30 06:00 8.50 6,146 6,387 AF DRLPR DRILL DOHD Directional drill & survey f/6146' to 6387' MD. AST 2.44 hrs. ART 2.69 hrs. DËNSt1'Y(ppg) FV 1 pV/YP I 58 13/30 9.30 GELS 13/17 1 pp 'I, WUHTHP\ 3.81 I ECD 110.73IMUD'DATA DAILYCOST I FClT.SOLI OIW' \ %Sand/MBTI Ph/pM PJ/Mf\ :Ct/Cà 1.0/5.5 I 0,25/1,5 10.10/0.71 0.5/2.5 2~.000/40 ' CUMCÖST \ CaCl2(wt%1 H2S LIME \ ES \ 6RPM BIT/RUN WOB (kip) I 3/4 2/4 RPM 1100 GPM I PRESS(psi) P BIT(psi) 283 2,150 113 4,959.0 2/28/2004 HRS 24HrDIST(ft) 124Hr ROP(ftlhr) ICUM HRSI CUM DEPTH(ft) I CUM ROP(ftlhr) 14.85 615.0 41.41 45.90 1,428.0 31.11 BHA IE \ ROT WT(lb)\ TORQUE(maxlmin) (ft-Ibf) I BHA hrsl JAR hrs \ MWD hrs\ MTR hrs I S8 hrs 30,000 98,000 86,000 86,000 5,000/4,000 4-3/4" HCM 404 PDC Pilot Bit, 7" DOSRWD Bi-Center Tool, 4-7/8" M1XL w/1.6AKO , SDC , 6" NMWBS , 5" MWD NMDP, HOS , Crossover, 3-1/2", 25 ppf HWDP (4), 4-3/4" DAILEY HYDRAULlC-MECH JARS, 3-1/2", 25 ppf HWDP (19), Crossover BHA NO, \ lEN.(ft) 5 809,6 BHA DESCRIPTION NO. 1 2 MAKE OF PUMP GARDNER-DENVER GARDNER-DENVER AVG. CONN: MAX. CONN: PUMP 1 HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) 9.000 9.000 5.500 106 282.58 PRESS. (psi) TOTAL Q 282.58 2,150 282.58 KILL SPM 1 PRESSURE 41 700 40 675 MUD GAS AVG. TRIP: MAX. TRIP: UNITS units 53 1,089 487 AVG. BKGRD: MAX. DRL: Printed: 4/8/2004 10:01 :00 WELL NAME PAXTON 1 MD 5,788.0 5,885.0 5,980.0 AZIMUTH 284.90 274.10 272. 70 INCL 24.90 24.00 23.70 . . IKB 17.0 IGL 144.00 124HRPROGITMD TVD IDFS IDOL IRPT# I DATE 615.0 6,387 4,626 15 19 21 02-Mar-2004 SURVEY DATA TVD VS N/S CUM E/W CUM DOGLEG MD INCL 4,079.25 3,652.97 3,252.88 -1,667.83 4.66 6,076.0 22.40 4,167.593,675.673,259.54 -1,707.26 4.69 6,171.0 22.50 4,254.48 3,693.94 3,261.83 -1,745.60 0.67 6,266.0 22.20 AZIMUTH 266.00 264.10 263.60 Nabors Alaska Drilling Marathon Baker Hughes Inteq Epoch Well Services M-I Drilling Fluids Page TVD VS N/S CUM EIW CUMDOGLEG 4.342.833,709.473,261.46 -1,783.13 3.05 4,430.63 3,721.90 3,258.33 -1,819.27 0.77 4,518.493,733.583,254.46 -1,855.18 0.37 PERSONNEL DATA . NO. HOURS CPMPANY 20 264.00 R&K Industrial 1 24.00 S&R Enterprises 2 48.00 Alaska Oil Sales 4 48.00 Wildflowers and Resin 1 24.00 LAST BOP TEST: 2/27/2004 'SIZÈ.(ìh)ID(ìn)· SHc5t<TEST (ppg). 20.000 18.730 9.625 8.681 7.000 6.276 LAST CASING TEST: 2/28/2004 16.87 16.42 '.MAXSICP . (psi) @ (ppg) 670 (psi) @ 9.20 (ppg) 1,271 (psi) @ 9.30 (ppg) TVD(ft) 100 1,682 3,417 , "MD(ft) 100 1,895 4,950 NEXT BOP TEST: ,wt (Ib/ft) GRADE 133.00 X-56 47.00 L-80 26.00 L-80 POB @ 06:00: .' NO. H()I.,IIi~· 2 18.00 2 2.00 1 2.00 1 3.00 3/5/2004 BORST, ,(psi) 6,870 7,240 Printed: 4/8/2004 10:01 :00 . . Page 1 of 2 WELL NAME PAXTON 1 SUPERVISOR Gene Anderson IGL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 124 HR PROG TMD TVD 1 DFS I DOL I RPT # DATE 630.0 7,017 5,222 16 20 22 03-Mar-2004 AUTH MD WBS 9,793 dx0309781capdrl r·~~.~~OO N~~.OOOO I """ v'"'''''. """T 1 LAST CASING I NEXT CASING 7.000 (in) @ 4,950 (ft) 4.500 (in) @ 9,757 (ft) 124 HR FORECAST Drill ahead. WT. Drill ahead. 5þ-....·....- ,...nC::T KB F!ELD NAME RIG PHONE r.:! 1"..1 '"AJr:t I r:OST WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS@ 6AM Drilling ahead. OPERATION COMMENTS Drill f/6387' to 7017' MD. 9072831315 COUNTY/OTHER 1 LEAKOFF 16.42 MANHRS WORKED I ACCIDENT TYPE 449.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Wet location, parts inventory I LAST SAFETY MTG 3/2/2004 SAF~1¥sur"MARY BOP PSI TEST LAST STOP CARD AUDIT RNEGULATORY INSP? 2/27/2004 3/2/2004 I LAST RIG INSPECTION 2/25/2004 ;;':""'_'~:>::":_::i.;:';',\< STEP,"~Ò~: 06:00 _~ ,';>:i:';·'>:!>S>:\:;f<: :;, \:-:, 'TO, 'H~~:::#RONl 06:00 24.00 6,387 ¡;.. ' OPE~:nONS SUMMARY TO' S4BPHASE " 'qf SUBOP TRB!- 7,017 AF DRLPR DRILL DOHD Directional & survey f/6387' to 7017' MD. AST 11.06 hrs. ART 7.62 hrs. COMMENTS Received 157 jts 4-1/2", 12.6 ppf, L-80, Hydril-521 liner on location. Three jts @ BOT for float equipment installation. f.ÇlJMc;PS:ç:: ';LIME I:E~16RPIVI BIT/RUN SIZE 3/4 7.000 BIT/RUNI WOB (kip) I 3/4 2/5 I s~~~,;;::·1 GPM I PRESS(psi) I P BIT(psi) 280 2,300 111 HRS I 24Hr DIST(ft) 18.68 630.0 \.;,::;~t;,:\::<:-1::,_::::- (, I ' I-Q-D-L.B-G;O;R 4,959.0 2/28/2004 6-8-BT-A-D- 1-RO-PR 124Hr ROP(ftlhr) ICUM HRsl CUM DEPTH(ft) I CUM ROP(ftlhr) 33.73 64.58 2,058.0 31.87 RPM 1100 BHA NO. 5 809.6 BHA DESCRIPTION I BHA hrs I JAR hrs! ríÀ I S8 hrs 110,000 90,000 90,000 6,000/4.000 4-3/4" HCM 404 PDC Pilot Bit, 7" DOSRWD Bi-Center Tool, 4-7/8" M1XL w/1.6AKO , SDC , 6" NMWBS , 5" MWD NMDP, HOS , Crossover, 3-1/2", 25 ppf HWDP (4), 4-3/4" DAILEY HYDRAULlC-MECH JARS, 3-1/2", 25 ppf HWDP (19), Crossover NO. 1 2 MAKE OF PUMP GARDNER-DENVER GARDNER-DENVER PUMP 1 HYDRAULIC DATA ST~0KE (in) LINER (in) SPM Q (gpm) 9.000 5.500 105 279.92 9.000 PRESS. (psi) TOTAL Q 2,300 279.92 279.92 KILL SPM / PRESSURE 41 750 40 710 AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: UNITS units 33 585 AVG. BKGRD: MAX. DRL: MD 6,361.0 6,456.0 6,553.0 INCL 22.10 21.90 21.90 AZIMUTH 265.40 268.50 267.80 SURVEY DATA TVD VS N/S CUM EfW CUM DOGLEG MD 4,606.483,745.533,251.02 -1,890.83 0.72 6,649.0 4,694.573,758.823,249.13 -1,926.36 1.24 6,745.0 4,784.57 3,773.05 3,247.96 -1,962.52 0.27 6,8420 INCL 21.20 18.10 14.30 AZIMUTH 267.70 268.80 270.50 TVD VS N/S CUM EfW CUM DOGLEG 4,873.86 3,786.68 3,246.58 -1,997.75 0.73 4,964.26 3,799.40 3,245.57 -2,030.01 3.25 5,057.39 3,810.64 3,245.35 -2,057.07 3.95 Printed: 4/8/2004 10:01:02 . . Page 2 of 2 WELL NAME PAXTON 1 IKB 17.0 IGL 144.00 124HRPROGTMD IrvD IDFS IDOL IRPT# I DATE 630.0 7,017 5,222 16 20 22 03-Mar-2004 SURVEY DATA MD INCL I AZIMUTH I TVD , VSIN/S CUMIE/W CUMDOGLEGI MD INCL I AZIMUTH I TVD 6,936.0 1 10.60 272.50 15,149.16 3,819.64 3,245.831-2,077.321 3.96 I I I I 16.87 16.42 PERSÖN~El DATA NO. HOURS COMPANY 20 264.00 R&K Industrial 1 24.00 Unocal 2 48.00 Marathon 4 48.00 Weaver Brothers (WBI) 1 24.00 CASING SUMM~RY LAST CASING TEST: 2/28/2004 . . MAXSICP..TvD (ft) (psi) @ (ppg) 100 100 670 (psi) @ 9.20 (ppg) 1,895 1,682 1,271 (psi) @ 9.30 (ppg) 4,950 3,417 SERVICE VS IN/S CUMIEIW CUMIOOGLEG POB @ 06:00:. NO; HOURS 2 34.00 4 4.00 2 1.00 2 2.00 COMPANY Nabors Alaska Drilling Marathon Baker Hughes Inteq Epoch Well Services M-I Drilling Fluids LAST BOP TEST: 2/27/2004 ..... }$IB:E;'(in)' . . ID (in) SHdÈitEST (ppg) . 20.000 18.730 9.625 8.681 7.000 6.276 NEXT BOP TEST: WT\(¡b/ft) . GRABe. 133.00 X-56 47.00 L-80 26.00 L-80 3/5/2004 . ···BÜß:$1r (Piü'. 6,870 7,240 Printed: 4/8/2004 10:01 :02 WELL NAME PAXTON 1 SUPERVISOR Gene Anderson F!ELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS@ 6AM Drilling ahead. OPERATION COMMENTS Drill f/7017' to 7198'. CBU. WT. 124 HR PROG TMD TVD 1 DFS IDOL 1 RPT # DATE 638.0 7,655 5,863 17 21 23 04-Mar-2004 AUTH MD WBS 9,793 dx0309781capdrt MOC WI NRI II DAILY WEll COST 9072831315 60.0000 60.0000 '- COUNTY/OTHER 1 LAST CASING I NEXT CASING I LEAKOFF 7.000 (in) @ 4,950 (ft) 4.500 (in) @ 9,757 (ft) 16.42 124 HR FORECAST Drill ahead. WT. Drill ahead. . MARATHON OIL Daily Drill Exploit IGL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 KB RIG PHONE Drill f/7198' to 7655'. . Page 1 of 2 !'i^PIW"'!,: C:OST CUM \'VELL COST SAFETY'SUIJlMAJ:tV . BOP PSI TEST LAST STOP CARD AUDIT RNEGULATORY INSP? 2/27/2004 3/312004 I LAST RIG INSPECTION 2/25/2004 MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG 440.00 None 3/3/2004 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: PPE, Pump pressure, Slick & icy conditions, Prep liner, Pit drill. ~TJ:P FROM !¡;IRS FR'PM TO .0 ~UB PHASE 00 06:00 15:30 9.50 7,017 7,198 AF DRLPR DRILL DOHD 15:30 16:00 0.50 7,198 7,198 AF DRLPR TRIP CIRT 16:00 16:30 0.50 7,198 7,198 AF DRLPR TRIP WTRP 16:30 17:00 0.50 7,198 7,198 AF DRLPR RIG SERV 17:00 18:00 1.00 7,198 7,198 AF DRLPR TRIP WTRP 18:00 06:00 12.00 7,198 7,655 AF DRLPR DRILL DOHD DENSITY(ppg) FV r PVtYp/ 69 I 15/34 9.30 GELS 14/18 I PP r WLlHTHP/ 3.61 Directional drill & survey fl 7017' to 7198' MD. ART 1.30 hrs. AST 5.92 hrs. CBU for WT. Wipe hole 11 stds to 6146'. Hole slick, no drag. Service TID, dwks, blocks. TIH. Wash last std to btm for safety. No fill. Directional drill & survey fl 7198' to 7655' MD. ART 8.56 hrs. AST 0.5 hrs. EèD1O.nIMUD DATAl DAILYC?S! I" FCIT.SQL I OIW ! 'ÌoSänd/MBT! Ph/PMI Þf/Mfl CIICa o 1.0/6.0 ' " 0.25/6.0 9.30/0.4 0.312.4 28,000/40 I CUM COST ICaCI2(Wt~l H2~ LIMe I ES 16~PM BIT/RUNI WOB (kip) \ 3/4 2/5 RPM 1100 GPM I PRESS(psi) I P SIT(psi) 267 2,515 101 HRS 24Hr DIST(ft) 124Hr ROP(ftIhr)\CUM HRS\CUM DEPTH(ft)\CUM ROP(ftIhr) 16.28 638.0 39.19 80.86 2,696.0 33.34 BHA I EFF WT(lbJI P/U(lbJ\ S/O(lb)! ROT WT(lb) I TORQUE(rríaxlníin) (ft-Ibf) I BHA hrs\ JAR hrsl MWOhrs\ MTR hrs SS hrs 30,000 124,000 102,000 102,000 I 7,000/4,000 4-3/4" HCM 404 PDC Pilot Bit, 7" DOSRWD Bi-Center Tool, 4-7/8" M1XL w/1.6AKO , SDC , 6" NMWBS , 5" MWD NMDP, HOS , Crossover, 3-1/2", 25 ppf HWDP (4), 4-3/4" DAILEY HYDRAULlC-MECH JARS, 3-1/2", 25 ppf HWDP (19), Crossover BHA NO. \' LEN.(ft) 5 809.6 BHA DESCRIPTION NO. 1 2 MAKE OF PUMP GARDNER-DENVER GARDNER-DENVER AVG. CONN: MAX. CONN: 4,959.0 2/28/2004 6-8-BT-A-D- 1-RO-PR PUMP 1 HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) 9.000 5.500 100 266.59 9.000 20 MUD GAS AVG. TRIP: MAX. TRIP: PRESS. (psi) TOTAL Q 2,515 266.59 266.59 KILL SPM / PRESSURE 38 900 39 850 UNITS units 23 802 554 AVG. BKGRD: MAX. DRL: Printed: 4/8/2004 10:01 :04 WELL NAME PAXTON 1 MD 7,032.0 7,128.0 7,223.0 7,319.0 INCL 8.80 6.30 4.60 4.10 A21MUTH 277.50 277.80 276.30 272.10 . . MARATHON,OfL COMPANY Page 2 of 2 rt IKB 17.0 IGL 144.00 124 HR PROG I TMD I TVD 1 DFS I DOL 638.0 7,655 5,863 17 21 ~URVEY DATA TVD VS N!S CUM E!W CUM DOGLEG MD INCL 5,243.79 3,827.66 3,247.18 -2,093.42 2.07 7,414.0 3.60 5,338.95 3,834.46 3,248.85 -2,105.93 2.60 7,510.0 3.10 5,433.523,839.263,249.98 -2,114.88 1.80 7,605.0 3.00 5,529.24 3,842.83 3,250.52 -2,122.13 0.62 AZ!MUTH 272.80 265.00 268.90 PERSONNELD~TA .. NO~ HÇlU~S. COM~ANY 20 264.00 R&K Industrial 1 24.00 Weaver Brothers (WBI) 2 48.00 Marathon 4 48.00 Peak Oilfield Service Co. 1 24.00 Wildflowers and Resin C()MPANY Nabors Alaska Drilling Marathon Baker Hughes Inteq Epoch Well Services M-I Drilling Fluids IRPT# 1 DATE 23 04-Mar-2004 TVD VS N/S CUM E/VV CUMDOGLEG 5,624.023,845.77 3,250.79 -2,128.51 0.53 5,719.863,848.063,250.72 -2,134.10 0.70 5,814.73 3,849.95 3,250.44 -2,139.15 0.24 LAST CASING TEST: 2/28/2004 16.87 16.42 (psi) @ (ppg) 670 (psi) @ 9.20 (ppg) 1,271 (psi) @ 9.30 (ppg) 100 1,895 4,950 LAST BOP TEST: 2/27/2004 ^' 'lì:gi(Ë,::(_i!n:) I_izi¡:('id)"::'!,:' sÌ:-l'<ZÏI_"'im'~:s~; :~~-~pjg~,:~! "c':, 20.000 18.730 9.625 8.681 7.000 6.276 100 1,682 3,417 NEXT BOP TEST: .GRÁDe X-56 L-80 L-80 133.00 47.00 26.00 POB@06:pO: . . NO. . !:lOURS. 2 20.00 2 3.00 1 3.00 1 2.00 1 4.00 3/5/2004 BURst (psi) 6,870 7,240 Printed: 4/8/2004 10:01 :04 WEll NAME PAXTON 1 SUPERVISOR Gene Anderson F!ELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS @ 6AM Drilling ahead. OPERATION COMMENTS Drill f/7655' to 8441'. CBU. WT. . . Page 1 of 2 1 DFS IDOL 1 RPT II DATE 18 22 24 05-Mar-2004 SAPIWBS COST Gl 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 KB 124 HR PROG TMD 849.0 8,504 AUTH MD 9,793 TVD 6,713 WBS dx0309781capdrl NR' I nAil V'Alel' "nST I I' ...._..., ...... "'V'" I 60.0000 60.0000 I NEXT CASING 4,950 (ft) 4.500 (in> @ 9,757 (ft) I lEAKOFF 16.42 R!G PHONE MOC\'VI CUM WEll COST 907283 1315 COUNTY/OTHER I lAST CASING 7.000 (in) @ 124 HR FORECAST Drill to TD. CONfiDENTIAL Drill f/8441' to 8504'. MANHRS WORKED I ACCIDENT TYPE I LAST SAFETY MTG 433.00 None 3/4/2004 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Spill drill, Valve drill, Service loop safety SAÅE:rV SUMMARY BOP PSI TEST LAST STOP CARD AUDIT I RNEGUlATORY INSP? 2/27/2004 3/4/2004 LAST RIG INSPECTION 2/25/2004 06:00 01:00 19.00 7,655 8,441 AF DRLPR DRILL DOHD Directional drill & survey fl 7655' to 8441' MD. ART 15.44 hrs Change liners in #1 pump to 5". 01:00 02:00 1.00 8,441 8,441 AF DRLPR TRIP CIRT CBU for WT. 02:00 03:00 1.00 8,441 8,441 AF DRLPR TRIP WTRP Wipe hole 13 stds to 7198'. Hole slick, 10K drag on std #13. 03:00 04:00 1.00 8,441 8,441 AF DRLPR TRIP WTRP TIH. Wash last std to btm for safety, no fill. 04:00 06:00 2.00 8,441 8,504 AF DRLPR DRILL DOHD Directional drill & surveyf/8441' to 8504' MD. ART 1.30 hrs. COMMENTS Rack, strap & drift 157 jts 4-1/2",12.6 ppf, L-80, Hydril-521 liner OAL 6243.91'. eqpt @ BOT. DENSITY(ppg) I 9.30 :: I ~:;: I ~~~: I I PP I I/VUHTHP "I 4.21 Does not include 3 shoe jts or float rEC.DJ10.61IMUDDÂTAIDA!~YC9ST I FelT.sOL 1 Oll/V "I %SänillIÌ/1BT Ph/pM 1 Pf/llìlfl" 1.0/6.0 I 0.25/7.0 9.30/0.4 0.313.1 I CUM COST ¡Ca'CI2(Wt%1 H2S LIME I ES I ilRPM . CIICa 28,000/40 BIT/RUN 1 WOB (kip) 1 3/4 12 RPM 1100 GPM 1 PRESS(psi) 1 P BIT(psi) 271 2,840 104 4,959.0 2/28/2004 6-8-BT-A-D- 1-RO-PR HRS 1 24Hr DIST(ft) 124Hr ROP(ftlhr) ICUM HRSI CUM DEPTH(ft) 1 CUM ROP(ftlhr) 16.74 849.0 50.72 97.60 3,545.0 36.32 . BHA EFF WT(lb) P/U(lb) I S/O(lb)! ROT WT(lb) TORQUE(maxlmin) (ft-Ibf) I BHA hrs I JAR hrsl MWD hrsl MTR hrs I SS hrs 30,000 134,000 103,000 103,000 8,700/7,000 4-3/4" HCM 404 PDC Pilot Bit, 7" DOSRWD Bi-Center Tool, 4-7/8" M1XL w/1.6AKO , SDC , 6" NMWBS , 5" MWD NMDP, HOS , Crossover, 3-1/2", 25 ppf HWDP (4), 4-3/4" DAILEY HYDRAULlC-MECH JARS, 3-1/2", 25 ppf HWDP (19), Crossover BHA NO.!I.-EN.(ft) 5 809.6 BHA DESCRIPTION NO. 1 2 MAKE OF PUMP GARDNER-DENVER GARDNER-DENVER AVG. CONN: MAX. CONN: PUMP 1 HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) 9.000 5.000 123 270.99 9.000 PRESS. (psi) TOfAL Q 2,840 270.99 270.99 KILL SPM 1 PRESSURE 42 890 39 900 MUD GAS AVG. TRIP: MAX. TRIP: UNITS units 90 1,119 1,655 AVG. BKGRD: MAX. DRL: Printed: 4/8/2004 10:01 :06 WELL NAME PAXTON 1 MD 7,701.0 7,796.0 7,893.0 7,989.0 INCL 2.70 2.30 2.30 1.90 AZIMUTH 271.70 270.60 268.30 273.40 . . Page 2 of2 IKB 17.0 IGL 144.00 124 HR PROGITMD 849.0 8,504 TVD IDFS IDOL IRPT# I DATE 6,713 18 22 24 05-Mar-2004 SURVF.Y DATA TVD VS N/S CUM EIW CUM DOGLEG MD INCL 5,910.61 3,851.98 3,250.46 -2,143.92 0.34 8,084.0 1.40 6,005.52 3,853.81 3,250.55 -2,148.06 0.42 8,180.0 1.20 6,102.443,855.423,250.51 -2,151.95 0.10 8,274.0 1.50 6,198.373,856.943,250.55 -2,155.47 0.46 8,370.0 1.20 AZIMUTH 276.10 287.60 299.20 283.90 . PERSONNEL DATA' NO~ HOURS c:ÒM~~Y. """ 20 264.00 M-I Drilling Fluids 1 24.00 R&K Industrial 2 48.00 Weaver Brothers (WBI) 4 48.00 .COMPANY Nabors Alaska Drilling Marathon Baker Hughes Inteq Epoch Well Services 16.87 16.42 /' CÁ"SING SUMMARY LAST CASING TEST: 2/28/2004 tv1ÄxSICP MD (ft)WD(ft) (psi) @ (ppg) 100 100 670 (psi) @ 9.20 (ppg) 1,895 1,682 1,271 (psi) @ 9.30 (ppg) 4,950 3,417 LAST BOP TEST: 2/27/2004 SIZE (in) ". .ID (in). S¡':¡OE TES:Ì:(ppg) 20.000 18.730 9.625 8.681 7.000 6.276 TVD VS N/S CUMEIW CUM DOGLEG 6,293.333,858.293,250.77 -2,158.19 0.53 6,389.31 3,859.57 3,251.19 -2,160.32 0.34 6,483.28 3,861.24 3,252.09 -2,162.33 0.43 6,579.263,862.89 3,252.95 -2,164.40 0.49 . POB @ 06:Òp: . NQ., ~ ,äqORS 1 24.00 2 24.00 1 1.00 NEXT BOP TEST: . WT' (ib/ft) . GRADE .... 133.00 X-56 47.00 L-80 26.00 L-80 3/5/2004 BURST (psi) 6,870 7,240 Printed: 4/8/2004 10:01 :06 · . MARATHON OIL COMPANY Page 1 of 2 WELL NAME PAXTON 1 SUPERVISOR Gene Anderson F!ELD NAME 124 HR PROG TMD TVD I DFS I DOL I RPT # I DATE 1,009.0 9,513 7,721 19 23 25 06-Mar-2004 AUTH MD WBS SAPIWBS COST 9,793 dx0309781 capdrl MOC WI NRI I "4.' V'AlCI I r:n~T 9072831315 60.0000 60.0000. COUNTY/OTHER I LAST CASING I NEXT CASING 7.000 (in) @ 4,950 (ft) 4.500 (in) @ 9,757 (ft) 124 HR FORECAST CBU. TFNB. Test BOPE. TIH. Drill ahead. IGL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 KB R!G PHONE r:IIM WELL COST '1 WILDCAT-FOR UNNAMED FIELD STATEfPROV Alaska CURRENT STATUS @ 6AM Circulate for trip. OPERATION COMMENTS Drill f/8504' to 9513'. CBU for trip. I LEAKOFF 16.42 MANHRS WORKED ! ACCIDENT TYPE 451.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Manlift safety, Slick/Icy conditions. I LAST SAFETY MTG 3/5/2004 , S~::ETY,~SUMMARY I BOP PSI TEST I LAST STOP CARD AUDIT 2/27/2004 3/512004 N 06:00 05:30 23.50 8,504 9,513 AF DRLPR DRILL DOHD Directional drill & survey f/8504' to 9513' MD. ART 18.2 hrs. Change liners in #2 pump to 5". CBU for trip for new bit. 05:30 06:00 0.50 9,513 9,513 AF DRLPR TRIP CIRT COMMENTS Total 160 jts, 4-1/2", 12.6 ppf, L-80, Hydril-521 liner on location - OAL 6363.96', includes 3 shoe joints (no float equipment included). DENSLT:Y{ppg) I ;; I ~:~;I 9.35 GELS, 12/17 I CUM COST LI~E I ESj.6RPM eiTIßUN[ SIZE I ' 3/4 7.000 BITIRUN[ WOB (kip) I 3/4 3/10 RPM 1100 BITS, JETS ORTF:A . DEPTH IN ,DATE-IN [ 13/13/13/13/13/131111 4,959.0 2/28/2004 6-8-BT-A-D- 1-RO-PR HRS [24Hr DIST{ft) [24Hr ROP(ftlhr) [CUM HRS[ CUM DEPTH(ft) [CUM ROP(Whr) 18.20 1,009.0 55.44 115.80 4,554.0 39.33 P BIT(psi) 100 BHA NO.LÈN;(fÌ) 5 809,6 BHA DESCRIPTION I EFF WT(lb) 'I ÞíU(lbJf S/O{lbJ! ROT WT(lbJ! TORQUE(max7nTiO)'(fHþf)! B)HA hrsj JARhrs. MWD hrs] MTRhrsl SS hrs 30,000 158,000 116,000 116,000 13,000/11,500 4-3/4" HCM 404 PDC Pilot Bit, 7" DOSRWD Bi-Center Tool, 4-7/8" M1XL w/1.6AKO , SDC , 6" NMWBS , 5" MWD NMDP , HOS , Crossover, 3-1/2", 25 ppf HWDP (4), 4-3/4" DAILEY HYDRAULlC-MECH JARS, 3-1/2", 25 ppf HWDP (19), Crossover NO. 1 2 MAKE OF PUMP GARDNER-DENVER GARDNER-DENVER PUN Þ 1 HYDRAULIG,DATA STROKE (inJ LINER (in) SPM Q (gpm) 9.000 5.000 120 264.38 9.000 PRESS. (psi) TOTAL Q 2,515 264.38 264.38 KILL SPM / PRESSURE 42 800 42 830 AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: UNITS units 101 1,111 AVG. BKGRD: MAX. DRL: MD 8,466.0 8,562,0 INCL 0.80 0.40 AZIMUTH 310,30 354,90 SURVEY DATA TVD VS N/S CUM EIW CUM DOGLEG MD INCL 6.675.243,864.133,253.62 -2,165.89 0.63 8,657.0 0.80 6,771.24 3,865.05 3,254,39 -2,166.43 0.61 8,753.0 1.50 AZIMUTH 82,70 89,90 TVD VS N/S CUM EIW CUM DOGLEG 6,866,23 3,865,16 3,254.80 -2,165.80 0,93 6,962,21 3,864.43 3,254.89 -2,163.88 0.74 Printed: 4/8/2004 10:01:08 WELL NAME PAXTON 1 MD 8,848.0 8,942.0 9,039.0 9,135.0 I.NCL 2.00 2.60 3.00 3.40 AZIMUTH 81.70 80.30 85.90 76.70 . . MARATHON Oil COMPANY Page 2 of 2 rt IKB 17.0 IGL 144.00 124 HR PROGITMD 1,009.0 9,513 SURVEY DATA TVD VS N/S CUM EfIN CUM DOGLEG MD 7.057.17 3.863.43 3.255.13 -2.161.00 0.59 9,229.0 7.151.09 3.862.39 3.255.73 -2.157.27 0.64 9.325.0 7.247.98 3.860.91 3.256.28 -2.152.57 0.50 9,421.0 7.343.833.859.433.257.11 -2.147.30 0.68 COMPANY Nabors Alaska Drilling Marathon Baker Hughes Inteq Epoch Well Services M-I Drilling Fluids R&K Industrial LAST BOP TEST: 2/27/2004 ;,:SJZE (in) . ID(írf)', SHOËT'ËSJ (ppg) 20.000 18.730 9.625 8.681 7.000 6.276 ITVD I DFS I DOL 1 RPT # 1 DATE 7.721 19 23 25 06-Mar-2004 INCL 3.40 3.90 4.10 AZIMUTH 76.70 79.30 78.20 TVD VS NIS CUM EIW CUMDQGLEG 7,437.66 3.858.30 3,258.40 -2.141.87 0.00 7.533.47 3.856.92 3,259.66 -2.135.89 0.55 7,629.23 3.855.33 3,260.97 -2.129.32 0.22 PERSONNEL DATA NO. HQU8S; . COMPANY . 20 264.00 Weaver Brothers (WBI) 1 24.00 Oilfield Hot Shot Service 2 48.00 Wildflowers and Resin 4 48.00 Marathon Underwood 1 24.00 Quadco 2 24.00 ,POB @ 06:00: NO. . . , HQURS 2 2.00 1 8.00 1 3.00 1 1.00 1 5.00 CASING:;StlMMARY LAST CASING TEST: 2/28/2004 TVD (fI)' · 100 1.682 3,417 16.87 16.42 (psi) @ (ppg) 670 (psi) @ 9.20 (ppg) 1.271 (psi) @ 9.30 (ppg) 100 1,895 4,950 NEXT BOP TEST: ,WT(lblft) . GRADE 133.00 X-56 47.00 L-80 26.00 L-80 3/5/2004 ;i31!J~8ir ·(psi) 6,870 7,240 Printed: 4/8/2004 10:01 :08 . . MARATHON DaUy D Expl Page 1 of 2 WELL NAME PAXTON 1 SUPERVISOR Gene Anderson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS @ 6AM Circulate btms up. OPERATION COMMENTS CBU for trip. TFNB. Test BOPE. TIH to 7" shoe. CBU. Sliplcut drilling line. SR. TIH. W/R 8823' to 9109'. CBU. IGL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 RIG PHONE 124 HR PROG TMD TVD I DFS I DOL I RPT # I DATE 9,513 7,721 20 24 26 07-Mar-2004 AUTH MD WBS SAPIWBS COST 9,793 dx0309781capdrl ..OCW1 NRI I nA"VW'"I "O"T ·"60.ÖÖOO 60.0000 L --~.- . --- - -. 1 LAST CASING I NEXT CASING I LEAKOFF 7.000 (in) @ 4,950 (ft) 4.500 (in) @ 9,757 (ft) 16.42 /24 HR FORECAST Drill to TD. CBU. Trip. Run OH logs. TIH. CUM WELL COS', KB 9072831315 COUNTY/OTHER SAFETY SU'Îì'lMARY IBOP PSI TEST LAST STOP CARD AUDIT I RNEGULATORY INSP? 3/6/2004 3/6/2004 I LAST RIG INSPECTION 2/25/2004 MANHRS WORKED I ACCIDENT TYPE 427.00 None ACCIDENT DESCRIPTION: I LAST SAFETY MTG 3/6/2004 SAFETY MTG TOPICS: Pinch points. $~~.ÊRêM . ':j1ø( IiIR$</ ·iF,;Rb.M rr,ør: :šliJliJ PH,~~~ 06:00 07:00 1.00 9,513 9,513 AF DRLPR TRIP CIRT Circulate shakers clean for trip. 07:00 13:30 6.50 9,513 9,513 AF DRLPR TRIP BIT Pull 5 stds. Mix & pump dry job. TFNB. Pull 20K over fl 8472' to 8462'. Test valves 1 - 20 including manual & hydraulic choke while tripping to 250 psi low/3000 psi high. 13:30 14:30 1.00 9,513 9,513 AF DRLPR TRIP BBHD UD bit, motor. P/U new bit & motor. Std back in derrick. 14:30 15:00 0.50 9,513 9,513 AF DRLPR TEST BOP Pull wear bushing. Install test plug. RlU to test BOPE. 15:00 18:00 3.00 9,513 9,513 AF DRLPR TEST BOP Test BOPE. Test annular, inside choke & kill line valves, hydraulic IBOP, pipe rams, HCR, outside kill valve, manual IBOP, TIW to 250 psi low/3000 psi high. Pull test jt, test blind rams & dart valve to 250 psi low/3000 psi high. Test accumulator. 18:00 18:30 0.50 9,513 9,513 AF DRLPR TEST BOP Pull test plug. Install wear bushing. RID. 18:30 20:00 1.50 9,513 9,513 AF DRLPR TRIP BIT TIH wI BHA & HWDP. Test MWD. 20:00 22:00 2.00 9,513 9,513 AF DRLPR TRIP BIT TIH to 7" csg shoe. 22:00 22:30 0.50 9,513 9,513 AF DRLPR CIRC CLN CBU, monitor well. 22:30 00:30 2.00 9,513 9,513 AF DRLPR RIG SCDL Slip & cut 129' drilling line. 00:30 01:00 0.50 9,513 9,513 AF DRLPR RIG SERV Service TID, dwks, blocks. 01:00 01:30 0.50 9,513 9,513 TA DRLPR EQUIP RSEQ SOTH Replace Epoch pump pressure sensor damaged while testing BOP. 01:30 04:30 3.00 9,513 9,513 AF DRLPR TRIP BIT TIH to std #85. Tight hole @ 8823'. 04:30 05:30 1.00 9,513 9,513 AF DRLPR TRIP WSHR W/R fl 8823' to 9109' MD. B/U gas 1464 units. 05:30 06:00 0.50 9,513 9,513 AF DRLPR CIRC CLN CBU. Circulate gas out of hole. COMMENTS Chuck Scheve, AOGCC waived witness of BOP test, 07:35 hrs, 3/6/2004. Received 3 - 4-1/2" Hydril-521 P/U nubbins. DENSITY(ppg) 9.35 FV I PVNP \ GELS 71 16/25 9112 PP WUHTHP I 4.01 I ECDI1O·53MUD DATAl DAILY COST I FCrr.SOL \ O/w \ %Sand/MBT \ Ph/pM I Pf/Mf I 1.016.5 I 0.25/8.0 9.30/0.5 0.512.91 CI/Ca 26,500/60 CUM COST I CaCI2(wt%1 H2S LIME I ES \ 6RPM BI'FS BIT/RUN SIZE MANUF. TYPE SERIAL NO. JETS OR TFA DEPTH IN DATE IN I-O-D-L-B-G-O-R 3/4 7.000 Hughes DOSRWD 7103745 13/13/13/13/13/131111 4,959.0 2/28/2004 6-8-BT -A-D- 1-RO-PR 4/5 7.000 Hughes DOSRWD 7103744 11/11/11/11/11/11/111 9,513.0 3/6/2004 4-6-BT-G-D- 1-JD-TD BIT/RUN WOB () RPM FloRt() PRESS() PBIT() HRS 24Hr DIST() 24Hr ROP() ¡CUM HRS CUM DEPTH() CUM ROP() Printed: 4/8/2004 10:01:10 WELL NAME PAXTON 1 BIT/RUN WOB () BHA NO. LEN.(ft) 6 809.5 BHA DESCRIPTION . . MARATHON OIL COMPANY Page 2 of 2 rt RPM IKB 17.0 FloRt() I PRESS() IDFS IDOL IRPT# I DATE 20 24 26 07-Mar-2004 CUM HRS CUM DEPTH() I CUM ROP() GL 124 HR PROGTMD TVD 144.00 9,513 7,721 P BIT() HRS 24Hr DIST() I 24Hr ROP() BHA EFF WTO \ P/UO I S/OO I ROT WTO I TORQUE(~axlmin) 0 I BHA hrs I JAR hrs I MWD hrs I MTR hrs I S8 hrs 4-3/4" HCM 404 PDC Pilot Bit, 7" OOSRWD Bi-CenterTool, 4-718" M1XL w/1.6AKO, SDC, 6" NMWBS, 5" MWD NMOP, HOS , Crossover, 3-1/2", 25 ppf HWDP (4), 4-3/4" DAILEY HYDRAULlC-MECH JARS, 3-1/2", 25 ppf HWDP (19), Crossover PUMPIHYDRAULICfOATA . . ;." STROKE (In) L.ltJER(llif" SPM .;:Q (gpm) PRE~S. (psi) TO.TALQ. 9.000 5.000 120 264.38 2,560 264.38 9.000 264.38 KILL SPM .I;PRESSURE 41 775 40 750 1 2 GARDNER-DENVER GARDNER-DENVER AVG. CONN: MAX. CONN: units 151 800 Nabors Alaska Drilling 20 264.00 M-I Drilling Fluids 1 24.00 Marathon 1 24.00 R&K Industrial 2 18.00 Baker Hughes Inteq 2 48.00 Oilfield Hot Shot Service 1 1.00 Epoch Well Services 4 48.00 16.87 16.42 CÀSING ~VMMARY·; LAST CASING TEST: 2/28/2004 MAX SICP MD (ft) "JVD (ft) (psi) @ (ppg) 100 100 670 (psi) @ 9.20 (ppg) 1,895 1,682 1,271 (psi) @ 9.30 (ppg) 4,950 3,417 6,870 7,240 LAST BOP rEST: 3/6/2004 SIZE (in) 10 (in) SHOÈTEST (ppg); 20.000 18.730 9.625 8.681 7.000 6.276 NEXT BOP TEST: 'NT (Ib/ft) GRADE 133.00 X-56 47.00 L-80 26.00 L-80 3/13/2004 BURST (psi) . CONHDEN1\ f\l Printed: 4/8/2004 10:01 :10 WELL NAME PAXTON 1 SUPERVISOR Gene Anderson F!ELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS @ 6AM Circulate for WT. OPERATION COMMENTS CBU. WIR f/9109' to 9513' MD. . . Page 1 of2 IGL 17.0 144.00 RIG NAME & NO. 124 HR PROG TMD TVD I DFS IDOL 1 RPT # I DATE 602.0 10,115 8,320 21 25 27 08-Mar-2004 AUTH MD WBS SAPIWBS COST 9,793 dx0309781capdrl MOC W1 NRI I. DAILY WELL COST 60.0000 60.0000 1 LAST CASING 1 NEXT CASING I LEAKOFF 7.000 (in) @ 4,950 (ft) 4.500 (in) @ 10,115 (ft) 16.42 124 HR FORECAST WT. CBU. Trip to log. Run OH logs. TIH. CBU for liner. KB NABORS DRILLING 129 RIG PHONE CUM 'IJELL COST 9072831315 COUNTY/OTHER Drill f/9513' to 9993' MD. Circulate. Drill f/9993' to 10,115' MD to final TD. CBU. LAST SAFETY MTG 3/7/2004 :SARETY SUMMARY IBOP PSI TEST I LAST STOP CARD AUDIT 3/6/2004 3/7/2004 ope~mIONSSUMMÄRY' . ..,... !PHASE OF''' ŠÛBOP ,TRB,L . ·DE~¿~;~ì1QN . DRLPR CIRC CLN CBU. Circulate gas out of hole. DRLPR TRIP WSHR W/R to btm. W/R f/9109' to 9513' MD. DRLPR DRILL DOHD Directional drill & survey f/9513' to 9757' MD planned TO. ART 5.47 hrs. Directional drill & survey fl 9757' to 9993' MD to new TO. ART 5.27 hrs. Circulate, discuss mud log wI geologist. Decision to drill ahead to 10,115' MD. Directional drill & survey f/9993' to 10,115' MD final TD. ART 3.59 hrs. 05:00 06:00 1.00 10,115 10,115 AF DRLPR TRIP CIRT CBUx2forWT. ·Q~NSITY(ppg) I 9.45 I PP I I.ECD10.54IMUbDATA! DAlLY¢Q~TI '. :~1¡1!~~~: . rl~ft~: I W~~¡P I F~~~~~kl or; 'I ~~~:TI9:~~:610~:;~~ I 27 ~~~~o MANHRS WORKED I ACCIDENT TYPE 426.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Eye protection ':. )!'.,:;:),}'J'i' ;':,,(,'<:;~\,,-'.:<' FR:ðr.." 9,513 9,513 9,513 S"ÈP'F~Ç~ . 06:00 06:30 08:30 TO " 06:30 08:30 15:30 'HRS 0.50 2.00 7.00 ,'- "., ,"- ,'--_:<:>~~i>~; SUB 9,513 AF 9,513 AF 9,757 AF 15:30 22:00 6.50 9,757 9,993 CS DRLPR DRILL DOHD 22:00 00:00 2.00 9,993 9,993 CS DRLPR CIRC HOLE 00:00 05:00 5.00 9,993 10,115 CS DRLPR DRILL DOHD I CUM COST IC¡¡CI2(wt%1 H25 L.··.IM.E. ...,. ES ß"'PM 1'1',),. . BIT/RUNI WOB (kip) I 4/5 12 RPM 1105 GPM I PRESS(psi) I P BIT(psi) 265 2,900 197 HRS I 24Hr DIST(ft) 124Hr ROP(ftIhr) ICUM HRSI CUM DEPTH(ft) ICUM ROP(ftIhr) 14.33 602.0 42.01 14.33 602.0 42.01 BHA I EFF WT(lb) P/U(lb) I S/O(lb) I ROT WT(lb) TORQUE(inaxlmin) (ft-Ibf) I BHA hrs I JAR hrs I MWDhrs I MTR hrsl S8 hrs 30,000 170,000 119.000 119,000 16,500/12,500 4-3/4" HCM 404 PDC Pilot Bit, 7" DOSRWD Bi-Center Tool, 4-7/8" M1XL w/1.6AKO, SDC, 6" NMWBS, 5" MWD NMDP , HOS , Crossover, 3-1/2", 25 ppf HWDP (4), 4-3/4" DAILEY HYDRAULlC-MECH JARS, 3-1/2", 25 ppf HWDP (19), Crossover BHA NO. LEN.(ft) 6 809.5 BHA DESCRIPTION NO. 1 2 MAKE OF PUMP GARDNER-DENVER GARDNER-DENVER PUMP 1 HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) 9.000 9.000 5.000 120 264.38 PRESS. (psi) TOTAL Q 264.38 2,900 264.38 KILL SPM / PRESSURE 41 775 40 750 Printed: 4/8/2004 10:01 :12 WELL NAME PAXTON 1 AVG. CONN: MAX. CONN: . . IKB 17.0 IGL 144.00 124 HR PROGTMD ITVD DFS 602.0 10,115 8,320 21 RPT# I DATE 27 08-Mar-2004 MUD GAS AVG. TRIP: MAX. TRIP: MID 9,517.0 9,613.0 9,709.0 9,804.0 . SURVEY DATA TVID VS NtS CUM EIW CUM IDOGlEG MID INCL 7,724.923,853.363,262.33 -2,121.75 1.07 9,900.0 5.70 7,820.54 3,850.86 3,263.51 -2,113.30 0.18 9,995.0 5.90 7,916.16 3,847.92 3,264.22 -2,104.80 0.41 10,045.0 5.50 8,010.75 3,844.83 3,264.93 -2,095.98 0.64 10,115.0 5.50 5.10 5.10 5.10 5.60 Nabors Alaska Drilling Marathon Baker Hughes Inteq 20 264.00 Epoch Well Services 1 24.00 M-I Drilling Fluids 2 48.00 R&K Industrial LAST BOP TEST: 31612004 SIZE (in)' . ID (in»), SH()È1;!::ST (pþg) ~(v 20.000 18.730 9.625 8.681 7.000 6.276 Page 2 of 2 IDOL 25 UNITS units 58 981 1,538 AVG. BKGRD: MAX. DRl: . AZIMUTH 89.80 91.00 105.00 105.00 TVÖ VS NtS CUM EIW CUM DOGLEG 8,106.293,841.343,265.47 -2,086.55 0.64 8,200.80 3,837.22 3,265.40 -2,076.95 0.25 8,250.55 3,834.55 3,264.74 -2,072.07 2.89 8,320.23 3,830.24 3,263.00 -2,065.59 0.00 4 1 2 48.00 24.00 18.00 LAST CASING TEST: 2/28/2004 MAX SICf'. (psi) @ (ppg) 670 (psi) @ 9.20 (ppg) 1,244 (psi) @ 9.45 (ppg) NEXT BOP TEST: 3/13/2004 16.87 16.42 100 1,895 4,950 100 1,682 3,417 133.00 X-56 47.00 L-80 26.00 L-80 6,870 7,240 Printed: 4/8/2004 10:01:12 . . KB TVD IDFS IDOL IRPT# ¡DATE 22 26 28 09-Mar-2004 ..,..,........_-~_....... WELL NAME PAXTON 1 SUPERVISOR Gene Anderson F!ELD NAME IGL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS @ 6AM Drifting HWDP prior to M/U shuttle assembly for logs. OPERATION COMMENTS CBU. WT. CBU. POOH to log. RlU loggers. Could not get below 7920' wI W/L, log f/7920' to csg shoe. RID loggers. TIH wI biUHWDP. Drop drift, POOH. 124 HR PROG TMD 10,115 8,320 AUTH MD WBS 9,793 MOC WI NRI 9072831315 60.0000 60.0000 COUNTY/OTHER I LAST CASING I NEXT CASING 7.000 (in> @ 4,950 (ft) 4.500 (in) @ 10,115 (ft) 124 HR FORECAST Run OH logs. Run/cmt4-1/2" liner. RIG PHONE dx0309781capdrl CAlLY \'VELL COST CUM WELL COST I LEAKOFF 16.42 MANHRS WORKED 'I ACCIDENT TYPE 460.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Pinch points while tripping, RA sources " ,SAFEîY St,nnMARY BOP PSI TEST LAST STOP CARD AUDIT I RNEGULATORY INSP? 3/6/2004 3/8/2004 I LAST RIG INSPECTION 2/25/2004 06:00 07:00 1.00 10,115 10,115 AF DRLPR TRIP CIRT CBU x 2 for WT. 07:00 08:00 1.00 10,115 10,115 AF DRLPR TRIP WTRP Wipe hole 15 stds to 8730'. Pull 20K over @ 9043'/8965'/8829' . 08:00 08:30 0.50 10,115 10,115 AF DRLPR RIG SERV Service T/D. 08:30 09:30 1.00 10,115 10,115 AF DRLPR TRIP WTRP TIH. Wash last std to btm for safety, no fill. 09:30 11:00 1.50 10,115 10,115 AF DRLPR TRIP CIRT Circulate shakers clean. Mix & pump dry job. Drop 2" drift. 11:00 18:30 7.50 10,115 10,115 AF DRLPR TRIP LOGS POOH to run open hole logs. SLM. No corr. Found drift @ top of HWDP. 18:30 19:30 1.00 10,115 10,115 AF DRLPR TRIP BBHD Retrieve MWD sensor. LD MWD, motor, bit. Clean floor. 19:30 02:00 6.50 10,115 10,115 AF EV ALPR LOG OPEN RlU loggers. RIH wI Quad Combo suite of logs. Could not get below 7920'. Run Quad Combo log fl 7920' to csg shoe at 4950'. RID loggers. 02:00 02:30 0.50 10,115 10,115 AF EVALPR TRIP BIT M/U bit & TIH on HWDP. 02:30 03:00 0.50 10,115 10,115 AF EVALPR CIRC CLN Break circulation, blow down T/D. 03:00 06:00 3.00 10,115 10,115 AF EVALPR TRIP BIT Drop 1.99" drift. POOH, UD & replace 2 jts HWDP. UDbit, bit sub. , OENSITy(IiP9) FV I PVNP I 62 16/28 9.40 GELS 10/15 PP WL/JiTHP\ 4.81 IECD FCIT.SOL 1.0/7.0 IMUD DATAl DAIL'fCOST OIWI o/oSand/MBTI Ph/pM 'I Pf/Mf \ ' I 0.25/9.0 9.40/0.7 0.6/3.2 C.IICa 27,500/60 CUM èdsT I CaC12(wt%1 H2S , LIME \ ES \6RPM BIT/RUN I SIZE 4/5 7.000 BIT/RUN WOB 0 MANUI'. Hughes TYPE DOSRWD I SERIAL N°'1 7103744 ,BITS JETS OR T~A 11/11/11/11/11/11/111 HRS I 24Hr DISTO DEPTH IN DATE IN I-O·D-L~B.G·O~R 9,513.0 3/6/2004 4-6-BT-G-D- 1-JD-TD 24Hr ROPO ICUM HRS CUM DEPTHO I CUM ROPO RPM FloRtO PRESSO P BITO BHA N0'1 LEN.(ft) 6 809.5 BHA DESCRIPTION BHA I EFF W1() I P/u() I S/O() ¡ ROT WTO I TORQUE(~ax/min) 0 I BHA hrs \ JAR hrsl MWD hrs I MTR hrs I $8 hrs 4-3/4" HCM 404 PDC Pilot Bit, 7" DOSRWD Bi-Center Tool, 4-7/8" M1XL w/1.6AKO , SDC , 6" NMWBS ,5" MWD NMDP , HOS , Crossover, 3-1/2", 25 ppf HWDP (4), 4-3/4" DAILEY HYDRAULlC-MECH JARS, 3-1/2", 25 ppf HWDP (19), Crossover Printed: 4/8/2004 10:01 :14 24HRPROGTMD TVD IDFS IDOL IRPT# I DATE 10,115 8,320 22 26 28 09-Mar-2004 . WEll NAME PAXTON 1 IKB 17.0 Daily Drilli E~ploita IGl 144.00 NO. 1 2 PUMP 1 HYDRAULIC DATA STROKE (in) LINER !in) Sf>M Q (gpm) . 9.000 5.000 120 264.38 9.000 MAKE OF PUMP GARDNER-DENVER GARDNER-DENVER AVG. CONN: MAX. CONN: MUD GAS AVG. TRIP: MAX. TRIP: 420 PERSÒNNELDATA . Nq. HÒÙ.RS \' . éOMPANY 20 264.00 Alaska Oil Sales 1 24.00. S&R Enterprises 2 48.00 Alaska's Best Water 2 24.00 Lynden Transport 1 24.00 Epoch Well Services 1 5.00 Reeves Wireline 1 3.00 Wildflowers and Resin COI\I!~ANY Nabors Alaska Drilling Marathon Baker Hughes Inteq Epoch Well Services M-I Drilling Fluids R&K Industrial Oilfield Hot Shot Service LAST BOP TEST: 3/6/2004 . . . SIZE (i~J' IO!tih)SHPE TEST~(ppg) 20.000 18.730 9.625 8.681 7.000 6.276 LAST CASING TEST: 2/28/2004 .,. .. MAXSICP ..... (psi) @ (ppg) 670 (psi) @ 9.20 (ppg) 1,244 (psi) @ 9.45 (ppg) 100 1,895 4,950 100 1,682 3.417 16.87 16.42 . Page 2 of 2 PRESS. (psi) TOTAL Q 2,850 264.38 264.38 KILL SPM ! PRESSURE AVG. BKGRD: MAX. DRL: 41 775 40 750 UNITS' I units 38 219 POB @ 06:00:.' NO. HOJRS 1 1.00 2 2.00 1 1.00 1 1.00 1 12.00 4 48.00 1 3.00 SERVICE Logging Consultant NEXT BOP TEST: . WT Ob/fb' . 133.00 X-56 47.00 L-80 26.00 L-80 3/13/2004 BI;JRsT (p$i) 6,870 7,240 Printed: 4/8/2004 10:01:14 . . IGL 124 HR PROG TMD TVD IDFS 17.0 144.00 10,115 8,320 23 RIG NAME & NO. AUTH MD WBS NABORS DRILLING 129 9,793 dx0309781capdrl RIG PHONE 907283 1315 M~;.;~OO N=~.OOOO I DA!lVW<;'! ""<"T I ~~.,--;-". COUNTY/OTHER 1 lAST CASING 1 NEXT CASING --'I~~K~F;-' 7.000 (in) @ 4,950 (ft) 4.500 (in) @ 10,115 (ft) 16.42 124 HR FORECAST Run/cmt liner. POOH LDDP. WELL NAME PAXTON 1 SUPERVISOR Gene Anderson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATE/PROV Alaska CURRENT STATUS@ 6AM Rig released to completion @ 06:00 hrs, 3/10/2004. OPERATION COMMENTS M/U shuttle BHA. P/U logging tools. TIH on DP. Pump out logging tools. tools. Release rig to completon @ 06:00 hrs, 3/10/2004. KB Page 1 of 2 IDOL RPT# ¡DATE 27 29 ~~~~~~~~~~ POOH to shoe running open hole logs. POOH. LID HWDP & logging SAF"EGrY SUMMÄR¥ [BOP PSI TEST LAST STOP CARD AUDIT [ RNEGULATORY INSP? 3/6/2004 3/8/2004 I LAST RIG INSPECTION 2/25/2004 \--':,!:',,- :;;~OR; WORKED I~~~:ENT TYPE I ~~~:ETY MTG ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: RA sources, Valve drill, Drift concems. :stEI:'FROM TO' HRS - FR.()M _ ~UB .PHÄSÈ' SU~Ó~ ~BL 06:00 09:00 3.00 10,115 10,115 AF EVALPR LOG OTHR 09:00 09:30 0.50 10,115 10,115 AF EVALPR LOG OTHR 09:30 11:30 2.00 10,115 10,115 AF EVALPR LOG OTHR 11:30 12:00 0.50 10,115 10,115 AF EV ALPR RIG SERV 12:00 15:30 3.50 10,115 10,115 AF EV ALPR LOG OTHR 15:30 18:00 2.50 10,115 10,115 AF EV ALPR CIRC CLN 18:00 19:30 1.50 10,115 10,115 AF EVALPR LOG OTHR 19:30 00:00 4.50 10,115 10,115 AF EVALPR LOG OTHR 00:00 02:00 2.00 10,115 10,115 AF EVALPR TRIP LOGS 02:00 04:00 2.00 10,115 10,115 AF EVALPR TRIP LDDP 04:00 06:00 2.00 10,115 10,115 AF EV ALPR TRIP LDDP DENSITY(ppg) 1 FV I PVIYP 78 17/28 9.65 GELS 9/15 1 PP 1 WUHTHP 4.21 1 ECD 110.591 MUD DATA I DAILY COST I FCIT.SOL I OIW %Sand/MBT Ph/pM I Pf/Mfl 1.0/8.0 I 025/10.0 9.30/0.5 0.4/2.9 I CUM COST 27 ~~~:o I CaCI2(wt°1 H2S LIME I ES 6RPM Rack & strap 6 jts 3-1/2" DP & shuttle tools. M/U shuttle BHA. PJSM. PIU Reeves Quad Combo shuttle logging tools. TIH on 3-1/2" HWDP. Pump through tools ok. TIH on 3-1/2" DP to csg shoe. Fill pipe @ 20 stds, fill pipe & brk circulation @ shoe. Service TID & dwks. FTIH. Put DP on depth. Btm of DP @ 10,109' MD. CBU x 1.5 till shakers clean. TG 1511 units. 9.7 ppg inl 9.5 ppg out. SID pump to simulate connection. CBU. 9.65 ppg in/out. Mix dry job. Std back 1 std, P/U 10'. Pump down messenger @ 2 bpm, deploy logging tools below 3-1/2" DP shuttle. Logging tool length - 100'. Pump dry job. POOH 3 minlstd logging Quad Combo fl 10,100' to csg shoe @ 4950'. POOH wI shuttle to top of HWDP. POOH LID 3-1/2" HWDP. LID jars fl derrick. PJSM. LID 3-1/2" DP carrier. Retrieve & LID Reeves logging tools. Finish LID carrier. Evaluate open hole logs. Release rig to completion @ 06:00 hrs, 3/10/2004. BHA NO. LEN.(ft) 7 852.4 BHA DESCRIPTION BHA I EFF WTO I P/uO [ S/OO I ROT WTO [ TORQUE(~axlmin) () \ BHA hrs [ JAR hrs I MWD hrs I MTR hrs I SS hrs 6" Reamer Shoe, Landing/Circulation Sub, 4 Jts 3-1/2", 13.3 ppf DP (4), Lower Latch Sub, Upper Latch Sub, 1 Jt 3-1/2", 13.3 ppf DP , Float Sub, 1 Jt 3-1/2", 13.3 ppf DP , Float Sub, 3-1/2" Heavy Weight Drill Pipe (21), Cross Over Printed: 4/8/2004 10:01 :16 . . Page 2 of 2 WELL NAME PAXTON 1 IKB 17.0 GL 144.00 124HRPROGITMD ITVD IDFS IDOL IRPT# I DATE 10,115 8,320 23 27 29 10-Mar-2004 NO. 1 2 MAKE OF PUMP GARDNER-DENVER GARDNER-DENVER PUMP 1 HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) 9.000 5.000 120 264.38 9.000 5.000 96 211.51 PRESS. (psi) TOTAL Q 2,950 475.89 2,150 475.89 KILL SPM I PRESSURE MUD GAS AVG. TRIP: MAX. TRIP: UNITS . . ·.CQMP~Y . Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids R&K Industrial SERVICE . PERSONNEL DÀTA HOURS' .. . COMP,Atty . 264.00 Epoch Well Services 24.00 Reeves Wireline 24.00 BJ Services 24.00 Lynden Transport 5.00 units 150 250 . POB @ O~:OO: ;:. HOÚRS . 1 24.00 4 96.00 2 3.00 2 3.00 AVG. CONN: MAX. CONN: 1,511 AVG. BKGRD: MAX. DRL: Logging Consultant CASING SUMMARY' LAST CASING TEST: 2/28/2004 MAX SICP MD (ft) . WQ:(ft) (psi) @ (ppg) 100 100 670 (psi) @ 9.20 (ppg) 1,895 1,682 1,208 (psi) @ 9.65 (ppg) 4,950 3,417 LAST BOP TEST: 3/6/2004 _<,: r: :'-.-.' "':"':-':::':->""'-'.,-:." ':_~--\'_: . SIZE (in) 10 (irt)f SHOE TESt (ppg) . 20.000 18.730 9.625 8.681 7.000 6.276 16.87 16.42 NEXT BOP TEST: WT (lblft) 133.00 X-56 47.00 L-80 26.00 L-80 3/13/2004 BURST (psÎ): 6,870 7,240 Printed: 4/8/2004 10:01 :16 . . WELL NAME PAXTON 1 SUPERVISOR Rowland Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS @ 6AM Circ.4 1/2" liner. OPERATION COMMENTS Run 4 1/2" liner. IGL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 RIG PHONE KB 9072831315 COUNTY/OTHER Pagê 1 of 1 TVD IDFSo IDOL RPTtI ¡DATE w~320 28 30 11~1IA.~'::"~~~~ DX0309781CAPCMP MOC WI NRI I nA,' V WI', I. COST 60.0000 60.0000 I I LAST CASING I NEXT CASING 4.500 (in) @ 10,070 (ft) (in) @ 0 (ft) 124 HR FORECAST Cement liner. POOH w/DP. Clean to top of liner. 124 HR PROG TMD 10,115 AUTH MD I . ,- - -. CUM \'YELL COST I LEAKOFF I ACCIDENT TYPE 492.00 ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: Running liners. S~~i¡¡mSWMM~R¥ IBOP PSI TEST I LAST STOP CARD AUDIT I REGULATORY INSP? I LAST RIG INSPECTION 3/6/2004 N CONFIDtN~ iAl FROM . to . .. HRS '¡F~9~ TO SUB PHASE 06:00 08:00 2.00 10,115 10,115 AF CSGPRO EQUIP RURD 08:00 09:00 1.00 10,115 10,115 AF CSGPRO CSG RUN 09:00 17:30 8.50 10,115 10,115 AF CSGPRO CSG RUN 17:30 18:30 1.00 10,115 10,115 AF CSGPRO CSG RUN 18:30 22:30 4.00 10,115 10,115 AF CSGPRO TRIP PUDP 22:30 00:00 1.50 10,115 10,115 AF CSGPRO CSG RUN 00:00 03:00 3.00 10,115 10,115 AF CSGPRO CSG RUN 03:00 05:30 2.50 10,115 10,115 AF CSGPRO CSG RUN RIU Weatherford CSG tools. P/U and Bakertok 41/2" 12.6ppf L-80 Hydril 521 shoe tract. Run 4 1/2" 12.6ppf L-80 Hydril 521 liner (total 134joints) CIO joint #50 w/joint#159. Joint#50 was bent. M/U Baker 4.5" rotatable liner hanger ZXP liner top packer assy. P/U and rabbit 3-4 3/4" DC and RIH. Get string parameters(S/O 50K, PIU 58K, ROT 54K TQ 3-4K 2.2BPM @ 500psi). Cont. P/U total 28-4 3/4" DC. M/U Baker plug dropping assy and UD. Cont. RIH with liner on 3 1/2" DP. Circ. last stand of DP down. Tag @ 10,101'. Attempt to circ. to bottom (1 0, 115). Could not circ. down. Attempt to rotate wI max torque 12,000ft-lb. Could not rotate. Stuck liner @ 10,098'. Worked liner free. Circ. liner and condition mud for cement(2.2BPM@950psi start 4BPM 11 OOpsi end). 05:30 06:00 0.50 10,115 10,115 AF CSGPRO CEMT PRIM M/U Baker plug dropping assyto DP. DENSITY(pp~) I 9.50 IFÌp I IEce 110.831MUD oAt~1 Dþ,ILycbsT I I CUMCQST : I ~~~: I :~~s IW~~:HFÌr F~~:~L I~: I :;~~:~TI9~~~0~510::~1 27~1~~;60 IC~CI2(wt%1 H2S LfMEES 16~~M SERVICE POB @.Ö6:00: NO. HOURS 1 24.00 3 36.00 4 48.00 4 32.00 COMPANY Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids Reeves Wireline PERSONNEL DATA NO. HOURS COMPÞ.NY 20 264.00 Baker Oil Tools 1 24.00 Weatherford 2 24.00 BJ Services 1 24.00 R&K Industrial 4 16.00 SERVICE LAST BOP TEST: 3/6/2004 SIZE (in) lID (in) ISHOE TEST (ppg~ 4.500 3.958 I CASING SUMMARY LAST CASING TEST: MAX SICP I MD (ft) I (psi) @ 9.65 (ppg) 10,070 3/13/2004 I BURST (psi) 8,440 TVD (ft) 8,286 NEXT BOP TEST: WT (Iblft) I GRADE 12.60 L-80 Printed: 4/8/2004 10:02:57 · . MARATHON OIL COMRANY Page 1 of 2 Daily Ex WELL NAME PAXTON 1 SUPERVISOR Rowland Lawson FIELD NAME GL 17.0 144.00 RIG NAME & NO. KB NABORS DRILLING 129 RIG PHONE 124 HR PROG TMD 10,115 AUTH MD IDFSO IDOL IRPT# DATE 29 31 12-Mar-2004 TVD 8,320 WBS "4Þ/wI'-C: I':O!'¡T DX0309781 CAPCMP I r'Af· v~.....t· -~-... I MOC WI NRI 9072831315 60.0000 60.0000 .. COUNTY/OTHER 1 LAST CASING I NEXT CASING 4.500 (in) @ 10,070 (ft) (in) @ 0 (ft) 124 HR FORECAST UD DP and tools. Run TBG. Test tree. WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS@ 6AM POOH UD DP. OPERATION COMMENTS Cement 4 1/2" liner. Set ZXP liner top packer. liner to 6%KCL brine. POOH. ro "'" 'Uf"' .....~~.... "I LEAKOFF Circ. out. POOH UD DP and DC. RIH and dress liner top. Test liner to 1500psi. Displace above I ACCIDENT TYPE 388.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: High pressure testing. '. ··S'À.FETYSt:Jí)j(¡¡ARY BOP PSI TEST LAST STOP CARD AUDIT I RNEGULATORY INSP? 3/6/2004 LAST RIG INSPECTION 06:00 06:30 06:30 07:00 0.50 10,115 10,115 AF CSGPRO CEMT PRIM 0.50 10,115 10,115 AF CSGPRO CEMT PRIM 07:00 08:00 1.00 10,115 10,115 AF CSGPRO CEMT PRIM 08:00 09:30 1.50 10,115 10,115 AF CSGPRO CEMT PRIM 09:30 10:30 1.00 10,115 10,115 AF CSGPRO CEMT PRIM 10:30 11:30 1.00 10,115 10,115 AF CSGPRO CEMT PRIM 11:30 12:00 0.50 10,115 10,115 AF CSGPRO~KRPLG SET 12:00 13:00 1.00 10,115 10,115 AF CSGPRO CIRC CLN 13:00 14:00 1.00 10,115 10,115 AF CSGPRO EQUIP RURD 14:00 15:30 1.50 10,115 10,115 AF CSGPRO TRIP BHA 15:30 16:00 0.50 10,115 10,115 AF CSGPRO RIG SERV 16:00 19:00 3.00 10,115 10,115 AF CSGPRO TRIP BHA 19:00 21:30 2.50 10,115 10,115 AF CSGPRO TRIP BBHD Cont to MIU Baker plug dropping assy. Drop setting ball. Circ. 2BPM 850psi. Set hanger w/1800psi. Verify hanger has set. Release from hanger w/3000psi. Verify release. Stack 15K on liner and blow ball seat out w/4000psi. Liner shoe @ 10,071', LC@ 9946', and TOL@ 4703' CBU(B/U gas 1450units). 2.0BPM 850psi and increase to 5BPM 1970psi. PJSM prior to cementing operation(reduce Yp to below 20). Rotate liner w/12K ft-Ib. Rotate and CBU. 12RPM 8-11K ft-Ib. 5BPM 2000psi. PJSM prior to cementing liner. Pump 5bbls water ahead. Test cement lines to 3500psi. Bleed off pressure. Pump 40bbls 10.5ppg MCS-4D spacer. Mix and pump 690sx Class"G" cementw/2%KCL, 22%LW-6, 5%MPA-1, .6%CD-32, .25%R-3, .9%BA-10, .15%SMS and 19phs FP-6L to yield 219bbls 12.8ppg slurry. Avg rate 5BPM. Could not rotate liner after 20bbls of spacer came around shoe(torque greater tan 12K ft-Ib). Wash out cement lines to slop tank. Drop DP dart. Displace w/80bbls 6% KCL w/2ppb flovis(observed liner wiper plug shear out@30bbls) finish displacement w/31 bbls 9.5ppg mud. Bumped plug w/5000psi 1500psi over displacement pressure. Avg rate 4BPM. Bleed off pressure and check floats held. CIP@11 :30hrs. Lost 20bbls mud during cement job. Pressure up to 400psi. P/U and engage pumps when pressure bled down. Circ. and set ZXP liner top packer with rotating dog sub. CBUX2. 25bbls spacer to surface. Break down plug dropping assy. POOH UD 3112" DP. Service rig. Cont. POOH UD 31/2" DP (total 123jnts). Rack back 6-4 3/4" collars. UD 22-4 3/4" collars. Printed: 4/8/2004 10:02:59 . . Page 2 of 2 WEll NAME PAXTON 1 IKB 17.0 IGl 144.00 124 HR PROGITMD 10,115 ITVD IDFS 8,320 0 IDOL 29 RPT# I DATE 31 12-Mar-2004 FROM TO 21 :30 22:00 22:00 01 :00 HRS FROM TO SUB PHASE 0.50 10,115 10,115 AF CSGPRO 3.00 10,115 10,115 AF CSGPRO DESCRIPTION Inspect and UD liner hanger running tool. PIU 4.85" pollish mill and 6" dress mill. RIH(SLM) tag TOL @ 4703'. Polish seal bore and dress TOL wldress mills. CBU. Test liner to 1500psi/30min. Mix 6% KCL brine. Displace to 6%KCL brine. Flow check well. Tes1 liner to 1500psi/10min. 0.50 10,115 10,115 AF CSGPRO MUD CHNG Clean shakers. Pump dry job(heavy brine). 1.50 10,115 10,115 AF CSGPRO TRIP LDDP POOH UD DP. 8.60 I pþ Ie:CD :MUD DÄ:'rÄ:tDAILYCOSTI ~~~$I w~~p I Fc~.SQL\1 °r;I¡~'n~MB1:¡':~;~~ I Pf~f [:;~~~I OPERATIONS SUMMARY OP SUBOP TRBL TRIP BHA TRIP BHA 01 :00 02:00 02:00 02:30 02:30 04:00 1.00 10,115 10,115 AF CSGPRO DRILL CEMT 0.50 10,115 10,115 AF CSGPRO TEST CSG 1.50 10,115 10,115 AF CSGPRO MUD CHNG 04:00 04:30 04:30 06:00 QENSJ:N(Þ~» I I""' '"'I' FV pvìYÞ 26 1/1 I ' cu~cos:t '1 cac'2(Wt'%1[¡:2~ : LIME lÊ$c1; I; 6RPM o 70,000 62,000 62,000 8,000 I 4.85" Fluted Mill ,23/8" Spear Ext , XIO 2 7/8" Reg-B x 2 3/S"Reg-p , XIO 3 1/21F-B x 2 7/8"Reg-P , 6" Liner top dress mill ,43/4" 47PPF DC (6), 3 1/2" 15.50PPF S-135 HT-38 DP Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids 17 204.00 Baker Oil Tools 1 24.00 BJ Services 2 24.00 R&K Industrial 1 24.00 Alaska Petroleum Contra 1 4 4 3 24.00 32.00 32.00 24.00 LAST BOP TEST: 3/6/2004 CASING SUMMARY LAST CASING TEST: 3/12/2004 NEXT BOP TEST: 3/13/2004 4.500 (psi) @ 9.65 (ppg) 12.60 8,440 Printed: 4/8/2004 10:02:59 WELL NAME PAXTON 1 SUPERVISOR Rowland Lawson FIELD NAME WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS @ 6AM Test TBG seals. OPERATION COMMENTS POOH UD DP. Pull wear bushing. . . Page 1 of 2 IDFso IDOL 30 IRPT# DATE 32 13-Mar-2004 GL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 KB 124 HR PROG TMD 10,115 AUTH MD S¡"DAAI~c:. ~f'~T TVD 8,320 WBS DX0309781 CAPCMP ~ rAil v \^It=I! r.O!=;T CUM WELL COST RIG PHONE MOC WI NRI 9072831315 60.0000 60.0000 COUNTY/OTHER I LAST CASING I NEXT CASING 4.500 (in) @ 10,070 (ft) (in) @ 0 (ft) 124 HR FORECAST Test TBG seals. Run BPV. NID BOP. N/U and test Tree. I LEAKOFF Run 4.5" Production TBG. Land TBG on hanger and test seals. SAFETY MTG TOPICS: Running TBG. 5ROM ~~.~';j"'~$e< OR ' st;1åoP ':TR~LE 06:00 12:30 10,115 10,115 AF CSGPRO TRIP BHA Cont. POOH UD 31/2" DP(total128jnts) and 6- 4 3/4"DC. Inspect Polish/Dress mill. 12:30 13:30 1.00 10,115 10,115 AF RCMP TRIP WEAR Pull wear bushing. 13:30 16:00 2.50 10,115 10,115 AF RCMP TRIP PUDP Rack, strap and drift 4 1/2" TBG. 16:00 17:30 1.50 10,115 10,115 AF RCMP EQUIP RURD RIU Weatherford TBG running tools. Organize rig floor. PJSM prior to running TBG. 17:30 20:30 3.00 10,115 10,115 AF RCMP :JLRNRP PTBG P/U Baker 4.5"seal assy. RIH w/4.5" 12.6PPF L-80 Butt-modTBG(52 joints). 20:30 22:00 1.50 10,115 10,115 AF RCMP :JLRNRP PTBG M/U injection mandrel. RIU Pollard wireline to run control line. Connect control line and test line to 1000psi. Bleed to 500psi. PJSM prior to running TBG w/controlline. 22:00 01:30 3.50 10,115 10,115 AF RCMP :JLRNRP PTBG Cont. RIH wI 4.5" TBG(totaI111jnts). 01:30 04:00 2.50 10,115 10,115 AF RCMP :JLRNRP PTBG M/U joint 112 and circ. head. Circ. down. M/U joint 113 and eirc. head. Circ. down and find TOL ZXP @ 4607 TBG tally. UD joint 113 and 112. Mouse hole joint 111. MIU pups 7.8' , 12.10' and 12.14'. M/U joint 111. M/U Vetco 11" X 4 1/2" TBG hanger assy. M/U landing joint. 04:00 04:30 0.50 10.115 10,115 AF RCMP :JLRNRP PTBG Run control line through Vetco TBG hanger. 04:30 05:30 1.00 10,115 10,115 AF RCMP CIRC CLN Spot 6% KCL brine wlcorrosion inhibitor 303A in annulus circulating the long way. Land hanger(top of no go 2' above ZXP@4705'(TBG tally). Injection mandrel top @ 2517'. 05:30 06:00 0.50 10,115 10,115 AF RCMP TEST CSG Set lockdowns on TBG hanger. Test TBG seals to 750psi/10min. MANHRS WORKED I ACCIDENT TYPE 316.00 None ACCIDENT DESCRIPTION: DENSITY(ppg) FV PVNP 26 1/1 I PP I WU;THP 8.60 GEl.S 1/1 LAST SAFETY MTG 3/13/2004 SAFETYSÜMMARY' BOP PSI TEST I LAST STOP CARD AUDIT I REGULATORY INSP? 3/6/2004 N LAST RIG INSPECTION Note: Pressure on 9 5/8" X 7" annulus bled to zero and build up to 150psi in 18hrs. IECDI Fcrr.SOL I IMUD DATAl DAILY COST I OIW o/oSand/MBT Ph/pM Pf/Mf I 1 8.501 I CUM COST ¡CaCI2(wt%j H2S LIME ES SRPM CIICa 30.5001 BHA N0'1 LEN.(ft) 8 206.4 BHA DESCRIPTION BHA I EFF WT(} I P/U(} I S/O(} I ROT WTO I TORQUE(~aX/min) () I BHA hrs I JAR hrs I MWD hrs I MTR hrs I SS hrs 4.85" Fluted Mill, 2 3/8" Spear Ext . XIO 2 7/8" Reg-B x 2 3/8"Reg-p . XIO 3 1/21F-B x 2 7/8"Reg-P . 6" Liner top dress mill . 4 3/4" 47PPF DC (6), 3 1/2" 15.50PPF S-135 HT-38 DP Printed: 4/8/2004 10:03:01 WELL NAME PAXTON 1 Nabors Alaska Drilling Marathon Epoch Well Services . KB 17 204.00 M-I Drilling Fluids 1 24.00 Baker Oil Tools 2 24.00 R&K Industrial LAST BOP TEST: 3/6/2004 LAST CASING TEST: 3/12/2004 . 8,320 1 1 2 24.00 24.00 16.00 NEXT BOP TEST: 3/13/2004 8,440 Printed: 41812004 10:03:01 TVD I DFSO I DOL I RPT # I DATE WB~320 31 33 ~~~~::;~~; DX0309781 CAPCMP MOC WI NRI II DAILY WELL COST 60.0000 60.0000 10,070 (ft) I NEXT CAsIN(~n) @O (ft) . . MA COMPANY n Repørt . Gas WELL NAME PAXTON 1 SUPERVISOR Rowland Lawson FIELD NAME IGL 17.0 144.00 RIG NAME & NO. NABORS DRILLING 129 KB 124 HR PROG TMD 10,115 AUTH MD R!G PHONE WILDCAT-FOR UNNAMED FIELD STATElPROV Alaska CURRENT STATUS @ 6AM Rig released to Nabors Alaska Drilling OO:OOhrs 03/14/2004. OPERATION COMMENTS NID BOPE. N/U and test tree. Clean pits. Rig released to Nabors drilling Alaska @ OO:OOhrs 3/14/2004. 9072831315 COUNTY/OTHER I LAST CASING 4.500 (in) @ 124 HR FORECAST Rig released. Page 1 of 1 CUM \-'EtL ëÒST - í I LEAKOFF MANHRS WORKED I ACCIDENT TYPE 257.00 None ACCIDENT DESCRIPTION: SAFETY MTG TOPICS: N/D. I LAST SAFETY MTG 3/13/2004 . ..' ,SJ.tiS'e1BSUrJlMJ.tRM I~~=' ~'TIW_Aë¿~fIDEN-rTÃC~N .FR-ÐM Í:'IRS J71i!!>M Jt(¡¡l;'·'SUB 06:00 06:30 0.50 10,115 10,115 AF RCMP TEST EOUI UD landing joint. Test hanger seals to 5000psi/10min. Install BPV. 06:30 07:30 1.00 10,115 10,115 AF RCMP NUND DBOP Flush mud pumps, top drive, mud lines and blow down same. NID choke and kill lines. Prep stack to N/D. 07:30 12:00 4.50 10,115 10,115 AF RCMP NUND DBOP Flush Hydril. UD beaver slide. Move catwalk. NID hydril. 12:00 15:00 3.00 10,115 10,115 AF RCMP NUND DBOP Remove rams and flush BOP. NID double gate, mud cross and adaptor spool. Clean pits. 15:00 18:30 3.50 10,115 10,115 AF RCMP NUND UTRE Run chemical injection line through wellhead. N/U Vetco 4 1/8" 5000psi tree w/11" 5000psi X 4 1/8" 5000psi adaptor. Test tree void to 5000psi/10min. 18:30 19:30 1.00 10,115 10,115 AF RCMP TEST EOUI Pull BPV and install TWC. Test tree to 5000psi/10min wlmethanollwater mix. Pull TWC and set BPV. 19:30 00:00 4.50 10,115 10,115 AF RCMP CLEAN PIT Clean pits. Clear floor of tools. Prep to RID top dive. Note: Pressure on 9 5/8" X 7" annulus 200psi. Rig released to Nabors Drilling Alaska OO:OOhrs 03/14/2004. ÒENSITÝ(PP9) I FV I PVNP \ 26 1/1 I PP I Wu.:THP I IECCI FCfT/OL I ¡MUD DA"rAI DAILÝC.OST I oml %SandlMBT I Ph/pM \ Pf/Mf I I 1 8.501 I Cl/Ca 30,5001 I CUM COST \ CaCI2(wt%1 H2S 8.60 GELS 1/1 COMPANY Nabors Alaska Drilling Marathon Epoch Well Services M-I Drilling Fluids Baker Oil Tools PERSONNEL DA"rA NO. HOURS COMPANY 18 162.00 R&K Industrial 1 18.00 ABB Vetco Gray 2 18.00 Weaver Brothers (WBI) 1 6.00 Lynden Transport 1 6.00 SERVICE SERVICE LAST BOP TEST: 3/6/2004 SIZE (in) liD (in) ¡SHOE TEST (ppg~ 4.500 3.958 I CASING SUMMARY LAST CASING TEST: 3/12/2004 MAX SICP I MD (ft) I TVD (ft) (psi) @ 9.65 (ppg) 10,070 8,286 NEXT BOP TEST: WT (Iblft) I GRADE 12.60 L-80 LiM~1 ES \ 6RPM POB @ 06:00: NO. HÐURS 2 18.00 1 16.00 1 12.00 1 1.00 3/13/2004 I BURST (psi) 8,440 Printed: 4/8/2004 10:03:02 . . MARATHON Oil Company Paxton Pad Pxtnl slot #1 Exploration Kenai Peninsula, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref Our ref License MWD <0-10115> svy7020 Date printed Date created Last revised 8-Mar-2004 18-Feb-2004 8-Mar-2004 Field is centred on n60 48 21.994,w150 49 18.963 Structure is centred on 209346.057,2231200.156,999.00000,N Slot location is n60 5 45.601,w151 36 30.844 Slot Grid coordinates are N 2230585.150, E 206409.580 Slot local coordinates are 685.58 S 2920.82 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North . MARATHON Oil Company Paxton Pad,Pxtn1 Exploration,Kenai Peninsula, Alaska Measured Inclin Depth Degrees 0.00 110.00 195.00 286.00 376.00 466.00 555.00 645.00 735.00 833.00 929.00 1024.00 1120.00 1216.00 1311. 00 1406.00 1502.00 1598.00 1693.00 1789.00 1850.00 1981. 00 2072 . 00 2168.00 2263.00 2358.00 2454.00 2550.00 2645.00 2741.00 2837.00 2933.00 3028.00 3123.00 3219.00 3314.00 3410.00 3506.00 3602.00 3697.00 3793.00 3888.00 3984.00 4080.00 4176.00 4271.00 4366.00 4463.00 4559.00 4654.00 7.10 7.20 8.00 10.10 14.20 18.90 23.10 26.80 30.40 33.90 35.60 38.80 42.70 47.30 50.80 52.30 53.60 54.70 55.90 56.90 56.20 56.40 56.40 55.70 56.60 57.00 55.90 56.40 56.90 56.00 56.30 55.60 55.80 55.00 54.80 56.40 56.70 55.40 55.70 56.20 55.10 55.10 55.50 54.40 53.40 Azimuth Degrees 0.00 0.10 1. 00 1. 90 4.40 0.00 27 4.40 274.40 307.10 325.50 339.10 340.00 339.60 339.50 335.90 337.30 334.70 334.80 334.20 334.70 335.00 334.30 334.20 334.60 334.80 333.90 334.10 334.40 334.90 334.90 335.30 335.30 335.60 335.00 334.90 334.00 334.20 333.60 333.70 333.80 333.90 334.10 334.90 334.90 335.00 335.10 335.10 335.70 335.60 336.00 335.30 335.60 335.40 334.80 335.50 True Vert Depth 0.00 110.00 195.00 285.97 375.83 465.37 553.68 642.88 731. 76 827.55 919.54 1008.21 1095.24 1179.51 1259.93 1337.99 1414.44 1487.16 1554.31 1617.22 1655.15 1734.08 1787.38 1842.03 1894.60 1946.96 2000.23 2053.35 2106.41 2159.88 2212.45 2265.50 2318.42 2370.65 2423.70 2476.62 2530.37 2584.47 2638.98 2693.61 2747.84 2800.21 2853.82 2908.12 2961.88 3015.48 3069.83 3125.05 3180.19 3236.16 R E C TAN G U L A R COO R DIN ATE S O.OON O.OlN 0.07N 1.04N 4.79N 12.83N 23.21N 34.38N 47.64N 66.67N 91.78N 122.84N 159.46N 200.92N 246.53N 295.54N 347.98N 404.41N 464.98N 530.52N 573.59N 667.56N 733.99N 805.32N 876.97N 948.87N 1021.43N 1094.16N 1165.75N 1237.98N 1310.45N 1382.42N 1453.27N 1524.38N 1596.14N 1666.96N 1738.45N 1810.03N 1881. 59N 1952.00N 2023.82N 2095.71N 2168.12N 2240.24N 2312.79N 2384.24N 2455.11N 2527.68N 2598.97N 2668.62N O.OOE 0.10W 0.91W 2.90W 6.05W 9.99W 13.86W 17.97W 22.92W 30.84W 41. 65W 55.56W 72.83W 92.63W 114.42W 137.42W 162.28W 189.50W 218.51W 249.49W 270.17W 316.00W 348.05W 381. 84W 415.40W 448.78W 482.15W 515.37W 548.30W 582.06W 616.70W 651.65W 686.36W 721. 58W 756.97W 791. 74W 826.61W 860.75W 894.27W 927.18W 960.59W 993.97W 1027.12W 1059.76W 1092.36W 1124.70W 1157.07W 1190.14W 1223.23W 1255.49W Dogleg Deg/100ft SURVEY LISTING Your ref Last revised 0.00 0.09 1. 06 1. 31 2.96 3.34 0.17 0.89 2.33 4.25 15.85 26.89 38.75 52.87 73.46 . Page 1 MWD <0-10115> 8-Mar-2004 Vert Sect G RID Easting COO R D S Northing 2230585.15 2230585.16 2230585.24 2230586.26 2230590.08 2230598.22 2230608.69 2230619.95 2230633.33 2230652.55 2230677.91 2230709.29 2230746.31 2230788.24 2230834.36 2230883.92 2230936.94 2230994.01 2231055.26 2231121.53 2231165.08 2231260.12 2231327.31 2231399.43 2231471. 87 2231544.55 2231617.89 2231691.40 2231763.77 2231836.79 2231910.08 2231982.87 2232054.53 2232126.47 2232199.06 2232270.70 2232343.01 2232415.39 2232487.73 2232558.92 2232631.52 2232704.20 2232777.38 2232850.26 2232923.58 2232995.79 2233067.42 2233140.76 2233212.83 2233283.23 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #1 and TVD from RKB (N-129) (161.00 Ft above mean sea level). Bottom hole distance is 3861.84 on azimuth 327.66 degrees from wellhead. Vertical section is from N 0.00 E 0.00 on azimuth 335.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 4.91 4.53 3.85 3.76 3.69 100.78 134.81 175.30 221.24 271.78 1. 80 3.36 4.06 4.85 3.65 325.93 383.96 446.61 513.76 586.26 2.72 1. 00 1. 24 1.32 1. 05 634.03 738.56 812.31 891.24 970.36 0.82 0.21 0.26 0.90 0.94 1049.63 1129.49 1209.45 1288.25 1367.98 0.89 1.16 0.74 0.53 0.94 1448.30 1528.30 1607.18 1686.52 1766.50 0.33 0.75 0.72 0.83 0.23 1845.38 1924.91 2004.21 2083.23 2160.96 1. 67 0.32 1. 45 0.32 0.62 2240.17 2319.43 2399.06 2478.22 2557.75 1. 31 0.26 0.45 1. 25 1.21 2636.18 2714.09 2793.83 2872.42 2949.18 0.00 0.05 0.45 2.17 6.90 206409.58 206409.48 206408.67 206406.70 206403.65 206399.90 206396.28 206392.44 206387.82 206380.36 206370.15 206356.99 206340.61 206321.82 206301.14 206279.32 206255.73 206229.88 206202.33 206172.94 206153.31 206109.75 206079.32 206047.26 206015.43 205983.80 205952.18 205920.72 205889.53 205857.52 205824.63 205791. 43 205758.44 205724.94 205691.29 205658.24 205625.10 205592.69 205560.91 205529.70 205498.03 205466.40 205435.00 205404.11 205373.26 205342.66 205312.01 205280.69 205249.33 205218.76 . MARATHON Oil Company Paxton Pad,Pxtnl Exploration,Kenai Peninsula, Alaska Measured Inclin Depth Degrees 4749.00 4827.00 4868.00 4899.00 5028.00 5124.00 5217.00 5312.00 5408.00 5504.00 5600.00 5696.00 5788.00 5885.00 5980.00 6076.00 6171. 00 6266.00 6361.00 6456.00 6553.00 6649.00 6745.00 6842.00 6936.00 7032.00 7128.00 7223.00 7319.00 7414.00 7510.00 7605.00 7701.00 7796.00 7893.00 7989.00 8084.00 8180.00 8274.00 8370.00 8466.00 8562.00 8657.00 8753.00 8848.00 8942.00 9039.00 9135.00 9229.00 9325.00 52.60 52.00 51. 60 51.60 49.00 46.30 42.40 39.10 35.80 31. 40 28.00 26.30 24.90 24.00 23.70 22.40 22.50 22.20 22.10 21. 90 21.90 21. 20 18.10 14.30 10.60 Azimuth Degrees 335.50 335.40 334.80 335.00 332.40 329.80 325.80 324.00 319.80 314.80 305.50 294.30 284.90 274.10 272.70 266.00 264.10 263.60 265.40 268.50 267 .80 267.70 268.80 270.50 272.50 8.80 6.30 4.60 4.10 3.60 277.50 277.80 276.30 272.10 272.80 3.10 3.00 2.70 2.30 2.30 265.00 268.90 271.70 270.60 268.30 1. 90 1. 40 1. 20 1. 50 1. 20 273.40 276.10 287.60 299.20 283.90 0.80 0.40 0.80 1. 50 2.00 310.30 354.90 82.70 89.90 81.70 2.60 3.00 3.40 3.40 3.90 80.30 85.90 76.70 76.70 79.30 True Vert Depth 3293.33 3341. 03 3366.38 3385.64 3468.04 3532.71 3599.22 3671.18 3747.39 3827 . 35 3910.77 3996.25 4079.25 4167.59 4254.48 4342.83 4430.63 4518.49 4606.48 4694.57 4784.57 4873.86 4964.26 5057.39 5149.16 5243.79 5338.95 5433.52 5529.24 5624.02 5719.86 5814.73 5910.61 6005.52 6102.44 6198.37 6293.33 6389.31 6483.28 6579.26 6675.24 6771. 24 6866.23 6962.21 7057.17 7151. 09 7247.98 7343.83 7437.66 7533.47 RECTANGULAR COO R DIN ATE S 2737.65N 2793.79N 2823.02N 2845.02N 2933.99N 2996.10N 3051.13N 3101.87N 3147.82N 3186.92N 3217.65N 3239.51N 3252.88N 3259.54N 3261. 83N 3261. 46N 3258.33N 3254.46N 3251.02N 3249.13N 3247.96N 3246.58N 3245.57N 3245.35N 3245.83N 3247.18N 3248.85N 3249.98N 3250.52N 3250.79N 3250.72N 3250.44N 3250.46N 3250.55N 3250.51N 3250.55N 3250.77N 3251.19N 3252.09N 3252.95N 3253.62N 3254.39N 3254.80N 3254.89N 3255.13N 3255.73N 3256.28N 3257.11N 3258.40N 3259.66N 1286.95W 1312.59W 1326.16W 1336.46W 1380.39W 1414.64W 1449.19W 1484.82W 1520.75W 1556.64W 1592.76W 1630.52W 1667.83W 1707.26W 1745.60W 1783.13W 1819.27W 1855.18W 1890.83W 1926.36W 1962.52W 1997.75W 2030.01W 2057.07W 2077.32W 2093.42W 2105.93W 2114.88W 2122.13W 2128.51W 2134.10W 2139.15W 2143.92W 2148.06W 2151.95W 2155.47W 2158.19W 2160.32W 2162.33W 2164.40W 2165.89W 2166.43W 2165.80W 2163.88W 2161.00W 2157.27W 2152.57W 2147.30W 2141. 87W 2135.89W . SURVEY LISTING Page 2 Your ref MWD <0-10115> Last revised 8-Mar-2004 Dogleg Deg/l00ft Vert Sect 0.84 0.78 1.51 0.51 2.54 3025.05 3086.76 3118.98 3143.27 3242.48 G RID Easting 205188.97 205164.69 205151.83 205142.06 205100.29 205067.55 205034.33 204999.94 204965.12 204930.18 204894.81 204857.59 204820.62 204781. 36 204743.08 204705.56 204669.36 204633.36 204597.64 204562.07 204525.90 204490.64 204458.36 204431. 31 204411. 08 204395.01 204382.55 204373.63 204366.39 204360.03 204354.43 204349.38 204344.61 204340.47 204336.58 204333.07 204330.35 204328.23 204326.24 204324.19 204322.72 204322.20 204322.84 204324.76 204327.65 204331. 39 204336.10 204341.40 204346.85 204352.86 COO R D S Northing 2233353.01 2233409.74 2233439.29 2233461.53 2233551.54 2233614.46 2233670.30 2233721. 88 2233768.69 2233808.64 2233840.23 2233862.99 2233877.26 2233884.87 2233888.08 2233888.61 2233886.35 2233883.35 2233880.78 2233879.74 2233879.44 2233878.91 2233878.67 2233879.11 2233880.08 2233881.81 2233883.79 2233885.13 2233885.85 2233886.27 2233886.33 2233886.18 2233886.31 2233886.50 2233886.56 2233886.68 2233886.96 2233887.44 2233888.39 2233889.29 2233890.00 2233890.78 2233891.18 2233891. 22 2233891. 39 2233891. 90 2233892.34 2233893.05 2233894.20 2233895.31 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #1 and TVD from RKB (N-129) (161.00 Ft above mean sea level). Bottom hole distance is 3861.84 on azimuth 327.66 degrees from wellhead. Vertical section is from N 0.00 E 0.00 on azimuth 335.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 3.45 5.16 3.69 4.35 5.41 3313.25 3377.71 3438.76 3495.59 3546.19 5.96 5.60 4.66 4.69 0.67 3589.31 3625.08 3652.97 3675.67 3693.94 3.05 0.77 0.37 0.72 1.24 3709.47 3721.90 3733.58 3745.53 3758.82 0.27 0.73 3.25 3.95 3.96 3773.05 3786.68 3799.40 3810.64 3819.64 2.07 2.60 1. 80 0.62 0.53 3827.66 3834.46 3839.26 3842.83 3845.77 0.70 0.24 0.34 0.42 0.10 3848.06 3849.95 3851.98 3853.81 3855.42 0.46 0.53 0.34 0.43 0.49 3856.94 3858.29 3859.57 3861. 24 3862.89 0.63 0.61 0.93 0.74 0.59 3864.13 3865.05 3865.16 3864.43 3863.43 0.64 0.50 0.68 0.00 0.55 3862.39 3860.91 3859.43 3858.30 3856.92 . . ... MARATHON Oil Company Paxton Pad,Pxtnl Exploration,Kenai Peninsula, Alaska SURVEY LISTING Page 3 Your ref MWD <0-10115> Last revised 8-Mar-2004 Measured Inclin Azimuth True Vert R E C T A N G U LA R Dogleg Vert G RID C o 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg /100 ft Sect Easting Northing 9421.00 4.10 78.20 7629.23 3260.97N 2129.32W 0.22 3855.33 204359.45 2233896.46 9517.00 5.10 81.10 7724.92 3262.33N 2121. 75W 1. 07 3853.36 204367.06 2233897.64 9613.00 5.10 83.00 7820.54 3263.51N 2113.30W 0.18 3850.86 204375.54 2233898.62 9709.00 5.10 87.40 7916.16 3264.22N 2104.80W 0.41 3847.92 204384.05 2233899.13 9804.00 5.60 83.60 8010.75 3264.93N 2095.98W 0.64 3844.83 204392.89 2233899.62 9900.00 5.70 89.80 8106.29 3265.47N 2086.55W 0.64 3841. 34 204402.32 2233899.93 9995.00 5.90 91. 00 8200.80 3265.40N 2076.95W 0.25 3837.22 204411. 92 2233899.63 10045.00 5.50 105.00 8250.55 3264.74N 2072.07W 2.89 3834.55 204416.78 2233898.85 10115.00 5.50 105.00 8320.23 3263.00N 2065.59W 0.00 3830.24 204423.22 2233896.96 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #1 and TVD from RKB (N-129) (161.00 Ft above mean sea level) . Bottom hole distance is 3861.84 on azimuth 327.66 degrees from wellhead. Vertical section is from N 0.00 E 0.00 on azimuth 335.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ . MARATHON Oil Company Paxton Pad,Pxtnl Exploration,Kenai Peninsula, Alaska MD TVD ----------------------------------------------------------------------------------------------------------- 10115.00 8320.23 Top MD Top TVD . SURVEY LISTING Page 4 Your ref MWD <0-10115> Last revised: 8-Mar-2004 Rectangular Coords. Comment Comments in wellpath -------------------- -------------------- 3263.00N 2065.59W Projection to TD Rectangular Coords. Casing positions in string 'A' Rectangular Coords. ------------------------------ ------------------------------ Bot MD Bot TVD ----------------------------------------------------------------------------------------------------------- Casing 0.00 0.00 0.00 0.00 0.00 0.00 Target name O.OON O.OON O.OON O.OOE 4950.00 O.OOE 10115.00 O.OOE 1895.00 3417.68 8320.23 1682.53 T.V.D. 2880.83N 3263.00N 605.67N Geographic Location Targets associated with this wellpath Rectangular Coordinates 1353.54W 2065.59W 285.87W 7 Casing 4 1/2 Liner 9 5/8 ----------------------------------------------------------------------------------------------------------- Revised Pxtn1 - Top Tyonek - Pxtn1 - T2 - 1/5/04 Pxtn1 - T3 - 1/5/04 Pxtn1 - TD - 1/05/04 ------------------------------------- ------------------------------------- 204622.000,2233205.000,0.0000 204297.000,2233655.000,0.0000 204297.000,2233655.000,0.0000 204297.000,2233655.000,0.0000 3361. 00 3961.00 5461. 00 7940.00 2576.03N 3018.07N 3018.07N 3018.07N 1850.19W 2185.94W 2185.94W 2185.94W 13-Nov-2002 13-Nov-2002 13-Nov-2002 5-Jan-2004 Paxton I Completion Information 2ó«~o/õ Ken, While reviewing the completion report you submitted for Paxton 1, I noticed that we only have the 10-407 form and completion diagram. We do not have any directional information or operational history information in the well file. Did you submit these items to the Commission? Thanks, Steve Davies Petroleum Geologist Alaska Oil and Gas Conservation Commission Telephone: (907) 793 -1224 I of I 3/23/2005 II :25 AM ~ ¡TI;i~Yu'E ~ fÆ [~!A\ ~ K( ~\ . j)~'f., ~ /0 / FRANK H. MURKOWSKI, GOVERNOR AI¡ASIiA OIL AND GAS CONSERVATION COMMISSION / 333 W. ]f" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 James R. Thompson Senior Completion Engineer Marathon Oil Company PO Box 1949 Anchorage, AK 99611 Re: Ninilchik Unit, Paxton #1 305-023 Dear Mr. Thompson: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior 0 unless rehearing has been requested. DATED this~ day ofebruary, 2005 Enel. 2- 2-05; > 2'",PM;MARA'.011 J t ~ 'ì. \ ~ '1 fA MARATHOI 4 Maratho Oil February 2, 2005 ~ '~ :::~ $' ~ Winton Aubért Alaska Oil & Gas Conservation Commission 333 West ih Ave, Suite 100 Anchorage, AK 99501 ~ .: t # 21 9 ; 7 t2963306 Dontestl' uctiOl1 P.o. Box 168 ::.. AI( 9951""68 Teleph 7/561-5311 j Fax 9071584-6489 ~ _.~ J ~..,- 1 }~'C~/v.s . , " . f:s (}2 ' Ð. ,*¡f~ . <"'0&-: ~~, Reference: Application for Sundry Approval 10-403 for p - rmit 204-010 Field: Ninilchik Unit- Beluga I Tyonek Well: PaXton No. 1. .~ Þ;, .' í . .~ ~!: Dear Mt; Aubert,.. ~ ,~', ',.i ..',._ ~, ',w." ~~~=r~e~: ~~~ ~~~~':.t\~n -:::;I;t~~a~=£~et cased ~eC~~;~~.5· monobore production string tô surface. Request for approval is eing made to fracture stimulate the upper perforations from 81~8'-8266'?Uponsucces ful post stimulation ~ testing, two additional intervals may be perforated as iÇldicated. fii f.:... ,. Should you require further information, I can be reach~d at 907- 2730, or by a-mail at JRThompson@MarathonOil.cort'l. ø Sincerely, ~~ James R. Thompson. Sr. Completions Engineer t; t ) \ ",~ ~ .- , EnclosuréS: Wellbore Dia' m Work proced 1~ ,!,! ~- . ~' J>: . . . , -0524 I 713-296- ~-.'~ f .. -j · , , · :{ " ..,r.; · ¡:. ,- t J j · , 1 OR' G\ NAL W~A- 'L{~I ;7132963396 # W7S 2/3 (5 L Perfora . / Waiver U \,.gtimUIa,. [Z"" Time Extension 0 h ~Suspended Well D 5. Permit 10 Drln Number: 1_ T ÿPe of REic¡uest: 2- 2-05; 2:30PM;MARATHO~ OIL \ 1 s _ '1~CÁ~\~ AbandonU, Susr;.end U Alter casing D Repair 0 Change approved pl'Ogram D Pull TI,I ng 0 .. .. ......-. 2_ Operator Name: " 4; ~":"',,,,, .~. . . ~. . . ~ srratl¡Jðhlc o o ExplOratory D. ServIce D ä. API NÜÕ1ber: / 50- 133-20535-00-00 Marathon Oil Company 3. Addre&$: ~_ . __n_ _ _ .. P.O. Box 1949, Kenai, AI( 99611-1949 7_ KB Elevatlon'(ft): ¡ '4 , 9_ Wètl Name añd Nùmber:-- '" 1 NinilGtl k Unit, Paxton #1 /' 167' 8. Property DesignatiOn: 10. FieldtPools(s): Ninilon"t - 6ell,lgaIT yOóek ADL-359242 & 384372 . 11. Total Depth MD (ft): 10115' CasIng Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (f\): See Well Schematic PackEtl'$ and SSSV Type: ¡Total Depth, ìVD (ft): 8320' Length PRt.:$aff vn:u. COIIIIJITION SUMMARY IE~e Depth MD (ft):IEffective Depth. TVD (ft); , 9948' 8152' ~ MD nm PIu!3$(meaSl,lred) : NA Burst NA 100' 20" !I' 100' 100' 3060 pslg 1895' 9-a\. 1895' 1683' 6870 psig 4950' ~ ~ -4950' 3418' 8160 pslg , " _ i 5368' ~1F' I P, erforat, ion Depth TVD (~ , ,"_ $èèWen~ematl Bak~ ZXP ,;I f(m' ... 8276' 1 ITI.IbirIQ ~: 1... Tubing Grade: (1/2" _._ . L. Packer. .,~ Packers and SSSiD (ft): ~ U '1-, 13. Well ClássattI\,oposed WOÞo: D. Exploratory D. :. De ,.....'!'- . . 15. Wen StatuuflenroPosBd 011 0 ~ 0 WAG D GIN.J 0 12. Attachrmirits: Oèsctiptìon Summary of P Detailed Operations Program 0 BOP S 14_ Estimated Date for Commencing Operations: 16. Verb<ll ÅPproval: Date: , 204-010 IJl,lnk (tne$$urãd): NA Cotlap$e NA 1500 psig 4750 pSig 7020 psig 8430 pslg 7500 psog ITUbin9 MD (ft): 4703' 4703' Plugged 0 WINJ 0 Ii rnent 0 / Service 0 -' .~ Commission RepresentatiVe: 17. I hereby cenify that the foregoing is true and correct ,. the best of my knQwIedge. Printed Name Jám$S Ft Thompson' T:"1tle ..........Qa...,...../c!.t.--ì1' ~. _ _A,~ ~~",l'Ie' 713-296·27301907-529-0524 Date U ---~ ..- COMMIS$lÒN USE ONLY 1 , Cor¡tact I Abandoned WDSPL o o James R. ThQmp$Olt pletion ~ngineer 2/1/2005 ISundryN~mber: ~..5.- ()J- 3 ,- Loca~ larance 0 , ::;'-::~"ta+=~1 D Other: " ; . f 0-40t\. ,.. COMMISSIONeR .i II APPROVED BY THE COMfy'IISSION q ,... RBDMS 8Fl FEB 014 2005 Form 10-403 RcWised 11.~4 ... ~ , ~ '. t~ M{ :;¡ 6, W~' :;f~t"" Submit in CM:I¿te o R t G 1 ~\lA L 2- 2-05; 2:30PM;MARATHON OIL. . I -r í ~ API . 50-183-2058$:??oo' PormUJI.2040010 W8S 1/ DX..03.OØ1Ø1.CAP.CMP.02 '~ Y=H308T9 Loll, NeO&4U89 ,onq;W1~1a.30-S92 . :~:_..I- ì ~.xton #1, Wildcat Field 782' ~L & 2905' FEL Sec. '3-T1S-R14W \ ~ WI (y4- ':~ ' ,'," J Li ~ .- "f . .. ., ~ ~ 'f .. FormSlIon Top$: J:IIIiIII1!Im Sterling Beluga Ty_ TD DcI:>Ih (MOl Dcoth lTVD¡ NlA WA 6$3' "1' 47$1' 3291\' 10,115' 18320' I ", t . t -. "...-. \ t i . ~ ~ " .. "'1 ~ :.-- .i-I... TJ): 10,115' 8320' -VD ¡ 1 2Oppt.,. L-80 ..r ~ 0'" 4950' i j ".' -;" ,..... ...,-.... ...,.. ",,~ TyOOltk.fed/Ç; ~ ,.. ... ~ r ~r - ;713;963396 . ConclUetOt 20" K-ð5 183 ppf PE I9J!.. Bóltom MD 0' 100· TVD 0' 10U ... $UI1'ace Caslna 9-518" If1 ppf !M. MD f1 TVD 0' L-80 ~ 1895' 1683· .. .1· 12.1/4" hOle wlt/l.lo 5'18 ~kói 12 ppg 0I!>II'Ifn"¡1 /-;' J ~ II( ~{ 4' '~;'.f': BTC "" MD TVD 0' M18' 81i!H268', 7811, Claaa 1 (3000 psI @ 6397' TVO) PJ_ 8784-8804',2011, Class 1 (? psi @ 6993' TVD) 891&08938',2011, CJa-ss 1 (? psi @ 7125' TVD) 9088-9142, 5411, Clasa1 (3422 psi 0 729T TVD) PJ _ 9.22Go92t56, as II, Class 2 (M84 pili 0 74211' TVD) PJ IIiOG !;I$42.9sse, 14 II, ~ 1 (31135 psll/t 7750· TVD) PJ 2506 Aeperf; 9113-33; 8234+";8'1118-8208' MD Pd 2506 ~ 001101181 or F~{\I RÐl;gmDk>tIQ" Ta~ts; 71511-'1251', 93ft, ClaM 1 (1 PSi @ 6389' TVD) 757\)-7588',1811, Clua1 (? 1181 @ 5780' TVD) / Tagged PBTD ¡at 995:J' with colllublng ano aUckhnø Y!!!!: 4-112" 12.6 ppl L-ðO HydrU 521 !9l!.. AII1IIIID MD 4703' 10071' TVD 3286' 827$' 7" hokI willi .10 890 sics 12.8 PPII .)' JJ ~~ t # 9 4/ , BTC i , '.' . ' I ~AATH~ OICOMPA f ALA9<A R ; ION .f Nin chik ., Id ~ on #1 FractUle Sti ulation P edure ~ BS # DX.0$978rP,CAP_CMJ'*02 ~~~":~':~'ifn'~':=.UI~: ~':iw"(¡~~La:h-I\1i~:.t::,~~ fluldcontacUn9 other Pèrl ,~.~ -.. ;r:~~ íì ~", 1. MIRU Expro wireline. H$t sand envîro,menffl meetin!i: Install pack off and flow tee. C flow tee to flat tank with ¡hiok n and have \f3.o tr~k on looff:¡n to handle any water displace hole with tools and wirelme. rform wire tWist tEf5t. PU tód string consisting of weight ba spang jars into lubricator. MU " gauge ring with junk basket and pressure test lubricator to 37 with MOC methanol skid. 0 n well and RIH with 3.8" gauge ring and junk basket to tag (previously recorded at 9953') d record flUid level, if detectab.le. . . 2. If PBTD is below 8300' MD, p~eed to RIH with Expro and sela Baker4.5? 12.6# wireline settabJe, CT retrievable plug at +/- 8300'M~:.;(.· ensu..redePthîis cor, elated wit CBL ap. . ·Wi...... .... logS). POOH and RDM.0 Expro. Go to step #20. If P6Tq,,~s above 830(. MD ~tep 3. rj~, ~. .' . <t· . , J;: 3. Deliver clean 500 bbl. Rain-fori ent ,tank, ±3!i0 bb110w bae.: tank, and-eOC gas buster to locaUn. Deliver MOC 2", 5K flowback id (P1IfChase~fro . etoo) aA:! flowbaCk:~icksan to location. De~er APC diesel fuel truck, 1000 lion diesel ~k, r r, and flunnage to :lcation. Deliver Mara-qon methanol injection skid with do Ie diaphragrf and skel pu np to loca~. Deliver Airport Rent.65 KW rental generator, three lig lants, Model 185 compres.sor with M~ air drier, and diesel-fulfed man lift to location. Deliver portable tOj1~, d pster, a1d ASRC fo~ lift with fork extensions, to location. Set gas buster on fl baCk tanK aæ bin own with chains aroboomers. (NOTE: some of this equipment may already b n location leftover m facilities work and'Jseable for well work) 4. MIRU BJ Coil Tech 1-3/4" coil ing ~nit, fluiJpum ~N2 pump and weath'Îtord MHA, jars (Dailey t 7/8" OD), 2-7/8" CT-PDM mo and 3.80" OrJ.mill. U pumping and flowback iron as needed. RU 50/50 ta~ for freeze proteptio nd pressure ~stin . Mix up ~ain for Ren!. nk with 6% KCL and adq FRW-14,t 1 GPT. II.. I· ! t . i', . 5. Nipple u~ wellhead asser bly HA). WHA to. 'nolu 4-1/16",10M Flow CrQss, 4-1/16",1 OM BOP ~ (dressed for 1-3/4" CT) ard 4- 6" lubricator rs n1ed to cover the BHA. i . 6. Stab 1-§4" CT in injector. AU Î ector to WHo . '.. . ....~ 7. Pressure lest BJ pump lroo (2 4509 psi). fit ba .equIPm.:n and BO~& p";). -- I 8. Nipple down injector. Pick up 10M lubricator as eded. In~all CT con~"'Ctor. Pull test CT conn~or (20,000 Ibs). Pressure test CT nnector (2001>sil 0 pSi). '+4 9. Make up BHA. BHA to include 7/8" DFCV, BaSS ~I cirmàtion sub, ~S./8" motorßnd 3.80" mill~ ::;t :1 10. RU Injector to WHA. Pressure at WHA (200 ~sil4 psi) -- .~ 11. Open WH & RIH @ 75 FPM t 200' PumPin~mini~m rate f~ids. Establi~ top of fill. PUH 25'. : i'" ~ t 12. Increase pump rate to 2.5 BP Mill ahead at 1 0 F~ to 9953'. . , .;. , t 13. AT PBTD increase N2 rate to 00 -1200 SOFM. .st on bottom for 30 mif1ltes. .~, f l .~ 2- 2-05; 2:30PM;MARATHON OIL , ? 14. Circulate bottoms up. ;7132963396 I 9 f ,. '. - .~ ~ ,;- ~7 .!'. .. .. : . d " 2- 2-05; 2:30PM;MARATHON. OIL ;7132963396 # 6/ 9 . . 15. POOH pumping 2.5BPM at 50 FPM to 6000' r,.<' 16. Decrease pulling rate to 25 FPM in high dEfviation section fron 6200' - 2000'. 17. Increase pulling rate to 50 FPM from 2000' to surface. ~ " 18. RDMO BJ Coil Tubing. 19. ~~ to set retrievable pl1with EJ<pro as d_~bed In steplr.!. above at +/. 83QO'MD. RDMO· 20. MIRU PowelWell Services well testers. MIRU MOC Sand buster. NU Powerwell Services Test'"1g 3- 1/181" 5K companion flange With 3", 1502 connection to end of flowline spool flange downstrf!Ø1of SSV. Lay flow lines to sand buster, separator and vent stack. Plumb in methanol injection line to flow back line and air Jines to SSV. Ensure that SSV has a lock open plug and a needle valve attached. Load separator with j; 20 bbls glyool water. Pressure test PowelWell Services flowback lines to separator to 250/4500 psi with rnethanolwater. 21. MIRU BJ frac trucks and equipment. Pressure test frae trucks and lines to 9500 psig. / Note: APC to lay liner and berm around·tor PowelWell Services Well liest separator, flow lines, vent stack, and diesel fuel truck. APC to laYf· 'ner and-berm around Rain-for-Rent, MOC choke skid, and ~::gn::::.:'k. wner to be placed a, und wellIiead aÍld vici;ity to 7 occupied by wireline and coil Stinger Wellhead Isolation Tool Installation Procedure (Steps 22~ 22. Take Wellhead pressure reading and Ch~ Wellhead rating. L~t SITP -aken was 2625 psig. 23. Make sure you do not have Gaj or Oil flowing back through p¡p¿Jines or ~ck to flow back tank. t 24. Check all Wellhead valves to\sure they are in the right pos~on. Ensure master valves are ~sed. Make sure that Wellhead pressure is bled off in order to installrsolation Tool. Remember to wo~ff of / highest blind ram or valve. !Ì ...! ~, 25. Before bleeding pressure, check all flow lines, manifolds and ta~s for pr'Jper set-up. 26. Relieve pressure from We[hea~ and record proper measúrements. , 27. Prior to lifting the Tool, close 'manual valve and make sure the needle vajve on the polish rod is in the open position. It! 1:' f 28. Lift boom and attach to Tool- make sure safety latch is in llace~ ¡ 1.-. 1 tî¡.} 29. Lift Tool and hang beside crane, then attach hydraulic hostS to Tool. 30. Stroke Tool down and check all connections to ensure they are tight. Take main mandrel measurements and record on Call Sheet. 31. Stroke Tool up and check packing nut for proper adjustment. Ct¡eck to e 1sure that 2"x1 equalizing valves are in the open position both on the flow tee and on the bottom of the Tool. All bleed-off needle valves are in the closed position and the main 'fê3.lve is open. 32. At this time ensure that all required connections are clean and 4ringS are replaced. t~ .. ~ -I ..; , 'i . ~ ; . í ~ J .' , . r" ¡ t~ t 2- 2-05; 2:30PM;MARATHON OIL ;7132963396 # 7/ 9 , ' 33, 'After installing all ne!ry éXlen$ions and cup L..be sure toLl before instaìnng - tool. 1 .... ...¡ . 34. ~nsure that ring g.wve í~ clean arí<l in goooshap¡¡. Flanges on I"oIallon T ~I Should be J and hew nnggasket ,nstalled. i . 35. Bolt down the Isolation Tool to the Wellhead, having slacked off the winch line. Ensure that all flanges are hammered down straight and tight. Have bleed-off needle valve pointing away from equipment - point tOwards pit, if possible. 36. Recheck all valves, wing valves, flow tees, equalizing lines, etc. to ensure. that everything is in the proper position. 37. When mandatory radius (30') around Wellhead is clear of all personnel, open Wellhead slowly and count the tums on the valve(s) to ènsure they are open completely. 38. When Wellhead (with Tool in. St4.~lIed) has been equa.lized, check all union and flang.e connections for leaks. Stroking the Tool intcjan equalized Well, will ensure that the pack-off cups will not try to set prematurely before the mandrel is stroked all the way dQwn. 39. Begin stroking Tool into Well - watch the hydraulic gauge closely for pressure increase. If an unusual increase in hydraulic p~ure is encountered. stop and remove Tabl. Inspect cups and cup tool for unusual wear,fe, etc. Note: If Tool will not stroke down, it, probably dueto the hydraulic fittings not being Ø,roperly connected (even though they may SJ'pear to be). 40. When Tool is stroked in comp~tely the hydraulic pres~ure wi~ rise on the gauge, indicating the tool is all the way down. Screw down the lock-down nut on Isolation Tool and hammer lockdown union until tight. C 41. Close the hydraulic valve on th, Isolation Tool. f: 42. In order to check for cup seal and valve seal, open flow back Une to the tank or pit after careful inspection of the flow back line" Once pressure is bled off, close the bleed-off valve (on flow line) to the tank or pit and ope!n','w, needle valve bleed- off, to check for proper seal. If proper seal is made, close 2" x 1" equalizi valve on the flow tee, then close the 2" x 1" equalizing valve on the bottom of the Tool. Check r trapped pressure by opening W' needle valve between the valves. If proper seal is not ma stop and remove Tool. Inspect the cups for unusual wear, connections for possible o-ring sak, etc. 43. If a proper seal is made, bleed....l.nd remove hydraulíc hoses from main valve, open manual valve on top of Tool and install hydr8flic hoses on setting tool for removal. 44. Upon applying downward hydriuliC pressure, hammer ~op union loose and spin off. Clear Wellhead area of all personnel..Stroke up and clear top unÎon. 45. Remove ~" equalizing hose al'ld instaJl quick connect plugs in both equalizing caps on the flow tee and the bottom. '" It 46. After applying tension to winchine, the stay rod keepers and pins can be removed. Lift the setting tool from the Wellhead ¡ ~rea and set aside. 47. The Frac line can be properly pched to Isolation Tool valve or Frac Head with Jroper line jack or swing installed. Use properammer techniques and Fall Protection. ' ~ I ~ 48. Prior to pumping, attend pre-jo-'l safety meetíng. Discuss 30' saf,ty area around \Vellhead. Have service company appOÎn' one individual to tell us to open 9r close main val'P' Request f '. f í I ., 1 / . 2- 2-05; 2~30PM;MARATHON OIL ~ \ I . :. r i ~dio coOOnunication with t~ service comäy for these opera ns. Also, informaJl.involved if . our cup¥re not set, what ~edure we .ke to I set the cup uring pumping. Note: If ther1s no preSSlre on the Well, have the service çcrnpany notify youl ,en the hole loads or catches pressure! 1 49. =~=~ ~~~~h~ ":,~~:Fe:~~We~h\7ln vsM). Do Not O¡)èn ~ ....:¡'Ï 50. Have th. service company provide. at least 0 p.J above Wellh " sure, on, top of main before o~ening. \ ~'t.' 51. l!efqre Pimping, open valve to monitor prop up """I using ~I compa flow back equipment. If not apticable, use Stinger 2" x 1" equalizi valvè with W'l')eedle v bleed-off. 52. When in$tructed. open main valve on Isolati Toolend ensure the val is fully open. Check valve periodically during pumping. Watch for ks on Wellhead, Tool a seal. Be aware of "rough" pumping. ;7132963396 # 8/ 9 I I . §:-: 1 53. Fill well with 6% KCL and fracture stimulate the interval from 8188' - ~6' per pump schedule œlow_ After pur/ing frac volumes, RDMO frac eqUi~ment and Stingtr Wellhea~ Isolation Tool as direct# .. _n. - -..- ..#'. ',,-... ---';, ~·S .. --'. LtPl' ~ ~. ',:" .~'<i,q4q,~ ï . ' --. . - I."... r··· . :~:' ~'\J1 ; 'e;,;í <~it1me~ 1 ':", . .. ~,..\ ~~.,~,... i\"":<MI":~ ,~~ f""~f' ':'. J¡"1. ~ . o 2520 Ltng 1~~:·~~,,~~·;-~·'..~~rit· ~ 2.i4'Ú!~ ;~.~h;t1~~'!:; "25 0 0 1, '0 ~ '.. 12016 Ltr'lg 1 aoo 25 2101. 2.0 4.4 \4627 4· 2016 0 2. 2016 Ltng<1S00 25 2198~ 2.1 6.5 6825 65$2 3528 504 41" 2520 Ltng" 1800 . 25.. 2976;' 2.8 9.3 9801 9012 8820 1260 2520 Ltr'lg 180j) 25 t - 3204'. . 3.1 12.4' 3005 11692 13230 1890 : 2100 Ltng 1S(I) 2.5 ... 2860 2.7 .. 1.5.1 i. 5865' 1.~. 2 14700 2100 o 5234 Lt/1g 1~' 25 5234 _5-0_. .?O_1 21099 ~6 0 0 ". ~. . 42294 5754 ;·.1 ~ 54. MIRU . T. RU CTU, Fluid pump and N2 pump. RU ~mping and flowNck iron as needed. RU tank for eze protection and pressure testing. ADD FltW-14 to treatme,.t fluid at 1 GPT. 55. Nipple ul wellhead assembly (WHAI:WHA to include 4-1/16",1 OM Flow~ross, 4-1/16",1 OM BOP .' (dresse~or 1·3/4" CT). .J .. ~ ~ : 56. Make up. BHA. BHA to include 1 ·3/4" CT connector. 1-314" DFCV. 1-3I4":-everse circulation sub a 2" nozzle. .. ~. .,. ~. ... 1 2 3 4 5 6 7 .. / 57. RU Inj iron ( ~ ~) r to WHA. pressu retest WHA, BOP and fIOwb.., ack iron (200 P",'; 4500 psi._Pressure test.f~....·"." 00 psi). ~ . .. 'I ~ ating minimum rate fluids to top oUiII (8100' +1-)' t , 58. RIH cir ; ~ 59.1ncreas . ump rate to 2.50 BPM. Wash ahead at 30 FPM to top of WRP~(8300' +/-) 60. Drop atJ ball to shift reverse circulation sub and displace with bOttoms t hoie volume at 2.50 st· 61. POOH at 50 FPM circulating at2.50 BPM to 6200', i .; r : ~ 62. Continue to circulate at 2.50 BPM and decrease pulling rate to 25 FPM t"'1rough the highly devia.t~ S~,'. 'on;~;...rom 6200' -2000'. . .~. . .. ! t , >\ , .'t Ii , . ) ,. ~ < 2- 2-05; 2:30PM;MARATHON OIL . 132963396 f 9/ 9 . \ , . 63. Circulate bottoms up at 2000' 64. Stop fluid pumps and start N2 pump at 750 5CFM. RIH jetting- Maintain WH pressure at choke to prevent formation flow. Adjust N2rate as needed. Jet to top of WRP. 65. Jet on bottom. With fluidoolumn well above CTTD POOH jettingt,uid to surface maintaining back pressure to prevent formation influx.. . i ì 66. With total wellbore volume recovered at surface 81 choke manifold tnd.. N2 cap well bore to +/·2600 psig SITP. "'. . s 67. At surface 51 WHA and release CTP to flowback tank. "i ;.. 68. RD injector head and ensure there is enough 10M lubricator cover WRP retrieval toolstring and plug assy. 69. Make up BHA. BHA to include OT connector, DFOV, BOSS and Retrieval Head. 70. RUlnjector to WHA. Pressure test WHA (200/4500 psi). Pump N2 asneeded to equalize pressure between CT and CTfTBG annulUs. ' 71. RIH to top of WRP at +/-- 8300' MD. 72. Latch and pull WRP at +/. 8300' MD. Avoid circulating fluids unless necessary to clean up top Of WRP. 73. Allow plug to relax and POOH. Verify WRP retrieval. 74. RDMO CTU. J 75. Open well to well testers and flowtest well as instructed by on site MOC personnel. Once well has cleaned up and is making enough gas, put well to MOC production system. Continue flowing through well testers equipment and MOC sand buster until production is relatively solids free from frac job. Put well to MOC facility through flowline and RDMO well testers. 76. Once well is satisfactorily cleaned up and stable, MIRU Expro wireline and add perforations as described below. Document any surface pressure and production rate increases after each interval is perforated. a. 7570-7588' OHL b. 7158-7251' OHL 77. RDMO Expro. JRT 1-18-05 ¡ .~ ~: ¡a . . . Alaska Business Unit M MARATHON . , Marathon Oil Company P.O. Box 1949 Kenai, AK 99611-1949 Telephone 907/283-1311 Fax 907/283-6175 January 28, 2005 Winton Aubert AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Dear Mr. Aubert: Attached and submitted for your records is the Form 10-407 for the original completion work performed in the Paxton #1 well bore. Also, included with this submission is a wellbore diagram. This well was completed in April and May, 2004 and has remained shut-in since that time. Plans are to start producing the well to sales in the very near future, flow the well for about one week, perform a hydraulic stimulation, and possibly add new perforations. A separate Form 10-403 request will be made to perform the stimulation activities and add new perforations. If you would like any other information, please contact me at 283-1311 or kdwalsh@marathonoil.com. Sincerely, 1~Ì),w~ Ken D. Walsh Advanced Production Engineer Enclosures _ STATE OF ALASKA _ ALAS~LAND GAS CONSERVATION COMMI~ ........ ... WELL COMPLETION OR RECOMPLETION REPORT AND têGJ Oil 0 Gas 0 Plugged U 1a. Well Status: Abandoned 0 20AAC 25.105 GINJD WINJD WDSPLD 2. Operator Name: MARATHON OIL COMPANY 3. Address: P. O. Box 1949, Kenai, AK 99611-1949 4a. Location of Well (Governmental Section): Surface: 2905' FEL, 782' FNL, Sect. 13, T1S, R14W, SM Top of Productive Horizon: 1097' FWL, 1957' FSL, Sect. 12, T1S, R14W, SM No. of Completions Total Depth: 307' FWL, 2481' FSL, Sect. 12, T1S, R14W, SM 4b. Location of Well (State Base Plane Coordinates): , Surface: x- 'J.ðÎ:,¡ttz2·1.' 'j;.... Z23()S'liJ~~¡ Lone- 4 TPI: x- 205134 i y- 2233318 Zone- 4 Total Depth: x- 204354 )(.,.:,-/"37 y- 2233842 ').1-3::11/11 Zone- 4 18. Directional Survey: Yes 0 No 0 .41>,11,1:..' ç . V· 21. Logs Run: Reeves Quad Combo: GRlCal/Den/Neutron/Sonic/Res 22. CASING WT. PER GRADE FT. SuspendedD WAGD 1b. Well Clas$,:b"b. 20AAC25.110 Development 0 EJ(919~¡:¡t9~W Other Service 0 Stratigr~phic TestO 5. Date Comp., Susp., or 12. Permit to Drill Number: Aband.: 05/29/04 / 204-010 6. Date Spudid.1~ 13. API Number: Februa~ 2004 d'Þ,)" 50-133-20535-00 7. Date TD Reached: l~" 14. Well Name and Number: March~ 2004 ·r Ninilchik Unit, Paxton #1 8. KB Elevation (ft): 15. Field/Pool(s): 153' Ninilchik/Beluga- Tyonek 9. Plug Back Depth(MD+ TVD): 9946' 8152' 10. Total Depth (MD + TVD): 10115' MD 8320' TVD 11. Depth Where SSSV Set: 16. Property Designation: ADL-359242 + 384372 17. Land Use Permit: 19. Water Depth, if Offshore: feet MSL 20. Thickness of Permafrost: CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED NIA NIA NIA NIA NIA NIA 20" 133# 47# 29# 100' 1895' 4950' K-55 L-80 L-80 0' 0' 0' 9-5/8" 7" 4-112" 12.75# L-80 4703' 10071' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 8188-8266' MD, 6397-6475' TVD . 8784-8804' MD, 6993·7013' TVD . 8916-8936' MD, 7125-7145' TVD . 9088-9142' MD, 7297-7351' TVD 9220-9256' MD, 7429-7465' TVD ' 9542·9558' MD, 7750·7766' TVD ' . 8,,//;.\;.. -ß,/p1 'ml> I {d,::. i/I--/d:>Ýt, '7"Vþ .)~'1.ß(' 7'''' 26. Date First Production: 0' 0' 0' 100' 1683' 3418' 12-1/4" 8-112" Driven in place, 516 sx in place, 290 sks 3266' 8276' 7" in place, 690 sx TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 4703' 4703' 24. SIZE 4-1/2" 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: I Gas-Oil Ratio: 5/12/2004 24 Test Period ..... 0 2092 8 25 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. 500 o 24-Hour Rate -.0 2092 8 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". Form 10-407 Revised 12/2003 CONTINUED ON REVERSE J ì~ I ¡.;.'~"""...,,,..(~,,,,,....:~t.: Þ COMPLETlon.~ S DAm ",. , ~ <S: ~~~t?;¡ "~J8). ¡ trl"~'~~: c.I._~.",..".".,.,...~,~..,.,~.._."""."> RBDMS BFL MAY 2 {) 2005 "...., l J NAME GEOLOGIC MARKE. TVD 29. _ORMATION TESTS Include and briefly s . ize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 28. Beluga Tyonek 653 4751 651 Perfed 9542-9556 (4/19/2004) 3294 Flowed 1307 mdfpd @ 1550# ftp Added perfs (4/20-21/2004) 9220-9256 9088-9142 Flowed 1675 mcfpd @ 1010# ftp Added perfs (4/30/2004) 8188-8266 Flowed 2003 mcfpd @ 80#psi Added perfs (5/27/2004) 8916-8936 8784-8804 8402-8437 Flowed 3040 mcfpd @ 255# ftp 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ken D. Walsh Printed Name: Ken D. Walsh Signature: ) ú.M.. b. W~ Title: Advanced Production Engineer Phone: 907-283-1311 Date: 1/28/2008:' INSTRUCTIONS 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 Item 1 a: 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 prod Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. 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: True vertical thickness. 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 in Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain ). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Paxton #1 Wildcat Field 686' FNl & 2921' FEl Sec. 13-T1S-R14W ..011I JI. Formation Tops: Formation Sterling Beluga Tyor¡ek TD Depth (MD) Depth (TVD) N/A N/A 654' 652' 4751' 3295' 10,115· 8320' TD: 10,115' MD 1 8320' TVD * ~ ~ ~ ~ 1 ~ j; .~ > .. Intermediate Casinq 7" L Conductor 20" K-55 133 ppf PE Im:L Bottom MD 0' 100' TVD 0' 100' Surface Casinq 9-5/8" 47 ppf Im:L MD 0' TVD 0' 1895' 1683' BTC BTC 8-1/2" hole with +1-180 sks 12.5 ppg Lead + 110 sks 13.5 ppg Tail Tvonek Perfs: 12-114" hole with +1- 516 sks 12 ppg cement MD TVD 29 ppf Im:L 0' 0' L-80 Bottom 4950' 3418' 8188-8266',78 ft, Class 1 (3000 ps; @6397' TVD) PJ 2506 9088-9142, 54 ft, Class 1 (3422 psi @ 7297' TVD) PJ 2506 9220-9256, 36 ft, Class 2 (3484 psi @ 7429' TVD) PJ 2506 9542-9598, 16 ft, Class 1 (3635 ps; @ 7750' TVD) PJ 2506 Reperf:9113-33; 8234-54'; 8188-8208' MD PJ 2506 PJ 2506 8916-8936',20 ft, Class 1, (3342ps; @7125'TVD}3-3/8"Ower¡ 8784-8804',20 ft, Class 1, (3280 ps; @ 6994' TVD) 3-3/8" Owen Tagged PBTD at 9953' with co;1 tubing and sl;ckline Liner 4-1/2" 12.6 ppf L-80 Hydril 521 Im:L Bottom MD 4703' 10071· TVD 3266' 8276' 7" hole with +1- 690sks 12.8 ppg 4/30/2004 4/21/2004 4/20/2004 4/19/2004 5/07/2004 5/28/2004 5/28/2004 [Fwd: LOIC! 04-007 Paxton Pad Gas Development and Lateral Pipeline] . . That document is the "Well Data Submittal". -------- Original Message -------- Subject: Lo/cI 04-007 Paxton Pad Gas Development and Lateral Pipeline Date: Tue, 22 Jun 2004 13:54:21 -0800 From: Bruce Webb <bruce webb@dnr.state.ak.us> Reply-To: bruce webb@dnr.state.ak.us To: my file <bruce webb@dnr.state.ak.us>, Chick at Marathon <caunder\tJOod@marathonoil.com> cc: Bob Crandall <bob crandall@admin.state.ak.us>, Bob Shaverson - CI Keepers <bob@inletkeeper. ?F.9.?, "Bob@DEC" <bob blankenburg@dec. state. aJ<:..:~.§_?':, "Chuck Young @ Fish & Wildlife" <Chuck Young@fws.gov>, "Dan @ KenaiBorough" <DBevington@borough.kenai.ak.us>, "Dave @ cOE" 5.p~y'g.Casey@poa02.usace.army.mil>, DML&W - Gaskill <karlee gaskill@dnr.state.ak.us>, "Jim B@DEC" <Jim Baumgartner@dec.state.ak.us>, "Kathy @ OPMP" <Kathy dugan@dnr.state.ak.us>, Stephanie· Ludwig <steranie lud,,,ig~~g~:r,:=~-tate.ak.us>, "Tom@AOGCC" <tom maunder@admin.state.ak.us.~, "Tony@JPO" <tbraden@jpo.doi.gov> Attached is the final consistency determination and leas plan of operations approval. Paxton Permit and Content-Type: application/msword Content-Encoding: base64 Content-Type: application/msword Paxton Well Data Submittal Req.doc Content-Encoding: base64 1 of 1 4/4/2005 11 :32 AM DIVISION OF OIL AND GAS FRANK H. MURKOWSKl, GOVERNOR ©~&~] @~ &1J©~ DEPARTMENT OF NATURAL RESOURCES 550 WEST 7TH A VENUE, SUITE 800 ANCHORAGE, ALASKA 99501-3510 PHONE: (907) 269-8800 FAX: (907) 269-8938 June 22, 2004 Marathon Oil Company Attn: Charles Underwood P.O. Box 196168 Anchorage,AK. 99519-6168 RE: FINAL CONSISTENCY DETERMINATION Lease Plan of Operation Approval Paxton Pad Gas Development and Lateral Pipeline ADL 384372 LOICI 04-07 Dear Mr. Underwood: Marathon Oil Company has applied for a Plan of Operation Approval for a gas development project on the Kenai Peninsula. The State of Alaska, Department of Natural Resources Division of Oil and Gas (DO&G) has reviewed the Plan of Operations for the gas development activities at the Paxton #1 well pad located west ofthe Sterling Highway at milepost 131.3. The pad is located approximately 4 miles North ofNini1chik within the Nini1chik Oil and Gas Unit. The project was reviewed for consistency with the Alaska Coastal Management Program, the Kenai Peninsula Borough Coastal District Plan, and other concerns. Project Description and Scope of Project Reviewed Marathon Oil Company proposes to install gas production facilities, a lateral tie-in to the Happy Valley Extension to the Kenai Kachemak Gas Pipeline, and to commence production from the Paxton well pad. The pad will be expanded on the north side to within 475 feet ofthe mean high water of Cook Inlet. Production facilities will be housed in heated metal buildings on the pad. Gas flow lines, and heating, dehydration, separation, and metering equipment will be installed on the pad. Water will be supplied from the existing water well. A 2,250 foot 8 inch welded steel gas pipeline will be buried adjacent to the existing pad access road. Electricity and telephone will also be brought in. Additional wells may be drilled, produced, and serviced in the future. The facilities are on privately owned surface lands. The pad is located in NE1/4NWl/4, Sec 13, T1S,R14W, SM. "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans. " LO/CI 04-07 Paxton Pad. Development and Lateral Pipeline . Evaluation and Consistency Statement The Division of Oil and Gas has completed coordinating the State's review of your proposed project for consistency with the Alaska Coastal Management Program (ACMP). Your project description, dated April 2, 2004, was evaluated against the applicable enforceable policies ofthe ACMP and alternative measures, if any, to make the project consistent were included in the Proposed Consistency Response. Seven alternative measures under 6AAC50.260(h)(3) were proposed. The project as amended is consistent with the standards of the ACMP and the enforceable policies of the Kenai Peninsula Borough Coastal District Plan to the maximum extent practicable. Based on the evaluation contained in the Proposed Consistency Detennination, the State concurs with your consistency certification that the project is consistent. This is the final ACMP decision for your project and a final administrative order and decision under the ACMP for purposes of Alaska Appellate rules 601-612. Any appeal from this decision to the superior court of Alaska must be made within thirty (30) days ofthe date this detennination is issued and meet the requirements of AS 46.40.096 (i). Plan of Operation Approved The plan of operation application of April 2, 2004, and supporting infonnation is approved subject to the tenns ofthe oil and gas lease, the mitigation measures in the most recent Cook fulet Areawide Sale, the seven alternative measures proposed by the Kenai Peninsula Borough, Attachment No.1, and the following: 1. The lateral pipeline as proposed in the plan of operations is not approved, pending resolution of the surface ownership agreement or bond, as appropriate. 2. Well tests must be pre-approved as part of a unit plan of exploration or unit plan of development, and the unit operator shall report all production to the Division of Oil and Gas in accordance with the appropriate royalty accounting procedures. For questions concerning royalty and operator reporting, contact Jim Stouffer, Chief of Royalty Accounting at 907-269-8796. 3. The roads and pad are on private property and may have other beneficial uses. The gravel structures will remain according to the respective rights of the lessee and the surface owner. 4. The state does not own the surface at the location ofthe road and pad. The lessee is required to have a surface use agreement with the surface owner that is sufficient to conduct these activities. 5. This approval does not authorize activity on Mental Health Trust Lands. 6. Lessee will notify this office in Anchorage at 269-8778 when the drilling activities commence and when they are completed. Page 2 LOICI 04-07 Paxton Pad. Development and Lateral Pipeline . 7. A Status Report for the activities conducted under this approval must be filed with this office on May 1 and November 1 each year, from the date this approval is issued and until a Completion Report is filed with the Division. Failure to file in a timely manner may result in revocation of this approval. A Completion Report for the activities conducted under this approval must be filed with this office within thirty days of completion of approved activities. The report shall contain a statement describing clean-up activities conducted, the method of debris disposal, and a narrative description of known incidents of surface damage. 8. The applicant shall defend, indemnify and hold the State of Alaska harmless from and against any and all claims, damages, suits, losses, liabilities and expenses for injury to or death of persons and damage to or loss of property arising out of or in connection with the entry on and use of State lands authorized under this approval by the applicant, its contractors, subcontractors and their employees. 9. Amendments and modifications to this approval require 15-day advance notice and must be approved in writing by the Department of Natural Resources. 10. The applicant shall inform and insure compliance with any and all conditions of this approval by its employees, agents and contractors, including subcontractors at any level. 11. The Commissioner of the Department ofN atural Resources may require that an authorized representative be on-site during any operations conducted under this approval. 12. Rehabilitation shall be completed to the satisfaction ofthe Commissioner. 13. The Alaska Historic Preservation Act (AS 41.35.200) prohibits the appropriation, excavation, removal, injury, or destruction of any state-owned historic, prehistoric (paleontological) or archaeological site without a permit from the commissioner. Should any sites be discovered during the course of field operations, activities that may damage the site will cease and the Office of History and Archaeology in the Division of Parks and Outdoor Recreation ((907) 762-2622) and the appropriate coastal district shall be notified immediately. This Plan of Operation Approval is issued in accordance with Alaska Statute 38.05, Alaska Administrative Code 11 MC 83.158 or 11 MC 83.343, and Alaska Statute 46.40. A person affected by this decision may appeal it, in accordance with 11 MC 02. Any appeal must be received by July 13, 2004 and may be mailed or delivered to Thomas E. Irwin, Commissioner, Department of Natural Resources, 550 W. 7th Avenue, Suite 1400, Anchorage, Alaska 99501; faxed to 907-269-8918, or sent by electronic mail to dnr_appeals@dnr.state.ak.us. This decision takes effect immediately. If no appeal is filed by the appeal deadline, this decision becomes a final administrative order and decision of the department on the 31 st day after issuance. An eligible person must first appeal this decision in accordance with 11 MC 02 before appealing this decision to Superior Court. A copy of 11 MC 02 may be obtained from this office or any regional information office of the Department of Natural Resources. Page 3 LOICI 04-07 Paxton Pad .Development and Lateral Pipeline . This approval signifies only that the State of Alaska has no objection to the operations outlined in the lease operations application. It does not constitute certification of any property right or land status claimed by the applicant nor does it relieve the applicant of responsibility to obtain approvals or penuits from other persons or governmental agencies that may also be required. All stipulations contained in the original lease and subsequent approvals remain in effect. If activities have not commenced, this approval expires at midnight, June 22, 2007. Failure to comply with the tenus and conditions outlined in the lease and this authorization may result in revocation of this lease operations approval. If you have any questions please contact the Division of Oil and Gas in Anchorage, at 269-8778, fax 269-8943, or e-mail bdw@dnr.state.ak.us. Sincerely, SI Bruce D. Webb Natural Resources Specialist Attachment 1 - Well Data Submittal E-Distribution: Dale Bagley, Mayor - Kenai Peninsula Borough Daniel Bevington - Kenai Peninsula Borough Bob Blankenburg -DEC, Solid Waste Jim Baumgartner - DEC, Air Lydia Miner - DEC, SPAR Kaye Laughlin - OPM&P Bill Keller - Corps of Engineers Tony Braden - Joint Pipeline Office Bob Shavelson - Cook Inlet Keeper Lee McKinley - OHM&P, Kenai Tom Maunder - AOGCC Bob Crandall - AOGCC Chuck Young - U.S. Fish and Wildlife Service Page 4 LOIC! 04-07 Paxton .as Development . Attachment 1 Well Data Submittal Requirement (TJR 11/18/2002) (a) The lessee shall submit to the Alaska Department of Natural Resources all geological, geophysical and engineering data obtained from the lease within 30 days after completion, abandonment, or suspension of the well and within 30 days after completion or plugging of a well branch, if occurring at a different time. The lessee shall submit to the Alaska Department of Natural Resources data acquired subsequent to well completion within 30 days following acquisition of that data. The state may waive receipt of operational data from some development, service or injection wells. The state will inform the operator of the waiver prior to well completion. The lessee shall submit the data to the Division of Oil and Gas, Department of Natural Resources. The data shall include the following: 1. a copy of the well completion report (AOGCC form 10-407) with all attachments, including summaries of perforations open to production, production tests, core data, formation tops or geologic markers, and formation tests. 2. daily drilling reports or a summary report of daily drilling. 3. latitudinal and longitudinal coordinates (based on NAD-27 spheroid) for the completed surface and bottom hole locations, include locations for all plug-backs and pilot holes. 4. Paper and digital copies of all directional surveys, include surveys for all plug-backs and pilot holes. 5. a summary list of all logs run and the depth interval covered by each, also list logs for all plug-backs and pilot holes. 6. a list of formations and other geologic markers encountered and the measured depths (MD) and true vertical depths (TVD) of each. 7. a summary of cored intervals (both conventional and sidewall), including depth, formation name, lithology, presence of oil, gas and water, porosity, fractures and apparent dips, indicate "none" in space provided on completion report or in an attachment if no cores were taken. 8. paper and digital copies of all core reports including lab analyses oflithology, porosity, permeability (vertical and horizontal, air and liquid), density, capillary pressure, and fluid saturation, if available. 9. paper and digital copies of all conventional and sidewall core photos (plain light and ultraviolet), if available. 10. identify depth and formation name for oil and gas shows, indicate "none" on the completion report or in an attachment if no shows were observed. 11. identify zones of abnormal pressure, indicate "none" on the completion report or in an attachment if none were observed. 12. a synopsis or summary of testing and all fluid recovery efforts, including production tests (IP), drill stem tests (DST), wire line formation tests (i.e. repeat formation tests (RFT) and modular dynamics tests (MDT», and other production and formation testing data; the summary should include test date, time, depth, formation name, method of operation, recovered fluid type(s) and amount(s), and fluid rate, gas-oil ratio (GOR), oil gravity, pressure, and choke size, when available. If no tests were undertaken, indicate "none" where appropriate on the completion report or in an attachment, if tests were undertaken but failed to recover fluids indicate "no recovery". 13. paper and digital copies of all pressure build-up, and fluid PVT analyses, if available. Attachment 1 Page 1 LOICI 04-07 Paxton &as Development . 14. paper and digital copies of geochemical and formation fluid analyses and reports, if available. 15. a copy of the permit to drill (AOGCC form 10-401) and the survey as-built of the well location. 16. copies of all open flow potential test reports and report attachments AOGCC Forms 10-421 . 17. paper copy (no sepia copies, please) of all final2-inch open hole and cased hole logs, including measured depth (MD) and true-vertical depth (TVD) versions, specialty logs (such as Schlumberger's cyberlook, formation microscanners and dipmeter logs), measured-while-drilling (MWD) and logged-while-drilling (LWD) logs (in color, when available). Provide 5-inch scale logs when 2-inch scale logs are unavailable. 18. paper copy of final composite mud or lithology log and report, with lithology display, oil and gas show indicators, and cuttings descriptions (in color, when available). 19. a digital version of well logs in LAS format on IBM format floppy disks, ZiplOO disk, or CD, and a digital version of final directional surveys in ASCII format (other formats may be acceptable upon agreement with the Division of Oil and Gas). 20. a paper copy of all available well data and reports, including, paleontology, palynology, thermal maturity, vitrinite reflectance (an ASCII format digital version of the above data shall also be submitted, when available). 21. all final reports of velocity, checkshot or VSP surveys (an ASCII format digital version of the above data shall also be submitted), indicate "none" in your response to this request if no velocity, checkshot or VSP surveys were undertaken. Submission of velocity, checkshot, and VSP surveys are always required by DNR under the operator surface-use permit obligations. All material should be either hand-carried by bonded courier or mailed by registered mail to: Tim Ryherd, Geologist Dept. of Natural Resources-Div. of Oil and Gas State of Alaska 550 W. 7th Avenue, Suite 800 Anchorage, AK 99501-3510 Telephone: Fax: Email: (907)269-8771 (907)269-8942 tjr@dnr.state.ak.us The state may also require the lessee to submit additional data in accordance with the applicable statutes and regulations in effect at the time of the drilling and completion of the well. Any data submitted to the state by the lessee in connection with this lease will be available at all times for use by the state and its agents. The state will keep information confidential as provided in AS 38.05.035(a)(9) and its applicable regulations. In accordance with AS 38.05.035(a)(9)(c), in order for geological, geophysical and engineering data submitted under the lease agreement named above to be held confidential, the lessee must request confidentiality at the time the data is submitted by indicating "CONFIDENTIAL" on all confidential data items. This action does not eliminate the need to file all data normally filed with the Alaska Oil and Gas Conservation Commission (AOGCC) under their permit requirements. Attachment I Page 2 · Alaskeiness Unit ... Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 April 22, 2004 Alaska Oil & Gas Conservation Commission Attn: Howard Oakland 333 W. ih Avenue, Suite 100 Anchorage, AK 99501 Delivered by Courier RE: Marathon Oil Company CONFIDENTIAL Well Sa~p~ ~( '3 c;.- Marathon Cannery Loop No.7 ;2.. u3 -f;/(~ \ <1 Marathon Paxton No. 1 .:z.O'1YÒIò. , I J JJ Marathon Falls Creek No.4 J. t) J - .;z.l .::IJ i=t Marathon Kasilof South No. lRD ;J..ú ~-::l \~<,. \t") 0 Marathon Kasilof South No. LlL ;t.Q:ì.. - :z \-ì -:±t \ l ~ \ The following CONFIDENTIAL well samples are being forwarded to AOGCC as shown on the attached listi. When the samples have arrived, please confirm your receipt by signing one copy of this letter and returning to my attention at the letterhead address. Thank you, Kaynell Zeman Technical Assistant Reoeivedby ~'fVJ OW Date: d )~ ðlr ~ '-\.. -; /' r;.. t lß-ýY'\ . Marathon Paxton No.1 (pAX 1) CONFIDENTIAL Nini1chik Unit, Cook Inlet, Alaska Sec. 13, T-I-S, R-14-W, Seward Meridian API #: 50133205350000 8 Boxes - Well Samples Paxton #1 Well Sam"Jles Depth From Depth To (Feet) (Feet) 1,905 2,900 2,900 3,980 3,980 5,100 5,100 6,280 6,280 7,420 7,420 8,660 8,660 9,993 9,492 10,115 Box No. 1 2 3 4 5 6 7 8 . tt- It ) '1 ) G'-l - OlO · Alaska eess Unit l' -~ Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 April 16, 2004 Attention: Howard Oakland Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Hand Delivered RE: Marathon Paxton # 1 Well Data CONFIDENTIAL Enclosed are the following CONFIDENTIAL data for the above referenced well: Paper Digital Daily Drilling Report & Daily Completion Report ............................................. X....................... NA Well Completion Report.............................................................................. In Progress Directional Survey........ ....................................................................................... X ....................... ..X Pennit To Drill .................................................................................................... X ....................... NA Epoch Mud Log Data Report wi CD .................................................................... ...........................X Paper & CD of Well Logs (list of CD contents attached)................................... X .........................X I ;t~&( The DataView and ReeView viewer software for the Reeves well logs can be downloaded from their website at: httv:/Iwww.reeves-wireline.com/. Please indicate your receipt of this data by signing below and returning one copy to me at the letterhead address. Thank you, ~~~ Technical Assistant Enclosures /) / () ('(11 / j Received by: ~ ~ Date: II O~)~ ~(y..{ - 0 ((J Ft'{ L .. . .. Paxton 1 Log Data ...~:.I¡;¡~m: FINAL Marathonyaxton 1 Run 1.dpk SHUTTLE MAIN LOG.la> [!) FINAL Data_Marathon_Paxton 1 Run 2_Shuttle.dpk Paxton 1 Directional 1 final survey. doc pax1_dir Jinal.dat 57 ICB Microsoft Word Doc. . . 3 KB DAT File 3/6/2004 11 :31 AM 4/1/2004 11 :33 AM Paxton 1 Mud Log Data 2/24/2004 11 :28 PM 3/11/2004 11 :25 AM 3/11/20044:55 PM 3/11/20044:56 PM Well Report PDF Files DMLData Morning Reports Las Files File Folder File Folder File Folder File Folder File Folder 4/2/2004 1 :23 PM 4/2/2004 1 :31 PM 4/2/20042: 14 PM 4/2/20042:14 PM 4/2/20042: 15 PM _~ ":'.f ~.%F'1;-..iJl>.'-':! ' ..I ~.rJ<~#'mf ... 1" ~. !'t'Jj,r~-~·"'., 4: ¡ ""'t tiY e - FRANK H. MURKOWSKI, GOVERNOR AI,l\SIiA. ORAND GAS CONSERVATION COMMISSION Steven S. Lambe Senior Drilling Engineer Marathon Oil Company PO Box 196168 Anchorage AK 99516 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Paxton #1 Marathon Oil Company Permit No: 204-010 Surface Location: 3405' FEL, 1168' FNL, Sec. 13, TIS, RI4W, SM Bottomhole Location: 140' FWL, 2522' FSL, Sec. 12, TIS, RI4W, SM Dear Mr. Lambe: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or approvals 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. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Si/e~ ~... 10~y,~,/ ~~.Þse~unt Commissioner BY ORDER OF THE COMMISSION DATED this 2?'day of January, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1a. Type of Work: DrillŒJ Re-entry 0 . W~A I' t.fl Z-CO'f . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RedrillD 1 b. Current Well Class: Stratigraphic TestD Exploratory ŒJ ServiceD Development Oil 0 Development GasD Multiple Zone 0 Single zoneD 2. Operator Name: Marathon Oil Company 3. Address: PO Box 196168, Anchorage, AK, 99516-6168 Surface: 4a. Location of Well (Governmental Section): 3405' FEL, 1168· FNL, Sect. 13, T1S, R14W, SM Top of Productive Horizon: 465' FWL, 1802' FSL, Sect. 12, ns, R14W, SM Total Depth: 140' FWL, 2522' FSL, Sect. 12, ns, R14W, SM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 205913 16. Deviated Wells: Kickoff Depth: 250 18. Casing Program: Size Casin¡¡ 9-5/8 7 4-1/2 Hole 12.25 8.5 7 19. Total Depth MD (It): Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (It): 20. Attachments: 21. Verbal Approval: / y_ 2230114 J Zone- 4 It. 560 5. Bond: ŒJBlanket o SinglewellD 11. Well Name and Number: Maximum Hole Angle: Specifications Weight 40 26 13 Coupling AB·M AB-M AB-M Grade L-80 L-80 L-80 Length 1900 4950 5043 Bond No. 5194234 Paxton #1 6. Proposed Dept'J; MD: 9,793' TVD: 7. Property Designation: 12. Field/Pool(s): 8,000' > ADL 384372 Wildcat 8. Land Use Permit: 13. Approximate Spud Date: 15-Feb-04 /' Private Property 9. Acres in Property: 14. Distance to Nearest Property: 1,900' 3508 10. KB elevation 15. Distance to Nearest Well within Pool: 6,000' (Height Above GL): 17 feet 17. Anticipated Pressure (see 20 AAC 25.035) Max. Downhole Pressure: 3744@ TD Setting Depth Max. Surface Pressure: 1986 Quantity of Cement c.f. or sacks. (Including Stage Data) 446 sx ./' 410 sx ./'. 626 sx ,/' psig. psig. Top Bottom MD 17 17 4750 TVD 1686 3417 8000 TVD 17 17 3352 MD 1900 4950 9793 PRESENT WELL CONDITION SUMMARY (to be completed for Redrill and Re-Entry Operations) Total Depth TVD (It.) Plugs (measured) Effective depth MD (It) EffectivRFeF Length Size Cement Volume MD Steven 7 'fmbe ~__/ ./_ ~.z_. ve.UeasUred) TVD J'A' r·1 (! \1 'J R 2004 Filing Fee ŒJ BOP Sketch [U w- Oil &.GK~. COItr.1&oIioo NÌI.~:'" Perforation Depth TVD (It): Drilling program[U Time v. Depth PlotD Shallow Hazard Analysis 0 Property PlatŒJ Diverter Sketch ~ Seabed ReportD Drilling Fluid program~ 20 AAC 25.050 Requirements 0 Date: Commission Representative: Printed Name 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Senior Drilling Engineer Signature Contact Phone (907) 564-6332 January 9, 2004 Date Commission Use Only IAPI Numb~r: _ ,-<'3 ,- . .... '. permitAPproval 50-/ 3'?y- 2-D-&- ~ - DC; Date: !Xfyes DNo ~NO Conditions of approval: Permit to Drill "7 /"\(1. .~. /'" /~ Number: ~. L)/C) Samples required Hydrogen sulfide measures DYes other:T-e·~t- 'BoPE tc 3000 p5.l. Approved by: Form 10-401 Revised 3/2003 Oñglna' Signed By DAN SEAMOUNT Mud log required ) JtØi I < ~Yes Œ:(ves I See cover letter for other requirements. DNO DNo Directional survey required COMMISSIONER BY ORDER OF THE COMMISSION i tJ ¿i"Pliæ" Date: · - MARATHON MARATHON Oil COMPANY DRilliNG PROGRAM Originator: Drilling Superintendent: North America Drilling Manager: Paxton Pad Paxton #1 Revised 1/9/04 S. S. Lambe P.K. Berqa B.J. Roy Page 1 of 13 - e Table of Contents General Well Data ................................................................................................................................. ..................................3 Geologic Program Summary......................................................................................................................... ..........................3 Summary of Potential Drilling Hazards.......................................................................................................................... ..........4 Formation Evaluation Summary......................................................................................................................... .....................4 Drilling Program Summary........................................................................................................................... ............................5 Casing Program..... ........................................................................................................................................... .......................6 Casing Design .............................................................................................................................. ...........................................6 Maximum Anticipated Surface Pressure............................................. ....................................................................................6 BOP E Program....................................................................................................................... .................................................8 Wellhead Equipment Summary........... ................................................................................................................. ..................9 Directional Program Summary........................................................................................................................ ........................9 Directional Surveying Summary ............... ......................................................................................... ....................................10 Drilling Fluid Program Summary............................................................................................................................. ...............10 Drilling Fluid Specifications.......... ......................................................................... ......... ....................... ................................ .11 Solids Control Equipment............................................................................................................................ ........................ ..11 Cement Program Summary.................................................................................................................... ............... ............... .12 Bit Summary.......................................................................... ............................................................................................... .12 Hydraulics Summary................................................................................................................................... .......................... .13 Formation Integrity Test Procedure ...................................................................................................................................... .13 Page 2 of 13 General Well Data Well Name Surface Location Slot/Pad KB Elev. Ground Level Elev. Perm. Datum Water Depth W(jter Protection Depth Comments: e . Paxton #1 LeaselLicense 3405' FEL, 1168' FNL, Sect. 13, T1S, R14W, SM WBS Code Spud Date API No. Well Class Rig Contractor Rig Name DD.03.09502.CAP.DRL 2~04 (est.) /"5' Paxton Pad Field Ninilchik 217 County/Province Kenai Peninsula 200 State I Country Alaska KB Total MD .~ <}1'i~¡ NIA Total TVD 8,000' ~~" Exploitation-Gas Nabors #129 GeoloQic PrOQram Summary MD - RKB TVD - RKB Pore Pressure Pore Pressure Possible Fluid Formation (ft) (ft) (psi) (ppg) Content Glacial I Gravels 0 0 .433 8.3 Snd/Shl/Coal Water Sterling 400' 400' .433 8.3 SndlShllCoal Water Beluga 902' 895' .433 8.3 Snd/Shl/Coal Water Tyonek 4,949' 3,417' .468 90 ~ Snd/Shl/Coal Gas T-2 5,730' 4,017' .468 9.0 Snd/Shl/Coal Gas T-3 7,310' 5,517' .468 9.0 Snd/Shl/Coal Gas From Lease/Block Lines Latitude Longitude UTM North (Y) UTM East (x) Tolerance Target Top Tyonek T2 T3 TD Comments: Surface Location Coordinates 3405' FEL, 1168' FNL, Sect. 13, T1S, R14W, SM N 60 540.833 W 151 36 40.408 2230114 205913 Depth Horizontal Displa~ment (ft) MD TVD +N/-S +E/-W Tolerance (ft) (ft) Location (Y) (X) (ft) 4,949' 3,417' 465' FWL, 1802 FSL, Sect. 12, T1S, R14W, SM / 2865 -1336 Circle 250' radius 5,730' 4,017' 140' FWL, 2522 FSL, Sect. 12, T1S, R14W, SM / 3314 -1545 Circle 250' radius 7,310' 5,517' 140' FWL, 2522 FSL, Sect. 12, T1S, R14W, SM 3703 -1727 Circle 250' radius 9,793' 8,000' 140' FWL, 2522 FSL, Sect. 12, T1S, R14W, SM 3703 -1727 Circle 250' radius Page 3 of 13 e e Summary of Potential Drillinç¡ Hazards Hazard Event Lost Circulation Differential Sticking Discussion Sized Calcium Carbonate as Required Maintain Mud Weights below 10 ppg Comments: Potential Hazards Statement To comply with state regulations the Potential Hazards section and the well shut-in procedures must be posted in the drillers dog house. The man on the brake (driller or relief driller) is responsible for shutting the well in (BOPE or diverter as applicable) as soon as warning signs of a kick are detected and an influx is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC inspector. This well's primary objective is gas and no oil sands are expected to be encountered. No H2S is anticipated. í/ '" Gas sands will be encountered from +1- 4,949' MD (3,417' TVD) to total depth of the well. These sands will run normal i/ pressured, lost circulation and differential sticking are potential hazards. The Flo-Pro mud system that will be used to drill the well will help reduce these risks and lost circulation materials will be on location. No well interference hazards exist. / Formation Evaluation Summary Interval LWD Surface None 0' -1,900' MD Intermediate None 1,900' - 4,950' MD Production None 4,950' - 9,793' MD Completion N/A Electric Logs CH - Neutron/GR. Acquired wI OH Logs Mud Basic with GCA, shale density, temperature in and out, sample collection (10' samples). Basic with GCA, shale density, temperature in and out, sample collection (10' samples). Basic with GCA, shale density, temperature in and out, sample collection (10' samples). N/A CH - Neutron/GR. Acquired wI OH Logs Reeves Quad Combo GR, CCL Coring Requirements: None Comments: Page 4 of 13 e e Drillina Proaram Summary CONDUCTOR: 1. 2. 3. 4. 5. Drive 20" conductor to +1-100 ft. RKB. Move in and rig up rotary drilling rig. Install starting head 20" SOW x 21 1/4", 2M flanged. /' Nipple up 21 1/4", 2M diverter, 16" diverter valve, and 16" diverter line. Function test diverter and diverter valve. SURFACE: 1. 2. Drill a 12-1/4" hole to 1,900' MD (1,686' TVD) per the directional plan. RIH with 9 5/8" casing and hang off in the slips. Make up stab-in sub and centralizer on 4" drill pipe. TIH with inner string and latch into stab-in float collar. Cement 9 5/8" casing. Sting out and circulate drill pipe clean. TOOH with inner string. /' PU 9 5/8" casing, set casing slips in 20", cut off 95/8", ND diverter. Install 9 5/8" slip lock connection X 9 5/8" 5M flanged multibowl wellhead. / NU 135/8" 5M BOP'S. Test BOP'S and choke manifold to 250/3,000 psi. Set wear bushing. Test surface casing to 1,000 psi. 3. 4. 5. 6. 7. INTERMEDIATE: 1. 2. 3. 4. 5. 6. 7. Drill out float equipment and make 20' of new hole. CBU. Displace the hole with new mud. Te?shoe to leak off. Estimated EMW is 15.5 ppg. Drill 8 1/2" directional hole to 4,950' MD (3,417' TVD) as per directional plan. Make wiper trips as necess/, Change out variable pipe rams with 7" casing rams. Run test plug and test casing rams to 3,000 psi. Run and cement 7" casing. Land hanger in multibowl wellhead. Back out landing joint. Change out 7" casing rams with variable pipe rams. Run test plug and test pipe rams to 250/3,000 psi. /" Set wear bushing. Test casing to 3,000 psi. / PRODUCTION: 5. 6. Drill float equipment and 20' of new formation wI 6" x 7" DOSRWD system. CBU. /' Displace the hole with new mud. Test shoe to leak off. Estimated EMW 15.5 ppg. Drill a 7" hole to 9;æ~f MD (8,000' TVD) per the directional program. TOOH. RU logging company. Run open hole logs drill pipe conveyed as per plan.' Logging BHA will be configured to wipe hole on the logging pass. RD logging company. TOOH and laydown BHA and 5,000' of drill pipe. Pull wear bushing. Run 4 1/2" Hydril 521 casing liner with hanger and liner hanger packer on drill pipe to TD. On bottom reciprocate liner while /' circulating the hole. Set liner hanger at approximately 4,750' MD. Cement casing as per the attached cementing program, while rotating liner, displacing cement with gelled KCI. Ensure circulation of cement to above top of liner. Bump plug with 500 psi over displacement pressure. Set liner hanger packer, disconnect from liner, circulate hole clean. TOOH. PU mill for 4 1/2" along with string mill for 7" casing. Make cleanout trip to top of 4 1/2" liner with mill combo on drill pipe. Polish 41/2" liner seal bore. TOOH laying down. Run 4 1/2" tubing with seal unit. Displace hole with 6 % KCL. Space out tubing and land hanger. ND BOP, NU tree and test to 5,000 psi. Rig down and move out drilling rig. J 1. 2. 3. 4. 7. 8. 9. 10. 11. COMPLETION: Completion will be done without a rig. Page 5 of 13 · e Casing Program MD (ft) Connection API Ratings Q) c:: Casing / / Makéup "§ ~=- 0 Ciì ïñ ro C/) ïñ a. Size Weight O. D. Torque Hole Size :::J .e: = a. c:: g I1J o~ Q) (in) Top Bottom (Ibs/ft) Grade Type (in) (ft-Ibs) (in) Ü ~ 20" 0 100' 133 X-56 Welded 20" 9-5/8" 17' 1,900' 40 L-80 Buttress 10.625 Mark 12.25 5750 3090 916 7" 17' 4,950' 26 L-80 Buttress-M 7.656 Mark 8.5" 7240 5410 604 4-1/2" 4,750' 9,793' 12.6 L-80 Hydril 521 4.73 8,000 7" 8440 7500 289 Comments: * The make up of the buttress connection will be to the proper marlc Make-up torque shown for the Hydril 521 is 50% of yield. The final make up torque for the liner should be above any potential torque that would be used to release the running tool from the hanger. See liner running procedure for more details. Casing Design Casing Size (in) 9-5/8" Weight (Ib/ft) 40 26 12.6 Casing Shoe Sëtting Mud Wt Frac. Form Depth When Set Grad Press (TVD) (Ib/gal) (Ib/gal) (Ib/gal) L-80 1686 9.2 15.5 8.3 860 L-80 3417 9.4 15.5 9.0 / 1,986 L-80 8000 9.6 / 15.5 9.0 1,986 7" 3.57 2.39 2.21 2.43 2.88 1.88 3.97 2.92 1.86 4-112" Comments: Maximum Anticipated Surface Pressure Setting Dépth Casing Size TVD MAWP * (in) (ft) (psi) 9-518" 1686 3,946 7" 3417 4,837 4-1/2" 8000 4,837 * MAWP = Maximum allowable working pressure ** MASP = Maximum anticipated surface pressure MASP ** Mud/Gas (psi) Ratio 860 30170 1,986 30170 1.986 / 30170 Comments: Page 6 of 13 · e MASP I MAWP CALCULATIONS: Surface casinQ: 9 5/8" (1.900' MD. 1,686' TVD) MASPfrac = «(Fracture gradient at shoe + SF) x .052 X TVDshoe) - Hydrostatic pressure of gas column at the shoe. MASPfrac = (15.5 ppg + 0.5 ppg) x .052 x 1,686' - (.1 psilft x 1,686') MASPfrac = 1 ,403 psi - 169 psi MASPfrac = 1,234 psi. MASPbhp = BHPopen hole td - Hydrostatic pressure of mud portion - Hydrostatic pressure of gas portion MASPbhp = (9.0 ppg x .052 x 3,417') - (0.3 x 9.4 ppg x .052 x 3,417') - (0.7 x 0.1 psilft x 3,417') MASPbhp = 1,599 psi - 501 psi - 239 psi MASPbhp = 860 psi MASP = MASPbhp = 860 psi MAWP = (0.7 x Casing Burst) - (Mud WI. - Backup Fluid WI.) x .052 x TVD MAWP = (0.7 x 5,750) - (9.2 - 8.3) x .052 x 1,686' MAWP = 4,025 psi - 79 psi = 3,946 psi / Intermediate casinQ: 7" (4,950' MD, 3,417' TVD) MASPfrac = «Fracture gradient at shoe + SF) x .052 X TVDshoe) - Hydrostatic pressure of gas column at the shoe. MASPfrac = (15.5 ppg + 0.5 ppg) x .052 x 3,417' - (.1 psi/ft x 3,417') MASPfrac = 2,843 psi - 342 psi MASPfrac = 2,501 psi. MASPbhp = BHPopen hole td - Hydrostatic pressure of mud portion - Hydrostatic pressure of gas portion MASPbhp = (9.0 ppg x .052 x 8,000') - (0.3 x 9.6 ppg x .052 x 8,000') - (0.7 x 0.1 psilft x 8,000') MASPbhp = 3,744 psi - 1,198 psi - 560 psi MASPbhp = 1 ,986 psi MASP = MASPbhp = 1,986 psi / MAWP = (0.7 x Casing Burst) - (Mud WI. - Backup Fluid WI.) x .052 x TVD MAWP = (0.7 x 7,240) - (9.6 - 8.3) x .052 x 3,417' MAWP = 5,068 psi - 231 psi = 4,837 psi Production liner: 4 1/2" (TOP - 4,750' MD, 3,288' TVD) (BOT - 9,792' MD, 8,000' TVD) MASP = MASP?" = 1 ,986 psi MAWP = MAWP7" = 4,837 psi / Page 7 of 13 e BOPE Program Casing Casing Size (in) Casing Test Test Fluid Press Density (psi) (Ib/gal) MAWP (psi) MASP (psi) Surface 95/8" 2,328 860 1,000 9.2 Intermediate 7" 4,837 1,986 3,000 9.4 Production Liner 4%" 4,837 1,986 3,000 9.6 Comments: Blowout Preventers e BOPS Size & Rating (1) 13-5/8" 5M annular (1) 13-5/8" 5M pipe ram (1) 135/8" 5M blind ram (1) 13-5/8" 5M drilling spool with 3-118" 5M outlets (1) 13-5/8" 5M pipe ram (1) 13-5/8" 5M annular (1) 13-5/8" 5M pipe ram (1) 13 5/8" 5M blind ram (1) 13-5/8" 5M drilling spool with 3-118" 5M outlets (1) 13-5/8" 5M pipe ram (1) 13-5/8" 5M annular (1) 13-5/8" 5M pipe ram (1) 13 5/8" 5M blind ram (1) 13-5/8" 5M drilling spool with 3-118" 5M outlets (1) 13-5/8" 5M pipe ram Test Pressure Low/High (psi) 250/3,000 /' 250/3,000 __ 250/3,000 ~ The blowout preventer stack will consist of a 13-5/8" x 5000 psi annular preventer, a 13-5/8" x 5000 psi double gate ram type preventer / with blind rams in the bottom and pipe rams in the top, a 13-5/8" x 5000 psi drilling spool (mud cross) with 3-118" x 5000 psi outlets, and a 13-5/8" x 5000 psi single pipe ram. The choke manifold will be rated 3-118" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor-boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mud pits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. Casing Test Pressures Casing test pressures are based on the lesser of (1) MASP, or (2) 70% of rated burst pressure of the casing adjusted for the mud weight used during the test less a 8.3 ppg back-up unless otherwise noted. Page 8 of 13 e e Wellhead Equipment Summary Component Casing Head Tubing Head Adapter Flange Comments: Description ABB Vetco Gray MB 150 Split Multi-Bowl System, 9-518" Slip Lock X 11" #m 11"3Mx11"5M 11" 5M x 4-1/2" 5M Casing Hanger Type 11" x 7" Fluted Mandrel 11" x 4 1/2" Mandrel Directional Program Summary Sec. No. Description KOP 2 End of Build 3 End of Hold End of Drop TO 6 7 8 9 Comments: Build Turn Coordinates MD TVD Rate Rate Dogleg Inclination Azimuth +N/-S +El·W (ft) (ft) (°/100') (°/100') (°1100') (deg) (deg) (ft) (ft) 250' 250' 0 0 0 0 335 0 1,900' 1,686' 2/4 0 2/4 56 335 592' -276' 4,517' 3,150' 0 0 0 56 335 2,559' -1,193' 7,318' 5,525' -2.0 0 2 0 335 3,703' -1,727' 9,793' / 8,000' ~ 0 0 0 0 335 3,703' -1,727' VS (ft) Potential Well Interference: Vertical section calculated from a reference azimuth of 43.01° taken from surface location to bottom hole location. None Page 9 of 13 " " ~ ~ 0 0 0 0 0 ~ V> .,s +' p. '" ¡ Q '¡¡j <..> ~ '€ '" ~ ;> '" ~ 0 '" e / Vertical Section at 335.00° [3000ftlin] Directional Survevina Summary Interval 0-1,900' 1,900' - 4,950' 4,950' - 9,973' MWD Survey X X X Magnetic Multishot Comments: Drillina Fluid Proaram Summary Interval- TVD From To (ft) (ft) Density (Ib/gal) 8.6 - 9.2 Fluid Description o 1,515 Gell Gelex Spud Mud 1,515 4,940 9.0 - 9.4 6% Flo-Pro wI Safecarb 4,940 7,991 9°9 6% Flo-Pro wI Safecarb Comments: e West(-)/East(+) [I 500ft/in] Gyro Multishot Comments Additives Gel, Gelex, Soda Ash, Caustic, Barite, Polypac Supreme UL Flo-Vis, Poly Pac UL. KCI, SafeCarb F&M, Asphasol Supreme, Lubetex, KlaGard, Caustic, Conqor 404, SafeScav NA Flo-Vis, DualFlo, KCI, Greencide 25G, SafeCarb F, KlaGard. Barite, Caustic, Conqor 404, SafeScav NA Minimum Inventory Vis~~ifier I Barite See mud prognosis for details. Sized CaC03 (SafeCarb) will be used to controlleakoff into the theif zones. Page 10 of 13 e e Drillin~ Fluid Specifications Interval- TVD LSRV From To Density Vis 1 min PV (ft) (ft) (Ib/gal) (seclqt) (lb./100tr) (cP) 0 1,686 8.6 - 9.4 60 - 100 1,686 3,417 9.0 - 9.4 40,000 8 - 14 3,417 8,000 9.2 - 9.6 ,/ 40,000 10 - 14 Comments: YP Fluid Loss Drill Solids (lb/100 tr) (cc) pH (%) 25 - 35 NC - 12 +1- 9.5 <7 8 - 10 +1- 9.5 +1- 5-8 <5 +1- 9.5 +1- 5 Solids Control Equipment c 0 Q) ~ CD ~ e> ~ Q) (\ ~ c Q) 0 :s .c (\ C> () '0 ~ Q) .2 rJ) rJ) rJ) ~ c Ü C> C> i:5 .>:: (\ .¡:: c c (\ rJ) ,j) '0 ë :¡:¡ :¡:¡ 0 .c Q) Q) :J Q) '5 '5 ~ Interval en 0 0 :2: Ü Ü Ü N Comments 0- 9,793' MD X X X Closed Loop System, Full Containment Item Shaker Desander Desilter Mud Cleaner Centrifuge Cuttings Dryer Cuttings Injection Zero Discharge Comments: Equipment Sþecific:átions (quantity, design type, brand, model, flow capacity, etc) 2 - Derrick Model 2000 Liner Motion Shakers N/A N/A Derrick Model 200 Flowline Cleaners 2 - Ml/Swaco units N/A Marathon G&I Facility N/A The solids control equipment will consist of two flowline cleaners, a desilter, and the MI centrifuge van. Included will be equipment to de-water the underflow from the mud processing equipment to allow for disposal of the cuttings and solids by slurrification and injection into the disposal well at the KGF. ./ Page 11 of 13 e e Cement Proaram Summary Depth Gauge Top of Cement Open Casing Hole Ann Vol Slurry WOC Hole Size MD TVD Size MD TVD To TOC Vol Time Excess (in) (ft) (ft) (in) (ft) (ft) (ft3) (ft3) (hrs) ('Yo) 95/8" 1,900 1,686 12.25 0 0 710 1,116 8 50 7" 4,950 3,417 8.5 1,500 1 ,420 438 850 12 50 4 )1," ~ 8,000 7.0 4,750 3,352 819 1,120 12 35 Caliper +35 'f 1~ ~. ÍJ.I GI\- Mix Water Compressive Casing Slurry TOC Str~l)gth Size Density Qty Yield Vol MD Qty WL FW (psi) (in) Slurry Cement Description (lb/gél) (sx) (ft3/sx) (ft3) (ft) (gal/sx) Type (cc) ('Yo) 8 hr 24hr Lead Surface 12 446/ 2.5 1,116 0 10.84 Fresh 812 0 500 95/8" Tail 0 Lead 12.5 270 2.23 600 1500 9.74 Fresh NIA NIA NIA NIA 7" Tail 13.5 140 1.83 250 3950 9.25 Fresh N/A NIA N/A N/A Lead 12.8 626 1.79 1,120 4750 5.8 Fresh NIA N/A NIA N/A 4 )1," Tail 0 Comments: See cement prognosis for details and spacer specifications. Bit Summary Interval - MD From To (ft) (ft) o 1,900 1,900 4,950 4,950 9,793 Type Recommended Estimated Size WOS Rotating ROP (in) Manufacturer Model No. IADC (kips) RPM Hours (ftIhr) 12.25 Christensen MX-1 117 1 - 4 80 - 350 8.5 Christensen DP0622 PDC M223 2-5 80 - 300 7 Christensen DOSRWD46.000 M233 3-5 100 - 350 Comments: The DOSRWD is a 6" (pass through) x 7" (reaming) configuration. It has a 4 0/.," pilot PDC bit HCM404 (IADC M233). See bit prognosis for additional information. Page 12 of 13 Hydraulics Summary Rig mud pumps available are shown below. e e Max Press @ Displacement @ Liner 10 Stroke 90% WP 95% eff Max Rate Hole Sections Used Qty Make Model (in) (in) (psi) (gallstroke) (spm/gpm) On Gardner 5 9 3,600 2.29 175 I 357 All 2 PZ9 Triplex Denver 5 9 3,600 2.29 175 I 357 All Tabulated below are the expected flow rates, standpipe pressures and nozzle sizes for each hole section. Hole DepthcMD Size Pump Rate (ft) (in) (gpm) o - 1,900 12.25 800 1,900 - 4,950 8.5 530 4,950 - 9,793 7 316 Comments: See separate hydraulics calculations. Formation Intearity Test Procedure Standpipe Min Nozzle Pressure AV ECD Size (psi) (fpm) (Ib/gal) (32"s) Remarks 3 - 18's Hughes Christensen Calculations 3,000 146 1 - 15 7 - 11's Hughes Christensen Calculations 2,980 231 4 -10's 2,715 235 2 - 11 's in Hughes Christensen Calculations RWD / Surface and Intermediate casing shoes will be tested to Leak-off. Prior to drilling out of casing strings, test BOPs and casing to the specified pressure listed in the BOP Program section. Plot test and record volume required on the drilling report. Leak-off tests (LOT) are to be conducted as described below: 1. Drill 20' to 25' of new formation below the casing shoe and condition the mud to the same properties in and out. 2. Pull drill string into the casing shoe and close ram preventer, and line up to the choke manifold with a closed choke. 3. Begin slowly pumping fluid down the drill string at 1/2 bpm while recording casing and drillpipe pressures at 1/2 bbl intervals. A running plot of pressure versus volume should be kept by the drilling foreman while the test is in progress. 4. Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the IADC and morning reports. 5. Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes. Page 13 of 13 e ~I r- r-- , I i \ - - ~ ~~ ~,.,~ ":w '1''6 ~ d}1~ .J ::;~ IFH,~ ~ 1\ ~~f ~h >{~~~ /\ /\ yw 0.. r::( ~=~JUJ ] [£JI~~^']~ ,---, , , 'Ž e NABORS ALASKA RIG 129E GENERAL ARRANGEMENT ] D B I. DIVfI!1ER ANNfJIAR HORIIAU.Y OP£N. 2. RiW-VAlIo£' NORI/A/lY GtOSëD. f , 1 I '-.-.-., """ . IV .cctAUAltII' HYDIIfI.IISP r-'--'- '~' -..-..--';,...... I ANIMAR ~ : ! ~ '.-- ~ I ¡-.;..-..- \ ' ! i I ,.---1: .,..-1 I 9111 I ~~ ~-+-:wu -~ ~ 1_-VALIo£' 16'~' 66 ~ VALlo£' ANSI ISO FWIGES " DNER1ER SPOOl. N'f 2/ '/~'-2OOOPSI FWIŒS [ '-~ ] ~J ] ] ~.~ ~~ DIVERTER CONFIGURATION ] ==" [J F=; !'&IIêlDl'l.r'LZ~~ ., 8Na6anNalla ~""c=~,~ .___.... ~#~ MQJ-2tJi ........ NABORS ALASKA RIG /29 mu: GÐIEFW.. ARfWIGEJIENf 12' DMR1EI1 MIDI 21CC111J A JA p.s. I/!1IJfIE1I ØIÐ!II1I (II- IN; ,1-1/,. MMANI) - 'I!w IUD l"'"'%r SIIrH 1-" AU SI/IIH ,.... A "'" 'II!: 'II' 7- - k.u N/A.... J/28/OJ - NO- 129_0001 ""i 0/ I ( , '\ \ e IJ-5/8" 5000# HYDRIL DOUBLE GlTE' PR£'ÆNTOR 1J-5/8" 50001 WP \ FlANGED TOP AND BOTTOM HeGHT = 54" J ) 9'-':¡" / ~ ~ ,1/ ; . HYDRAUL ACTUATE'D J-1/16" 10,0001 WP \ / GlTE' VALVE \ J" CHOKE UNE - - ....'LY ""'""" ~ 7 J-1/16" 5,0001 WP ~ GlTE' VALVE e NABORS ALASKA RIG 129 BOP STACK CONFIGURATION 1J 5/8" 50001 ./ WP HYDRIL, TYPE "GK" / 1J 5/8" 50001 WP SCREWED TOP BY IJ 5/8" FlANGED BOTTOM ANNUlAR BOP HeCHT = 51.25" MANUALLY OPERATED 2-1/16" 5,0001 WP GlTE' VALVE MANUALLY OPERATED / ~2-1/16" 5,0001 WP ~ GlTE'VALVE - - 2" KILL UNE I J-5/8" 50001 API FlANGED TOP AND BOTTO/.l /.IUD CROSS W/ ONE (I) 4-1/16" (CHOKE UNE) & ONEil) J-1/16" (KILL UNE) 5,000 API FlANGED OUTtErS I6OECOJ A JA. P.S. _""'STACKI'fR_~_ ... '11[''1'''':"- -- =:A~m".~~~'" -".",AIGfIrø =-c -= '::',:'. .... .__--.. ~, Na.ka moJ-2OJt to7-283-aooo NIJJIJRS AlASKA RIG /29 Il.owour PRfVEP/T£R STACK CONF1GURAnOll -.& I/S1rIN ,......PAIl'SII/H ,-" PAI.l SII/H I""'· A ~ ~ ~~ H N/A ocr 200J 129_0002 1« 1 ....... 1i1t.£ ~'6' MUO MIX HOPPER 6~' MUD MIX 2 ~ HOPPER 6' 6' 6' ~ I .. ~~ . DISCHARGE MANIFOLD . . 6' iNI- 6t . LEGEND -0- CONCENTRIC REDUCER - GATE VALVE -INJ- BUTTERFLY VALVE C/W FLANGES -g- -;;¿ SUCTION VALVE, TEE TYPE SUCTION VALVE, ELL TYPE , ~ DESIL TER 6' ,+n~~ ~~ 6,j2{~' 6' 6' º6' X º6' º º 8' 8' º ~;, º ~J' a 6'.8' .~J' . ® BOTTOM MUD GUN LOW PRESSURE TYPE NABORS ALASKA RIG 129 MUD SYSTEM SCHEMATIC NOT SHOWN ARE TANK CLEANOUTS SUMP SUCTION OR STEAM LINES / ~ '~'I" ~ I TO SUMP !F~, ~'---J~ I~' X 6' 6' º .. X . º 6' 6'X º . S¿ 8' ~ ~J' ~J' .. . . 8" FLOW LINES TO MUD PUMPS ~ AGITATOR I TOTAL ACTIVE VOLUME = 1183 BbIS. TOTAL GROSS VOLUME = 1470 Bbls. ~K EQUALIZER ~ b~ SKIMMER ACTIVE EQUALS VOLUME TO BOTTOM OF MUD DITCH GROSS EQUALS VOLUME TO FULL HEIGHT OF TANK ( NOT INCLUDING TRIP TANK) I1fF: HOOGSCN /NDUSTRfAL ~ LIII. DWG. NO. RJ052-115 .... . (2\. · !F ~!--=;rrl 1 0 · o o'~o,L- º'l}t. s<'" L ~J' .. II "II'- "If WELL RETURNS "t,,· .. .. 8' . , ~ I SHALE SHAKE~ r-:HALE SHAKER L~J 6' ~ , . JJ' J' ~t;I MANIFOLD n\ 8":W' 36" MUO GAS SEPARATOR . 6'. J' J' D----!HJ-- TRIP TANK . TO FLARE . ~ ........ 11II ê 'aJI'.l &'M~w....""'U'I" AlMan'" =-ç-=,=~' .." An. ~ ... . ~'t-m::.='" -.... NABORS AlASKA RfG 129 MUD S\'SlDt SCl/OOTTC 118J BII. AC1M" MIDI -oil A!S!t1N """'M SIIII/ ~....... If _ SIIII/ ,..... _ !CIU M'I( NO. SMf. N/A _ 200J 129_1JOOJ I of I ...... """ e e SURFACE USE PLAN FOR PAXTON #1 WELL Surface Location: NE 1/4 of NW 1/4, Sec. 13, T1S, R14W, S.M. v 1. Existing Roads The Sterling Highway will be used for access to the Paxton #1 well and is shown on the attached map. Ninilchik, Alaska is the nearest town to the site. 2. Access Roads to be Constructed or Reconstructed A new drilling pad will be construct to facilitate the drilling of the wells. The access road to the pad is existing. Gravel from a local pit will be used to build the pad. 3. Location of Existing Wells There are no existing wells in general area of the location. The nearest well reside on the Susan Dionne pad located approximately 2 miles to the North. -' 4. Location of Existing and/or Proposed Facilities No facilities are proposed at this time. 5. Location of Water Supply A new water well will be drilled to a depth as not to interfere with local domestic water users. The well will be used for the water based mud system. 6. Construction Materials No materials are required. 7. Method of Handling Waste Disposal a) Mud and Cuttings Cuttings will be dewatered on location. The cuttings and excess mud will be ¡ hauled to Pad 41-18 in the Kenai Gas Field for disposal into Well KU 11-17, a Class 1/ disposal well (AOGCC Disposal Injection Order No.9, Permit #81-176). M:\Wells\Ninilchik\Paxton #1 \Paxton#1 SURFUSE.doc Surface Use Plan Paxton #1 Well Page 2 e e b) Garbage All household and approved industrial garbage will be hauled to the Kenai Peninsula Borough Soldotna Landfill. c) Completion Fluids Clear fluids will be hauled to Pad 34-31 of the Kenai Gas Field and injected ¡,/ in Well WD #1, an approved disposal well (AOGCC Permit #7-194). d) Chemicals Unused chemicals will be returned to the vendor who provided them. Efforts will be made to minimize the use of all chemicals. e) Sewage Sewage will be hauled to the Kenai sanitation facility. 8. Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four trailer house type structures will be required for this purpose. Bottled water will be used for human consumption. Potable water will be obtained from the water well on the pad. S & R will collect and transport sanitary wastes to their ADEC approved disposal facility. No additional structures will be necessary. 9. Plans for Reclamation of the Surface Reclamation of the pad, if required by the landowner, will occur after abandonment of all wells. 10. Surface Ownership Spencer Paxton Estate is the surface owner of the land at the Paxton #1 well site. 11. Operator's Representative and Certification I hereby certify that I, or persons under my direct supervision, have inspected the proposed drill site and access route; that I am familiar with the conditions that currently exist; that the statements made in this plan are, to the best of my knowledge, true and correct; and that the work associated with operations proposed M:\Wells\Ninilchik\Paxton #1\Paxton#1 SURFUSE.doc Surface Use Plan Paxton #1 Well Page 3 e e herein will be performed by Marathon Oil Company and its contractors and subcontractors in conformity with this plan and the terms and conditions under which it is approved. This statement is subject to the provisions of 18 U.S.C. 1001 for the filing of a false statement. Date: January 09, 2004 j J_ _ /' /. Name & Title: ~~ /--- -- Marathon 011 Company P. O. Box 196168 Anchorage, Alaska 99519-6168 (907) 564-6332 Senior Orillinq Enqineer M:\Wells\Ninilchik\Paxton #1 \Paxton#1 SURFUSE.doc R 14 T 1 o 3 COOK INLET, ALASKA January 2004 o:freehand\Ninilchik\ninpax1Igc.FH 1 0 N DRAWlMCNUIo!ØER REFERENcr DRAW]NG~SO¡IPflOM ACCESS ROAD LATERAL TO ,,;:e;" " " " " / / I I I I I I I I I I I I I I I I I I I \ \ \ \ \ \ OVERALL SCALE: 1";4Ø' SITE PLAN PAXTON PAD MEV {loUt BY CI« REVISIONS DESCRIPTION OAT[ BY CHK REVISIONS CEsælPTION r~~~~REV 81/13,^,W 81/IJ ......W REVISED PER ClIENTCOMMENT5 I$SUE FOR INrnM. REVIEW "W"" ~~:&!~5~ Alaska Anvil Inc. A,"..JoI>No.:MJi:2ItB = rTm~":'7f,!J/fJ 1141 ENG.AI'PROV"l BY DATE PROJECT WW STRUCT. .11M PROCESS WECHAN. RPa ELECT. ¡(OC !NS"TRUM.JJH ARCH N/A r.!!s BJJ "'. "'. I NOTES e lEGEND 5' -ø" MINIMUM ENGINEERED FILL REQUIRED e (.M.') Marathon MAR"'.ON Oil Company . Alaska R~Qn NINILCHIK, ALASKA NINILCHIK DEVELOPMENT PAXTON PAD PRELIMINARY OVERALL SITE PLAN PAXTON PAD ;~~11~1~1~~1'~1 ;~I 0~~'21~;1 ; ""~ ,":..- w.o. NO. ~ /' DRAINAGE RAVINE (TO INLEr) / ~ /"" / / ¿Y Á'/ ð /0'< " ~ / / / ./ /' /' /' /' /' / / / "" / 'v FUTURE GRAVEL PIT AREA -- /' /' < "" "" "" ACTIVE GRAVELPfT /1 ./ ~ '"', / LIMITS ÖF SEASorjAL D,RAINAGEqHAN~EL .. ' ..1' -4' DEEP f : I' f (FLOyVING i30UrH T9' NORlH) ~ SC, o I FE e I ) e :) : I 'i I¡ i II II if NOTE 1 BASIS OF COORDINATES IS NGS MONUI T'HE STERLING HIGHWAY, LATITUDE AND I o - 400 - BOO - 1200 - 1600 - 2000 - 2400 - ..--... 2800 - -+- <1> <1> '+- '--" 3200 - ...c -+- 0... <1> 3600 - 0 0 4000 - Ü -+- L <1> > 4400 - <1> :J L 4800 - l- I V 5200 - 5600 - 6000 - 6400 - 6800 - 7200 - 7600 - 8000 - e MARATHON un----e Oil Company Structure : Paxton Pod Well: Pxtn 1 Location: Kenai Peninsula. Alaska '" . ! Field : Exploration 0.00 KOP o 2.00 4.00 o 6.00 8.00 10.00 16.00 20.00 24.00 28.00 32.00 36.00 44.00 9 52.00 ~ 56.00 OLS: 2.00 deg per 1 DO It 335.00 AZIMUTH 4086' TO TD OLS: 4.00 deg per 1 DO It 4 5/8 Casing EOC TRUE TANGENT ANGLE 56.00 DEG 56.00 54.00 50.00 46. 0 42.00 38.00 34.00 32.00 30.00 28.00 26.00 24.00 22.00 20.00 18.00 16.00 14.00 12.00 10.00 8.00 6.00 . 4.00. 2.00 0 0'.00 · OLS: 2.00 deg per 100 It End of Drop ---- WELL PROFILE DATA ---- / POlr'll ----- MD ,", Oir 1VO North East V...Sec'Í Deg/1 00 / Tíe on . 0.00 0.00 D.DO 0.00 0.00 0.00 0.00 0.00 End of rum 250,00 0.00 335.00 250.00 0,00 O.DO 0.00 0,00 End of Build 750.00 10.00 335.00 747.47 39.44 -18.39 43.52 2.00 End of Build 1900,00 56.00 335.00 1686,24 591.97 -276.04 653.17 4.00 End of Hold 4517.63 56.00 335.00 3150.00 2558.76 -1193.17 2823.28 0.00 End of Drop 7317.63 0.00 335,00 5525.02 3703.27 -1726,86 4086.10 2.00 T.D. de End of Hold !?~6 D.DO 335.00 8000.00 3703.27 -1 726.86 4086.10 0.00 TO o 400 800 1200 1600 2000 2400 2800 3200 3600 Vertical Section (feet) -> Azimuth 335.00 with reference 0.00 N, 0.00 E from slot #1 MARATHON <- West (feet) 2000 1600 1200 800 400 o 1/2 Liner T -3 Target T-2 Target 4000 - 3600 - 3200 - 2800 ^ - 2400 I Z - 2000 0 , -+- ::r ..--... - 1600 ..., () () -+- '--" - 1200 - 800 - 400 - 0 Top Tyonek 7 Casing ~ U' ·0 o ~ Tyonek T -2 Target 9 5/8 T -3 Target TARGET ANGLE 0.00 DEG J.b 4 1/2 Liner Created by bmíchoel Date plotted: 6-Jon-2004 Plot Reference is Pxtn Ver 4, 4000 4400 Coordinates ore in feet reference slot #1. True Vertical Depths are reference Est RKB (NI29). mil. Bt.IS~ES INTEQ · e MARATHON Oil Company Paxton Pad Pxtnl slot #1 Exploration Kenai Peninsula, Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref Our ref License Pxtn 1 Ver prop5336 Date printed Date created Last revised 6-Jan-2004 13-Nov-2002 6-Jan-2004 Field is centred on n60 48 21.994,w150 49 18.963 Structure is centred on 209346.057,2231200.156,999.00000,N Slot location is n60 5 40.843,w151 36 40.408 Slot Grid coordinates are N 2230114.000, E 205912.999/ Slot local coordinates are 1168.56 S 3405.90 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North 1/ e MARATHON Oil Company Paxton Pad,Pxtnl Exploration,Kenai Peninsula, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 0.00 100.00 200.00 250.00 350.00 450.00 550.00 650.00 750.00 800.00 4.00 6.00 8.00 10.00 12.00 900.00 1000.00 1100.00 1200.00 1300.00 16.00 20.00 24.00 28.00 32.00 1400.00 1500.00 1600.00 1700.00 1800.00 36.00 40.00 44.00 48.00 52.00 1900.00 2000.00 2500.00 3000.00 3500.00 56.00 56.00 56.00 56.00 56.00 4000.00 4500.00 4517.63 4617.63 4717.63 56.00 56.00 56.00 54.00 52.00 4817.63 4917.63 4948.73 5017.63 511 7.63 50.00 48.00 47.38 46.00 44.00 5217.63 5317 .63 5417.63 5517 . 63 5617.63 42.00 40.00 38.00 36.00 34.00 5717.63 5729.51 5817.63 5917.63 6017.63 32.00 31.76 30.00 28.00 26.00 6117.63 621 7 . 63 6317 . 63 6417.63 6517.63 24.00 22.00 20.00 18.00 16.00 0.00 0.00 0.00 0.00 2.00 0.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 0.00 100.00 200.00 250.00 349.98 449.84 549.45 648.70 747.47 796.54 893.55 988.64 1081. 34 1171.20 1257.79 1340.67 1419.46 1493.76 1563.21 1627.47 1686.24 1742.16 2021. 76 2301.35 2580.95 2860.55 3140.14 3150.00 3207.35 3267.53 3330.46 3396.06 3417.00 3464.26 3534.97 3608.10 3683.57 3761.28 3841.14 3923.05 4006.91 4017.00 4092.62 4180.08 4269.18 4359.80 4451. 85 4545.20 4639.75 4735.37 R E C TAN G U L A R COO R DIN ATE S 0.00 N 0.00 N 0.00 N 0.00 N 1. 58 N 6.32 N 14.22 N 25.27 N 39.44 N 48.09 N 70.01 N 98.01 N 131.96 N 171.68 N 216.98 N 267.65 N 323.44 N 384.07 N 449.25 N 518.67 N 591. 97 N 667.11 N 1042.79 N 1418.47 N 1794.16 N 2169.84 N 2545.52 N 2558.76 N 2633.00 N 2705.38 N 2775.81 N 2844.20 N 2865.05 N 2910.48 N 2974.56 N 3036.37 N 3095.83 N 3152.86 N 3207.40 N 3259.38 N 3308.74 N 3314.43 N 3355.42 N 3399.35 N 3440.50 N 3478.80 N 3514.21 N 3546.68 N 3576.19 N 3602.69 N 0.00 E 0.00 E 0.00 E 0.00 E 0.74 W 2.95 W 6.63 W 11. 78 W 18.39 W 22.43 W 32.65 W 45.70 W 61. 53 W 80.06 W 101.18 W 124.81 W 150.82 W 179.10 W 209.49 W 241.86 W 276.04 W 311. 08 W 486.26 W 661. 45 W 836.63 W 1011.81 W 1186.99 W 1193.17 W 1227.79 W 1261.54 W 1294.38 W 1326.27 W 1335.99 W 1357.18W 1387.06 W 1415.88 W 1443.61 W 1470.20 W 1495.64 W 1519.87 W 1542.89 W 1545.54 W 1564.66 W 1585.14 W 1604.33 W 1622.19 W 1638.70 W 1653.85 W 1667.60 W 1679.96 W Dogleg Deg/lOOft e PROPOSAL LISTING Page 1 Your ref Pxtn 1 Ver 4 Last revised 6-Jan-2004 Vert Sect 0.00 0.00 0.00 0.00 2.00 0.00 0.00 0.00 0.00 KOP 1. 75 2.00 2.00 2.00 2.00 4.00 6.98 15.69 27.88 43.52 53.06 4.00 4.00 4.00 4.00 4.00 77.25 108.15 145.60 189.43 239.42 4.00 4.00 4.00 4.00 4.00 295.32 356.88 423.78 495.70 572.29 4.00 0.00 0.00 0.00 0.00 653.17 EOC 736.07 1150.59 1565.11 1979.63 0.00 0.00 0.00 2.00 2.00 2394.15 2808.67 2823.28 Begin Drop 2905.19 2985.05 2.00 2.00 2.00 2.00 2.00 3062.76 3138.23 3161.23 Top Tyonek 3211. 36 3282.07 2.00 2.00 2.00 2.00 2.00 3350.27 3415.87 3478.80 3538.98 3596.33 2.00 2.00 2.00 2.00 2.00 3650.79 3657.07 T-2 Target 3702.29 3750.77 3796.17 2.00 2.00 2.00 2.00 2.00 3838.43 3877.50 3913.33 3945.89 3975.12 All data is in feet unless otherwise stated. Coordinates from slot #1 and TVD from Est RKB (N129) (217.00 Ft above mean sea level). Bottom hole distance is 4086.10 on azimuth 335.00 degrees from wellhead. Total Dogleg for wellpath is 112.00 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 335.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e -- MARATHON Oil Company PROPOSAL LISTING Page 2 Paxton Pad,Pxtn1 Your ref Pxtn 1 Ver 4 Exploration, Kenai Peninsula, Alaska Last revised 6-Jan-2004 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg /100 ft Sect 6617.63 14.00 335.00 4831. 96 3626.14 N 1690.90 W 2.00 4001.00 6717.63 12.00 335.00 4929.39 3646.53 N 1700.40 W 2.00 4023.50 6817.63 10.00 335.00 5027.55 3663.82 N 1708.47 W 2.00 4042.58 6917.63 8.00 335.00 5126.32 3678.00 N 1715.08 W 2.00 4058.22 7017.63 6.00 335.00 5225.57 3689.04 N 1720.23 W 2.00 4070.41 7117.63 4.00 335.00 5325.18 3696.94 N 1723.91 W 2.00 4079.12 7217.63 2.00 335.00 5425.04 3701.68 N 1726.12 W 2.00 4084.36 7309.61 0.16 335.00 5517 .00 3703.26 N 1726.86 W 2.00 4086.09 T-3 Target 7317.63 0.00 335.00 5525.02 3703.27 N 1726.86 W 2.00 4086.10 End of Drop 7500.00 0.00 335.00 5707.39 3703.27 N 1726.86 W 0.00 4086.10 8000.00 0.00 335.00 6207.39 3703.27 N 1726.86 W 0.00 4086.10 8500.00 0.00 335.00 6707.39 3703.27 N 1726.86 W 0.00 4086.10 9000.00 0.00 335.00 7207.39 3703.27 N 1726.86 W 0.00 4086.10 9500.00 0.00 335.00 7707.39 3703.27 N 1726.86 W 0.00 4086.10 9792.61 0.00 335.00 8000.00 3703.27 N 1726.86 W 0.00 4086.10 TD All data is in feet unless otherwise stated. Coordinates from slot #1 and TVD from Est RKB (N129) (217.00 Ft above mean sea level). Bottom hole distance is 4086.10 on azimuth 335.00 degrees from wellhead. Total Dogleg for we11path is 112.00 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 335.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ · e MARATHON Oil Company Paxton Pad,Pxtn1 Exploration,Kenai Peninsula, Alaska PROPOSAL LISTING Page 3 Your ref Pxtn 1 Ver 4 Last revised: 6-Jan-2004 Comments in we11path --------------~----- ------------~------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 250.00 250.00 0.00 N 0.00 E KOP 1900.00 1686.24 591.97 N 276.04 W EOC 4517 . 63 3150.00 2558.76 N 1193.17 W Begin Drop 4948.73 3417.00 2865.05 N 1335.99 W Top Tyonek 5729.51 4017.00 3314.43 N 1545.54 W T-2 Target 7309.61 5517.00 3703.26 N 1726.86 W T-3 Target 7317.63 5525.02 3703.27 N 1726.86 W End of Drop 9792.61 8000.00 3703.27 N 1726.86 W TD Casing positions in string 'A' -----------~-----~------------ -------------------------~---- Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 0.00 0.00 O.OON O.OON O.OON O.OOE O.OOE O.OOE 1900.00 4950.00 9792.61 1686.24 3417.86 8000.00 591.97N 2865.90N 3703.27N 276.04W 1336.39W 1726 . 86W 9 5/8 Casing 7 Casing 4 1/ 2 Liner Targets associated with this we11path ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- Pxtn1 Pxtn1 Pxtn1 Pxtn1 - Top Tyonek - - T2 - 1/5/04 - T3 - 1/5/04 - TD - 1/05/04 204622.000,2233205.000,0.0000 204297.000,2233655.000,0.0000 204297.000,2233655.000,0.0000 204297.000,2233655.000,0.0000 3417.00 4017.00 5517.00 7996.00 3059.01N 3501. 05N 3501.05N 3501. 05N 1365.l1W 1700.85W 1700.85W 1700.85W 13-Nov-2002 13-Nov-2002 13-Nov-2002 5-Jan-2004 . MARATHON Oil Company Paxton Pad Pxtn1 slot #1 Exploration Kenai Peninsula, Alaska . 3-D M I N I MUM D 1ST A N C E C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref Our ref License Pxtn 1 Ver prop5336 Field is centred on n60 48 21.994,w150 49 18.963 Structure is centred on 209346.057,2231200.156,999.00000,N Date printed Date created Last revised 6-Jan-2004 13-Nov-2002 6-Jan-2004 Slot location is n60 5 40.843,w151 36 40.408 Slot Grid coordinates are N 2230114.000, E 205912.999 Slot local coordinates are 1168.56 S 3405.90 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 200 feet Object wellpath DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* PMSS <0 - 11600>"MGO,Nini1chik 1 Socal Falls Creek#2"MGO,Ninilchik 1 MWD <2523 - 12026'>"MGO #2,Ninilchik 1 MGO Plan Upper Ver #l"MGO #2,Ninilchik 1 No Proposa1"MGO #2,Nini1chik 1 Texaco Ninilchik#l"MGO #2,Ninilchik 1 SD#2 Version #3"SD#2,Ninilchik #1 SD ?"KS#lL2,Ninilchik #1 MSS <2498 - 14931'> DepthShifted"SD#l,Ninilch MSS <2507-14940'>"SD#1,Nini1chik #1 MWD <0-10255'>"SD#3,Ninilchik #1 CCF #1 St#l Version #l"CCF#l,Corea Creek Fede PMSS <0-9738'>"CCF#1,Corea Creek Federal #1 Wolf Lake #3 Verso #1"WlfLk#3,Wo1f Lake #3 GMS <0 - 13600'>"WlfLk#1,Wolf Lake GMS <0 - 14451'>"WlfLk#2,Wolf Lake MWD <4455 - 8770>"WlfLk#lRd,Wolf Lake GMS <0 - 13580'>DepthShifted"WlfLk#1,Wolf Lak GMS <0 - 4455>"W1fLk#1,Wolf Lake SN #2 Version #l"SN #2,South Ninilchik #2 S.N. Option C Verso 1"Option C,Ninilchik Stat NS#l Version #5"NS#1,Ninilchik State #1 Abalone #1 Version #2"Aba1one #l,Clam Shell P MWD <0-10356'>"Abalone #1,C1am Shell Pad MSS <2200 - 16121'>"K#1,Kasilof DipMeter <0-5518'>"K Unt#1,Kasi1of Closest approach with 3-D Last revised Distance 10-Sep-2001 32179.9 8-Mar-2000 30035.0 29-0ct-2001 28068.5 17-Sep-2001 24196.1 7-Feb-2000 32303.9 8-Mar-2000 29100.5 19-Nov-2003 9375.9 28-Feb-2003 5528.1 31-Aug-2001 8008.1 31-Aug-2001 8008.1 25-Jul-2002 6124.9 16-Jul-1996 43568.4 5-Apr-1996 43499.2 14-Aug-1998 288308.1 26-Mar-2002 242495.5 2-Apr-2002 242780.1 23-Aug-2002 242088.4 30-Jul-2002 242495.6 31-Jul-2002 242494.8 11-Jun-1996 2238099. 10-Jan-1996 21159.9 13-Jun-2002 26169.8 14-Jan-2003 59609.8 4-Mar-2003 59591.0 15-Jul-1996 87727.6 15-Jul-1996 87573.2 Minimum Distance method M.D. 9792.6 7317.6 9792.6 7309.6 5729.5 9792 . 6 4517.6 9792 . 6 9792.6 9792.6 9792.6 7309.6 7309.6 9792.6 7317.6 9792.6 9792 . 6 7317.6 7309.6 250.0 9792.6 4948.7 9792 . 6 7309.6 9788.6 7317.6 Diverging from M.D. 9792.6 7317.6 9792 . 6 7309.6 5729.5 9792.6 4517.6 9792 . 6 9792.6 9792 . 6 9792.6 7309.6 7309.6 9792.6 7317.6 9792.6 9792 . 6 7317.6 7309.6 9792.6 9792.6 4948.7 9792 . 6 7309.6 978 8.6 7317.6 · e MSS <0-6686'>"KS#2,Kasilof 15-Jul-1996 88375.9 7309.6 7309.6 NoTool<0-14015'>"CpKasilofl,Kasilof 14-Nov-2003 87277.4 7309.6 7309.6 KS#1 Ll N Tgts Ver 7"KS#IL2,Kasilof 14-Dec-2003 88936.9 7317.6 7317.6 MWD <2573 - 7335>"KS#I,Kasilof 30-0ct-2003 88807.3 7309.6 7309.6 MWD <2953-10520>"KS#I,Kasilof 16-Nov-2003 88887.1 7317.6 7317.6 Gyro <0-9782'>"KS#I,Kasilof 13-Nov-2003 88977.2 7317.6 7317.6 MWD <10533 - 17665>"KSILl,Kasilof 29-Dec-2003 88968.4 7309.6 7309.6 MWD <10465-17618>"KS#I,Kasilof 23-Dec-2003 87057.4 9792.6 9792.6 Paxton #3 Version #2"Pxtn3,Paxton Pad ll-Apr-2003 128.4 0.0 9792.6 Paxton #2 Version #2"Pxtn2,Paxton Pad ll-Apr-2003 48.0 0.0 9792.6 · e MARATHON Oil Company Paxton Pad Pxtn1 slot #1 Exploration Kenai Peninsula, Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref Our ref License Pxtn 1 Ver 4 prop5336 Date printed Date created Last revised 6-Jan-2004 13-Nov-2002 6-Jan-2004 Field is centred on n60 48 21.994,w150 49 18.963 Structure is centred on 209346.057,2231200.156,999.00000,N Slot location is n60 5 40.843,w151 36 40.408 Slot Grid coordinates are N 2230114.000, E 205912.999 Slot local coordinates are 1168.56 S 3405.90 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North · MARATHON Oil Company Paxton Pad,Pxtnl Exploration,Kenai Peninsula, Alaska Measured Inclin Depth Degrees 0.00 100.00 200.00 250.00 350.00 450.00 550.00 650.00 750.00 800.00 4.00 6.00 8.00 10.00 12.00 900.00 1000.00 1100.00 1200.00 1300.00 16.00 20.00 24.00 28.00 32.00 1400.00 1500.00 1600.00 1700.00 1800.00 36.00 40.00 44.00 48.00 52.00 1900.00 2000.00 2500.00 3000.00 3500.00 56.00 56.00 56.00 56.00 56.00 4000.00 4500.00 4517.63 4617.63 4717 .63 56.00 56.00 56.00 54.00 52.00 4817.63 4917.63 4948.73 5017.63 5117.63 50.00 48.00 47.38 46.00 44.00 5217.63 5317.63 5417.63 5517.63 5617.63 42.00 40.00 38.00 36.00 34.00 5717.63 5729.51 5817.63 5917.63 6017.63 32.00 31. 76 30.00 28.00 26.00 6117.63 6217.63 6317.63 6417.63 6517.63 24.00 22.00 20.00 18.00 16.00 Azimuth Degrees 0.00 0.00 0.00 0.00 2.00 0.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 335.00 True Vert Depth 0.00 100.00 200.00 250.00 349.98 449.84 549.45 648.70 747.47 796.54 893.55 988.64 1081. 34 1171.20 1257.79 1340.67 1419.46 1493.76 1563.21 1627.47 1686.24 1742.16 2021.76 2301. 35 2580.95 2860.55 3140.14 3150.00 3207.35 3267.53 3330.46 3396.06 3417.00 3464.26 3534.97 3608.10 3683.57 3761.28 3841.14 3923.05 4006.91 4017.00 4092.62 4180.08 4269.18 4359.80 4451.85 4545.20 4639.75 4735.37 R E C TAN G U L A R COO R DIN ATE S O.OON O.OON O.OON O.OON 1. 58N 6.32N 14.22N 25.27N 39.44N 48.09N 70.01N 98.01N 131.96N 171.68N 216.98N 267.65N 323.44N 384.07N 449.25N 518.67N 591.97N 667.11N 1042.79N 1418.47N 1794.16N 2169.84N 2545.52N 2558.76N 2633.00N 2705.38N 2775.81N 2844.20N 2865.05N 2910.48N 2974.56N 3036.37N 3095.83N 3152.86N 3207.40N 3259.38N 3308.74N 3314.43N 3355.42N 3399.35N 3440.50N 3478.80N 3514.21N 3546.68N 3576.19N 3602.69N O.OOE O.OOE O.OOE O.OOE 0.74W 2.95W 6.63W 11. 78W 18.39W 22.43W 32.65W 45.70W 61. 53W 80.06W 101.18W 124.81W 150.82W 179.10W 209.49W 241. 8 6W 276.04W 311. 08W 486.26W 661. 45W 836.63W 1011.81W 1186.99W 1193.17W 1227.79W 1261. 54W 1294.38W 1326.27W 1335.99W 1357.18W 1387.06W 1415.88W 1443.61W 1470.20W 1495.64W 1519.87W 1542.89W 1545.54W 1564.66W 1585.14W 1604.33W 1622.19W 1638.70W 1653.85W 1667.60W 1679.96W Dogleg Deg/100ft e PROPOSAL LISTING Page 1 Your ref Pxtn 1 Ver 4 Last revised 6-Jan-2004 0.00 0.00 0.00 0.00 2.00 2.00 2.00 2.00 2.00 4.00 6.98 15.69 27.88 43.52 53.06 Vert Sect G RID Easting COO R D S Northing 2230114.00 2230114.00 2230114.00 2230114.00 2230115.60 2230120.39 2230128.38 2230139.54 2230153.88 2230162.62 2230184.78 2230213.09 2230247.40 2230287.56 2230333.36 2230384.58 2230440.98 2230502.28 2230568.17 2230638.34 2230712.45 2230788.41 2231168.20 2231547.99 2231927.79 2232307.58 2232687.37 2232700.76 2232775.81 2232848.98 2232920.18 2232989.32 2233010.39 2233056.33 2233121.11 2233183.59 2233243.70 2233301.36 2233356.49 2233409.04 2233458.94 2233464.69 2233506.13 2233550.55 2233592 .14 2233630.86 2233666.66 2233699.49 2233729.32 2233756.10 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #1 and TVD from Est RKB (N129) (217.00 Ft above mean sea level). Bottom hole distance is 4086.10 on azimuth 335.00 degrees from wellhead. Total Dogleg for we11path is 112.00 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 335.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 4.00 4.00 4.00 4.00 4.00 77.25 108.15 145.60 189.43 239.42 4.00 4.00 4.00 4.00 4.00 295.32 356.88 423.78 495.70 572.29 4.00 0.00 0.00 0.00 0.00 653.17 736.07 1150.59 1565.11 1979.63 0.00 0.00 0.00 2.00 2.00 2394.15 2808.67 2823.28 2905.19 2985.05 2.00 2.00 2.00 2.00 2.00 3062.76 3138.23 3161.23 3211.36 3282.07 2.00 2.00 2.00 2.00 2.00 3350.27 3415.87 3478.80 3538.98 3596.33 2.00 2.00 2.00 2.00 2.00 3650.79 3657.07 3702.29 3750.77 3796.17 2.00 2.00 2.00 2.00 2.00 3838.43 3877.50 3913.33 3945.89 3975.12 0.00 0.00 0.00 0.00 1. 75 205913.00 205913.00 205913.00 205913.00 205912.30 205910.20 205906.71 205901.83 205895.56 205891.74 205882.05 205869.67 205854.66 205837.10 205817.08 205794.68 205770.01 205743.21 205714.39 205683.71 205651.30 205618.09 205452.01 205285.93 205119.85 204953.77 204787.69 204781.83 204749.01 204717.02 204685.88 204655.65 204646.43 204626.34 204598.02 204570.69 204544.41 204519.19 204495.08 204472 .10 204450.28 204447.77 204429.65 204410.23 204392.04 204375.11 204359.45 204345.09 204332.05 204320.34 · e MARATHON Oil Company PROPOSAL LISTING Page 2 Paxton pad,Pxtnl Your ref Pxtn 1 Ver 4 Exploration,Kenai Peninsula, Alaska Last revised 6-Jan-2004 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C o 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect Easting Northing 6617.63 14.00 335.00 4831.96 3626.14N 1690.90W 2.00 4001.00 204309.97 2233779.82 6717.63 12.00 335.00 4929.39 3646.53N 1700.40W 2.00 4023.50 204300.96 2233800.43 6817.63 10.00 335.00 5027 . 55 3663.82N 1708.47W 2.00 4042.58 204293.31 2233817.91 6917.63 8.00 335.00 5126.32 3678.00N 1715.08W 2.00 4058.22 204287.04 2233832.24 7017.63 6.00 335.00 5225.57 3689.04N 1720.23W 2.00 4070.41 204282.16 2233843.41 7117.63 4.00 335.00 5325.18 3696.94N 1723.91W 2.00 4079.12 204278.67 2233851.39 7217.63 2.00 335.00 5425.04 3701.68N 1726.12W 2.00 4084.36 204276.57 2233856.19 7309.61 0.16 335.00 5517.00 3703.26N 1726.86W 2.00 4086.09 204275.88 2233857.77 7317.63 0.00 335.00 5525.02 3703.27N 1726.86W 2.00 4086.10 204275.87 2233857.78 7500.00 0.00 335.00 5707.39 3703.27N 1726. 86W 0.00 4086.10 204275.87 2233857.78 8000.00 0.00 335.00 6207.39 3703.27N 1726.86W 0.00 4086.10 204275.87 2233857.78 8500.00 0.00 335.00 6707.39 3703.27N 1726.86W 0.00 4086.10 204275.87 2233857.78 9000.00 0.00 335.00 7207.39 3703.27N 1726.86W 0.00 4086.10 204275.87 2233857.78 9500.00 0.00 335.00 7707.39 3703.27N 1726.86W 0.00 4086.10 204275.87 2233857.78 9792.61 0.00 335.00 8000.00 3703.27N 1726.86W 0.00 4086.10 204275.87 2233857.78 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #1 and TVD from Est RKB (N129) (217.00 Ft above mean sea level). Bottom hole distance is 4086.10 on azimuth 335.00 degrees from wellhead. Total Dogleg for wellpath is 112.00 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 335.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ e MARATHON Oil Company Paxton pad,Pxtnl Exploration,Kenai Peninsula, Alaska Comments in wellpath -------~------------ -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- e PROPOSAL LISTING Page 3 Your ref Pxtn 1 Ver 4 Last revised: 6-Jan-2004 250.00 250.00 O.OON O.OOE KOP 1900.00 1686.24 591.97N 276.04W EOC 4517.63 3150.00 2558.76N 1193.17W Begin Drop 4948.73 3417.00 2865.05N 1335.99W Top Tyonek 5729.51 4017.00 3314.43N 1545.54W T-2 Target 7309.61 5517.00 3703.26N 1726.86W T-3 Target 7317.63 5525.02 3703.27N 1726.86W End of Drop 9792.61 8000.00 3703.27N 1726.86W TD Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 0.00 0.00 O.OON O.OON O.OON O.OOE O.OOE O.OOE 1900.00 4950.00 9792.61 1686.24 3417.86 8000.00 591.97N 2865.90N 3703.27N Target name T.V.D. Targets associated with this wellpath Rectangular Coordinates Revised ------------------------------------- ------------------------------------- Geographic Location 276.04W 1336.39W 1726.86W 9 5/8 Casing 7 Casing 4 1/2 Liner ----------------------------------------------------------------------------------------------------------- Pxtn1 - Top Tyonek - Pxtn1 - T2 - 1/5/04 Pxtn1 - T3 - 1/5/04 Pxtn1 - TD - 1/05/04 204622.000,2233205.000,0.0000 204297.000,2233655.000,0.0000 204297.000,2233655.000,0.0000 204297.000,2233655.000,0.0000 3417.00 4017.00 5517.00 7996.00 3059.01N 3501.05N 3501.05N 3501.05N 1365.11W 1700.85W 1700.85W 1700.85W 13-Nov-2002 13-Nov-2002 13-Nov-2002 5-Jan-2004 ~ --IFE E...'·::..·.·.·..··.··.··..·..·..N........................ '^-'-e-' .,: j , .., , e e Marathon Oil Company Well Name: Paxton #1 Location: Kenai, Alaska. I· N..·· . ..Iy.... ..........iE'iG,· ..·.ft AI..... \.T········'E.·.·. _. i ¡ T",--",;o{j-!ßft. ¡ '.: .I.... ........... ....AP ....A ......... .J..¡~ INEERIN R FL IDS JECT . ...SIFE ~-----~ , ~ Prepared For: MARATHON OIL COMPANY Well Paxton #1 Kenai Peninsula, Alaska Prepared by: Tony Tykalsky Reviewed by: Hal Martins Presented to: Steve Lambe LAN January 8th, 2004 IFE e e - --....IFE ~¡."·,,..".."'Jm'~~ ~"'~;..,'''''~''~ .~ Marathon Oil Company Well Name: Paxton #1 Location: Kenai, Alaska. Marathon Oil Company PO Box 190168 Anchorage, Alaska 99519 ATTN: Steve Lambe Steve: Enclosed is the revised recommended drilling fluid program for the Paxton #1 Well to be drilled this year. The following is a brief synopsis of the program. Overview: Paxton #1 is an exploration well targeting Tyonek formations in the Ninilchik area. A Gel/Gelex spud mud is recommended for the surface interval. Flo-Pro fluid will be used for the intermediate and production intervals. After logging the production interval, the well will be completed with 3 1/2" liner cemented in place. Surface Interval: A standard fresh water Gel/Gelex spud mud will be used. Initial funnel viscosity should be in the 50 -75 sec/qt range. Lower funnel viscosity to 45 - 60 sec/qt after gravel has been drilled. Lower fluid loss to < 10 cc's API prior to running surface casing. Potential fluid losses to the formation may be controlled by additions of G-Seal and/or sized calcium carbonate. G-Seal can also reduce torque in the build area ofthe surface hole. Intermediate Interval: This interval will be drilled with a Flo-Pro fluid. After drilling out the surface cement, the well will be displaced to a standard Flo-Pro KCl fluid. Safecarb bridging material will be maintained according to the mud program to minimize losses to the formation. Expected clays encountered will require the use of the centrifuge van as well as dilution to minimize solids buildup in the mud. Production Interval: This interval will be drilled with Flo-Pro fluid. After drilling out the intermediate cement and 20 - 25 feet of new hole, the well will be displaced to a new Flo-Pro KCl fluid. Fluid loss should be maintained @ < 6 cc's API for this interval. Potential coal sloughing may require the addition of Asphasol Supreme. Completion: This program assumes the well will be completed with 6% KCl brine. Tony Tykalsky Project Engineer M - I Drilling Fluids Reference Wells: Susan Dionne #3 NOTE: This pr02ram is provided as a 2uide only. Well conditions will always dictate fluid properties required. e e ~ Marathon Oil Company IFE Well Name: Paxton #1 Location: Kenai, Alaska. Project Summary Casing Hole Casing Depth TVD Mud Mud Sum Interval Size Size Program System Weight Days Mud Cost (in) (in) (ft) (ft) Solids Control (ppg) 9-5/8" 12-1/4" 1900' 1686' Gel/Ge1ex Spud 8.6 - 9.4 5 $13,445 Mud Screens 150/180 mesh Desi1ter Centrifuge Van 7" 8-1/2" 4950' 3418' F10- Pro 9.2 - 9.4 10 $108,719 w/S afeC arb Screens 180 ~ 210 mesh Desìlter Centrifuge Van [<. 3-1/2" 7" 9792' 8000' F1o-Pro 9.2 ~~;' 7 $102,745 w/SafeCarb Screens 230 - 210 mesh Desi1ter Centrifuge Van 3 112" 7" Completion 9792' 8000' 6% KC1 8.55 2 $7,226 ).> Utilize all solids control equipment to minimize the build up of drill solids in the system (if possible, centrifuge the surface mud during trips to reduce drill solids). ).> Condition the mud prior to running casing for all intervals. ).> Cost does not include any considerations for whole mud losses. ).> Cost includes 3% Lubetex concentration for intermediate and production interval. ~:~ IFE e -- IFE Marathon Oil Company Well Name: Paxton #1 Location: Kenai, Alaska. Plans & Procedures => COMMUNICATION - The Field Mud Engineer will communicate daily with the In-Town Project Engineer. The Project Engineer will then communicate daily with the rig Drilling Engineer. Communications should be about, but not limited to, fluid properties, hole difficulties, possible changes to the mud program, and proposals to use products not included in the mud program. => Whole Mud Losses to the Sterlng AS Sands - Refer to fluid fonnulas and the Optibridge charts for maintaining proper bridging material concentration in the mud system while drilling the intennediate and production intervals. => FLUID LOSS CONTROL - In the intennediate interval the API fluid loss will be maintained in the 7 - 9 cc's range. In the production interval the API fluid will be maintained at less than 6 cc's at all times. In addition to sufficient fluid loss agent additions, this may require adequate dilution of the mud system in order to keep reactive drill solids to a minimum. It is particularly important to maintain a low hardness «200 ppm Ca) for effective use of DualFlo, therefore cement contamination should be completely treated as rapidly as possible prior to adding DualFlo to control or reduce fluid loss. NOTE: If additions of DualFlo do not appear to be lowering the fluid loss adequately, then switch to additions of Polypac Supreme SL after consultation with town. => LSRV - When drilling with a FloPro fluid, the low shear rate rheology should be maintained around 40,000 cps. In addition to adequate additions of Flo Vis Plus, this will also require keeping reactive drill solids to a minimum in order to reduce or eliminate false and unwanted high LSR V. => DRILL SOLIDS - MDT - The MBT should be kept at less than 5 ppb in the production interval through aggressive use of solids equipment and dilution as needed. => MIXING CONDITIONS - Whenever possible all treatments to the mud system should be made as pre-mix additions. Polymers and KCl should first be mixed in fresh water in that order and then blended into the active system over one or two circulations as needed. => CORROSION - Conqor 404 additions should be made daily when drilling with FloPro fluid in order to maintain a Conqor 404 concentration of +/- 2000 PPM. => CORRlSION - SafeScav NA additions should be made daily as needed with any fluid in the hole. Maintain a DO reading ofless than 3 ppm => GREENCIDE 2SG ADDITIONS - Greencide 25G additions should be made daily when drilling in the production interval, in the range of 5 gallons per day. => SOLIDS VAN USAGE - The Solids Van should be used whenever drill solids become un-acceptably high and reduction of drill solids in the mud can be more economically done with centrifuging and dilution then just with dumping and diluting. The weight of the drilling fluid alone should not be the detennining condition for when to use the Solids Van. => WEIGHTING UP - All increases in mud weight should be accomplished with barite additions. In the production interval, insure chloride concentration is maintained at 30,000 to minimize the need for barite additions. e e Marathon Oil Company Well Name: Paxton #1 Location: Kenai, Alaska. Interval Summary - 12-1/4" hole Drilling Fluid System Gel/Gelex Spud Mud Key Products MI Gel / Gelex / Soda Ash / Caustic Soda / MI Bar / PolyPac Supreme UL Solids Control Shale Shakers / Desilter / Centrifuge Van Recommended shaker screens - 150 - 180 mesh Potential Problems Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions Depth Mud Funnel Yield APJ Drill Interval Weight Viscosity Point Flûid Loss pI! Solids (ft) (ppg) (sec.lqt) (lb./l00fe) (ml/30iliin) (%) 0- 1900' 8.6 - 9.4 60 - 100 25 - 35 NC - 12 +/- 9.5 < 7% ~ Treat drill water with Soda Ash to reduce hardness. ~ Build spud mud with 20 - 25 PPB M-I Gel to +/- 100 sec.qt funnel viscosity. ~ Lower funnel viscosity to +/- 75 after gravel zone has been drilled. ~ Add Gelex as needed to maintain sufficient viscosity for hole cleaning. ~ Increase funnel viscosity if fill on connections begins to occur. ~ Reduce fluid loss with additions ofPolypac Supreme UL prior to running surface casing. ~ Add 2 - 5 PPB of M - I Seal Fine to mud system if seepage losses becomes a problem.. ~ Condition mud prior to cementing casing to reduce yield point and gel strengths. ~ Estimated volume usage for interval- 1507 barrels. ~ Estimated haul off volume - 2215 barrels. e - IFE Marathon Oil Company Well Name: Paxton #1 Location: Kenai, Alaska. Interval Summary - 8-1/2" hole Drilling Fluid System Flo-Pro Fluid Key Products Flo- Vis / PolyPac UL / KCI / SafeCarb F & M, Asphasol Supreme / Lubetex / KlaGard / Caustic Soda / Conqor 404 / SafeScav NA Solids Control Shale Shakers / Desilter / Centrifuge Van Recommended shaker screens - 210 mesh Potential Problems Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions Depth Interval (ft) 1900 - 4950' Mud Weight (ppg) 9.2- 9.4 Plastic Viscosity ( cp.) 8 -12 LSRV 1 min (cps) 40,000 API Fluid Loss (mIJ30min) 8 - 10 pH Drill Solids (%) +/- 7.5 % +/- 9.5 ~ Use one rig pit to drill out surface casing. In other rig pits, build new Flo-Pro fluid using the enclosed formula. ~ After drilling out surface casing, displace hole to Flo-Pro fluid prior to running leak offtest. ~ Maintain DO reading of less than 3 ppm with additions of SaveScav NA. ~ Maintain Conqor 404 concentration of 2000+ ppm. ~ If running coals become a problem, increase Asphasol Supreme additions. ~ Estimated volume usage for interval- 1502 barrels. ~ Estimated haul off volume - 1712 barrels. ~ Condition mud prior to running 7" casing. NOTE: Follow BOSCO guidelines when adding biocide, oxygen scavenger and corrosion inhibitor. · e ~ ---~ IFE Marathon Oil Company Well Name: Paxton #1 Location: Kenai, Alaska. Intermediate Interval Fluid Formula 8-1/2" I nterval from 1900 - 4950' Input Dèscription MudW~ight W eight M~terial Cod.~ Weight Material SG Order of Addition 1 2 3 4 5 6 7 8 9 10 11 12 Output - 1 bbl I Concentration Volume Field,lb Lab, gm Field,bbl Water 298.70 298.70 0.853 Soda Ash 0.25 0.25 0.000 Flovis 2.00 2.00 0.004 Polypac Supreme UL 2.00 2.00 0.004 Caustic Soda 0.50 0.50 0.001 Potassium Chloride 19.07 19.07 0.023 KlaGard 6.00 6.00 0.018 SafeCarb F 10.00 10.00 0.010 SafeCarb M 10.00 10.00 0.010 Asphasol Supreme 2.00 2.00 0.006 If bit balling becomes a problem, add the following: D-D CWT I 1.00 I 1.00 I 0.003 I 1.00 Reduce BHA Balling If torque becomes a problem, or sliding is difficult, add up to 5% of the following: Lubetex 14.00 14.00 0.041 14.43 Paxton #1 9.2 - 9.4 MI Bar 4.2 Prehydrated Gel Prehydrated Gel Cone. KCI Wt% No 6 Products Lab,ml 298.70 0.10 1.33 1.25 0.23 7.98 6.25 3.60 3.60 2.08 Total Calculated Mud Weight Total Chloride 399 399 9.500 29600 1.000 350 Estimated Volume Usage Product Usage Reduce Hardness Viscosity Fluid Loss Control pH Control Inhibition Inhibition Bridging Agent Bridging Agent Wellbore Stability Lubricity 1502 Barrels · e ...... ---, IFE Marathon Oil Company Well Name: Paxton #1 Location: Kenai, Alaska. Interval Summary -7" hole Drilling Fluid System Flo-Pro Fluid KeyProducts Flo-Vis / DualFlo / KCl/ Greencide 25G / SafeCarb F, KlaGard / MI Bar / Caustic Soda / Conqor 404 / SafeScav NA SolidsControl Shale Shakers / Desilter / Centrifuge Van Recommended shaker screens - 210 - 230 mesh Potential Problems Lost circulation, coal sloughing, drill solids build-up, gas kick, tight hole conditions Depth Mud Plastic LSRV API Drill Interval Weight Viscosity 1 min Fluid Loss pH Solids (ft) (ppg) (cp.) ( cps) (mIJ~Omin) (%) 4950 - 9792' 9.2 - 9.6 10 - 14 40,000 <6 +/- 9.5 +/- 5% )P> Use one rig pit for drilling out intennediate casing. In other rig pits, build new Flo-Pro fluid using the enclosed fonnula. )P> If running coals become a problem, treat with a 2 PPB addition of Asphasol Supreme. )P> Periodic additions of Greencide 25G will be needed to control bacteria build-up. )P> Estimated volume usage for interval- 1391 barrels. )P> Estimated haul off volume - 2426 barrels. )P> Condition mud prior to running 3-1/2" casing. NOTE: Follow BOSCO guidelines when adding biocide, oxygen scavenger and corrosion inhibitor. e e Marathon Oil Company Well Name: Paxton #1 Location: Kenai, Alaska. Production Interval Fluid Formula 7" Interval from 4950 - 9792' Input Description MUd Weight Weight Material Code Weight Material SG Weight·Materi.al Price Order of Addition 1 2 3 4 bA 5B 6 7 8 9 10 11 12 13 Paxton #1 9.2 - 9.6 MI Bar 4.2 Prehydrated Gel PrehydratedGel Cor1c. KCI Chloride KCI Wt% 6 No Products I Volume Field, bbl 0.929 0.000 0.003 0.011 0.015 0.006 0.025 0.001 0.004 0.001 0.001 Lab, ml 325.19 0.10 0.84 4.00 5.30 2.30 8.68 0.30 1.43 0.23 0.25 Output- 1 bbl Concentration Field, Ib Lab,gm Water 325.19 325.19 Soda Ash 0.25 0.25 FloVis Plus 1.25 1.25 DualFlo 6.00 6.00 SafeCarb Fine 14.00 14.00 SafeCarb Medium 6.00 6.00 Potassium Chloride 20.76 20.76 Greencide 25G 0.25 0.25 CONQOR 404 2.00 2.00 Caustic Soda 0.50 0.50 SafeScav NA 0.25 0.25 If Bit balling becomes a rroblem, add the following D-D 4.00 I 4.00 I 0.011 I 4.00 If sliding or high torque becomes a problem add 1 - 3% of the following Lubetex I 7.00 I 7.00 I 0.021 I 7.00 If sloughing coals become a problem add 2 - 4 ppb of the followinQ Asphasol Supreme I 2.00 I 2.00 I 0.004 I 1.33 Mix fluid in the order listed above. Wait for 1 - 2 circulations before adding SafeScav NA to the system. Alternate additions of Greencide 25G and SafeScav NA as needed. Maintain 5 - 6 ppb concentration of DualFlo to maintain as Iowa API fluid loss as possible. Plan on daily additions of DualFlo to achieve> 6.0 cc's API Fluid Loss Reduce concentration of FloVis as needed to maintain rheology. Total I Calculated Mud Weight Total Chloride 380.1 9.2 29600 Estimated Volume Usage I 380.1 Product Usage Reduce Hardness Viscosity Fluid Loss Control Bridging Agent Bridging Agent Inhibition Biocide Corrosion Control pH Control Oxygen Scavenger Reduce BHA Balling Lubricity Well bore Stability 1391 Barrels e tit IFE Marathon Oil Company Well Name: Paxton #1 Location: Kenai, Alaska. HSE Issues HANDLING OF DRilLING FLUID PRODUCTS HEALTH AND SAFETY 1. Drilling crews should be instructed in the proper procedures for handling fluid products. 2. Personal Protective Equipment (PPE) charts should be posted in the pit room, the mud lab, and the office of the Drilling Forman. 3. PPE must be in good working order and be utilized as recommended by the PPE charts. 4. Product additions should be made with the intent to use complete unit amounts of products (sacks, drums, cans) as much as possible in order to minimize inventory of partial units. 5. Insure all MSDS sheets are up to date and readily available for workers to access for information. ENVIRONMENTAL 1. Insure that all product stored outside is protected from the weather. 2. Do not store partial units (sacks, etc) outside if possible. 3. Properly secure all products for shipment between job sites. 4. When transferring fluid and or cuttings from the rig to trucks, insure all hoses are properly secured. 5. When utilizing the centrifuge solids van, insure all hoses and connections between the van and the rig are secure. Marathon Oil Company Wen Name: Paxton #1 Location: Kenai, Alaska. Product Health and Safety Reference HMIS HAZARD RATINGS Product Function PPE M-I BAR Weighting Agent E M-I GEL Viscosity control E GELEX Bentonite Extender E FLOVIS Viscosifier E DUAL-FLO Modified Starch E POLYPAC Fluid Loss Reducer E XCD Viscosifyer E HEC Loss Circulation Material E ~.- Safe-Carb F,M,C Bridging and weighting E agent ~ LO WATE Weighting agent E Nut Plug Loss Circulation Material E M-I Seal F, M, C Loss circulation Material ...-..,,, ~ ~ E ~ "- Mix" F,M,C Loss circulation Material E DESCO CF Dispersant <~'." 7"""J 1 E SPERSENE CF Dispersant E TANNATHIN Dispersant E VENTROL 401 Surfactant E SAL T (Solar) Densifier E BROMIDE (NaBr) & Densifier F Brine Solution POTASSIUM Shale Inhibitor E CHLORIDE - IFE Marathon Oil Company Well Name: Paxton #1 Location: Kenai, Alaska. Product Health and Safety Reference HMIS HAZARD RATINGS Product Function PPE CAUSTIC SODA Alkalinity control X CAUSTIC POT ASH pH Modifier X BORAX Inorganic Borate E SAPP Sodium Pyrophosphate E SODA ASH Alkalinity control E SODIUM Alkalinity control E BICARBONATE CITRIC ACID pH Adjuster E BIOBAN BP-PLUS Biocide J GREEN CIDE 25G - Biocide J DEFOAM X - Defoamer J G-SEAL Sized graphite LCM E KLA-GARD Shale Control agent J LUBE TEX Lubricant J D-D CWT Detergent J Concor404 Corrosion Inhibitor J SAFEKLEEN Drilling fluid additive J AsphasolD Shale Inhibitor J Soltex Shale Inhibitor J SafeScav NA Oxygen Scavenger J e e Marathon Oil Company Well Name: Paxton #1 Location: Kenai, Alaska. Product Health and Safety Reference HMIS HAZARD RATINGS HAZARDOUS MATERIALS IDENTIFICATION SYSTEM (HMIS) HAZARD RATINGS 4 - Severe hazard 3 - Serious hazard 2 - Moderate hazard 1 - Slight hazard o - Minimal hazard * An asterisk next to the health rating indicates that a chronic hazard is associated with the material. HMIS PERSONAL PROTECTIVE EQUIPMENT INDEX A - Safety Glasses B - Safety Glasses, Gloves C - Safety Glasses, Gloves, Synthetic Apron D - Face Shield, Gloves, Synthetic Apron E - Safety Glasses, Gloves, Dust Respirator F - Safety Glasses, Gloves, Synthetic Apron, Dust Respirator G - Safety Glasses, Gloves, Vapor Respirator H - Splash Goggles, Gloves, Synthetic Apron, Vapor Respirator I - Safety Glasses, Gloves, Dust and Vapor Respirator J - Splash Goggles, Gloves, Synthetic Apron, Dust and Vapor Respirator K - Air Line Hood or Mask, Gloves, Full Suit, Boots X - Consult your supervisor for special handling directions IFE œ'r Marathon Paxton 1 Pennit to Drill e e Steve Steven Lambe mentioned that you had called about shallow gas/hazards in this well. Two forms of data exists to evaluate this request. Well Control Marathon Susan Dionne 1 (1962) and 3 (2002) were drilled through the shallow section (Glacial Gravels and Tertiary Sterling Formation) at a location two miles north. No shallow hazards / were encountered in these wells/8. Mobil Ninilchik 1 (1964) also drilled this section slightly over one mile to the south. This well also did not encounter any shallow hazards. / Unocal Pearl 1 (2002) was drilled as a twin to the Mobil Ninilchik 1. To my knowledge, no / hazards have been reported for that well. Seismic We have recently received a processed version of our 3D survey that we shot last year over the Paxton area. This data does not reflect any shallow gas anomalies or potential hazards. ,--- If you have further questions, please call. David David L. Brimberry Advanced Senior Geologist Alaska Production Region Marathon Oil Company POB 196168 Anchorage AK 99519-6168 Office: 907-564-6402 Home: 907-696-0673 Cell: 907-529-0527 dlbrimberry@marathonoil.com 1 of 1 1/20/20043:53 PM Paxton # 1 Shallow Hazards Information . . Steven, During review of the application for the Paxton 1 exploratory well, I didn't see anything to address the following regulation concerning shallow drilling hazards. Could you please call me at 793-1224? Thanks, Steve Davies AOGCC 20 AAC 25.061 WELL SITE SURVEYS. (a) For an exploratory or stratigraphic test well, near surface strata to a depth of2,000 feet in the vicinity of the well must be evaluated seismically by common depth point refraction or reflection profile analysis, or by another method approved by the commission, to identifY anomalous velocity variations indicative of potential shallow gas sources. Analysis results must be included with the application for the Permit to Drill (Form 10-401). (b) For a well drilled offshore from a mobile bottom-founded structure, jack-up rig, or floating drilling vessel, the vicinity of the well must be evaluated by sidescan sonar and other pertinent surveys to determine whether potential seabed hazards to drilling operations are present. Survey results must be included with the application for Permit to Drill. (c) Upon request by the operator, the commission will, in its discretion, waive the requirements of this section if the operator can identifY, by other equally effective means, the likelihood of encountering potential shallow gas or seabed hazards or if the commission already has information that substantiates the presence or absence of shallow gas or seabed hazards. History - Eff. 4/13/80, Register 74; am 4/2/86, Register 97; am 11/7/99, Register 152 Authority - AS 31.05.030 1 of 1 4/4/2005 11 :30 AM Re: paxton 1 . . Kathy, I'm just a geologist, so can you tell me what the proposed (draft?) is? Thanks, Steve D. P.S. How do you and Kaye split the reviews? (I' don't want to bother the wrong person). SD Kathleen Sheehan-Dugan wrote: Steve, The project did get a review. Comments were due Jan 8 & the proposed went out Jan 13. 1 of 1 4/4/2005 11 :31 AM ACMP review needed for Marathon's Paxton 1 Exploratory Well on... . . Kaye, Did this project need an ACMP review? If so, was one completed? Thanks, Steve Davies I of 1 4/4/2005 11:31 AM #1 p p o - · -- Alaska Region Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 January 8, 2004 Sarah Palin Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Ave, Suite 100 Anchorage, AK 99501 Reference: Drilling Permit Application Field: South Ninilchik - Wild Cat Well: Paxton #1 REcEIVED JAN 0 9 2004 --Ql&Gllea..~ A~~.~~ . Dear Ms. Palin Enclosed please find the PERMIT TO DRILL application, along with the associated attachments and filing fee of $1 00. The intent is to drill a exploration well in the South block of the Ninilchik Unit. If you require further information, I can be reached at 907-564-6332 or bye-mail at sslambe@marathon.com. Sincerelr_7.~/ / J;t~--~þLp Steven S. Lambe Senior Drilling Engineer Enclosures Check No Check Date Bank Bank No Vendor NOe I Marathon Oil Company P. D. Box 3128 Houston. TX 77253 Al 1109883 01/09/2004 NCBAS 77BO 5001123 W@Wi'NMþH·..···.. )@.@~~...þ~(~þ¥~MtWM~. AL1 00.00 01/08/2004 1900000737 TOTAL: ~ R~~c:UI~¥~ir~;y~¿LE DEPARTMENT Accts Payable - Customer Serv Phone: 713-296-4336 .·.·..·.µj$iiMi1f..·.. )·...·MWiWmWAiiiMfu> · 100.00 100.00 Hndlg 100.00 100.00 (FOLD ON PERFORATION BELOW AND DETACH CHECK STUB BEFORE DEPOSITING) -¡. JI ~ [.) ..,~ ~; I' J~ I ~ ~1-"I¡!f~':1 ~ II ~ [tt :" V (-,~,~, -.. ¡; I =II!; I::{ "I ~iI :,~\ I! ,1~ H 'l'!~ I- ,~':I =ø I ~. 'l [.] 1I:::i"'; I =- ~ I ~ I =-:J =1,11: '1'1" 'I'] ~. f.' (~¡'1I ~~ ['i;{'!];I:I' ~. (lÜ~ , II' 0 0 0 . . 0 ~ a a ~ II' I: 0 L. . 2 0 ~ a ~ 5.: o. a ~ L. a L. II' · e TRANSMJT AL LETTER CHECKLIST CIRCLE APPROPRIATELETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER .. ~. WELL NAME IZ~JoY\ I PTD# 2-D (I·~ 0 ID CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API num ber last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing weD Permit No, API No. Production should continue to be reported as a function of the original API number stated above. BOLE In accordance with 20 AAC 25.005(1), an records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for we)) (name on permit). SPACING EXCEPTION ARY DITCH / SAMPLE Rev: 07/] 0/02 C\jodY\1emplates The permit is approved subject ·to fun compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. An dry ditch sample sets submitted to tbe Commission must be in no greatertban 30' sample intervals from below tbe permafrost or from where samples are first caught and ] 0' sample intervals tbrough target zones. D D Well bore seg Annular Disposal _On _Program EXP OnlOff Shore 51432 Unit Well Name: PAXTON EXP I PEND GeoArea 820 Exploratory well within Njnjlchjk Unit Top 9f produçtiv~jntervaJ ioterval <lod TD He withlnAD_L3S4_372. leas_e_lioe. ~FD Surface location fee lease; produ_cti\(e_ is :-2900 feet from oearest Yes Yes Yes No_ Yes Yes Yes Yes Yes Yes Yes Yes Yes NA Initial Classrrype Field & Pool MARATHON OIL CO Permitfee attached _ _Lease number <lppropriate Company _U_ni~ue well.n_aOle _aod ou_mber Jo_cated '" - 10~",~" nnn' _ Jocated ; from drilling unilbpund<lry_ Jo_cated ; from other wells. t.._..... "'_wtll!.....~ -rY"....... WeJI Wel WeJ _Svfficient <lcrea~eaYailable In_drilJio~ unit Jfdeviated, is_weJlbore plClUncluded 2 3 4 5 6 7 8 9 PTD#: 20401 00 Administration onl}' affected party bas.approprlate_b_ond in Permilcao be i$su_ed witbout Permitc<lo be i$sued witbo_ut Can permit . ~ nnn.n"o" ....~.n Well Jocate< I .trata <luthorized by_lojectioo Order tl (put Jorce. conservation order administrati\(e_approvaJ 15-day wait {)per<ltor {)per<ltor 10 11 e In_commeots) (For 10# Dç .....,........\..v"'u Uwlvre :1 (14/2QO~ SED af(ectGommiss(on _ability toiss~e pennjt I='roject js_ currently voc[er reyiew. Doesf\'t be_protected. S¡:D Casing shoe will lie_-}OQ' offshore_at a depth of -:168_6'_ ND. Ao}' pote_ntial USDWswill Adequate ex_cess. NabJ)l:sJ29E. New wel MClx MW _9.6_ ppg._ e 19_86 psi Test to _30QO_ psLMSP- .NA NA Np Yes Yes Yes Yes Yes Yes Yes NA Y~$ Yes Yes Yes Yes Yes Yes N_o_ NA only) All wells _within _1l4 _mil~ _are.a.of reyiew ideotified (For s_ervice w~1J onl}') Pre-produçed_ iojector: duratio_n _of pre-production I~ss_ than_ 3- months_ (for _service well 12 13 14 15 6 7 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 Date Appr SFD 1/20/2004 COnJ>isteocyh<lS been jssued_ foctbis proiect Çooductor strjng_provlded ACMP_Fjnd[ng _of Engineering known USOWs J:ondvctoc& su_rf_CSg ~ v dace CMTvola_dequateJo circul<lteon casin-9_protects_ al Jong _string tosud CS-9_ tie-in kl'!own producliye bori~on$ _CMT vpl adequ_ate_ to ÇM:Cwill coyeral Ç<lsiog desigos ad_equate for C,T, B_&_permafrost Adequat~ JankCl~e_or re_serve pit Jta_re-drill, has a tO~403 for abandonment beeo approved Adequat~ wetlbore. sepClration proposed m_eel reguJatiQl'!s_ list _adequate Jfdiverter it DrilJio~ fluid_program sc_hematic& eqvip required, does Date 1/14/2004 Appr WGA _BOPEs, do _they meet reguJatiol'! _BOPE pre_ss ratiog appropriate; test to -<put (May 84) in_comments) Work will occur_ without Js_ presence_ oJ H2S gas_ prob_able Mecbanlcalcoodjtloo ot weJls withJI'l AOR yerifiec[ (For_service well onJy) psig Çhoke_manifold compJies w/APLR~-53_ operCltion $butdown Yes Yes Yes NA Yes NorOlaLpressure expected. NeClrest welJ is _6,OOO'awCl'}'; it was drilled with_ 9_.8 ppg_or Hghter mud Offs_et weiLand 3D seismic datCl do oo_t reflect aoy_s_hallow_g<ls Clnomalies_or potel'ltiaLh_azards. Ste\(en_Lambe, 90~-564~6~32 :;¡; fZ / ðf- Permit c_ao be issued w/o_ hydrogen s_ul_fide measvres 35 36 Date 37 1/20/2004 38 39 Geology Appr SFD _D<ltapresel'!tect on_ potential overpressure ZOl'les ~eismlc_anCllysis_ of sbaJlow gas_zooes_ of(-shore) (if _Seé1lbed cOl1ditioo survey Co_ntact n_ame/phOl'le Jor weekly progres_s _rep_orts[e1'<plorCltory _ooly] Date Engineering Commissioner: Date: Geologic Commissioner: