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ϭϬ͘>WZǁŝƚŚϯͲϭͬϮ͟ƚĞƐƚũŽŝŶƚ;ƉĂƐƐĞĚͿ ϭϭ͘hWZǁŝƚŚϯͲϭͬϮ͟ƚĞƐƚũŽŝŶƚ͕ĐŚŽŬĞǀĂůǀĞϯ;ƉĂƐƐĞĚͿ ϭϮ͘ůŝŶĚƌĂŵƐ;ƉĂƐƐĞĚͿ͘ĐĐƵŵƵůĂƚŽƌdĞƐƚ͗ ^ǇƐƚĞŵƉƌĞƐƐƵƌĞсϮ͕ϵϱϬƉƐŝ WƌĞƐƐƵƌĞĂĨƚĞƌĐůŽƐƵƌĞсϭ͕ϱϱϬƉƐŝ ϮϬϬƉƐŝĂƚƚĂŝŶĞĚŝŶϰϮƐĞĐŽŶĚƐ &ƵůůƉƌĞƐƐƵƌĞĂƚƚĂŝŶĞĚŝŶϭϵϬƐĞĐŽŶĚƐ EŝƚƌŽŐĞŶŽƚƚůĞƐͲϲĂƚϮ͕ϭϬϬƉƐŝ ϯͬϲͬϮϬϮϮͲ^ƵŶĚĂǇ ĐĐĞƉƚZŝŐĂŶĚďĞŐŝŶZŝŐƵƉĨŽƌKWdĞƐƚ͘ ϯͬϳͬϮϬϮϮͲDŽŶĚĂǇ ϯͬϰͬϮϬϮϮͲ&ƌŝĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϯͬϮͬϮϬϮϮͲtĞĚŶĞƐĚĂǇ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϯͬϯͬϮϬϮϮͲdŚƵƌƐĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW&ͲϵϬϯ ŽǇŽŶϭϰ ϱϬͲϬϮϵͲϮϯϮϲϲͲϬϬͲϬϬ ϮϬϱͲϬϴϳ ϯͬϲͬϮϬϮϮ ϯͬϭϲͬϮϬϮϮ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ WĞƌĨŽƌŵŵĂŶƵĂůĐŚŽŬĞƚĞƐƚ͘WƌĞƐƐƵƌĞĚƵƉĂŶĚĂƚƚĞŵƉƚƚŽďůĞĞĚŽĨĨďƵƚǁŽƵůĚŶŽƚďůĞĞĚŽĨĨĞǀĞŶǁŝƚŚĂĨƵůůŽƉĞŶĐŚŽŬĞ͘ ůĞĞĚŽĨĨƚŚƌƵŚǇĚƌĂƵůŝĐĐŚŽŬĞ͘ůŽǁĚŽǁŶƚŚĞĐŚŽŬĞŵĂŶŝĨŽůĚ͘ZŝŐŵĞĐŚĂŶŝĐƚƌŽƵďůĞƐŚŽŽƚĂŶĚĨŽƵŶĚƚŚĂƚƚŚĞĞŶĚŽĨƚŚĞ ĐŚŽŬĞƐƚĞŵŚĂĚďƌŽŬĞŶĂƚƚŚĞƚŝƉ͘ZĞĐŽǀĞƌƐƚĞŵƚŝƉĨƌŽŵƚŚĞƐĞĂƚ͘ZŝŐŵĞĐŚĂŶŝĐǁĞŶƚƚŽĞĂĚŚŽƌƐĞƚŽŐĞƚŶĞǁŵĂŶƵĂů ĐŚŽŬĞƉĂƌƚƐ͘^ŝŵŽƉƐ͗WhĂŶĚDhϭϱƐƚĂŶĚƐϱΖΖWƵƚŝůŝǌŝŶŐƚŚĞŵŽƵƐĞŚŽůĞƚŽĂŝĚŝŶƚŚĞƐƚĂŶĚŝŶŐďĂĐŬŽĨƚŚĞϮͲϳͬϴ͟ƚƵďŝŶŐ͘ ƵŝůĚĐŽŶƚĂŝŶŵĞŶƚďĞƚǁĞĞŶƚŚĞƌŝŐĂŶĚƐƉŽŽůŝŶŐƵŶŝƚ͘DĞĐŚĂŶŝĐŽŶůŽĐĂƚŝŽŶǁŝƚŚĐŚŽŬĞƉĂƌƚƐ͘/ŶƐƚĂůůŶĞǁĐŚŽŬĞƐƚĞŵ͕ ƌĞĂƐƐĞŵďůĞƚŚĞĐŚŽŬĞĂŶĚĨƵŶĐƚŝŽŶƚĞƐƚ;ŐŽŽĚͿ͘ŽŶƚŝŶƵĞKWƚĞƐƚƚŽϮϱϬͬϯ͕ϬϬϬƉƐŝ͘ dĞƐƚƐ͗ ϭϯ͘DĂŶƵĂůĂĚũƵƐƚĂďůĞĐŚŽŬĞ;ĨĂŝůͬƉĂƐƐĞĚͿ ϭϰ͘,ǇĚƌĂƵůŝĐƐƵƉĞƌĐŚŽŬĞ;ƉĂƐƐĞĚͿ ϴŚŽƵƌƐƚŽƚĂůƚĞƐƚƚŝŵĞ͘ůŽǁĚŽǁŶĐŚŽŬĞĂŶĚůŝŶĞƐ͘ZKWƚĞƐƚŝŶŐĞƋƵŝƉŵĞŶƚ͘Zh͕ďůĞĞĚŽĨĨϰϬƉƐŝĨƌŽŵ/ĂŶĚŵŽŶŝƚŽƌ ƐĂŵĞ͘DhĚƌǇƌŽĚ͕ƉƵůůd^ƉůƵŐĂŶĚWsĂƐƉĞƌt,Z͘>ĂǇĚŽǁŶƚŚĞĚƌǇƌŽĚ͘ůŽƐĞ/ĂŶĚƚƵďŝŶŐŽŶĂǀĂĐ͘DhϮͲϳͬϴΖΖ ůĂŶĚŝŶŐũŽŝŶƚǁŝƚŚ&K^sĂŶĚyKƐ͕t,ZK>^͘Whϭϯϱ<ƵŶƐĞĂƚŚĂŶŐĞƌ͕ƉƵůůŚĂŶŐĞƌƚŽƚŚĞƌŝŐĨůŽŽƌǁŝƚŚWhсϭϮϬ<ĨƌŽŵϭϮ͕ϬϳϯΖ ƚŽϭϮ͕ϬϯϳΖ͘ƚƚĞŵƉƚƚŽĨŝůůƚŚĞŚŽůĞ͕ƉƵŵƉĞĚϭϯϮďďůƐĂŶĚĚŝĚŶŽƚŐĞƚĨůƵŝĚƚŽƐƵƌĨĂĐĞ͘W:^D͘ZhƚŚĞĞůĞƉŚĂŶƚƚƌƵŶŬƚŽƚŚĞ ƐŚĞĂǀĞŝŶƚŚĞĚĞƌƌŝĐŬ͘W:^D͘>ĂǇĚŽǁŶƚƵďŝŶŐŚĂŶŐĞƌ͕ƌĞŵŽǀĞƚŚĞd/tĨƌŽŵƚŚĞůĂŶĚŝŶŐũŽŝŶƚĂŶĚůĂǇĚŽǁŶƚŚĞůĂŶĚŝŶŐũŽŝŶƚ͘ ŚĂŶŐĞĞůĞǀĂƚŽƌƐ͘dKK,ǁŝƚŚ^WĐŽŵƉůĞƚŝŽŶƐƚĂŶĚŝŶŐďĂĐŬƚŚĞϮͲϳͬϴΗƚƵďŝŶŐƐƉŽŽůŝŶŐ^WĐĂďůĞͬŝŶũĞĐƚŝŽŶůŝŶĞƌĞŵŽǀŝŶŐ ĐĂŶŶŽŶĐůĂŵƉƐĨƌŽŵϭϮ͕ϬϯϳΖƚŽϱ͕ϵϭϬΖ͘ ϯͬϴͬϮϬϮϮͲdƵĞƐĚĂǇ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW&ͲϵϬϯ ŽǇŽŶϭϰ ϱϬͲϬϮϵͲϮϯϮϲϲͲϬϬͲϬϬ ϮϬϱͲϬϴϳ ϯͬϲͬϮϬϮϮ ϯͬϭϲͬϮϬϮϮ ϯͬϵͬϮϬϮϮͲtĞĚŶĞƐĚĂǇ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ ŽŶƚŝŶƵĞƚŽdKK,ǁŝƚŚ^WĐŽŵƉůĞƚŝŽŶƐƚĂŶĚŝŶŐďĂĐŬƚŚĞϮͲϳͬϴΗƚƵďŝŶŐƐƉŽŽůŝŶŐ^WĐĂďůĞͬŝŶũĞĐƚŝŽŶůŝŶĞƌĞŵŽǀŝŶŐĐĂŶŶŽŶ ĐůĂŵƉƐĨƌŽŵϱ͕ϵϭϬΖƚŽϰ͕ϰϯϱΖ͘&ŝůůƚŚĞŚŽůĞĞǀĞƌǇŚƌǁŝƚŚϭϱďďůƐϴ͘ϰƉƉŐƐŽƵƌĐĞǁĂƚĞƌ͘^WĐĂďůĞƐƉŽŽůĨƵůů͕Dh&K^sĂŶĚ ĐŚĂŶŐĞŽƵƚƐƉŽŽůƐ͘ŽŶƚŝŶƵĞƚŽdKK,ǁŝƚŚ^WĐŽŵƉůĞƚŝŽŶƐƚĂŶĚŝŶŐďĂĐŬƚŚĞϮͲϳͬϴΗƚƵďŝŶŐƐƉŽŽůŝŶŐ^WĐĂďůĞͬŝŶũĞĐƚŝŽŶůŝŶĞ ƌĞŵŽǀŝŶŐĐĂŶŶŽŶĐůĂŵƉƐĨƌŽŵϰ͕ϰϯϱΖƚŽϲϰΖ͘&ŝůůƚŚĞŚŽůĞĞǀĞƌǇŚƌǁŝƚŚϭϱďďůƐϴ͘ϰƐŽƵƌĐĞǁĂƚĞƌ͘>ĂǇĚŽǁŶ^WƉƵŵƉĂƐƐĞŵďůǇ ĂƐƉĞƌĂŬĞƌĞŶƚƌŝůŝĨƚ͘ůĞĂƌƌŝŐĨůŽŽƌ͘>ĂǇĚŽǁŶ^WĐĂďůĞĂŶĚĐĂƉŝůůĂƌǇůŝŶĞƐ͘Z^WĐĂďůĞƚƌƵŶŬ͘ůĞĂŶƌŝŐĨůŽŽƌ͘DŽďŝůŝǌĞϯͲ ϭͬϮΗŚĂŶĚůŝŶŐĞƋƵŝƉŵĞŶƚĂŶĚZͬhƚŽƌƵŶϯͲϭͬϮΗǁŽƌŬƐƚƌŝŶŐ͘&ŝůůƚŚĞŚŽůĞĞǀĞƌǇŚŽƵƌǁŝƚŚϭϱďďůƐϴ͘ϰƉƉŐƐŽƵƌĐĞǁĂƚĞƌ͘/ŶƐƚĂůů ǁĞĂƌďƵƐŚŝŶŐŝŶƚƵďŝŶŐƐƉŽŽů;/сϵͲϭͬϴΗͿ͘DhzĞůůŽǁ:ĂĐŬĞƚϳͲϱͬϴΗϮϵ͘ϳηƚĞƐƚƉĂĐŬĞƌ͘Z/,ǁŝƚŚƚĞƐƚƉĂĐŬĞƌŽŶϯͲϭͬϮΗǁŽƌŬ ƐƚƌŝŶŐƵƚŝůŝǌŝŶŐůŝĨƚƐƵďǁŝƚŚϮͲϳͬϴΗĞůĞǀĂƚŽƌƐ͕ƚŽƌƋƵŝŶŐϮͲϳͬϴΗ/&ĐŽŶŶĞĐƚŝŽŶƚŽϳ͕ϬϬϬĨƚͬůďƐĨƌŽŵϭϬΖƚŽϯ͕ϮϭϱΖ;^Kсϲϱ<Ϳ͘&ŝůůƚŚĞ 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ƚŽŽŬϭϬ<ǁĞŝŐŚƚ͘EŽƚĞ͕ďŽƚƚŽŵŽĨ^WƉƵŵƉǁĂƐĂƚϭϮ͕ϬϮϮ͛͘&ŝůůƚŚĞŚŽůĞĞǀĞƌǇŚŽƵƌǁŝƚŚϭϬďďůƐϴ͘ϰƉƉŐƐŽƵƌĐĞǁĂƚĞƌ͘WhϭϬΖ ďƌĞĂŬŽǀĞƌĂƚϭϰϱ<͕ϭϰϮ<Wht͕ϳϮ<^Kt͘^ĞƚĚŽǁŶĂŐĂŝŶĂƚƐĂŵĞƐƉŽƚǁŝƚŚϭϬ<ǁĞŝŐŚƚ͘^ĞƚƐůŝƉƐ͕Dh&K^s͕ϭϱϬϮŚĞĂĚƉŝŶ ĂŶĚĐŝƌĐƵůĂƚŝŶŐŚŽƐĞ͘&ŝůůƉŝƉĞǁŝƚŚϭϵ͘ϮďďůƐͲĞƐƚŝŵĂƚĞĨůƵŝĚůĞǀĞůĂƚϮ͕ϮϴϰΖ͘^ƚĂŐĞƵƉƉƵŵƉƐƚŽϰ͘ϲWD͕ϴϭϬW^/ĂŶĚƉƵŵƉ ĂĚĚŝƚŝŽŶĂůϯϬďďůƐǁŝƚŚŶŽƌĞƚƵƌŶƐ͘ϯϬďďůƐсĐĂƐŝŶŐǀŽůƵŵĞĨͬϭϮ͕ϬϮϱΖƚͬϭϮ͕ϲϳϱΖ͘ƚƚĞŵƉƚƚŽZ/,͕ŵĂĚĞŝƚƚŽϭϮ͕ϬϮϴΖĂŶĚƐĞƚ ĚŽǁŶϭϬ<ƚǁŝĐĞ͘>ͬũŽŝŶƚͬ͘KĞůĞǀĂƚŽƌƐƚŽϱΗ͘DhyK͕&K^s͕yK͕ϱΗƉƵƉũŽŝŶƚĂŶĚDͬhƚŽƉĚƌŝǀĞ͘ƚƚĞŵƉƚƚŽƐĞƚϳͲϱͬϴΗ^yͲϭ ƚĞƐƚƉĂĐŬĞƌĂƐƉĞƌzĞůůŽǁ:ĂĐŬĞƚƌĞƉ͘ƉƉůǇϮǁƌĂƉƐ;ϯͲϱ<dYŽďƐĞƌǀĞĚͿƚŚĞŶǁŽƌŬƚŽƌƋƵĞĚŽǁŶǁͬϴƌĞĐŝƉƌŽĐĂƚŝŽŶƐ͘ƉƉůǇϭ ǁƌĂƉΘǁŽƌŬdYĚŽǁŶǁͬϲƌĞĐŝƉƌŽĐĂƚŝŽŶƐ͘ƉƉůǇϭǁƌĂƉΘǁŽƌŬdYĚŽǁŶǁͬϯƌĞĐŝƉƌŽĐĂƚŝŽŶƐ͘ƉƉůǇϭǁƌĂƉΘǁŽƌŬdYĚŽǁŶ ǁͬϯƌĞĐŝƉƌŽĐĂƚŝŽŶƐ͘WhƚŽŶĞƵƚƌĂůϵϱ<͘KďƚĂŝŶĨƌĞĞƌŽƚĂƚŝŽŶĂƚϰ<Θϴϱ<ƌŽƚĂƚŝŶŐĚŽǁŶǁĞŝŐŚƚ͘^ƚŽƉƌŽƚĂƚŝŽŶ͕WhϭϬΖƚŚĞŶ^K ĂŶĚŽďƐĞƌǀĞƉĂĐŬĞƌƐĞƚĂƚϭϮ͕ϬϮϳΖďŽƚƚŽŵŽĨƚŽŽů͕ϭϮ͕ϬϮϮΖĐĞŶƚĞƌŽĨĞůĞŵĞŶƚ͘&ŝůůϯͲϭͬϮΗĚƌŝůůƉŝƉĞǆϳͲϱͬϴΗĂŶŶƵůƵƐǁŝƚŚϴ͘ϰƉƉŐ 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ŽĨĂŶǇĂŝƌĂŶĚƉƌĞƐƐƵƌĞƵƉƚŽϭ͕ϳϬϬƉƐŝ͘WƌĞƐƐƵƌĞŝƐƐƚŝůůďůĞĞĚŝŶŐŽĨĨǁŝƚŚƚŚĞƐĂŵĞƚƌĞŶĚĂƐƉƌĞǀŝŽƵƐƚĞƐƚ͘ŝƐĐƵƐƐĞĚƌĞƐƵůƚƐ ǁŝƚŚƚŽǁŶĞŶŐŝŶĞĞƌĂŶĚĚĞĐŝƐŝŽŶǁĂƐŵĂĚĞƚŽWKK,͘ůĞĞĚƚŽϬƉƐŝĂŶĚŽƉĞŶƚŚĞhWZ͘ůŽǁĚŽǁŶƚŚĞĐŚŽŬĞŵĂŶŝĨŽůĚĂŶĚ ůŝŶĞƐ͘hŶƐĞƚƚŚĞƚĞƐƚƉĂĐŬĞƌĂŶĚŵĂŶŝƉƵůĂƚĞŝŶƚŽƚŚĞƌƵŶƉŽƐŝƚŝŽŶ͘WKK,ůĂǇŝŶŐĚŽǁŶϯͲϭͬϮΗǁŽƌŬƐƚƌŝŶŐƵƚŝůŝǌŝŶŐůŝĨƚƐƵďĨƌŽŵ ϭϮ͕ϬϮϱΖƚŽϯ͕ϮϵϱΖ͘&ŝůůƚŚĞŚŽůĞĞǀĞƌǇŚŽƵƌǁŝƚŚϭϱďďůƐϴ͘ϰƉƉŐƐŽƵƌĐĞǁĂƚĞƌ͘ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW&ͲϵϬϯ ŽǇŽŶϭϰ ϱϬͲϬϮϵͲϮϯϮϲϲͲϬϬͲϬϬ ϮϬϱͲϬϴϳ ϯͬϲͬϮϬϮϮ ϯͬϭϲͬϮϬϮϮ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ WKK,ǁŝƚŚĐůĞĂŶŽƵƚĂƐƐĞŵďůǇůĂǇŝŶŐĚŽǁŶϯͲϭͬϮΗǁŽƌŬƐƚƌŝŶŐƵƚŝůŝǌŝŶŐĂůŝĨƚƐƵďĨƌŽŵϭϬ͕ϲϱϴΖƚŽϯϭΖ͘>ͬƐĐƌĂƉĞƌ,ĨƌŽŵϯϭΖ͘ ůůĐŽŵƉŽŶĞŶƚƐŝŶŐŽŽĚĐŽŶĚŝƚŝŽŶ͕ŽŶĞƐŵĂůůƉŝĞĐĞŽĨƌƵďďĞƌŽŶƚŚĞƐĐƌĂƉĞƌďůĂĚĞ͘ůĞĂƌ,ĐŽŵƉŽŶĞŶƚƐĨƌŽŵƚŚĞƌŝŐĨůŽŽƌ͘ &ŝůůƚŚĞŚŽůĞĞǀĞƌǇŚŽƵƌǁŝƚŚϭϱďďůƐϴ͘ϰƉƉŐƐŽƵƌĐĞǁĂƚĞƌ;ϭϬďďůƐнƉŝƉĞĚŝƐƉůĂĐĞŵĞŶƚͿ͘WĞƌĨŽƌŵƌŝŐƐĞƌǀŝĐĞͲůƵďƌŝĐĂƚĞƌŝŐ ĨůŽŽƌĞƋƵŝƉŵĞŶƚĂŶĚƉŝƉĞƐŬĂƚĞ͘DͬhzĞůůŽǁ:ĂĐŬĞƚϳͲϱͬϴΗƚĞƐƚƉĂĐŬĞƌ͘Z/,ǁŝƚŚƚĞƐƚƉĂĐŬĞƌŽŶϯͲϭͬϮΗĚƌŝůůƉŝƉĞǁŽƌŬƐƚƌŝŶŐ ƵƚŝůŝǌŝŶŐůŝĨƚƐƵď͕ƚŽƌƋƵĞϮͲϳͬϴΗ/&ĐŽŶŶĞĐƚŝŽŶƐƚŽϳ͕ϬϬϬĨƚͬůďƐ͕ĨƌŽŵϭϬΖƚŽϵ͕ϯϰϳΖ͘&ŝůůƚŚĞŚŽůĞǁŝƚŚϴ͘ϰƉƉŐƐŽƵƌĐĞǁĂƚĞƌĂƚϭϬ W,͘ĂŝůǇ>ŽƐƐĞƐсϮϴϬďďůƐ͘dŽƚĂůůŽƐƐĞƐсϮϬϰϲďďůƐ͘ ϯͬϭϮͬϮϬϮϮͲ^ĂƚƵƌĚĂǇ ϯͬϭϭͬϮϬϮϮͲ&ƌŝĚĂǇ WKK,ǁŝƚŚƚĞƐƚƉĂĐŬĞƌůĂǇŝŶŐĚŽǁŶϯͲϭͬϮΗǁŽƌŬƐƚƌŝŶŐƵƚŝůŝǌŝŶŐůŝĨƚƐƵďĨƌŽŵϯ͕ϮϵϱΖƚŽϭϬΖ͘/ŶƐƉĞĐƚĂŶĚ>ͬƚĞƐƚƉĂĐŬĞƌ͘ DŝŶŝŵĂů͕ŶŽƌŵĂůǁĞĂƌŽďƐĞƌǀĞĚŽŶƉĂĐŬĞƌĞůĞŵĞŶƚƐ͘^ŵĂůůƉŝĞĐĞŽĨƌƵďďĞƌĂŶĚǁŝƌĞĨŽƵŶĚŽŶƐůŝƉĐĂƌƌŝĞƌ͘&ŝůůƚŚĞŚŽůĞĞǀĞƌǇ ŚŽƵƌǁŝƚŚϭϱďďůƐϴ͘ϰƉƉŐƐŽƵƌĐĞǁĂƚĞƌ;ϭϬďďůƐнƉŝƉĞĚŝƐƉůĂĐĞŵĞŶƚͿ͘ůĞĂƌƚĞƐƚƉĂĐŬĞƌĨƌŽŵƌŝŐĨůŽŽƌ͘DŽďŝůŝǌĞƐĐƌĂƉĞƌƌƵŶ ,ĐŽŵƉŽŶĞŶƚƐƚŽƚŚĞƌŝŐĨůŽŽƌ͘Dhϲ͘ϳϱΗƌŽůůĞƌĐŽŶĞďŝƚ͕ƚǁŽďŽŽƚďĂƐŬĞƚƐ͕ϳͲϱͬϴΗĐĂƐŝŶŐƐĐƌĂƉĞƌ͕ďŝƚƐƵď͕ŽŝůũĂƌĂŶĚyKƐƵď ƚŽϯϭΖ͘Z/,ǁŝƚŚĐůĞĂŶŽƵƚĂƐƐĞŵďůǇŽŶϯͲϭͬϮΗǁŽƌŬƐƚƌŝŶŐƵƚŝůŝǌŝŶŐĂůŝĨƚƐƵďĨƌŽŵϯϭΖƚŽϭϮ͕ϳϮϵΖ͘dŽƌƋƵĞϮͲϳͬϴΗ/&ĐŽŶŶĞĐƚŝŽŶƐ ƚŽϳ͕ϬϬϬĨƚͬůďƐ͘ŝĚŶŽƚƐĞĞĂŶǇďŽďďůĞƐŽŶƚŚĞǁĞŝŐŚƚŝŶĚŝĐĂƚŽƌ͘&ŝůůƚŚĞŚŽůĞĞǀĞƌǇŚŽƵƌǁŝƚŚϭϬďďůƐϴ͘ϰƉƉŐƐŽƵƌĐĞǁĂƚĞƌ͘ WKK,ĨƌŽŵϭϮ͕ϳϮϵΖƚŽϭϮ͕ϲϰϳΖ͘ŚĂŶŐĞĞůĞǀĂƚŽƌƐƚŽϱΖW͘WhĂŶĚDhĐƌŽƐƐŽǀĞƌƐĂŶĚũŽŝŶƚŽĨϱΗW͘Z/,ƚŽϭϮ͕ϲϴϬΖ͘dƵƌŶŽŶ ƚŚĞƌŽƚĂƌǇĂƚϯϬZWDсϱ<ĨƚͲůďƐ͕ǁŽƌŬƚŚĞ,ĨƌŽŵϭϮ͕ϲϴϬΖƚŽϭϮ͕ϲϬϬΖƚŚĞŶďĂĐŬĚŽǁŶƚŽϭϮ͕ϲϴϬΖ͘dƵƌŶŽĨĨƚŚĞƌŽƚĂƌǇ͘WƵŵƉ ϭϬďďůƐĚŽǁŶƚŚĞ/͘WhĨƌŽŵϭϮ͕ϲϴϬΖƚŽϭϮ͕ϲϰϳΖ͘>ĂǇĚŽǁŶƚŚĞũŽŝŶƚŽĨϱΗWĂŶĚĐƌŽƐƐŽǀĞƌƐ͘ŚĂŶŐĞĞůĞǀĂƚŽƌƐƚŽϮͲϳͬϴΗ͘ WKK,ǁŝƚŚĐůĞĂŶŽƵƚĂƐƐĞŵďůǇůĂǇŝŶŐĚŽǁŶϯͲϭͬϮΗǁŽƌŬƐƚƌŝŶŐƵƚŝůŝǌŝŶŐĂůŝĨƚƐƵďĨƌŽŵϭϮ͕ϲϰϳΖƚŽϭϬ͕ϲϱϴΖ͘&ŝůůƚŚĞŚŽůĞĞǀĞƌǇ ŚŽƵƌǁŝƚŚϭϱďďůƐϴ͘ϰƉƉŐƐŽƵƌĐĞǁĂƚĞƌ;ϭϬďďůƐнƉŝƉĞĚŝƐƉůĂĐĞŵĞŶƚͿ͘ĂŝůǇ>ŽƐƐĞƐсϰϱϱďďůƐ͘dŽƚĂůůŽƐƐĞƐсϭϳϲϲďďůƐ͘ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW&ͲϵϬϯ ŽǇŽŶϭϰ ϱϬͲϬϮϵͲϮϯϮϲϲͲϬϬͲϬϬ ϮϬϱͲϬϴϳ ϯͬϲͬϮϬϮϮ ϯͬϭϲͬϮϬϮϮ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ ŽŶƚŝŶƵĞƚŽWKK,ůĂǇŝŶŐĚŽǁŶϯͲϭͬϮΗĚƌŝůůƉŝƉĞĨƌŽŵϮ͕ϲϴϳΖƚŽϳͲϱͬϴΗƚĞƐƚƉĂĐŬĞƌĂƚϭϭΖƵƚŝůŝǌŝŶŐĂůŝĨƚƐƵď͘/ŶƐƉĞĐƚĂŶĚ>ͬ ƉĂĐŬĞƌͲŐŽŽĚĐŽŶĚŝƚŝŽŶ͘&ŝůůƚŚĞŚŽůĞǁŝƚŚϭϬW,ϴ͘ϰƉƉŐƐŽƵƌĐĞǁĂƚĞƌнƉŝƉĞĚŝƐƉůĂĐĞŵĞŶƚсϭϱW,͘tŚŝůĞƌĞŵŽǀŝŶŐƚŚĞ ƉĂĐŬĞƌĨƌŽŵƚŚĞƉŝƉĞƐŬĂƚĞǁŝƚŚĂďƌŝĚŐĞĐƌĂŶĞ͕ƚŚĞƌŽƵƐƚĂďŽƵƚƐĨŽŽƚǁĂƐŝŶũƵƌĞĚďǇƚŚĞƉŝƉĞƐŬĂƚĞĞũĞĐƚŽƌ͘^ŚƵƚĚŽǁŶ͕ŵŽǀĞ ƚŽƐĂĨĞůŽĐĂƚŝŽŶĂŶĚŵĂŬĞŶŽƚŝĨŝĐĂƚŝŽŶƐ͘ǁĂƐƚƌĂŶƐƉŽƌƚĞĚƚŽDŝůŶĞWŽŝŶƚĨŽƌŵĞĚŝĐĂůĂƚƚĞŶƚŝŽŶ͘WĞƌĨŽƌŵĂĐĐŝĚĞŶƚ ŝŶǀĞƐƚŝŐĂƚŝŽŶĂŶĚŚŽůĚƐĂĨĞƚǇƐƚĂŶĚĚŽǁŶǁŝƚŚƌŝŐĐƌĞǁ͘ĚĚŝŶŐϭϬW,ŽĨϴ͘ϰƉƉŐƐŽƵƌĐĞǁĂƚĞƌ͘W:^D͘ůĞĂƌƌŝŐĨůŽŽƌŽĨzĞůůŽǁ :ĂĐŬĞƚƚŽŽůƐĞƋƵŝƉŵĞŶƚ͘^ĞƌǀŝĐĞϮͲϳͬϴΗĞůĞǀĂƚŽƌƐ͘ZĞŵŽǀĞǁĞĂƌďƵƐŚŝŶŐ͘ĚĚŝŶŐϭϬW,ŽĨϴ͘ϰƉƉŐƐŽƵƌĐĞǁĂƚĞƌ͘ZhƚŽƌƵŶϮͲ ϳͬϴΗ^WĐŽŵƉůĞƚŝŽŶ͘DͬhϭϬΖƉƵƉũŽŝŶƚƚŽůĂŶĚŝŶŐũŽŝŶƚ͘DhϭϬ͘ϮΖƉƵƉƚŽĚŝƐĐŚĂƌŐĞŚĞĂĚ͘WƵůů^WĐĂďůĞĂŶĚĐĂƉŝůůĂƌǇůŝŶĞ ƚŚƌŽƵŐŚƐŚĞĂǀĞŽǀĞƌƚŚĞǁŝŶĚǁĂůůƐ͘ĚĚŝŶŐϭϬW,ŽĨϴ͘ϰƉƉŐƐŽƵƌĐĞǁĂƚĞƌ͘W:^D͘DhĐĞŶƚƌĂůŝǌĞƌĂŶĚŵŽƚŽƌŐĂƵŐĞƚŽ^W ŵŽƚŽƌ͘&ŝůůŵŽƚŽƌǁŝƚŚŽŝů͘DhƚĂŶĚĞŵƐĞĂůƐ͕ŐĂƐƐĞƉĂƌĂƚŽƌ͕ƉƵŵƉ͕ĚŝƐĐŚĂƌŐĞŚĞĂĚĂŶĚϮͲϳͬϴΗƉƵƉũŽŝŶƚ͘/ŶƐƚĂůůĐĂƉŝůůĂƌǇůŝŶĞ ĂŶĚĨůĂƚDŽƚŽƌ>ĞĂĚǆƚĞŶƐŝŽŶ͘/ŶƐƚĂůůĨůĂƚŐƵĂƌĚƐĂŶĚĐůĂŵƉƐŽŶD>͘ĚĚŝŶŐϭϬW,ŽĨϴ͘ϰƉƉŐƐŽƵƌĐĞǁĂƚĞƌ͘^ƉůŝĐĞƚŚĞD> ƚŽƚŚĞ^WĐĂďůĞ͘ĚĚŝŶŐϭϬW,ŽĨϴ͘ϰƉƉŐƐŽƵƌĐĞǁĂƚĞƌ͘Z/,ǁŝƚŚ^WƚŽϳϲΖ͘WhƐƚĂŶĚηϭĂŶĚůĂǇĚŽǁŶϮũŽŝŶƚƐ͘DhyE ŶŝƉƉůĞ͕ϭũŽŝŶƚ͕'>DǁŝƚŚsĂŶĚϭũŽŝŶƚ͘d/,ǁŝƚŚ^WĐŽŵƉůĞƚŝŽŶŽŶϮͲϳͬϴΗ͕ϲ͘ϱη͕>ͲϴϬhƚƵďŝŶŐĨƌŽŵƚŚĞĚĞƌƌŝĐŬ͕ƐƉŽŽůŝŶŐ ^WĂďůĞͬϯͬϴΗŝŶũĞĐƚŝŽŶůŝŶĞĂŶĚŝŶƐƚĂůůŝŶŐĐĂŶŶŽŶĐůĂŵƉƐ;ƚŽƌƋƵĞсϮ͕ϮϱϬĨƚͲůďƐͿĨƌŽŵϳϲΖƚŽϳ͕ϳϴϵΖ͘dĞƐƚŝŶŐ^WĐĂďůĞ ĐŽŶƚŝŶƵŝƚǇĞǀĞƌǇϮ͕ϬϬϬΖ͘Dh&K^sǁŝƚŚĐƌŽƐƐŽǀĞƌƐĨŽƌ^WĐĂďůĞƐƉůŝĐĞ͘ĚĚŝŶŐϭϬW,ŽĨϴ͘ϰƉƉŐƐŽƵƌĐĞǁĂƚĞƌ͘ĂŝůǇ>ŽƐƐĞƐс ϯϲϴďďůƐ͘dŽƚĂůůŽƐƐĞƐсϮϳϯϬďďůƐ͘ ϯͬϭϯͬϮϬϮϮͲ^ƵŶĚĂǇ Z/,ǁŝƚŚƚĞƐƚƉĂĐŬĞƌŽŶϯͲϭͬϮΗĚƌŝůůƉŝƉĞǁŽƌŬƐƚƌŝŶŐƵƚŝůŝǌŝŶŐůŝĨƚƐƵď͕ƚŽƌƋƵĞϮͲϳͬϴΗ/&ĐŽŶŶĞĐƚŝŽŶƐƚŽϳ͕ϬϬϬĨƚͬůďƐ͕ĨƌŽŵϵ͕ϯϰϳΖ ƚŽϭϮ͕ϱϵϳΖ͘dŽŽŬϭϬ<ǁĞŝŐŚƚ͘&ŝůůϭϱďďůƐŽŶ/ƚŽĂƚƚĞŵƉƚƚŽĨůƵƐŚ͘WhĂƚƚĞŵƉƚƚŽǁŽƌŬϯŵŽƌĞƚŝŵĞƐďƵƚƚŽŽŬǁĞŝŐŚƚĂƐƐĂŵĞ ƐƉŽƚ͘ϭϱϱ<WhtͬϳϬ<^Kt͘&ŝůůƚŚĞŚŽůĞǁŝƚŚϴ͘ϰƉƉŐƐŽƵƌĐĞǁĂƚĞƌĂƚϭϬW,͘>ƐŝŶŐůĞƚŽϭϮ͘ϱϴϵΖ͘ŚĂŶŐĞĞůĞǀĂƚŽƌƐ͕DhyK͕ &K^s͕yK͕ϱΗƉƵƉũŽŝŶƚĂŶĚƚŽƉĚƌŝǀĞ͘ϭϱϮ<WhͬϳϮ<^KͬϭϭϬ<ZKd͘ƉƉůǇƌŽƚĂƚŝŽŶϭϱZWDͬϲ<dY͘ZĞĐŝƉƌŽĐĂƚĞƉŝƉĞĂŶĚ ǁŽƌŬƌŽƚĂƚŝŽŶĚŽǁŶƚŽƐĞƚƉĂĐŬĞƌ͘WĂĐŬĞƌƐĞƚĂƚϭϮ͕ϱϴϰΖĐĞŶƚĞƌŽĨĞůĞŵĞŶƚ͘&ŝůůϯͲϭͬϮΗǆϳͲϱͬϴΗĂŶŶƵůƵƐǁŝƚŚϴ͘ϰƉƉŐƐŽƵƌĐĞ ǁĂƚĞƌĂŶĚĂůůŽǁĂŝƌƚŽďƌĞĂŬŽƵƚ͘ϳϮďďůƐƚŽĨŝůůĂŶŶƵůƵƐ͘ZŝŐƵƉƚĞƐƚĞƋƵŝƉŵĞŶƚ͕ĐůŽƐĞϮͲϳͬϴΗǆϱΗƵƉƉĞƌsZĂŶĚƉƵƌŐĞĐŚŽŬĞ ŵĂŶŝĨŽůĚ͘WƌĞƐƐƵƌĞƚĞƐƚĂŶŶƵůƵƐƚŽϭ͕ϵϬϬƉƐŝĨŽƌϯϬŵŝŶƵƚĞƐŽŶĐŚĂƌƚ;ŐŽŽĚƚĞƐƚͿ͘ϰ͘ϬďďůƐƉƵŵƉĞĚ͕ϰ͘ϬďďůƐďůĞĚďĂĐŬ͘KƉĞŶ hWZ͘WhĂŶĚƌĞůĞĂƐĞƉĂĐŬĞƌ͘WhƚŽϭϳϱ<͕ŶŽƌĞůĞĂƐĞ͘^KƚŽϭϬϬ<ĂŶĚĂƉƉůǇϳZ,ƚƵƌŶƐ͘^KƚŽϰϱ<ƚŚĞŶWhĂŶĚŽďƐĞƌǀĞƉĂĐŬĞƌ ƌĞůĞĂƐĞĂƚϭϲϬ<͘ƌĞĂŬŽƵƚƚŽƉĚƌŝǀĞ͕>yK͕&K^s͕yK͕ϱΗƉƵƉũŽŝŶƚĂŶĚĐŚĂŶŐĞĞůĞǀĂƚŽƌƐ͘>ϭũŽŝŶƚŽĨϯͲϭͬϮΗĚƌŝůůƉŝƉĞĨƌŽŵ ϭϮ͕ϱϴϵΖƚŽϭϮ͕ϱϰϵΖ͘DhyK͕&K^s͕yK͕ϱΗƉƵƉũŽŝŶƚĂŶĚƚŽƉĚƌŝǀĞ͘^ĞƚƚŽƉĚƌŝǀĞŽŶƉƵƉũŽŝŶƚ͘^ůŝƉĂŶĚĐƵƚϳϵΖŽĨĚƌŝůůŝŶŐůŝŶĞ͘ ^ĞƌǀŝĐĞƚŽƉĚƌŝǀĞ͘>yK͕&K^s͕yKĂŶĚϱΗƉƵƉũŽŝŶƚ͘ŚĂŶŐĞƚŚĞĞůĞǀĂƚŽƌƐ͘WKK,ǁŝƚŚƚŚĞƚĞƐƚƉĂĐŬĞƌůĂǇŝŶŐĚŽǁŶϯͲϭͬϮΗ ǁŽƌŬƐƚƌŝŶŐƵƚŝůŝǌŝŶŐĂůŝĨƚƐƵďĨƌŽŵϭϮ͕ϱϰϵΖƚŽϳ͕ϯϰϬΖ͘&ŝůůƚŚĞŚŽůĞĞǀĞƌǇŚŽƵƌǁŝƚŚϭϱďďůƐϴ͘ϰƉƉŐƐŽƵƌĐĞǁĂƚĞƌ;ϭϬďďůƐнƉŝƉĞ ĚŝƐƉůĂĐĞŵĞŶƚͿ͘WŝƉĞƐŬĂƚĞŚǇĚƌĂƵůŝĐŚŽƐĞŐŽƚƉŝŶĐŚĞĚďĞƚǁĞĞŶƚŚĞŚŽƐĞƌĞĞůĂŶĚƉŝƉĞƐŬĂƚĞĂƐŝƚĐĂŵĞďĂĐŬƉƵƚƚŝŶŐƚĞŶƐŝŽŶŽŶ ƚŚĞŚǇĚƌĂƵůŝĐŚŽƵƐĞĂŶĚƉĂƌƚŝŶŐĂƚĂĐŽŶŶĞĐƚŝŽŶ͘WŝƉĞƐŬĂƚĞǁĂƐƐĞĐƵƌĞĚĂŶĚůŽĐŬĞĚͬƚĂŐŐĞĚŽƵƚ͘^ƉŝůůĞĚϭƋƵĂƌƚŚǇĚƌĂƵůŝĐŽŝů ŝŶƚŽĐŽŶƚĂŝŶŵĞŶƚŝŶƚŚĞƉŝƉĞƐŚĞĚ͘ůĞĂŶĞĚƵƉĂŶĚĚŝƐƉŽƐĞĚŽĨƉƌŽƉĞƌůǇ͘dŚĞƌŝŐŵĞĐŚĂŶŝĐƌĞŵŽǀĞĚƚŚĞŚŽƐĞ͕ŵĂĚĞĂŶĞǁ ŚŽƵƐĞĂŶĚŝŶƐƚĂůůĞĚ͘&ƵŶĐƚŝŽŶƚĞƐƚĞĚŐŽŽĚ͘ŽŶƚŝŶƵĞƚŽWKK,ǁŝƚŚƚŚĞƚĞƐƚƉĂĐŬĞƌůĂǇŝŶŐĚŽǁŶϯͲϭͬϮΗǁŽƌŬƐƚƌŝŶŐƵƚŝůŝǌŝŶŐĂ ůŝĨƚƐƵďĨƌŽŵϳ͕ϯϰϬΖƚŽϮ͕ϲϴϳΖ͘&ŝůůƚŚĞŚŽůĞĞǀĞƌǇŚŽƵƌǁŝƚŚϭϱďďůƐϴ͘ϰƉƉŐƐŽƵƌĐĞǁĂƚĞƌ;ϭϬďďůƐнƉŝƉĞĚŝƐƉůĂĐĞŵĞŶƚͿ͘ĂŝůǇ >ŽƐƐĞƐсϯϭϲďďůƐ͘dŽƚĂůůŽƐƐĞƐсϮϯϲϮďďůƐ͘ ϯͬϭϰͬϮϬϮϮͲDŽŶĚĂǇ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW&ͲϵϬϯ ŽǇŽŶϭϰ ϱϬͲϬϮϵͲϮϯϮϲϲͲϬϬͲϬϬ ϮϬϱͲϬϴϳ ϯͬϲͬϮϬϮϮ ϯͬϭϲͬϮϬϮϮ 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Caliper 02/10/2022 Please include current contact information if different from above. 205-087 T36394 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.04 09:53:55 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20220216 1437 APPROVED MPU F-93 (PTD 205-087) Sundry 322-070 Step Revision Date:Wednesday, February 16, 2022 2:39:09 PM Attachments:MPU F-93 ESP Changeout Procedure Rev1 02-16-2022.docx Taylor, Revision 1 to Sundry 322-070 is approved. Thank you. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Taylor Wellman <twellman@hilcorp.com> Sent: Wednesday, February 16, 2022 10:53 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: MPU F-93 (PTD 205-087) Approved Sundry 322-070 Step Revision Mel, Following our discussion on MPU F-93 (PTD 205-087) under approved sundry 322-070 enclosed is the revised step for Doyon 14 moving over the well. Step 14. Current: RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. Revised: Set BPV. The change reflects that a BPV and the production tree will be in place while Doyon 14 is moved over the well. Once over the well, a CTS plug will be installed Doyon 14 will N/D the tree and set their BOPE with gantry cranes attached to the substructure. These steps remain the same as written. Attached is a copy of the revised procedure with the change in place. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC – Ops Engineer: Milne Point Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified 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. ESP Change Out Revision 1 – 02/16/2022 Well: MPU F-93 Date: 02/08/2022 Well Name: MPU F-93 API Number: 50-029-23226-00-00 Current Status: Oil Well [Failed ESP] Pad: F-Pad Estimated Start Date: March 5, 2022 Rig: Doyon 14 Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Darci Horner Permit to Drill Number: 205-870 First Call Engineer: Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (M) Current Bottom Hole Pressure: 1,927 psi @ 7,160’ TVD (DH Gauge - 10 day shut in / 5.2 ppg EMW) Maximum Expected BHP: 3,145 psi @ 7,160’ TVD (90 day PBU / 8.5 ppg EMW ) MPSP: 2,429 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU F-93 was drilled and completed as a cemented and perforated liner in 2005. The well was perforated and hydraulically fractured in the Kuparuk A1, A2 and A3 sands. The well produced with 3 ESP’s during through 2013. One installation had a broken shaft with heavy scale buildup in the pump and outside the motor. In 2014 the well was coil sidetracked with a multilateral system placing 3 laterals into the Kuparuk A1, A2 and A3 sands. Directly following the coil tubing multilateral sidetracks, an ESP completion was ran. The ESP ran for 4 years and 10 months prior to failure in 2019. The next ESP ran for 2 years and 11 months. Notes Regarding Wellbore Condition • CO 390A: A packer is not required on this ESP completion as the maximum anticipated reservoir pressure of 8.5 ppg EMW is less than 8.55 ppg EMW. A follow up BHP survey will be conducted to confirm prior to workover. • Last CSG Test (13,276’ – surface) 3,000 psi – 03/13/2014 • Offset Injector Support o F-70A offline o F-30A, F-88, F-92, F-95 online – all support additional producers in fault block Objective: Pull failed ESP, pressure test casing and run a new ESP. Slickline (Non-sundried steps): 1. RU SL unit and pressure test PCE to 250psi/2,500psi high. 2. Pull lower DGLV from 11,898’ md. 3. Pull LGLV from 132’ md and set DGLV. 4. Caliper tubing from 12,008’ to surface. 5. RD SL Unit. Pre-Rig Procedure: 6. Use downhole gauge to confirm BHP to confirm KWF prior to mobilization for RWO (KWF will be changed from produced water to a brine to provide a trip margin if needed). Notify AOGCC if exceeds 8.55ppg gradient. ESP Change Out Revision 1 – 02/16/2022 Well: MPU F-93 Date: 02/08/2022 7. Clear and level pad area in front of well. Spot rig mats and containment. 8. RD well house and flowlines. Clear and level area around well. 9. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 10. Pressure test lines to 3,000 psi. 11. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 bbl returns tank. a. Partial returns will probably be seen. After attempting circulation down the tubing, load the IA. 12. Confirm well is dead. Contact the operations engineer if freeze protection is needed depending on Doyon 14 arrival. 13. RD Little Red Services and reverse out skid. 14. Set BPV. Brief RWO Procedure: 15. MIRU Doyon 14, ancillary equipment and lines. 16. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ produced water. Set CTS plug. 17. NU 11” x 13-5/8” 5M casing spool. 18. NU 13-5/8” x 5M BOP as follows: • BOP configuration from top down: 13-5/8” x 5M annular / 13-5/8” x 5M double gate / 13-5/8” x 5M mud cross / 13-5/8” x 5M single gate • Double gate ram should be dressed with 2-7/8” x 5” VBRs in top cavity, blind ram in bottom cavity. • Single ram can be dressed with 2-7/8” x 5” VBRs. 19. Test BOP to 250/3,000 psi for 5/5 min. Test annular to 250/2,500 psi for 5/5 min. a. Notify the AOGCC 24 hours in advance of BOP test. b. Test upper 2-7/8” x 5” rams with the 2-7/8” and 3-1/2” test joints. c. Confirm test pressures with Approved Sundry. d. Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug. e. Once BOPE test is complete, send a copy of the test report (10-424 form) to AOGCC and town engineer. 20. Bleed any pressure off casing to the returns tank. Pull CTS plug and BPV. Kill well with produced water as needed. 21. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2019 ESP swap was 57 K lbs to free pipe, 62K up wt. after free. The current completion was landed with a PUW of 59k and slack off wt of 26k. 22. Recover the tubing hanger. 23. POOH and lay down the 2-7/8” tubing. Number all joints. Confirm with Operations Engineer if tubing will be saved for inspection and potential reuse on another well or if it will be scrapped based on caliper data. Lay down failed ESP. a. Pull out all visually bad joints and mark for disposal. b. Look for over-torqued connections from previous tubing runs and junk them. ESP Change Out Revision 1 – 02/16/2022 Well: MPU F-93 Date: 02/08/2022 c. 193 Cannon Cross Collar Clamps, 5 protectrolizers, and 3 flat guards were installed. 24. PU 7” test packer and run on 3-1/2” workstring to ±12,600’ md. a. Estimated TOC is at 12,541’ md (calculated from cementing report 7/7/05). 25. Test casing to 1,700psi for 30 minutes (charted). 26. PU new ESP and RIH on 2-7/8” 6.5# L-80 tubing. Check electrical connections every 2,000’ a. Base of ESP at ± 12,070’ MD (this is based on DSV and the only acceptable setting window for an ESP). a. Chemical injection diffuser along the centralizer. b. 1 joints of 2-7/8”, 6.5#, L-80, EUE 8rd tubing c. 2-7/8” XN (2.205” No-Go) Nipple d. 3-4 joints of 2-7/8”, 6.5#, L-80, EUE 8rd tubing e. Lower 2-7/8”x 1” Side-pocket GLM with Dummy GLV f. Multiple joints 2-7/8”, 6.5#, L-80, EUE 8rd tubing g. Upper 2-7/8”x 1” Side-pocket GLM @ ± 200’ MD with 0.25” OV h. ± 5 joints 2-7/8”, 6.5#, L-80, EUE 8rd tubing 27. Land tubing hanger (Caution not to Damage Cable while landing the hanger). Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 28. Set BPV. Post-Rig Procedure: 1. ND BOP stack and NU existing 2-9/16” 5,000# tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 2. RD Doyon 14. Move to next well location. 3. RD crane. Move 500 bbl returns tank and rig mats to next well location. 4. Replace gauge(s) if removed. 5. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. 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ůĞĞĚĂŶǇƉƌĞƐƐƵƌĞŽĨĨĐĂƐŝŶŐƚŽƚŚĞƌĞƚƵƌŶƐƚĂŶŬ͘WƵůůd^ƉůƵŐĂŶĚWs͘<ŝůůǁĞůůǁŝƚŚƉƌŽĚƵĐĞĚ ǁĂƚĞƌĂƐŶĞĞĚĞĚ͘ Ϯϭ͘ DhůĂŶĚŝŶŐũŽŝŶƚŽƌƐƉĞĂƌĂŶĚWhŽŶƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͘ Ă͘ dŚĞWhǁĞŝŐŚƚĚƵƌŝŶŐƚŚĞϮϬϭϵ^WƐǁĂƉǁĂƐϱϳ<ůďƐƚŽĨƌĞĞƉŝƉĞ͕ϲϮ<ƵƉǁƚ͘ĂĨƚĞƌĨƌĞĞ͘ dŚĞĐƵƌƌĞŶƚĐŽŵƉůĞƚŝŽŶǁĂƐůĂŶĚĞĚǁŝƚŚĂWhtŽĨϱϵŬĂŶĚƐůĂĐŬŽĨĨǁƚŽĨϮϲŬ͘ ϮϮ͘ ZĞĐŽǀĞƌƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͘ Ϯϯ͘ WKK,ĂŶĚůĂǇĚŽǁŶƚŚĞϮͲϳͬϴ͟ƚƵďŝŶŐ͘EƵŵďĞƌĂůůũŽŝŶƚƐ͘ŽŶĨŝƌŵǁŝƚŚKƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌŝĨ ƚƵďŝŶŐǁŝůůďĞƐĂǀĞĚĨŽƌŝŶƐƉĞĐƚŝŽŶĂŶĚƉŽƚĞŶƚŝĂůƌĞƵƐĞŽŶĂŶŽƚŚĞƌǁĞůůŽƌŝĨŝƚǁŝůůďĞƐĐƌĂƉƉĞĚ ďĂƐĞĚŽŶĐĂůŝƉĞƌĚĂƚĂ͘>ĂǇĚŽǁŶĨĂŝůĞĚ^W͘ Ă͘ WƵůůŽƵƚĂůůǀŝƐƵĂůůǇďĂĚũŽŝŶƚƐĂŶĚŵĂƌŬĨŽƌĚŝƐƉŽƐĂů͘ ď͘ >ŽŽŬĨŽƌŽǀĞƌͲƚŽƌƋƵĞĚĐŽŶŶĞĐƚŝŽŶƐĨƌŽŵƉƌĞǀŝŽƵƐƚƵďŝŶŐƌƵŶƐĂ ŶĚũƵŶŬƚŚĞŵ͘ ^WŚĂŶŐĞKƵƚ tĞůů͗DWh&Ͳϵϯ ĂƚĞ͗ϬϮͬϬϴͬϮϬϮϮ Đ͘ ϭϵϯĂŶŶŽŶƌŽƐƐŽůůĂƌůĂŵƉƐ͕ϱƉƌŽƚĞĐƚƌŽůŝǌĞƌƐ͕ĂŶĚϯĨůĂƚŐƵĂƌĚƐǁĞƌĞŝŶƐƚĂůůĞĚ͘ Ϯϰ͘ Whϳ͟ƚĞƐƚƉĂĐŬĞƌĂŶĚƌƵŶŽŶϯͲϭͬϮ͟ǁŽƌŬƐƚƌŝŶŐƚŽцϭϮ͕ϲϬϬ͛ŵĚ͘ Ă͘ ƐƚŝŵĂƚĞĚdKŝƐĂƚϭϮ͕ϱϰϭ͛ŵĚ;ĐĂůĐƵůĂƚĞĚĨƌŽŵĐĞŵĞŶƚŝŶŐƌĞƉŽƌƚϳͬϳͬϬϱͿ͘ Ϯϱ͘ dĞƐƚĐĂƐŝŶŐƚŽϭ͕ϳϬϬƉƐŝĨŽƌϯϬŵŝŶƵƚĞƐ;ĐŚĂƌƚĞĚͿ͘ Ϯϲ͘ WhŶĞǁ^WĂŶĚZ/,ŽŶϮͲϳͬϴ͟ϲ͘ϱη>ͲϴϬƚƵďŝŶŐ͘ŚĞĐŬĞůĞĐƚƌŝĐĂůĐŽŶŶĞĐƚŝŽŶƐĞǀĞƌǇϮ͕ϬϬϬ͛ Ă͘ ĂƐĞŽĨ^WĂƚцϭϮ͕ϬϳϬ͛D;ƚŚŝƐŝƐďĂƐĞĚŽŶ^sĂŶĚƚŚĞŽŶůǇĂĐĐĞƉƚĂďůĞƐĞƚƚŝŶŐǁŝŶĚŽǁĨŽƌ ĂŶ^WͿ͘ Ă͘ ŚĞŵŝĐĂůŝŶũĞĐƚŝŽŶĚŝĨĨƵƐĞƌĂůŽŶŐƚŚĞĐĞŶƚƌĂůŝǌĞƌ͘ ď͘ ϭũŽŝŶƚƐŽĨϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Đ͘ ϮͲϳͬϴ͟yE;Ϯ͘ϮϬϱ͟EŽͲ'ŽͿEŝƉƉůĞ Ě͘ ϯͲϰũŽŝŶƚƐŽĨϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Ğ͘ >ŽǁĞƌϮͲϳͬϴ͟ǆϭ͟^ŝĚĞͲƉŽĐŬĞƚ'>DǁŝƚŚƵŵŵǇ'>s Ĩ͘ DƵůƚŝƉůĞũŽŝŶƚƐϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Ő͘ hƉƉĞƌϮͲϳͬϴ͟ǆϭ͟^ŝĚĞͲƉŽĐŬĞƚ'>DΛцϮϬϬ͛DǁŝƚŚϬ͘Ϯϱ͟Ks Ś͘ цϱũŽŝŶƚƐϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Ϯϳ͘ >ĂŶĚƚƵďŝŶŐŚĂŶŐĞƌ;ĂƵƚŝŽŶŶŽƚƚŽĂŵĂŐĞĂďůĞǁŚŝůĞůĂŶĚŝŶŐƚŚĞŚĂŶŐĞƌͿ͘>ĂǇĚŽǁŶůĂŶĚŝŶŐ ũŽŝŶƚ͘EŽƚĞWh;WŝĐŬhƉͿĂŶĚ^K;^ůĂĐŬKĨĨͿǁĞŝŐŚƚƐŽŶƚĂůůǇ͘ Ϯϴ͘ ^ĞƚWs͘ WŽƐƚͲZŝŐWƌŽĐĞĚƵƌĞ͗ ϭ͘ EKWƐƚĂĐŬĂŶĚEhĞǆŝƐƚŝŶŐϮͲϵͬϭϲ͟ϱ͕ϬϬϬηƚƌĞĞͬĂĚĂƉƚĞƌĨůĂŶŐĞ͘dĞƐƚƚƵďŝŶŐŚĂŶŐĞƌǀŽŝĚƚŽϱϬϬ ƉƐŝůŽǁͬϱ͕ϬϬϬƉƐŝŚŝŐŚ͘WƵůůWs͘ Ϯ͘ ZŽǇŽŶϭϰ͘DŽǀĞƚŽŶĞǆƚǁĞůůůŽĐĂƚŝŽŶ͘ ϯ͘ ZĐƌĂŶĞ͘DŽǀĞϱϬϬďďůƌĞƚƵƌŶƐƚĂŶŬĂŶĚƌŝŐŵĂƚƐƚŽŶĞǆƚǁĞůůůŽĐĂƚŝŽŶ͘ ϰ͘ ZĞƉůĂĐĞŐĂƵŐĞ;ƐͿŝĨƌĞŵŽǀĞĚ͘ ϱ͘ dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ͘ZhǁĞůůŚŽƵƐĞĂŶĚĨůŽǁůŝŶĞƐ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ KW^ĐŚĞŵĂƚŝĐ 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ϮͲϳͬϴ͟yEͲEŝƉƉůĞ ;Ϯ͘ϮϬϱEŽͲŐŽ/Ϳ ϰ ϭϮ͕ϬϬϴ͘ϴ ŝƐĐŚĂƌŐĞ,ĞĂĚ͗'W/^ ϱ ϭϮ͕ϬϬϵ͛ WƵŵƉ͗ϴϲ&>yϰϳ ϲ ϭϮ͕ϬϯϬ͛ 'ĂƐ^ĞƉĂƌĂƚŽƌ͗'Z^&ZEZ ϳ ϭϮ͕Ϭϯϯ͛ dĂŶĚĞŵ^ĞĂů͗'^ϯhd^ͬ^W&^Θ'^ϯ>d^ͬ^W&^ ϴ ϭϮ͕Ϭϰϳ͛ DŽƚŽƌ͗ZdϱϲϮyWʹϮϯϲ,ƉͬϮ͕ϮϭϬsͬϲϱ ϵ ϭϮ͕Ϭϲϵ͛ W,KE/yydͲϭϱϬΘĞŶƚƌĂůŝǌĞƌʹ ŽƚƚŽŵсϭϮ͕Ϭϳϯ͛ ϭϬ ϭϯ͕Ϯϯϳ͛ ϯ͘ϱ͚͟y͛EŝƉƉůĞʹϮ͘ϴϭϯ/ ϭϭ ϭϯ͕Ϯϲϯ͛ ,^ZĂƚĐŚ>ĂƚĐŚʹƚŵΛϭϯ͕Ϯϲϲ͛ ϭϮ ϭϯ͕Ϯϳϲ͛ ϳͲϱͬϴ͟ǆϯ͘ϱ͟dEdWĞƌŵWĂĐŬĞƌ ϭϯ ϭϯ͕ϯϬϳ͛ ϯ͘ϱ͚͟y͛EŝƉƉůĞǁZ,ͲDͲϮ͘ϴϭϯ/ ϭϰ ϭϯ͕ϯϯϴ͛ ĂŬĞƌyWWĂĐŬĞƌ ϭϱ ϭϯ͕ϯϯϵ͛ ϰͲϭͬϮ͟t>'ʹ ƚŵΛϭϯ͕ϯϰϭ ϭϲ ϭϯ͕ϰϭϳ͛ ĂŬĞƌyWWĂĐŬĞƌ ϭϳ ϭϯ͕ϰϮϭ͛ <>ŝŶĞƌdŽƉWĂĐŬĞƌ ϭϴ ϭϯ͕ϰϮϳ͛ ĞƉůŽǇŵĞŶƚ^ůĞĞǀĞ ϭϵ ϭϯ͕ϰϯϭ͛ ^ĞĂůƐƐĞŵďůǇǁŝƚŚ&ƵůůDƵůĞ^ŚŽĞ ϮϬ ϭϯ͕ϰϯϱ͛ ĂŬĞƌ,D>ŝŶĞƌ,ĂŶŐĞƌ Ϯϭ ϭϰ͕ϭϭϴ͛ ůƵŵŝŶƵŵŝůůĞƚϮͲϯͬϴ͟^d>WŝŶ ϮϮ ϭϰ͕ϮϮϭ͛ ůƵŵŝŶƵŵŝůůĞƚϮͲϯͬϴ͟^d>WŝŶ Ϯϯ ϭϰ͕ϳϳϭ͛ WŽƌƚĞĚƵůůEŽƐĞͬĞƉůŽǇŵĞŶƚ^ůĞĞǀĞ Ϯϰ ϭϱ͕ϲϯϴ͛ ϮͲϯͬϴ͟^d>ƵůůŶŽƐĞ Ϯϱ ϭϱ͕ϳϭϬ͛ ϮͲϯͬϴ͟^d>ƵůůŶŽƐĞ Ϯϲ ϭϱ͕ϴϭϵ͛ ϮͲϯͬϴ͟^d>ƵůůŶŽƐĞ WZ&KZd/KEd/> DĞĂƐƵƌĞĚĞƉƚŚ ds ϭϯ͕ϴϰϳ͛ʹϭϯ͕ϴϲϬ͛ ϳ͕ϭϲϬ͛ʹϳ͕ϭϳϮ͛ ϭϯ͕ϴϲϲ͛ʹϭϯ͕ϴϳϵ͛ ϳ͕ϭϳϴ͛ʹϳ͕ϭϵϭ͛ ϭϯ͕ϴϴϳ͛ʹϭϯ͕ϵϮϬ͛ ϳ͕ϭϵϴ͛ʹϳ͕ϮϯϬ͛ KWE,K>ͬDEdd/> ϮϬΗ ϮϲϬƐǆƌĐƚŝĐ^Ğƚ;ƉƉƌŽǆ͘ͿŝŶϰϮ͟,ŽůĞ ϭϬͲϯͬϰΗ ϲϵϬƐǆ^>ŝƚĞ͕ϵϭϵƐǆ͚'͛ŝŶϭϯͲϭͬϮ͟,ŽůĞ ϳͲϱͬϴ͟͟ ϯϱϰƐǆůĂƐƐ͚'͛ŝŶϵͲϳͬϴ͟,ŽůĞ ϱͲϭͬϮ͟ ϲϮƐǆůĂƐƐ͚'͛ŝŶϲͲϯͬϰ͟,ŽůĞ ϯͲϭͬϮ͟ ϵϰƐǆůĂƐƐ͚'͛ŝŶϲͲϯͬϰ͟,ŽůĞ dZΘt>>, dƌĞĞ ϮͲϵͬϭϲ͟ϱD&D tĞůůŚĞĂĚ ϭϭ͟ǆϮͲϵͬϭϲ͟ϱD&DWŚĂƐĞ/ dƵďŝŶŐ,ĂŶŐĞƌ͗ϭϭ͟ǆϮͲϵͬϭϲ͟ dͲ//dΘϮ͘ϱ͟/tͲ,Wsd 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϯϮϮϲͲϬϬͲϬϬͬϲϬͲϬϬͬϲϭͲϬϬͬϲϮͲ ϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇŽǇŽŶϭϰͲϲͬϮϯͬϮϬϬϱ ^WZtKďǇEĂďŽƌƐŽǇŽŶϭϰʹϴͬϮϴͬϮϬϬϱ ^WZtKďǇEĂďŽƌƐϰ^ʹϲͬϭϮͬϮϬϬϲ ^WZtKďǇEĂďŽƌƐϯ^ʹϲͬϮϬͬϮϬϬϲ ^WZtKďǇEĂďŽƌƐϰ^ʹϳͬϮϳͬϮϬϭϬ dƵďŝŶŐ^ǁĂƉďǇŽǇŽŶϭϲʹϭϭͬϭϱͬϮϬϭϯ dƌŝƉůĞ>ĂƚĞƌĂůďǇEŽƌĚŝĐϮʹϰͬϱͬϮϬϭϰ ^W/ŶƐƚĂůůďǇŽǇŽŶϭϲͲϰͬϮϭͬϮϬϭϰ ^WZtKďǇ^ZηϭʹϮͬϮϲͬϮϬϭϵ dс ϭϰ͕ϭϴϯ͛;DͿͬdсϳ͕ϰϱϭ͛;dsͿ ϮϬ´ KƌŝŐ͘<ůĞǀ͗͘ϰϱ͘Ϭϳ͛ͬ'>ůĞǀ͗͘ϯϬ;ŽǇŽŶϭϰͿ ϳͲϱͬϴ͟ ϭϬͲϯͬϰ͟ DŝŶ/сϮ͘ϮϬϱ Λϭϭ͕ϵϱϲ͛ 5HYLHZ7XELQJ 7DOOLHVIRU*UHDWHU 'HWDLORIWKLV$UHD ¶WR¶ Wdс ϭϰ͕ϭϱϬ͛ ;DͿͬWdс ϳ͕ϰϱϭ͛;dsͿ ϱͲϭͬϮ͟ ϯͲϭͬϮ͟ %DNHU´ 0RQRERUH.%3NU :KLSVWRFN72: #¶0' BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗,ϮͬϭϭͬϮϬϮϮ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh&Ͳϵϯͬ>ϭͬ>ϭͲϬϭͬ>ϭͲϬϮ >ĂƐƚŽŵƉůĞƚĞĚ͗ϮͬϮϲͬϭϵ Wd͗ϮϬϱͲϬϴϳͬϮϭϯͲϮϬϱͬϮϭϯͲϮϬϲͬϮϭϯͲ ϮϬϳ ϮϮ >ϭ ϮͲϯͬϴ͟ůƵŵ͘ ŝůůŝƚǁͬ'^&E >ϭͲϬϭ >ͲϬϮϮ Ϯϭ Ϯϰ ϰϮϯ Ϯϱ Ϯϲ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϰͬ,ͲϰϬͬtĞůĚ ϭϵ͘ϭϮϰ ^ƵƌĨĂĐĞ ϭϭϯ͛ ϭϬͲϯͬϰΗ ^ƵƌĨĂĐĞ ϰϱ͘ϱͬ>ͲϴϬͬƚĐ͘ ϵ͘ϵϱϬ ^ƵƌĨĂĐĞ ϳ͕ϵϮϱ͛ ϳͲϱͬϴΗ WƌŽĚƵĐƚŝŽŶ Ϯϵ͘ϳͬ>ͲϴϬͬdDŽĚ ϲ͘ϴϳϱ ^ƵƌĨĂĐĞ ϭϯ͕ϱϰϭ͛ ϯͲϭͬϮ͟ >ŝŶĞƌ ϵ͘Ϯͬ>ͲϴϬͬ/d Ϯ͘ϵϵϮ ϭϯ͕ϭϵϰ͛ ϭϯ͕ϯϰϭ͛ ϱͲϭͬϮ͟ >ŝŶĞƌ ϭϳͬ>ͲϴϬͬ/dͲD ϰ͘ϴϵϮ ϭϯ͕ϰϭϳ ϭϯ͕ϳϴϮ͛ ϯͲϭͬϮ͟ >ŝŶĞƌ ϵ͘Ϯͬ>ͲϴϬͬ/d Ϯ͘ϵϵϮ ϭϯ͕ϯϮϳ͛ ϭϰ͕ϭϴϵ͛ ϮͲϯͬϴ͟ >ϭ>ŝŶĞƌ ϰ͘ϳͬ>ͲϴϬͬ,ǇĚƌŝůϱϭϭ ϭ͘ϵϵϬ ϭϯ͕ϰϮϭ͛ ϭϰ͕ϳϳϭ͛ ϮͲϯͬϴ͟ >ϭ>ŝŶĞƌ ϰ͘ϳͬ>ͲϴϬͬ,ǇĚƌŝůϱϭϭ ϭ͘ϵϵϬ ϭϰ͕ϮϮϭ͛ ϭϱ͕ϳϭϬ͛ ϮͲϯͬϴ͟ >ϭͲϬϭ>ŝŶĞƌ ϰ͘ϳͬ>ͲϴϬͬ,ǇĚƌŝůϱϭϭ ϭ͘ϵϵϬ ϭϰ͕ϭϭϴ͛ ϭϱ͕ϲϯϴ͛ ϮͲϯͬϴ͟ >ϭͲϬϮ>ŝŶĞƌ ϰ͘ϳͬ>ͲϴϬͬ,ǇĚƌŝůϱϭϭ ϭ͘ϵϵϬ ϭϰ͕ϳϳϭ͛ ϭϱ͕ϴϭϵ͛ dh/E'd/> ϮͲϳͬϴ͟ dƵďŝŶŐ ϲ͘ϱͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϰϰϭ ^ƵƌĨĂĐĞ цϭϮ͕Ϭϳϯ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ цϭϯϮ͛^ƚĂϮ͗'>DϮͲϳͬϴ͟ Ϯ цϭϭ͕ϴϵϴ͛^ƚĂϭ͗'>DϮͲϳͬϴ͟ ϯ цϭϭ͕ϵϱϲ͛ ϮͲϳͬϴ͟yEͲEŝƉƉůĞ;Ϯ͘ϮϬϱEŽͲŐŽ/Ϳ ϰ цϭϮ͕ϬϬϴ͘ϴ ŝƐĐŚĂƌŐĞ,ĞĂĚ͗ ϱ цϭϮ͕ϬϬϵ͛ WƵŵƉ͗ ϲ цϭϮ͕ϬϯϬ͛ 'ĂƐ^ĞƉĂƌĂƚŽƌ͗ ϳ цϭϮ͕Ϭϯϯ͛ dĂŶĚĞŵ^ĞĂů͗ ϴ цϭϮ͕Ϭϰϳ͛ DŽƚŽƌ͗ ϵ цϭϮ͕Ϭϲϵ͛ 'ƵĂŐĞΘĞŶƚƌĂůŝǌĞƌʹŽƚƚŽŵсцϭϮ͕Ϭϳϯ͛ ϭϬ ϭϯ͕Ϯϯϳ͛ ϯ͘ϱ͚͟y͛EŝƉƉůĞʹϮ͘ϴϭϯ/ ϭϭ ϭϯ͕Ϯϲϯ͛ ,^ZĂƚĐŚ>ĂƚĐŚʹƚŵΛϭϯ͕Ϯϲϲ͛ ϭϮ ϭϯ͕Ϯϳϲ͛ ϳͲϱͬϴ͟ǆϯ͘ϱ͟dEdWĞƌŵWĂĐŬĞƌ ϭϯ ϭϯ͕ϯϬϳ͛ ϯ͘ϱ͚͟y͛EŝƉƉůĞǁZ,ͲDͲϮ͘ϴϭϯ/ ϭϰ ϭϯ͕ϯϯϴ͛ ĂŬĞƌyWWĂĐŬĞƌ ϭϱ ϭϯ͕ϯϯϵ͛ ϰͲϭͬϮ͟t>'ʹ ƚŵΛϭϯ͕ϯϰϭ ϭϲ ϭϯ͕ϰϭϳ͛ ĂŬĞƌyWWĂĐŬĞƌ ϭϳ ϭϯ͕ϰϮϭ͛ <>ŝŶĞƌdŽƉWĂĐŬĞƌ ϭϴ ϭϯ͕ϰϮϳ͛ ĞƉůŽǇŵĞŶƚ^ůĞĞǀĞ ϭϵ ϭϯ͕ϰϯϭ͛ ^ĞĂůƐƐĞŵďůǇǁŝƚŚ&ƵůůDƵůĞ^ŚŽĞ ϮϬ ϭϯ͕ϰϯϱ͛ ĂŬĞƌ,D>ŝŶĞƌ,ĂŶŐĞƌ Ϯϭ ϭϰ͕ϭϭϴ͛ ůƵŵŝŶƵŵŝůůĞƚϮͲϯͬϴ͟^d>WŝŶ ϮϮ ϭϰ͕ϮϮϭ͛ ůƵŵŝŶƵŵŝůůĞƚϮͲϯͬϴ͟^d>WŝŶ Ϯϯ ϭϰ͕ϳϳϭ͛ WŽƌƚĞĚƵůůEŽƐĞͬĞƉůŽǇŵĞŶƚ^ůĞĞǀĞ Ϯϰ ϭϱ͕ϲϯϴ͛ ϮͲϯͬϴ͟^d>ƵůůŶŽƐĞ Ϯϱ ϭϱ͕ϳϭϬ͛ ϮͲϯͬϴ͟^d>ƵůůŶŽƐĞ Ϯϲ ϭϱ͕ϴϭϵ͛ ϮͲϯͬϴ͟^d>ƵůůŶŽƐĞ WZ&KZd/KEd/> DĞĂƐƵƌĞĚĞƉƚŚ ds ϭϯ͕ϴϰϳ͛ʹϭϯ͕ϴϲϬ͛ ϳ͕ϭϲϬ͛ʹϳ͕ϭϳϮ͛ ϭϯ͕ϴϲϲ͛ʹϭϯ͕ϴϳϵ͛ ϳ͕ϭϳϴ͛ʹϳ͕ϭϵϭ͛ ϭϯ͕ϴϴϳ͛ʹϭϯ͕ϵϮϬ͛ ϳ͕ϭϵϴ͛ʹϳ͕ϮϯϬ͛ KWE,K>ͬDEdd/> ϮϬΗ ϮϲϬƐǆƌĐƚŝĐ^Ğƚ;ƉƉƌŽǆ͘ͿŝŶϰϮ͟,ŽůĞ ϭϬͲϯͬϰΗ ϲϵϬƐǆ^>ŝƚĞ͕ϵϭϵƐǆ͚'͛ŝŶϭϯͲϭͬϮ͟,ŽůĞ ϳͲϱͬϴ͟͟ ϯϱϰƐǆůĂƐƐ͚'͛ŝŶϵͲϳͬϴ͟,ŽůĞ ϱͲϭͬϮ͟ ϲϮƐǆůĂƐƐ͚'͛ŝŶϲͲϯͬϰ͟,ŽůĞ ϯͲϭͬϮ͟ ϵϰƐǆůĂƐƐ͚'͛ŝŶϲͲϯͬϰ͟,ŽůĞ dZΘt>>, dƌĞĞ ϮͲϵͬϭϲ͟ϱD&D tĞůůŚĞĂĚ ϭϭ͟ǆϮͲϵͬϭϲ͟ϱD&DWŚĂƐĞ/ dƵďŝŶŐ,ĂŶŐĞƌ͗ϭϭ͟ǆϮͲϵͬϭϲ͟ dͲ//dΘϮ͘ϱ͟/tͲ,Wsd 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϯϮϮϲͲϬϬͲϬϬͬϲϬͲϬϬͬϲϭͲϬϬͬϲϮͲ ϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇŽǇŽŶϭϰͲϲͬϮϯͬϮϬϬϱ ^WZtKďǇEĂďŽƌƐŽǇŽŶϭϰʹϴͬϮϴͬϮϬϬϱ ^WZtKďǇEĂďŽƌƐϰ^ʹϲͬϭϮͬϮϬϬϲ ^WZtKďǇEĂďŽƌƐϯ^ʹϲͬϮϬͬϮϬϬϲ ^WZtKďǇEĂďŽƌƐϰ^ʹϳͬϮϳͬϮϬϭϬ dƵďŝŶŐ^ǁĂƉďǇŽǇŽŶϭϲʹϭϭͬϭϱͬϮϬϭϯ dƌŝƉůĞ>ĂƚĞƌĂůďǇEŽƌĚŝĐϮʹϰͬϱͬϮϬϭϰ ^W/ŶƐƚĂůůďǇŽǇŽŶϭϲͲϰͬϮϭͬϮϬϭϰ ^WZtKďǇ^Zηϭ ʹ ϮͬϮϲͬϮϬϭϵ dс ϭϰ͕ϭϴϯ͛;DͿͬdсϳ͕ϰϱϭ͛;dsͿ ϮϬ´ KƌŝŐ͘<ůĞǀ͗͘ϰϱ͘Ϭϳ͛ͬ'>ůĞǀ͗͘ϯϬ;ŽǇŽŶϭϰͿ ϳͲϱͬϴ͟ ϭϬͲϯͬϰ͟ DŝŶ/сϮ͘ϮϬϱ Λϭϭ͕ϵϱϲ͛ 5HYLHZ7XELQJ 7DOOLHVIRU*UHDWHU 'HWDLORIWKLV$UHD ¶WR¶ Wdс ϭϰ͕ϭϱϬ͛ ;DͿͬWdс ϳ͕ϰϱϭ͛;dsͿ ϱͲϭͬϮ͟ ϯͲϭͬϮ͟ %DNHU´ 0RQRERUH.%3NU :KLSVWRFN72: #¶0' @ 0LOQH3RLQW 'R\RQ ´%236WDFN STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS `<: 1. Operations Abandon LJ Plug Perforations LJ Fracture StimulateLi Pull Tubing ' Operations shutdown ET Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well❑ Re-enter Susp Well ❑ Other: ESP Change -out ❑� 2. Operator 4. Hilcorp Alaska LLC Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory ❑ 205-087 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, Stratigraphic ❑ Service ❑ 6. API Number: AK 99503 50-029-23266-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025509 / ADL0355017 /ADL0355018 MILNE PT UNIT F-93 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT/ KUPARUK RIVER OIL 11. Present Well Condition Summary: Total Depth measured 14,183 feet Plugs measured N/A feet true vertical 7,482 feet Junk measured N/A feet 13,276, 13,338, Effective Depth measured 14,150 feet Packer measured 13,417 & 13,421 feet ` 6,615, 6,647, true vertical 7,451 feet true vertical 6,750 & 6,754 feet Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 113' 113' N/A N/A Surface 7,890' 10-3/4" 7,925' 4,259' 5,21 Opal 2,470psi Production 13,509' 7-5/8" 13,541' 6,868' 6,890psi 4,790psi Liner 147' 3-1/2" 13,341' 6,677' 10,160psi 10,540psi Liner 365' 5-1/2" 13,782' 7,098' 10,140psi 10,500psi Liner 862' 3-1/2" 14,189' 7,488' 10,160psi 10,540psi Liner 1,350' 2-3/8" 14,771' 7,246' 11,200psi 11,780psi Liner Ll 1,489' 2-3/8" 15,710' 7,269' N/A N/A Liner L1-01 1,520' 2-3/8" 15,638' 7,267' N/A N/A Liner L1-02 1,048' 2-3/8" 15,819' 7,283' WA N/A Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5# / L-80 / EUE 8rd 12,073' 5,791- 7" x 3.5" HES, (2) Packers and SSSV (type, measured and true vertical depth) Baker 2XP & Ke 1 -TP N/A See Above 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 Tubing Pressure Prior to well operation: 318 81 2,056 1,180 271 Subsequent to operation: 0 0 0 1,560 0 14. Attachments (required per 20 nnc 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory❑ Development p ❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil r Gas LJ WDSPL 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: 319-049 Authorized Name: Chad Helgeson BDMS MM O c �Q�ntact Name: Taylor Wellman �Y��7 17 o Authorized Title: Operation(sMan'agerl CConntact Email: twellman(Whilcoro.com Authorized Signature: `� O Date: 2/28/2019 Contact Phone: 777-8449 r 5. 0/ ouvum vuyn iai V,uy Hilcorp Aleskp, LLC Crg. KB Elev.: 45.07/ GL Elev.: 30 (Doyon 14) L 143/4" Nin IR 220' 2 911,959 3 qW9 10& 11 12 Renee TU.g - 13 Taff.f.rcnwer 14 DeL d isA. t5 13,327 to 13,435 16 8 0:3.5 &4 u wFlu WhPSkxk TON 0 13.823' M11 3-1/2"A ' . It TD=14,183' (MD) /TD=7,451'(IVD) PBlD=14,150' (MD)/PBID=7,451'(TVD) SCHEMATIC TREE & WELLHEAD Tree 2-9/16" SM FMC 10-3/4" 11" x 2.9/16" SM FMC Phase I Wellhead Tubing Hanger: 11"x2-9/16" 5-1/2" TC -II T&B 2.S" CI W -H BPVr Milne Point Unit Well: MPU F-93 Last Completed: 2/26/19 PTD: 205-870 OPEN HOLE / CEMENT DETAIL 20" 260sx Arctic Set (Approx.) In 42" Hole 10-3/4" 690sx AS Llte, 919sx'G' In 13-1/2" Hole 7-5/8'" 354sx Class'G' In 9-7/8" Hole 5-1/2" 62sx Class'G' In 6-3/4" Hole 3-1/2" 94sx Class'G' in 6-3/4" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top 8tm 20" Conductor 94/H-40/Weld 19.124 Surface 113' 10-3/4" Surface 45.5/1-80/Stc. 9.950 Surface 7,92F- 7-5/8" Production 29.7/L-80/BTC Mod 6.875 Surface 13,541' 3-1/2" Liner 9.2/L-80/187 2.992 13,194' 13,341' 5-1/2" Liner 17/ L-80 / IST -M 4.892 13,417 13,782' 3-1/2" Liner 9.2/L -80/18T 2.992 13,327' 14,189' 2-3/8" Ll Liner 4.7 / L-80 / Hydr11511 1.990 13,421' 14,771' 2-3/8" LS Liner 4.7 / L-80 / Hydr11511 1.990 14,221' 15,710' 2-3/8" LS -01 Liner 4.7/L-80/Hydd1511 1.990 14,118' 15,638' 2-3/8" 1 L3-02 Liner 1 4.7 / L-80 / Hydr11511 1 1.990 1 14,771' 15,819' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EWE 8rd 1 2.441 1 Surface 12,098' JEWELRY DETAIL PERFORATION DETAIL No Depth I Item 1 132' Sta 2: GLM 2-7/B" w/ 1' DPSOV BK Latch 2 11,898' Sta 1: GLM 2-7/8" w/ 1" DMV SK Latch 3 11,956' 2-7/8" XN-Nipple (2.205 No-go ID) 4 12,008.8 Discharge Head: GPDIS 5 12,009' Pump: 86 FLEX47 6 12,030' Gas Separator: GRS FER NAR 7 12,033' Tandem Seal: osenoeurse/sa vfsa&wnwLTsa/se PHA 8 12,047' Motor: DERATED562XP-236H /2,210V/65A 9 12,069' PHOENIX XT-150&Centralizer -Bottom=12,073' 10 13,237' 1 3.5"'X'Nf le -2.8131D it 13,zt,3 I HES Ratch Latch -Btm @ 13,266' 12 137276' 7-5/8" x 3.5" TNT Perm Packer 13 13,307' 1 3.5"'X'Nlpplew RHC -M.2.813 ID 1413,338' Baker ZXP Packer 15 13,339' 4-1/2" WLEG-Btm@ 13,341 16 13,417' Baker ZXP Packer 17 13,421' KB Uner Top Packer 18 13,427' Deployment Sleeve 1913,431' Seal Assemhl with Full Mule Shoe 20 13,435' BakerHMC Liner Hanger 21 14,118' 1 Aluminum Billet 2-3/8" STL Pin 22 14,221' Aluminum Billet 2-3/8" STL Pin 23 14,771' TP.,td Bull Nose / Deployment Sleeve -2-3/8' 24 15,638' STL Bullnose 25 157710' 2-3/8"STL Bullnose 26 15,819' 2-3/8"STL Bullnose 23 r Alum. i W/ GS FN Measured Depth TVD 13,847'-13,860' 7,160'-7,172' 13,866'-13,879' 7,178'-7,191' 13,887'-13,920' 7,198'-7,230' GENERAL WELL INFO API: 50-029-23226,00-00 Drilled and Cased by Doyon 14- 6/23/2005 ESP RWO by Nabors Doyon 14 -8/28/2005 ESP RWO by Nabors 4ES-6/12/2006 ESP RWO by Nabors 35-6/20/2006 ESP RWO by Nabors 4ES-7/27/2010 Tubing Swap by Doyon 16 - 11/15/2013 Triple Lateral by Nordic 2 -4/5/2014 ESP Install by Doyon 16- 4/21/2014 ESP RWO by ASRa1-2/26/2019 Revised By: TDF 2/28/2019 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-93 ASR#1 50-029-23266-00-00 205-087 2/23/2019 2/26/2019 Daily Operations. 2/20/2019- Wednesday No activity to report. 2/21/2019 -Thursday No activity to report. 2/22/2019 - Friday No activity to report. 2/23/2019 -Saturday Start test BOP, completed good shell test, notified state and inspector Matt Herrera to witness BOP Test, state requested we keep testing BOP forward until arrival of state inspector, proceeding with BOP Test. Cont to test BOPE as per Sundry to 250psi low f/ 5 charted min, 2,500psi high f/ 5 charted mins. Good Test. RU, pull test sub and BPV TBG on a vac. Weight up pits to a 9.2 Ib NaCl. Fill the IA with 19.5 bbls = 513'md fluid depth of well. BOLDS, Unland tbg. unseat TBG hanger @ 57K, string weight @ 62k when weight broke over. POOH/W 2-7/8" 6.5# 8 rod tbg/w ESP. 2/24/2019 -Sunday CQotioue POOH w/ 2-7/8" tubing and ESP assembly laying down Pumping double displacement every 15 joints. Continue POOH laying down 2-7/8" tubing w/ ESP assembly, found worn and blown out spot in ESP power control cable at joint 363. Continue POOH laying down 2-7/8" tubing w/ ESP assembly, pulled total 371 joints of 2-7/8" tubing plus ESP assembly, OOH @ 17:40 hrs. Swap out old ESP cable with New in the spooling unit. Also load New reel of Cap. line on spooler. Make up, service and test ESP BHA as per sundry. Start picking up and RIH w/ ESP assembly and completion jewelry, cap string, and clamping at each collar as per Sundry. 2/25/2019 - Monday Cont. to RIH/W ESP on 2-7/8" 6.5# EUE Tbg to jnt # 267 @ 8,341.17'. Pull out Spooler with R&P. Change out the ESP reel with the rest of ESP cable. Spot in spooler. Make cable splice to new reel. Cont. to RIH/W ESP on 2-7/8" 6.5# EUE Tbg to jnt #386, EOT @ 12,072.89', Top of Lower GLM @ 11,897.87', Top of Upper GLM @ 132.14', Reel splice landed 5' dawn on Jnt# 275 in the hole. Start TBG Hanger splice. 2/26/2019 -Tuesday Continue Hanger Splice for ESP Cable and Cap String. Splice Complete, Land hanger with 19.5 K down weight. Run I lock downs screws, install BPV, RDMO ASR. THE STATE ALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU F-93 Permit to Drill Number: 205-087 Sundry Number: 319-049 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Wv .aogcc.olaska.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, ele:5�� Daniel T. Seamount, Jr. Commissioner (t DATED this rday of February, 2019. SCANNED FEB 0 6 2019 ECEWED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB O' 2019 APPLICATION FOR SUNDRY APPROVALS 9D AAO ?,, 9an 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: ESP Change -out ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ DevelopmentQ , c El3. StratigraphiService El 205-087 ' Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-23266-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D Will planned perforations require a spacing exception? Yes ❑ No 0 MILNE PT UNIT F-93 f"L 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025509 / A ADL0355018" I MILNE POINT/ KUPARUK RIVER OIL 11. L' 4. /'/ PRESENT WELL CONDITION SUMMARY Total Dep MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): j�5,3f0'"' 7- 289 1,600 15770` _77m, N/A N/A Casing Length j Size MD TVD Burst Collapse Conductor 78' 20" 113' 113' N/A N/A Surface 7,890' 10-3/4" 7,925' 4,259 5,210psi 2,470psi Production 13,509' - 7-5/8" 13,541' 6,868' 6,890psi 4,790psi Liner 147' 3-1/2" 13,341' 6,677' 10,160psi. 10,540psi Liner 365' 5-1/2" 13,782' 7,098' 10,140psi 10,500psi Liner 862' 3-112" 14,189 7,488' 10,160psi 10,540psi Liner 1,350' 2-318" 14,771' 7,246' 11,200psi 11,780psi Liner L1 1,489• 2-3/8" 15,710' 7,269' N/A N/A Liner Ll -01 1,520' 2-3/8" 15,638' 7,267' NIA N/A Liner L1-02 1,048' 2-318" 15,819' 7,283' N/A N/A Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 2-718" 6.5# / L-80 EUE 12,098 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 7" x 3.5" HES, (2) Baker ZXP & KB LTP and N/A 13,276/ 6,615, 13,33816,674, 13,417/ 6,750 & 13,421! 6,754 and N/A 12. Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ Development ❑� - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/21/2018 OIL ❑D • 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: Chad Helgeson Contact Name: Taylor Wellman Authorized Title: Operations Manager Contact Email: twellMan(EDhllcor .COm Contact Phone: 777-8449 Authorized Signature: Date: 2/1!2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: n (^ -D ct (-'I) Plug Integrity ❑ BOP Test ER/ Mechanical Integrity Test ElLocation Clearance ❑/✓', Other: .jr` oZ S -OC) PS -. /5 Post Initial Injection MIT Req'd? Yes ❑ No ❑,__, Spacing Exceptio uired? Yes ❑ No 53/ Subsequent Form Required: APPROVED BY Approved b COMMISSIONER THE COMMISSION Date: / kmr10-403 Revised b12017 Approved a is i s r f o h from /L pp p�it€F�rA Attachments in Duplicate til a.s-/q aryl 1••FEB /F/'� /i� K Ailcoq, Alaska, Ida ESP Change -Out Well: MPU F-93 Date:01/29/2019 Well Name: MPU F-93 API Number: 50-029-23266-00 Current Status: Shut in — ESP Down Pad: F -Pad Estimated Start Date: February 21, 2019 Rig: ASR Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 205-087 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Job Type: ESP Swap Current Bottom Hole Pressure: 2,470 psi @ 7,150' TVDss FL Shot 01/28/2019/ 6.65 ppg EMW Maximum Expected BHP: 2,470 psi @ 7,150' TVDss FL Shot 01/28/2019/ 6.65 ppg EMW MPSP: 1,600 psi (Maximum IA Pressure recorded on 7/30/2018) Brief Well Summary: S( MPU F-93 was drilled and completed as a cemented and perforated liner in 2005. The well was perforated and hydraulically fractured in the Kuparuk Al, A2 and A3 sands. The well produced with 3 ESP's during through 2013. One installation had a broken shaft with heavy scale buildup in the pump and outside the motor. In 2014 the well was coil sidetracked with a multilateral system placing 3 laterals into the Kuparuk Al, A2 and A3 sands. The upper completion placed the current to failure. ran for 4 years a Notes Regarding Wellbore Condition �� -;; dry • The 7-5/8" casing passed an MIT -IA to 3,OOOpsi on 3/13/2014 (the well had a 4-1/2" tubing string in place for CTD to drill the multilaterals and the casing was tested at this time). Objective: Pull the failed ESP and run a new ESP completion. Pre -Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.5 ppg seawater down tubing, taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. NO Tree. NU BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. Brief RWO Procedure: 10. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. U Dileoru Alaska, LG ESP Change -Out Well: MPU F-93 Date: 01/29/2019 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ 8.5 ppg sea water prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each P ✓ ram/valve and test for 5 -min). Record accumulator pre -charge pressures and chart tests. q a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. �y b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/ 8.5 ppg sea water as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2014 ESP running was 99K lbs / SOF = 66K lbs (Block weight= 40K lbs). b. If needed, circulate (long or reverse) pill with lubricant and/or baraclean pill prior to laying down the tubing hanger. 16. Recover the tubing hanger. contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 17. POOH and lay down the 2-7/8" tubing. Send all tubing to G&I for washing and disposal. Lay down ESP. a. Note any sand or scale inside or on the outside of the ESP on the morning report. b. Look for over -torqued connections from previous tubing runs. c. The completion has the following amount of clamps/guards: i. 5 Protectors ii. 3 Flat Gaurds iii. 193 Cross Collar Cannon Clamps H Hilcorl, Alaska, LLi ESP Change -Out Well: MPU F-93 Date:01/29/2019 18. PU new ESP with single cap string and RIH on 2-7/8" tubing. Set base of ESP assembly at ± 12,080' MD. a. Upper GLM @ ± 140' MD w/SO b. 2-7/8" tubing c. Lower GLM w/ DGLV d. 3 joints of 2-7/8" tubing e. 2-7/8" XN (2.205" No -Go) f. 1 joint of 2-7/8" tubing g. Downhole gauge for discharge temperature and pressure (connected with a jumper from the lower sensor. Does not require a separate tech wire). h. Base of ESP centralizer @ ± 12,080' MD 19. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 20. Set BPV. Post -Rig Procedure: 21. RD mud boat. RD BOPE house. Move to next well location. 22. RU crane. ND BOPE. 23. NU existing 2-9/16" 5,000# tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 24. RD crane. Move 500 bbl returns tank and rig mats to next well location. 25. Replace gauge(s) if removed. 26. Turn well over to production. RU well house and flowlines. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Blank RWO MOC Form K Hilcaro Alaska, LLC Orig. KB Elev.: 45.07/ GL Elev.: 30 (Doyon 14) B 108/4" Mn IQ 2.205 2 @ 1119M -Ira 5 6 7 0&11 1 R¢.ievTutirg 13 Tall.fcrBasals 14 09 IdthsMea t5 13,32Tbl3,435' Bdw 3.5' M7d.KBPla WHpslork TON @ 13.8 ku l TD=14,183' (ND) /To =7,451'(TVD) PBTD=14,15(' (MD) / P81D=7,451'(TVD) SCHEMATIC TREE & WELLHEAD Tree 2-9/16" 5M FMC 10-3/4" 11" x 2-9/16" 5M FMC Phase I Wellhead Tubing Hanger: 11" x 2-9/16" 5-1/2" TC -11 T&B 2.5" CI W -H BPVT Milne Point Unit WeII: MPU r- -` S Last Completed: 2/28/10 PTD: 20 s- O $77 OPEN HOLE/ CEMENT DETAIL 20" 260sx Arctic Set(Approx.) In 42" Hole 10-3/4" 690sx AS Lite, 919sx'G' in 13-1/2" Hole 7-5/8"" 354sx Class 'G' In 9-7/8" Hole 5-1/2" 62$x Class'G' in 6-3/4" Hole 3-1/2" 94sx Class 'G' in 6-3/4" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 94/H-00/Weld 19.124 Surface 113' 10-3/4" Surface 45.5 / L-80 / Btc. 9.950 Surface 7,925' 7-5/8" Production 29.7/L-80/BTC Mod 6.875 Surface 3,541' 3-1/2" Liner 9.2/L-80/IBT 2.992 13,194' 13,341' 5-1/2" Liner 17/ L-80 / I BT -M 4.892 13,417 13,782' 3-1/2" Liner 9.2 / L-80 / I8T 2.992 13,327' 14,189' 2-3/8" Ll Liner 4.7/L-80/Hydril 511 1.990 13,421' 14,771' 2-3/8" L3 Uner 4.7 / L-80 / Hydril 511 1.990 14,221' 15,710' 2-3/8" Ll -01 Liner 4.7/ L-80 / Hydr11511 1.990 14,118' 15,638' 2-3/8" L3-02 Liner 4.7 / L-80 / Hydril 511 1.990 14,771' 15,819' TUBING DETAIL 2-7/e" Tubing 6.5/L-80/EUE8rd 1 2.441 1 Surface 72,098' JEWELRY DETAIL PERFORATION DETAIL LhT No Depth Item 1 166' Sta 2: KBMM GLM 2-7/8" x 1" w/ DGLV 2 11,843' Sta 1: KBMM GLM 2-7/8" x 1" w/ DSOV 3 11,998' 2-7/8" XN-Nipple (2.205 No-go ID) 4 12,041.8' Discharge Head: 5 12,042' Pump: 6 12,061' Gas Separator: 7 12,066' Top of Upper & Lower Tandem Seal: 8 12,080' Motor: 9 12,094' Sensor & Centralizer - Bottom =12,098' 10 13,237' 3.5"'X'Nipple -2.8131D 11 13,263' HES Ratch Latch - Btm @ 13,266' 12 13,276' 7-5/8" x 3.5" TNT Perm Packer 13 13,307' 3.5"'X'Nipple w RHC -M -2.8131D 14 13,338' Baker ZXP Packer 15 13,339' 4-1/2" WLEG-Bon @ 13,341 16 13,417' Baker ZXP Packer 17 13,421' KB Liner Top Packer L 18 13,427' Deployment Sleeve 19 13,431' 1 Seal Assembly with Full Mule Shoe 20 13,435' Baker HMC Liner Hanger 21 14,118' Aluminum Billet 2-3/8" STL Pin 22 14,221' Aluminum Billet 2-3/8" STL Pin 23 14,771' Ported Bull Nose / Deployment Sleeve 24 15,638' 2-3/8"STLBullnme 25 15,710' 2-3/8" STL Bullnose 26 15,819' 2-3/8"STLBulinose 23 3" Alum. r W/ GS FN L(-07- L-021A2-- Measured Depth TVD 13,847'-13,860' 7,160'-7,172' 13,866'-13,879' 7,178'-7,191' 13,887'-13,920' 7,198'-7,230' GENERAL WELL INFO API: 50-029-23226-00-00 Drilled and Cased by Doyon 14- 6/23/2005 ESP RWO by Nabors Doyon 14 -8/28/2005 ESP RWO by Nabors 4E5-6/12/2006 ESP RWO by Nabors 3S-6/20/2006 ESP RWO by Nabors 4ES - 7/27/2010 Tubing Swap by Doyon 16 -11/15/2013 Triple Lateral by Nordic 2 -4/5/2014 ESP Install by Doyon 16-4/21/2014 1 at�-z6S Jlim pt13 _ z0L ad13- oto? Revised By: TDF 2/1/2019 (L3 - xa=arP tlaakaa.l.0 '' Orig. KB Elev.: 45.07'/ GL Bev.: 30 (Doyon 14) A 20" t 30-3/4" 2 Mn IR 2205 @ 11,998' 3 Pc,.TLL g Tribes for Gomer D9a rift Ftp 13,327011435' Saw 3.T MvrboelBPla Wrgsl Tav @13.873Not 6 7 3-1/2'1' k To= 14,10 (ND)/TD=7,45V(1VD) PBTD=14,150' (MD) / PBID=7,45r(TVD) PROPOSED TREE & WELLHEAD Tree 2-9/16" 5M FMC 10-3/4" 11" x 2-9/16" 5M FMC Phase I Wellhead Tubing Hanger: 11"x2-9/16" 5-1/2" TC -II T&B 2.5" CI W -H BPVF Milne Point Unit Well: MPU-64RA" 2- F -'i 3 Last Completed: 2/28/10 PTD:109-144 ;Z o S- 0187 OPEN HOLE / CEMENT DETAIL 20" 260sx Arctic Set (Approx.) in 42" Hole 10-3/4" 690sx AS Ute, 919sx'G' In 13-1/2" Hole 7-5/8"" 354sx Class'G' in 9-7/8" Hole 5-1/2" 62sx Class'G' In 6-3/4" Hole 3-1/2" 94sx Class 'G' In 6-3/4" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 94/H-00/Weld 19.124 Surface 113' 10-3/4" Surface 45.5 / L-80 / Btc. 9.950 Surface 7,925' 7-S/8" Production 29.7/L-80/BTC Mod 6.875 Surface 3,541' 3-1/2" Uner 9.2/L-80/IBT 2.992 13,194' 13,341' 5-1/2" Liner 17/ L-80 / IBT-M 4.892 13,417 13,782' 3-1/2" Liner 9.2/L-80/IBT 2.992 13,327' 14,189' 2-3/8" LS Liner 4.7/480/Hydril 511 1.990 13,421' 14,771' 2-3f8" L3 Liner 4.7/L-80/Hydri1511 1.990 14,221' 15,710' 2-3/8" LS -01 Liner 4.7/L -80/H dri1511 1.990 14,118' 15,638' 2-3/8" 1 Ll -02 Liner 1 4.7/L -80/H dril 511 1 1.990 1 14,771' 1 15,819' TUBING DETAIL 2-7/8" Tubing _TS /L-80/EUE Brd 1 2.441 1 Surface 1 12,098' JEWELRY DETAIL PERFORATION DETAIL No Depth Item 1 ±140' Sta 2: GLM 2-7/8" x 1" w/ SO 2 ±11,900' Sta 1: GLM 2-7/8" x 1" w/ DGLV 3 ±12,000' 2-7/8" XN-Nipple (2.205 No-go ID) 4 ±12,020' Discharge Head: 5 112,030' Pump: 6 ±12,050' Gas Separator: 7 ±12,055' Top of Upper S, Lower Tandem Seal: 8 ±12,070' Motor: 9 ±12,074' Sensor & Centralizer - Bottom =±12,080' SO 13,237' 3.5" 7C Nipple -2.8131D 11 13,263' HES Batch Latch - Btm @ 13,266' 12 13,276' 7-5/8" x 3.5" TNT Perm Packer 13 13,307' 3.5"')C Nipple RHC -M -2.8131D 14 13,338' Baker ZXP Packer 15 13,339' 4-1/2" WLEG-6tm @ 13,341 16 13,417' Baker ZXP Packer 17 13,421' KB Liner Top Packer 18 1 13,427' 1 Deployment Sleeve 19 13,431' Seal Assembly with Full Mule Shoe 20 13,435' Baker HMC Liner Hanger 21 14,118' Aluminum Billet 2-3/8" STL Pin 22 14,221' Aluminum Billet 2-3/8" STL Pin 23 14,771' Ported Bull Nose/ Deployment Sleeve 24 15,638' 2-3/8"STLBullnose 25 15,710' 2-3/8" STL Bullnose 26 15,819' 2-3/8" STL Bullnose V' Alum. , W/ GS FN ; 4-t7Z Measured Depth TVD 13,847'-13,860' 7,160'-7,172' 13,866'-13,879' 7,178'-7,191' 13,887'-13,920' 7,198'-7,230' GENERAL WELL INFO API: 50 -029 -23226 -DO -00 Drilled and Cased by Doyon 14-6/23/2005 ESP RWO by Nabors Doyon 14 -8/28/2005 ESP RWO by Nabors 4ES - 6/12/2006 ESP RWO by Nabors 3S-6/20/2006 ESP RWO by Nabors 4E5-7/27/2010 Tubing Swap by Doyon 16 -11/15/2013 Triple Lateral by Nordic 2 -4/5/2014 ESP Install by Doyon 16- 4/21/2014 Revised By: TDF 2/1/2019 H Ililrorp Almkn. LIA: 11" BOPE Milne Point ASR Rig 1 BOPE 2019 Updated 5/14/2018 BR or Pipe Rams ind ,es HHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Date: February 151, 2019 Subject: Changes to Approved Sundry Procedure for Well MP F-93 Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first calf' engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK HAK Prepared Approved B (initials) B (Initials) AOGCC Written Approval Received Person and Date Approval: Prepared: Operations Manager Date Operations Engineer Date • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ ~- (~ ~ ~ Well History File Identifier Organizing (done) ^ Two-sided III IIIII II III II III ^ Rescan Needed III IIIII II II III III RESCAN DIGITAL DATA OVERSIZED (Scannable) Color Items:Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: I ~ /s/ Protect Proofing III 111111 IIIII II III BY: Maria Date: ~~'~ (~ ~~~ /s/ ~`~ Scanning Preparation ~_ x 30 = ~ + ~~ =TOTAL PAGES~~ ~~ / ~ ~ (Count does not i ~S~ude cover sheet) , n n~ BY: Maria Date: ~/ y' Production Scanning Stage 1 Page Count from Scanned File: 1 ~ I (Count does include c/ov~er sheet) Page Count Matches Number in Scanning Preparation: I/ YES NO BY: Maria Date:' I' ~~ ~ ~] /s/ ~ n/~ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO I BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II IIIII ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: a~a~.~~.~~ iiiuiuiiiiuiiii 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA RECEIVED AL ..,KA OIL AND GAS CONSERVATION CO Q. _.ISSION REPORT OF SUNDRY WELL OPERATIONS DEC .1 2 2013 1. Operations Performed: AUGCC ❑Abandon ❑Repair Well ❑Plug Perforations ❑Perforate ❑Re-Enter Suspended Well ❑Alter Casing ®Pull Tubing• ❑Stimulate-Frac ❑Waiver ❑Other ❑Change Approved Program ❑Operation Shutdown ❑Stimulate-Other ❑Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration(Alaska) Inc. ❑Exploratory ❑Stratigraphic 205-087 • 3. Address: ®Development ❑Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-23266-00-00 • 7. Property Designation(Lease Number): 8. Well Name and Number: ADL 025509&ADL 35501'r MPF-93 • 9. Logs(list logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Milne Point Unit/Kuparuk River Sands ' 11. Present well condition summary: Total depth: measured 14189' feet Plugs:(measured) None feet true vertical 7488' feet Junk:(measured) None feet Effective depth: measured 14155' feet Packer: (measured) 13276' feet true vertical 7456' feet Packer: (true vertical) 6615' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 35'- 113' 35'- 113' 1530 520 Surface 7890' 10-3/4" 35'- 7925' 35'-4259' 5210 2480 Intermediate Production 13509' 7-5/8" 32'- 13541' 32'-6868' 8160 7020 Liner 365' 5-1/2" 13417'- 13782' 6750'-7098' 7740 6280 Liner 862' 3-1/2" 13327'- 14189' 6664'-7488' 10160 10530 Perforation Depth: Measured Depth: 13847'- 13920' feet True Vertical Depth: 7160'-7230' feet Tubing(size,grade,measured and true vertical depth): Work String:3-1/2", L-80 13341' 6677' 9.2# Packers and SSSV(type,measured and true vertical depth): 7-5/8"x 3-1/2" HES TNT Perm. Packer 13276' 6615' 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment description including volumes used and final pressure: SCANNED JAN 2 .`. N L)'L 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 49 24 1192 300 212 Subsequent to operation: 0 0 0 0 0 14.Attachments: ❑Copies of Logs and Surveys run 15.Well Class after work: ❑Exploratory ❑Stratigraphic ®Development ❑Service ®Daily Report of Well Operations 16. Well Status after work: 0 Oil • ❑Gas ❑WDSPL 0 Well Schematic Diagram ❑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: Contact: Abby Warren,564-5720 Email:Abigail.Warren @bp.com Printed Name: Joe Lastu Ilk 'i■ Title: Drilling Technologist Signature: V 1 Phsci]e:., 564-4091 Date: 12/12415 Form 10-404 Revised 10/2012 v,L //// //4 �* PI S E,M L OPEC 116 201 North America-ALASKA-BP 1 ors Operation Summary Report Common Well Name:MPF-93 AFE No Event Type:WORKOVER(WO) Start Date:11/8/2013 End Date:11/16/2013 1X3-0140C-C:(1,500,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/23/2005 12:00:00AM Rig Release:11/16/2013 Rig Contractor:DOYON DRILLING INC. UWI:500292326600 Active datum:ORIG KELLY BUSHING @45.07usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (usft) — — 11/8/2013 20:00 - 22:00 2.00 j MOB P PRE PJSM,MOVE RIG OFF MPF-53 MOVE RIG AROUND END OF F-PAD AND POSITION ON PAD BY MPF-93 22:00 - 00:00 2.00 MOB N RREP PRE MOVING SYSTEM CONTROLS INOPERABLE CALLED OUT ELECTRICIAN AND REPLACED SPEED CONTROL MODULE 11/9/2013 00:00 - 01:30 1.50 MOB P PRE PJSM,SPOT RIG OVER WELL MPF-93 SHIM RIG FOR LEVEL SPOT CUTTINGS TANK,FUEL TRAILER AND CHANGE TRAILER -ACCEPT RIG AT 01:30 HRS 01:30 - 06:00 4.50 WHSUR P DECOMP TPJSM,RIG UP FOR WELL KILL • R/U CIRCULATING LINES IN CELLAR FROM TREE TO WELL KILL MANIFOLD AND FLOW BACK TANKS -TEST MANIFOLD AND ALL LINES,250 PSI, '3500 PSI,5 MIN CHARTED FILL PITS WITH 9.9 PPG BRINE R/U AND FUNCTION TEST SSV REMOTE WARM UP ALL RIG SURFACE LINES AND MUD PUMP PT MUD PUMP TO 3500 PSI,CHECK POP F ;OFF 06:00 - 06:30 0.50 WHSUR P DECOMP PRESSURE TEST LINES OUT TO BOTH FLOWBACK TANKS. PURGE LINES WITH AIR. CONDUCT FIRE DRILL WITH RIG EVAC. CONDUCT AAR AFTERWARDS. 06:30 - 09:30 3.00 WHSUR P DECOMP RIG UP DSM LUBRICATOR. PRESSURE TEST 250/3500 PSI,GOOD. PULL BPV,RIG DOWN LUBRICATOR. 109:30 - 10:30 1.00 KILLW P DECOMP 1 PJSM FOR WELL KILL. CONDUCT CHECK OF FLOWBACK TANKS. 10:30 - 12:00 1.50 KILLW P DECOMP START WELL KILL. BLEED GAS OFF IA FROM 920 PSI TO 200 PSI, FLUID AT CHOKE. STOP BLEEDING GAS,START CIRCULATION KILL. PUMP 3 BPM FOR 70 BBLS DOWN TUBING, (TAKE RETURNS FROM IA. 12:00 - 13:00 1.00 KILLW P DECOMP MOVE TO BULLHEAD PART OF WELL KILL. UNABLE TO BULLHEAD ATA SUSTAINED RATE,AFTER 13 BBLS IAAT 3000 PSI,TUBING AT 2500 PSI. SHUT DOWN PUMP,ALLOW PRESSURE TO BLEED OFF. BULLHEAD ABOUT 5 BBLS TWO TIMES AND EACH TIME AND PRESSURE UP IA TO 2500 PSI.THEN ALLOW IT TO BLEED OFF. DISCUSS WITH ODE,DECISION IS MADE TO DISCONTINUE BULLHEADING AND CONTINUE WITH CIRCULATION. 13:00 - 16:00 3.00 KILLW P DECOMP CONTINUE CIRCULATING 675 BBLS DOWN TUBING TAKING RETURNS FROM IA. GET 9.9 PPG WATER BACK RIGHT AT CALCULATED BOTTOMS UP. Printed 12/2/2013 11:21:00AM North America-ALASKA-BP Page 2 of 8 Operation Summary Report Common Well Name:MPF-93 AFE No Event Type:WORKOVER(WO) Start Date:11/8/2013 End Date:11/16/2013 X3-0140C-C:(1,500,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/23/2005 12:00:00AM Rig Release:11/16/2013 Rig Contractor:DOYON DRILLING INC. UWI:500292326600 Active datum:ORIG KELLY BUSHING @45.07usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 16:30 0.50 KILLW P DECOMP SHUT DOWN PUMP AFTER 1.5 X BOTTOMS UP. TUBING AND IA SPIT BACK A LITTLE FLUID THEN BOTH STATIC AFTER 20 MIN. CONTINUE MONITORING WELL. 16:30 - 20:00 3.50 WHSUR P DECOMP PJSM,R/U AND TEST DSM LUBRICATOR,250 PSI,3500 PSI -INSTALL TWC -PERFORM ROLLING TEST FROM BELOW TWC,500 PSI,5 MIN,CHARTED -TEST FROM ABOVE,250 PSI,3500 PSI,5 MIN CHARTED -R/D DSM LUBRICATOR 20:00 - 21:00 1.00 ' WHSUR P DECOMP BLOW DOWN AND RIG DOWN ALL CIRCULATING LINES -RIG DOWN KILL MANIFOLD IN CELLAR -R/U AUXILIARY KILL LINE TO IA 21:00 - 22:30 1.50 WHSUR P DECOMP PJSM WITH FMC REP FOR N/D TREE -FMC BLEED DOWN TUBING VOID AT HANGER SEAL -N/D TREE AND ADAPTER FLANGE -CLEAN AND INSPECT TUBING THREADS IN HANGER,2 7/8"EUE 8RD THREADS,7 RH TURNS BY HAND 22:30 - 00:00 1.50 BOPSUR P DECOMP N/U BOPE,RISER,INSTALL TURNBUCKLES, -M/U KOOMEY LINES -R/U TEST EQUIPMENT,M/U FLOOR VALVES AND TEST JOINTS -OA=0 PSI -WELL KILL,804 BBLS PUMPED,722•BBLS OUT,23 BBLS BULLHEADED,59 BBLS LOST -POST WELL LOSSES=19 BBLS 11/10/2013 00:00 - 02:30 2.50 BOPSUR P DECOMP PJSM,PERFORM SPCC AND EQUIPMENT CHECKS -N/U BOPE AND R/U TEST EQUIPMENT 02:30 - 07:30 5.00 BOPSUR P DECOMP PJSM,TEST FOUR PREVENTER BOPE AND RELATED EQUIPMENT -TEST BOPE ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES -TEST ANNULAR WITH 2 7/8"TEST JOINT TO 250 PSI LOW,3500 PSI HIGH,5 MINUTES EACH,CHARTED -TEST UPPER AND LOWER 2 7/8"X 5" VARIABLE RAMS WITH 2 7/8"AND 4"TEST JOINT,250 PSI,3500 PSI,5 MIN,CHARTED -TEST BLIND RAMS,FLOOR VALVES,AND CHOKE MANIFOLD TO 250 PSI,3500 PSI,5 MIN,CHARTED -TEST WITH FRESH WATER -PERFORM ACCUMULATOR DRAW DOWN TEST -JEFF TURKINGTON OF AOGCC WAIVED { STATES RIGHT OF WITNESS TO THE BOP TEST 07:30 - 08:00 0.50 BOPSUR P DECOMP DRAIN BOP STACK. RIG DOWN BOP TEST EQUIPMENT. Printed 12/2/2013 11:21:00AM North America-ALASKA-BP Page 3 of 8 Operation Summary Report Common Well Name:MPF-93 AFE No Event Type:WORKOVER(WO) Start Date:11/8/2013 End Date:11/16/2013 X3-0140C-C:(1,500,000.00) Project:Milne Point ' Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/23/2005 12:00:OOAM Rig Release:11/16/2013 Rig Contractor.DOYON DRILLING INC. UWI:500292326600 Active datum:ORIG KELLY BUSHING 4245.07usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) I (usft) 08:00 - 11:00 3.00 WHSUR P DECOMP RIG UP DSM LUBRICATOR AND OFFSET LUBRICATOR. PRESSURE TEST 250/3500 PSI,LEAKING NEEDLE VALVE. CHANGE IT OUT THEN GETA GOOD TEST. 11:00 - 15:00 4.00 CASING P DECOMP RIG UP TO CIRCULATE A B/U BEFORE PULLING HANGER. CIRCULATE 448 BBLS AT 4 BPM DOWN TUBING,TAKING RETURNS THROUGH IA TO MGS. 15:00 - 15:30 0.50 PULL P DECOMP PJSM THEN BACK OUT LDS. PULL HANGER TO FLOOR WITH 110K(40K BLOCK WT) _ 15:30 - 17:00 1.50 PULL P DECOMP CLOSE UPPER RAMS AND CIRC A TUBING VOLUME THROUGH GAS BUSTER. ,17:00 - 17:30 0.50 PULL P DECOMP BLOW DOWN CHOKE MANIFOLD AND TOP DRIVE -BACK OUT AND L/D LANDING JOINT 17:30 - 00:00 6.50 PULL P DECOMP !PJSM,PULL 2 7/8"6.5#EUE 8RD TUBING ESP COMPLETION -LID FIRST 150 JOINTS 1X1 -FROM 12047'TO 8100'MD I-OA=0 PSI 24 HOUR FLUID LOSS=70 BBLS 9.9 PPG BRINE 11/11/2013 00:00 - 01:00 1.00 PULL P I DECOMP PJSM,PERFORM SPCC AND EQUIPMENT CHECKS -PULL 2 7/8"6.5#EUE 8RD TUBING ESP COMPLETION,FROM 8011'TO 7884'MD 01:00 01:30 0.50 PULL P DECOMP CHANGE OUT SPOOL IN CENTRILIFT SPOOLING UNIT 01:30 - 05:00 3.50 PULL P DECOMP CONTINUE TO PULL 2 7/8"6.5#EUE 8RD TUBING ESP COMPLETION,FROM 7884'TO 7419'MD -STAND BACK 53 STANDS IN DERRICK TO 3699' 05:00 - 12:00 7.00 PULL N WAIT DECOMP STOP OPERATIONS DUE TO HIGH WINDS AND PHASE 3 CONDITIONS. INSTALL TIWAND TORQUE IT UP. r I ( PERFORM LIFTING DEVICE INVENTORY, GENERAL HOUSEKEEPING. REVIEW DDI SOP'S 12:00 - 20:00 8.00 PULL N WAIT DECOMP MAKE CREW CHANGE OUT PLAN WITH WSL AND MILNE POINT OPERATIONS MANAGER 1 AUTHORIZATION -SUCCESSFUL CONVOY WITH ROADS AND { i I PADS FORKLIFT TO AND FROM MOBILE PAD -CONTINUE LIGHT DUTY TASKS AND REVIEW 'OF DDI SOPS Printed 12/2/2013 11:21:00AM North America-ALASKA-BP Page 4 of 8 Operation Summary Report Common Well Name:MPF-93 AFE No Event Type:WORKOVER(WO) I Start Date:11/8/2013 1 End Date:11/16/2013 X3-0140C-C:(1,500,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/23/2005 12:00:OOAM Rig Release:11/16/2013 Rig Contractor.DOYON DRILLING INC. UVU:500292326600 Active datum:ORIG KELLY BUSHING©45.07usft(above Mean Sea Level) Data From-To 1 Hrs Task ' Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 23:00 3.00 PULL P DECOMP NOTIFIED OF MILNE PT.PHASE 2 CONDITIONS,RETURN TO WORK -POOH WITH 2 7/8"ESP COMPLETION FROM 3699' -STAND BACK TOTAL OF 53 STANDS IN THE DERRICK -UD REMAINING 73 JOINTS TO ESP PUMP AND MOTOR CLAMPS ACCOUNTED FOR: 200 LASALLE 6 PROTECTOLIZERS 3 FLAT GAURDS 123:00 - 00:00 1.00 I PULL P DECOMP REMOVE ALL ESP FLAT WIRE PROTECTOLIZERS AND ARMSTER CLAMPS FROM ESP ASSY -MILNE POINT CALLED PHASE 1 ROAD CONDITIONS AT 23:30,NO CONVOY NEEDED FOR CREW CHANGE OUT -OA=0 PSI -LOSS RATE=2-3 BPH -24 HOUR FLUID LOSS=69 BBLS 9.9 PPG BRINE 11/12/2013 1 00:00 - 02:00 2.00 PULL P DECOMP 'PJSM,PERFORM SPCC AND EQUIPMENT CHECKS -L/D ESP MOTOR AND PUMP ASSY -FOUND TWISTED SHAFT ON UPPER TANDEM PUMP,HEAVY SCALE ON MOTOR 02:00 - 02:30 0.50 PULL P DECOMP PJSM,R/D ESP SHEAVE AND TRUNK 02:30 - 03:00 0.50 PULL P • DECOMP M/U RUNNING TOOL AND INSTALL WEAR RING -WEAR RING=7"ID 03:00 - 03:30 0.50 PULL P I DECOMP CLEAR ALL CENTRILIFT TOOLS FROM RIG 1 FLOOR -CLEAN RIG FLOOR,PREP TO RIFI VNTH CHAMP PACKER 03:30 - 04:00 0.50 PULL P DECOMP PERFORM TOP DRIVE INSPECTION -INSPECT AND SERVICE PIPE SKATE 04:00 - 07:30 3.50 1 EVAL P DECOMP 1 PJSM,M/U HES 7 5/8"CHAMP PACKER -RIH WITH PACKER ON 2 7/8"TUBING FROM DERRICK TO 4951' 07:30 - 12:00 4.50 EVAL P DECOMP MAKEUP DRILL PIPE SINGLES FROM PIPE SHED. RIHTO8100FT. 12:00 - 20:30 8.50 EVAL P DECOMP CREW CHANGE. RIG CHECKS AND WALKAROUNDS. CONTINUE MAKE UP DRILL PIPE SINGLES FROM PIPE SHED. RUN IN HOLE TO 13,320 FT _ PUW:158 K,SOW:85K 20:30 - 22:00 1.50 EVAL P DECOMP PJSM SLIP AND CUT DRILL LINE -HANG BLOCKS -SLIP AND CUT LINE Printed 12/2/2013 11.21:OOAM • North America-ALASKA-BP Page 5 of 8 Operation Summary Report Common Well Name:MPF-93 AFE No Event Type:WORKOVER(WO) Start Date:11/8/2013 End Date:11/16/2013 X3-0140C-C:(1,500,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/23/2005 12:00:00AM Rig Release:11/16/2013 Rig Contractor:DOYON DRILLING INC. UWI:500292326600 Active datum:ORIG KELLY BUSHING @45.07usft(above Mean Sea Level) Date From-To Hrs I Task Code i NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 23:00 1.00 EVAL P DECOMP I PJSM SET 7-5/8"HES CHAMP PACKER RIH AND SET DOWN 4K ON LINER TOP AT 113,318'MD 1-PICK UP&OBTAIN PARAMETERS AT 13,300 FT -SET DOWN AND ROTATE 3 TURNS I-PACKER SET AT 13,300'MD C.O.E. 23:00 - 00:00 1.00 EVAL P DECOMP 'PJSM,MIT-IA 7 5/8"L-80 29.7#CSG BY 2-7/8" TUBING&4"DP ANNULUS. 1-CONFIRM VALVE ALLIGNMENT PRIOR TO TEST -PUMPED 57 STKS(5 BBLS)TO 3,650 PSI FOR 30 CHARTED MINUTES. -50 PSI LOST IN 1ST 15 MINS -0 PSI LOST IN 2ND 15 MINS I -MIT-IA MEETS BP STP CRT-AK-10-45 CRITERIA -RECIEVED PERMISSION TO PROCEED FROM WTL -BLEED OFF PRESSURE,BLED BACK 5 BBLS RIG DOWN TEST EQUIPMENT SEE ATTACHMENTS 124 HR LOSSES TO WELL=36.9 BBLS 11/13/2013 00:00 - 09:30 9.50 EVAL P DECOMP SPCC CHECKS AND PRE-TOUR MEETING RELEASE CHAMP PACKER FROM 13,300 MD !-WORK PACKER PAST SET DEPTH I-ALLOW ELEMENTS TO RELAX -PULL OUT OF HOLE FROM 13,300 MD -LAYING DOWN 4"DRILL PIPE FROM 13319 _ FT TO 4950 FT. 09:30 - 12:00 2.50 EVAL P DECOMP LAY DOWN 2-7/8 TUBING FROM 4950 FT TO 3345 FT. 12:00 - 13:30 1.50 EVAL P DECOMP CREW CHANGE AND RIG CHECKS. INSPECT RIG FLOOR EQUIPMENT. CONTINUE LAY DOWN 2-7/8"EUE TUBING SINGLES INTO PIPE SHED. 13:30 - 14:00 0.50 EVAL P DECOMP LAST 2 DISPLACEMENTS SHOWED ZERO 1 LOSS. 'STOP PULLING PIPE AND FLOW CHECK WELL. WELL IS OBSERVED STATIC. CONDUCT KICK WHILE TRIPPING DRILL WITH DERRICKMAN ON THE BRAKE. ANNOUNCEMENT MADE OF DRILL,ALL HANDS WENT TO STATIONS. WELL WAS SHUT IN WITH TIWAND CLOSED ANNULAR. CONDUCT AAR WITH CREWS. 14:00 - 17:00 3.00 EVAL P DECOMP CONTINUE POOH WITH 2-7/8"EUE TUBING. 17:00 - 18:00 1.00 EVAL P DECOMP HES PACKER AT SURFACE. LAY DOWN PACKER. PULL WEAR RING 1-CLEAN/CLEAR RIG FLOOR 18:00 - 00:00 6.00 EVAL P DECOMP LOAD 3-1/2"L-80 TC-II TUBING IN PIPE SHED -DRIFT AND STRAP COMPLETION TUBING -STRAP AND O.D.JEWELRY 124 HR LOSSES=3 BBLS Printed 12/2/2013 11:21:00AM North America-ALASKA-BP Page 6 of 8 Operation Summary Report Common Well Name:MPF-93 AFE No Event Type:WORKOVER(WO) Start Date:11/8/2013 End Date:11/16/2013 X3-0140C-C:(1,500,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/23/2005 12:00:00AM Rig Release:11/16/2013 Rig Contractor.DOYON DRILLING INC. UWI:500292326600 Active datum:ORIG KELLY BUSHING©45.07usft(above Mean Sea Level) Date From-To Hrs I Task Code NPT I NPT Depth ! Phase Description of Operations (hr) (usft) 11/14/2013 00:00 - 03:30 3.50 EVAL P DECOMP SPCC CHECKS AND PRE-TOUR MEETING LOAD 3-1/2"L-80 TC-II TUBING IN PIPE SHED -DRIFT AND STRAP COMPLETION TUBING -STRAP SPACE OUT PUPS -DRIFT JEWELRY -RIG UP TO RUN COMPLETION 03:30 - 12:00 8.50 RUNCOM P RUNCMP PJSM MAKE UP 3-1/2'L-80 TC-II COMPLETION -MN 4-1/2"WLEG TO 3-1/2"X NIPPLE -M/U 7-5/8"X 3-1/2"HES TNT PACKER -BAKER LOK CONNECTIONS BELOW PACKER -RUN IN HOLE WITH 3-1/2"COMPLETION -MAKE UP TORQUE=2300 FT•LBS RIH WITH 165 JTS. 12:00 - 12:30 0.50 RUNCOM P RUNCMP CREW CHANGE AND RIG CHECKS. CONTINUE MAKING UP 3-1/2"TCII COMPLETION. 12:30 - 20:30 8.00 RUNCOM P RUNCMP RUN IN HOLE WITH COMPLETION FROM -5300 FT. r.: - PICK UP 3-1/2"SINGLES FROM PIPE SHED. - MAKE UP 3-1/2 TC-II COMPLETION TO 2300 FT'LBS. 20:30 - 21:00 0.50 RUNCOM P RUNCMP KICK WHILE TRIPPING DRILL AAR: - NEW CREWMEMBER WAS FILLING IN ON FLOORS,GOOD DIRECTION GIVEN BY OTHER FLOORHANDS - GOOD COMMUNICATION FROM MOTORMAN RE:ACCUMULATOR FUNCTION • - TIMELY DRILL,CREW RESPONDED QUICKLY AND CORRECTLY. 21:00 - 00:00 3.00 RUNCOM P RUNCMP CONTINUE IN HOLE WITH COMPLETION FROM-9900 FT. - PICK UP 3-1/2"SINGLES FROM PIPE SHED. - MAKE UP 3-1/2 TC-II COMPLETION TO 2300 FT'LBS. -RUN IN HOLE TO 11,953 FT -P/UWT=110K,S/OWT=70K 24 HR LOSSES=0 BBLS _ 11/15/2013 00:00 - 02:00 2.00 RUNCOM P RUNCMP SPCC AND PRE-TOUR CHECKS CONTINUE IN HOLE WITH COMPLETION FROM-12000 FT. - PICK UP 3-1/2"SINGLES FROM PIPE SHED. - MAKE UP 3-1/2 TC-II COMPLETION TO 2300 FT*LBS. _ -RUN IN HOLE TO 13,296 FT _ 02:00 - 02:30 0.50 RUNCOM P RUNCMP TAG 7-5/8"LINER TOP PACKER -MAKE UP AND RUN IN HOLE WITH JOINT #408 -SET DOWN 5K 17FT IN ON JT#409 -TAG AT 13,345 FT -PICK UP 5 FT AND CALCULATE SPACE OUT Printed 12/2/2013 11:21:00AM • North America-ALASKA-BP Page 7 of 8 Operation Summary Report Common Well Name:MPF-93 AFE No Event Type:WORKOVER(WO) Start Date:11/8/2013 End Date:11/16/2013 X3-0140C-C:(1,500,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/23/2005 12:00:00AM Rig Release:11/16/2013 Rig Contractor:DOYON DRILLING INC. UWI:500292326600 Active datum:ORIG KELLY BUSHING @45.07usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:30 - 04:00 1.50 RUNCOM P RUNCMP PJSM,MU SPACE OUT PUPS AND HANGER WITH FMC. 1 -MAKE UP SPACE OUT PUPS -M/U JOINT#407 !-M/U 4"LANDING JOINT W/FOSV TO FMC 11" X 4-1/2"TUBING HANGER PUW=123 K,SOW=76 K -LAND FMC 11"X 4-1/2"HANGER -FMC RUN IN LOCK DOWN SCREWS L/D LANDING JOINT 04:00 - 08:15 4.25 RUNCOM P 1 RUNCMP PJSM,ON REVERSE CIRCULATE COMPLETION FLUIDS. 1 -CLOSE BLIND RAMS -LINE UP TO PUMP THROUGH KILL LINE 1-BEGIN PUMPING 115 BBLS 9.9 BRINE DOWN IA TAKING RETURNS UP TUBING THROUGH THE GAS BUSTER. 1 INITIAL RATE IS ONLY 1.25 BPM AT 1000 PSI PUMP PRESSURE. DISCUSS WITH HES SUPERVISOR RISKS OF PREMATURE PACKER SETTING,DECISION IS MADE TO INCREASE RATE TO 2 BPM @ 1500 PSI. 08:15 - 11:00 2.75 RUNCOM P RUNCMP r AT 250 BBLS PUMPED,PRESSURE INCREASES. REDUCE RATE TO 1.5 BPM TO MAINTAIN 1500 PSI IA PRESSURE. •NOTE: DCR SHEAR VALVE AT 3000 FT IS PINNED TO SHEAR AT 2500 PSI,IS WHY 'THERE IS A 1500 PSI SURFACE LIMIT. 11:00 - 13:30 2.50 RUNCOM P RUNCMP PJSM THEN DROP BALL AND ROD WITH ROLLERS. LAY DOWN LANDING JOINT. WAIT 15 MIN THEN CLOSE BLINDS AND • PRESSURE TEST TUBING 250/3800 PSI, GOOD. TUBING LOSES 140 PSI FIRST 15 MIN,55 PSI SECOND 15 MIN,PASS AS PER CRT-10-45. j BLEED OFF TUBING TO 2100 PSI. 'PUMP DOWN IA,PRESSURE TEST TO 250/ 3750 PSI,GOOD. 1 CASING TEST LOSES 60 PSI FIRST 15 MIN,20 PSI SECOND 15 MIN. 'PASS AS PER CRT-10-45. 13:30 - 14:00 0.50 RUNCOM P RUNCMP GET AUTHORIZATION FROM WTL TO PROCEED WITH OPERATIONS. • BLEED OFF TUBING,AT 800 PSI TUBING/ 3600 PSI IA DCR WALVE SHEARS OPEN. PUMP BOTH WAYS,CONFIRM ITS CLEAR. ,14:00 - 15:30 1.50 RUNCOM P RUNCMP FMC REP INSTALL TWC. TEST FROM BELOW AND ABOVE TO 3000 PSI, GOOD. 15:30 - 17:00 1.50 RUNCOM P RUNCMP RIG DOWN BOP LINES. VAC OUT STACK. PREP FOR REMOVING BOP STACK. 17:00 - 18:30 1.50 RUNCOM P RUNCMP PJSM NIPPLE DOWN BOPS REMOVE FLOW NIPPLE AND TURNBUCKLES. LOTO KOOMY AND REMOVE HOSES. -SET BACK BOP STACK • Printed 12/2/2013 11:21:00AM • North America-ALASKA-BP f !age 8 of 8 Xe Operation Summary Report Common Well Name:MPF-93 AFE No Event Type:WORKOVER(WO) I Start Date:11/8/2013 End Date:11/16/2013 1X3-0140C-C:(1,500,000.00) Project:Milne Point 1 Site M Pt F Pad Rig Name/No..DOYON 16 Spud Date/Time:6/23/2005 12:00:00AM Rig Release:11/16/2013 Rig Contractor:DOYON DRILLING INC. UWI:500292326600 Active datum:ORIG KELLY BUSHING @45.07usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) r 18:30 - 22:00 3.50 RUNCOM P RUNCMP PJSM,N/U 4-1/16"5 M ADAPTER 8 TREE -N/U ADAPTER PER FMC REP -PT ADAPTER 250 PSI LOW AND 5000 PSI HIGH FOR 30 CHARTED MINS NIPPLE UP TREE PRESSURE TEST TREE -250/5000 PSI,BOTH 5 CHARTED MINUTES 22.00 - 00.00 2.00 RUNCOM P RUNCMP 'PJSM,R/U AND TEST DSM LUBRICATOR -TEST 250/3500 PSI, FOR 5 CHARTED MINUTES. I , PULL TWC I-LAY DOWN LUBRICATOR 24 HR LOSSES TO WELL=0 BBLS 11/16/2013 00:00 - 03:00 3.00 RUNCOM P RUNCMP SPCC CHECKS AND PRE-TOUR MEETING ■ PJSM WITH LRS,WSL,AND RIG CREW. 1-RU LRS TO TREE TO FREEZE PROTECT !WELL. -TEST LINES TO 250/3500 PSI. -PUMP 22 BBLS DIESEL INTO IA. -PUMP AT 1 BPM©100 PSI ALLOW TO U-TUBE FOR 1 HR. I 03:00 - 04:00 1.00 RUNCOM P RUNCMP I PJSM,R/U AND TEST DSM LUBRICATOR 1 -TEST 250/3500 PSI, FOR 5 CHARTED MINUTES. -SET BPV -LAY DOWN LUBRICATOR 04.00 - 05:00 1.00 RUNCOM P RUNCMP LRS TEST BPV -PRESSURE TEST BPV FROM BELOW -TEST 250 PSI LOW AND 3000 PSI HIGH FOR 5 CHARTED MINS 1-BLOW DOWN RIG DOWN LRS 05:00 06:00 1.00 RUNCOM P RUNCMP PREPARE TO RIG DOWN -SECURE VALVES ON TREE I 1-SECURE CELLAR -PREPARE TO MOVE TO MPF-78 OA=0 PSI IA=0 PSI RELEASE RIG FROM MPF-93 AT 0600 HRS ON I i.... J 11-16-2013 Printed 12/2/2013 11:21:00AM , TREE:2-9/16"-5M FMC Q Orig. :ley.= 45.07 Doyon 14 WELLHEAD:11"x 2-9/16"5M■ Phase 1 M P F-�/ Orig.._�lev. = 30.00 Doyon 14 Tub Hgr.11"x 2-9/16"TC-II T&B 2.5"CIW-H BPVT Conductor 112' I 11 . J KOP @ 250' Angle passes 50°@ 2350` Max Angle in Tbg=71°@ 8800' Angle thru liner= 18° 10 3/4"45.5#L-80 BTC Csg. 7,925' I i 3.5"9.2#/ft L-80 IBT-M (Drift id=2.867" cap= .0087 bpf) 7 5/8"29.7 ppf, L-80, BTC-Mod casing _ - (drift ID=6.75" cap.=0.0459 bpf) (cap w/4 1/2"tbg inside =0.0262 bpf) 1-5/S"X3-1/2."NES T►JT PILK. a g I3zZe' 1334I' - /t - 7 5/8"X 3 1/2" Liner: 13,327' 4.5"X 3.5"X-Over Sub 13,335' Baker Tie back Sleeve Baker ZXP Packer 13,338' 13,357' 80-40 Seal Bore Ext.Top 13,351' Baker Locator sub 80-40 Seal Bore Ext. Bottom Baker 80-40 Seal assy(2.86 ID) 13,358' 13,372' lit 4.5"X 3.5"X-Over Sub(2.992 ID) 13,372' 7 5/8"X 5 1/2" Liner: Baker ZXP Packer 13,417` 1[1 7 5/8"Float Collar 13,417' Baker HMC Liner Hanger 13,435' Perfs Al SPF MD TVD , 7 5/8"Weatherford Float Shoe 13,541' 6 13847'- 13860' 7160' 7172' 5 1/2"Baker Insert Float Collar 13,737` 6 13866'- 13879' 7178'-7191' , 6 13887'- 13920' 7198'-7230' 5 1/2"Baker Float Collar 13,779' 2 7/8"HSD,38C CP Big Hole i 1 5 1/2"Baker Float Shoe 13,782' — 3.5"Baker Landing Collar 14,123' Est.top of fill @ 13,926'from Noes RWO 3.5"HES Float Collar 14,155' A ik 3.5"HES Float Shoe 14,189' DATE REV.BY COMMENTS MILNE POINT UNIT 7/21/05 Lee Hulme Drilled&Completed Doyon-14 9/28/05 _ MDO FCO/ESP Completion DOYON-14 WELL MPF-93 6/12/06 MOR FCO/ESP Completion Nabors 4es API NO: 50-029-23266-00 6/20/06 MDO RWO 4-ES/3-S ESP Completion 7/27/10 REH ESP RWO-Nabors 4ES BP EXPLORATION (AK) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 ra12- WOWED _ FEB �, �_ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission J �f 333 West 7 Avenue Anchorage, Alaska 99501 J Subject: Corrosion Inhibitor Treatments of MPF -Pad C(Wf'--- 9.3 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPF -Pad 10129/2011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor! Well Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls ft gal MPF-01 1950450 50029225520000 10.2 N/A 10.2 N/A 122.4 8/7/2011 MPF-02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF-05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 1.2 N/A 15.3 8/2/2011 MPF-09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 8/2/2011 MPF -13 1950270 50029225490000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 8/2/2011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/1/2011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/9/2011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF -33 2010620 50029226890000 23 Need top job MPF -34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF-37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF-38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 MPF-41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF -42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF-45 1950580 50029225560000 8 N/A 8 N/A 78.2 , 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A N/A MPF-49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 8.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF-61 1951170 50029225820000 62 Need top job MPF-62 1951610 50029226090000 2.0 NN 2.0 N/A 13.6 9/1/2011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/31/2011 MPF-69 1951250 50029225860000 0.8 N/A 0.8 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -77 1951360 50029225940000 0.2 N/A 0.2 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 N/A 5.1 7/31/2011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 N/A 6.8 8/32011 MPF-80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/3/2011 MPF -81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF -82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF-83 2000930 50029229630000 1.2 N/A 1.2 N/A 13.6 8/3/2011 MPF-84B 2001760 50029229310200 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF -86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/12/2011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/13/2011 MPF -88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/3/2011 MPF -89 2050900 50029232680000 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/13/2011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/13/2011 . " -- 3 1 ' MPF -93 2050870 50029232660000 0.3 N/A 0.3 N/A 7.7 9/12011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/132011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/1/2011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/112011 STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI N REPOR OF SUNDRY WELL OPERA~ONS 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension Change-Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit~To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 205-087 3. Address: ^ Service ^ Stratigraphic 61~API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23266-00-00 7. Property Designation: ~ 5,m ` ~~ " ~ ~ 8. Well Name and Number: \ ADL 025509 i~ ADL 35501 $" ` MPF-93 9. Field /Pool(s): Milne Point Unit / Kuparuk River Sands 10. Present well condition summary Total depth: measured 14183 feet true vertical 7482 feet Plugs (measured) None Effective depth: measured 14150 feet Junk (measured) None true vertical 7451 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 113' 113' 1530 520 Surface 7890' 10-3/4" 7925' 4259' 5210 2480 Intermediate Production 13509' 7-5/8" 13541' 6868' 8160 7020 liner 365' S-1/2" 13417' - 13782' 6750' - 7098' 7740 6280 Liner 861' 3-1/2" 13322' - 14183' 6659' - 7482' 10160 10530 Perforation Depth: Measured Depth: 13847' - 13920' True Vertical Depth: 7160' - 7230' Tubing (size, grade, measured and true vertical depth): 2-7/8", 6.5# L-80 12082' 5795' Packers and SSSV (type, measured and true vertical depth): gaker ZXP Packer 13338' 6674' Baker ZXP Packer 13417' 6750' 11. Stimulation or cement squeeze summary: Intervals treated (measured): ~~ ~ ° F...~.,v ~'1../ Treatment description including volumes used and final pressure: ~ (~ ~~,ri ... 12. Representative Daily Average Production or Injection t)a "`° "'` Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 700 0 Subsequent to operation: 78 337 1399 380 303 13. Attachments: ^ Copies of Logs and Surveys run 14. Well Class after work: ,~ ^ Exploratory ®Development ^ Service erations ® Dail Re ort of Well O y p p ® Well Schematic Diagram 15. Well Status after work:°`~ ® Oil ^ Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. 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: Contact Mackie Derrick, 564-5891 N/A Printed Name Sondra Stewman Title Drilling Technologist Ph 0 D 7 ate _ Prepared By Name/Number. ~~ ~ ' (~ Sign ure one 564-4 5 Sondra Stewman, 564-4750 Form 10-404 Revised 07/20~~D~c ~~ ~ ~ LU~~ SS bmft Original Only TREE: 2-9/16" - 5M FMC WELLHEAD: 11" x 2-9116" 5M FMC 1 Tub Hgr. 11" x 2-9/16" TC-II T&B 2.5" CIW-H BPVT Conductor 112' KOP @ 250' Angle passes 50° @ 2350` Max Angle in Tbg = 71 ° @ 8800' Angle thru liner = 18° 10 3/4" 45.5# L-80 BTC Csg. 7,g25` COMMENTS Centrilift Dual ESP GPMTAR 1:1 12,003' GMPTAR 1:1 3as Separator GSTHVEVXH6 12,028` Tandem Seal Section, 12 033` GSB3DBUT/LT SB/SB PFSA , 7 5/8" X 3 1/2" Liner: Baker Tie back Sleeve Baker ZXP Packer 80-40 Seal Bore Ext. Top 80-40 Seal Bore Ext. Bottom 7 5/8" X 5 1/2" Liner: Baker ZXP Packer Baker HMC Liner Hanger Perfs SPF MD TVD 6 13847' - 13860' 7160' - 7172` 6 13866` - 13879' 7178' - 7191 ` 6 13887` - 13920' 7198` - 7230` 2 7I8" HSD, 38C CP Big Hole Est. top of fill @ 13,926' from Noes RWO / DATE EV. BY 7/21/05 Lee Hulmi 9/28/05 MDO 6/12/06 MOR 6/20/06 MDO 7/27/10 REH Orig. DF EI 45.07 Doyon 14 Orig. GL EI~ 30.00 Doyon 14 amco 2-7/8" x 1" KBMG-2 139' I ;amco 2-7/8" x 1" KBMG-2 3,215` amco 2-7/8" x 1" KBMG-2 HES XN-Nipple {2.25" id) Motor, 266 HP KMH 2345 volt / 69 amp, 11,818' 11,961` 12,047' I Pump Mate Sensor 12 069` w/6 fin centralizer , 4.5" X 3.5" X-Over Sub 13,335` 13,357` Baker Locator sub Baker 80-40 Seal assy (2.86 ID) 13,358` 4.5" X 3.5" X-Over Sub (2.ss2 IDS 13,372` 7 5/8 "Float Collar 13,417' I ~ 7 5/8" Weatherford Float Shoe 13,541 ` ~ 5 1/2 "Baker Insert Float Collar 13,737' 5 1/2 "Baker Float Collar 13,779' 5 1/2" Baker Float Shoe 13,782` - 3.5" Baker Landing Collar 14,123' 3.5" HES Float Collar 14,155` ~ 3.5" HES Float Shoe ~ y ! 83 MILNE POINT UNIT unueu a wniyieicu uvyun - w FCOIESP Com letion DOYON - 14 WELL MPF-93 FCO/ESP Completion Nabors 4es API NO: 50-029-23266-00 RWO 4-ES / 3-S ESP Completion ESP RWO -Nabors 4ES BP EXPLORATION • • North America -ALASKA - BP Page ~ of 1 Operation Summary Report Common Well Name: MPF-93 DIMS AFE No Event Type: MOBILIZATION (MOB) Start Date: 7/22/2010 End Date: 7/23/2010 X4-0009E-E (75,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Dateli'ime: 6/23/2005 12:0O:OOAM Rig Release: 7/28/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292326600 Active Datum: M_ PF-93: @45.1ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/22/2010 00:00 - 02:30 2.50 RIGD P PRE PJSM. RIG DOWN RIG COMPONENTS IN PREPARATION FOR MOVE TO MPF-93. 02:30 - 04:00 1.50 RIGD P PRE PJSM. SCOPE DOWN AND LAY OVER DERRICK. 04:00 - 06:00 2.00 RIGD N WAIT PRE CONTINUE TO PERFORM DUTIES RELATED TO RIG MOVE. -WAITING ON (28) MATTING BOARDS. =DOYON 14 WENT THROUGH THE ROAD, DELAYING MATTING BOARD DELIVERY. 06:00 - 00:00 18.00 RIGD N WAIT PRE CONTINUE TO WAIT ON RIG MATTING BOARDS TO MOVE RIG. -WAS ABLE TO LOCATE 6 MATTING BOARDS ON MPL-PAD. -PREP AREA BEHIND WELL. -LAYOUT MATTING BOARDS AND HURCULITE FOR SUBBASE. -PERFORM GENERAL MAINTENANCE ON RIG. -REPAIR HINGES ON HATCH IN PITS. 7/23/2010 00:00 - 02:00 2.00 RIGU P PRE RIG MATS ON LOCATION. SPOT SAME AROUND WELL. 02:00 - 06:00 4.00 RIGU - P PRE TRUCKS ON LOCATION. MOVE & SPOT RIG COMPONENTS OVER WELL. 06:00 - 09:30 3.50 RIGU. P PRE SPOT SUB BASE, PITS, AND PIPE SHED. -JACK UP AND LEVEL ALL THREE MODULES -2 MATTS HIGH AND HIGH-JACKED TO ACCOMIDATE TBG SPOOL HEIGHT AND DOUBLE GATE. 09:30 - 10:00 0.50 RIGU P PRE PJSM FOR STANDING DERRICK. -HANDS WORKING IN NEW POSITIONS. DERRICK HAND AND FLOORHAND ARE NEW TO POSITION. 10:00 - 11:00 1.00 RIGU P PRE STAND UP DERRICK AND PIN IN PLACE. 11:00 - 11:30 0.50 RIGU P PRE PJSM FOR SLOPING DERRICK. -HANDS WORKING IN NEW POSITIONS. DERRICK HAND AND FLOORHAND ARE NEW TO POSITION. 11:30 - 12:30 1.00 RIGU P PRE SCOPE UP DERRICK AND PIN IN PLACE. 12:30 - 16:00 3.50 RIGU P PRE CLEAN UP AROUND MPF-50, REMOVE HERCULITE, -RIG UP MUD LINES, LEVEL RIG & PIPE SHED -SHORE UP ALL STAIRS, RIG ACCEPTED @ 16:00 HRS, 07/23/2010. Printed 8/26/2010 1:51:21 PM North America -ALASKA - BP Page ~ of 6 Operation Summary Report Common Well Name: MPF-93 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/19/2010 End Date: 7/28/2010 X4-OOQ9F-E (525,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 6/23/2005 12:0O:OOAM Rig Release: 7/28/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292326600 Active Datum: MPF-93: @45.1ft (above Mean Sea Level) __ Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/23/2010 16:00 - 18:00 2.00 WHSUR P DECOMP TAKE ON 10.6 PPG BRINE TO PITS. -M/U LUBRICATOR, TEST TO 500 PSI, OK. PULL BPV. -RECORD PRESSURES, SITP - 650 SICP - 650 OA - 50 18:00 - 21:00 3.00 KILLW P DECOMP TAKE ON BRINE, APPLY HEAT TO BRINE, TEST SURFACE LINES. =CHECK FOR GAS ON TBG & UA, VERY LITTLE :GAS. -SET OUT GAS VENTING SIGNS AND NOTIFY MILNE BASE OF IMPENDING OPERATION. 21:00 - 00:00 3.00 KILLW P DECOMP 'PJSM: COMMENCE PUMPING 10.6 PPG BRINE DOWN TBG @ 3 BPM., HOLDING 675 - 700 PSI ON CHOKE. -PUMP 1 'V2 TBG\/OLUMES & SHUT DOWN TO LINE UP ON HI VIS"PILL. -SITP WENT TO 0 PSI, SICP @ 630 PSI WHILE LINING UP ON PILL. -PUMP 69 BBLS MI POWERVIS PILL, SHUT IN WELL, PUMP, (BULLHEAD), REMAINING PILL. (5 BBLS MORE) -CONTINUE PUMPING, (BULLHEADING), W/ BRINE, (69 BBLS), PILL NOW OUT OF TUBING. -ACHIEVED A MAX PRESSURE OF 1370 PSI WHILE BULLHEADING @ 15 BBLSAWAY. 1 -FINAL BULLHEAD PRESSURE OF 1210 PSI ON TBG, CASING @ 980 PS1.69 BBLS TOTAL BULLHEAD VOLUME. -MONITOR WELL AFTER BULLHEADING TO SPOT PILL ABOVE PERFS, TUBING DROPPED TO 80 PSI, VA TO 520 PSI. -BRING ON PUMP @ 3 BPM & CRACK CHOKE, HOLDING CASING PRESSURE @ 590, PUMP PRESSURE @ 900 PSI. -CONTINUE W/WELL KILL, MAINTAINING 900 PSI PUMP PRESSURE DOWN TUBING. -W/ 200 BBLS PUMPED AFTER SPOTTING PILL, 890 PUMP PRESSURE, 430 PSI ON CHOKE. 7/24/2010 00:00 - 03:00 3 00 KILLW P DECOMP CONTINUE W/WELL KILL- PUMPING 3 BPM . AVERAGING 900 PSI PUMP PRESSURE. - W/ 650 BBLS PUMPED AFTER SPOTTING PILL, SEE 10.6 PPG RETURNS. - FINAL PUMP PRESSURE @ 3 BPM, 900 PSI, CHOKE PRESSURE 60 PSL -SHUT DOWN AND OPEN CHOKE. SLIGHT VACUUM ON CASING, LITTLE VACUUM ON TUBING. 03:00 - 04:00 1.00 KILLW P DECOMP BLOW DOWN AND DISCONNECT OUTSIDE LINES, MONITOR WELL, WELL STABLE. 04:00 - 06:00 2.00 WHSUR P DECOMP PJSM. INSTALL TWC VALVE. TEST FROM THE TOP TO 3500 PSI, GOOD TEST. Printed 8/26/2010 1:51:30PM ~orth America. -ALASKA - BP • Page 2 of 6 Operation Summary Report Common Well Name: MPF-93 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/19/2010 End Date: 7/28/2010 X4-0009E-E (525,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 6/23/2005 12:0O:OOAM Rig Release: 7/28/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292326600 Active Datum: MPF-93: @45.1ft (above M_e_an Sea Level) ___ _ Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 07:30 1.50 WHSUR P DECOMP PJSM. LINE UP AND TEST TWC FROM BELOW @ 500 PSI / 10 MIN / CHARTED, (ROLLING TEST) - TEST IS GOOD. 1.5 BPM CcD 500 PSI INJECTIVITY RATE. -'41 BBLS TO FILL HOLE AND CONDUCT TEST. - -STATIC LOSS RATE = 7 BPH. 07:30 - 09:00 1.50 WHSUR P DECOMP PJSM N/D TREE AND REMOVE FROM CELLAR. 09:00 - 11:00 2.00 BOPSUR P DECOMP PJSM. DETERMINED THERE WILL BE HEIGHT ISSUES WITH THE DOUBLE GATE. - N/D TEST SPOOL... -MOVED-THE BOP.-STACK BACK AND REMOVED THE TEST SPOOL FROM THE CELLAR. 11:00 - 13:00 2.00 BOPSUR P DECOMP N/U THE-ADAPTER FLANGE AND SET THE BOP STACK BACK ON THE WELL HEAD. - REMOVE ACCUMULATOR LINES TO BOP STACK. 13:00 - 16:30 3.50 BOPSUR P bECOMP N/D THE BLIND /SHEAR RAM OPERATOR - RIG'UP SLING ON THE ANNULAR PREVENTOR. PICK UP 5K ON ANNULAR & NOTICED SLINGS CONTACTED DUTCH NIPPLE. - M/U SWINGS FOR THE NEW KOOMY LINES ON THE UPPER RAMS. 16:30 - 17:00 0.50 BOPSUR P DECOMP PJSM. RIG UP SLINGS ON THE ANNULAR PREVENTOR AGAIN. -PICK UP ON THE ANNULAR AND PULL IT OFF THE UPPER SINGLE GATE. 17:00 - 18:00 1.00 BOPSUR - - P DECOMP N/D THE UPPER SINGLE GATE OPERATOR AND REMOVE FROM BOP STACK. 18:00 - 18:30 0.50 BOPSUR P DECOMP PJSM. LINE UP ON ANNULUS AND FILL HOLE, 12.5 BBLS TO FILL. 18:30 - 21:30 3.00 BOPSUR P DECOMP PJSM. PICK UP DOUBLE GATE AND PLACE ON STACK. 21:30 - 00:00 2.50 BOPSUR P DECOMP BOLT UP AND TIGHTEN DOWN ALL CONNECTIONS ON STACK. - INSTALLING NEW ACCUMULATOR LINES. -INSTALL DUTCH SYSTEM LOCK DOWN FLANGE AND UPPER AIR BOOT. 7/25/2010 00:00 - 06:00 6 00 BOPSUR P DECOMP /8" X 5M BOPE W/ (4) . RAM CONFIGURATION. -TIGHTEN UP REMAINING FLANGE BOLTS ON STACK - FINISH UP CONNECTING NEW ACCUMULATOR LINES -BOLT UP CHOKE AND KILL LINES - INSTALL BLIND SHEAR RAM BLOCKS AND VBR RAM BLOCKS - FUNCTION TEST BOP STACK 06:00 - 09:30 3.50 BOPSUR P DECOMP CONTINUE TO FUNCTION TEST STACK. - REPLACE FITTING ON BOPE LINE -SPOT WELD COLLAR ON HCR /CHOKE LINE -FUNCTION TEST BOPE FROM ACCUMULATOR UNIT. -CHECK MEASUREMENTS, TIGHTEN BLIND RAM DOOR. Printed 8/26/2010 1:51:30PM ~orth America -ALASKA - BP ~ Page 3 of 6 Operation Summary Report ___ __-- Common Well Name: MPF-93 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/19/2010 End Date: 7/28/2010 X4-OOQ9F-E (525,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 6/23/2005 12:0O:OOAM Rig Release: 7/28/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292326600 Active Datum: MPF-93: @45.1ft (above Mean Se_a Level) _ _ Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 - 17:00 7.50 BOPSUR P DECOMP PJSM. RIG UP TEST EQUIPMENT, FULL TEST - TEST BOTH SETS PIPE RAMS, BLIND / SHEAR RAMS @ 250 /3500 PSI. -TEST ANNULAR PREVENTOR AND ALL CHOKE VALVES 250 / 3500 PSI. -TEST FLOOR VALVE, HCR VALVES, MANUAL KILL, 250/3500PS1. - DRAWDOWN TEST ON ACCUMULATOR, ALL 'TESTS GOOD, NO FAILURES. " - RIGDOWN TEST EQUPMENT. 17:00 - 17:30 0.50 BOPSUR P DECOMP PJSM. N/U RISER AND SPACER SPOOLS, DUTCH RISER. 17:30 - 18:30 1.00 WHSUR P DECOMP PICK UP LUBRICATOR & TEST TO 500 PSI, OK.. -CHECK FOR PRESSURE, WELL STABLE. - PULL TWC, L/D LUBRICATOR & DUTCH RISER. 18:30 - 19:30 1.00 PULL P DECOMP BOLDS ..PULL HANGER TO GET HANGER VING•_ - LEVELED OFF TO 73K UP WT, 37K DOWN WT: 19:30 - 20:00 0.50 PULL P DEGOMP PJSM. CIRCULATE (1) TUBING VOLUME, 3 6PM / 760 PSI. -NO VISUAL ON FLUID IN ANNULUS, 3 BBLS DOWN TUBING TO HIT FLUID -CONTINUE PUMPING DOWN TUBING, VA VALVE LEFT OPEN. - FILLED CELLAR AROUND WELLHEAD W/ BRINE, 20+ BBLS. - BRINE SPILLED OUTSIDE CONTAINMENT, INITIATE CLEANUP. 20:00 - 23:00 3.00 PULL N HMAN DECOMP CALL SUPERINTENDANT, REPORT SPILL, CALL MPU ENVIRONMENTAL. - VACUUM TRUCK ON LOCATION SUCKED OUT CELLAR AND OUTSIDE. - NOTIFIED NABORS HSE TO CONDUCT INVESTIGATION. -CLEAN UP OUTSIDE CELLAR. - RIG UP ELEPHANT TRUNK AND DRAIN LINE. -HOLE AVERAGING 13 BPH STATIC FLUID LOSS RATE. 23:00 - 00:00 1.00 PULL N DECOMP PJSM. POOH W/ 2 7/8" EUE 8RND ESP COMPLETION. -RIG UP ESP LINE TO SPOOLER 7/26/2010 00:00 - 06:00 6.00 PULL P DECOMP CONTINUE TO POOH W/ 2 7/8" ESP COMPLETION STRING. -ADJUST ELEPHANT TRUNK & CONTINUE TO POOH. -AVERAGING 14 BPH FLUID LOSS OVER DISPLACEMENT. -AFTER PULLING (40) STANDS, SIGNIFICANT AMOUNT OF ASPHALTINES ON PIPE. - REMOVING SAME WITH WIRE SCRAPE W/ POOH. (ASPHALTINE FLOATS IN BRINE) -ASPHALTINE BUILD UP ON PIPE CLEANING UP & CLEANED UP BY STAND #51. 06:00 - 07:00 1.00 PULL P DECOMP SERVICE RIG, DAILY INSPECTIONS, CHECK CROWN O MATIC, OK. - LAY DOWN LA SAILE CLAMPS, TAKE ON LOAD 290 BBLS) 10.6 PPG BRINE. Printed 8/26/2010 1:51:30PM ~orth America- ALASKA - BP ~ Page a of Operation Summary Report Common Well Name: MPF-93 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/1 912 01 0 End Date: 7/28/2010 X4-0009E-E (525,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 6/23/2005 12:0O:OOAM Rig Release: 7/28/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292326600 Active Datum: MPF-93: @45.1ft (above Mean Sea Level) _ _ _ Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:00 - 09:00 2.00 PULL P DECOMP PJSM. CONTINUE TO POOH W/ 2 7/8" EUE 8 RND ESP COMPLETION STRING. - KEEPING HOLE FULL, 13 BPH LOSS RATE OVER PIPE DISPLACEMENT. - 90 STANDS OUT, CUT ESP SPLICE. 09:00 - 11:00 2.00 PULL N WSEO DECOMP ATTEMPTED TO MEG ESP CABLE IN ESP FIRE ENTRAPPED GAS IN ESP CABLE IGNITED WHILE MEGGING CABLE. RIG HAND RESPONDED W/ FIRE EXTINGUISHER VERY QUICKLY - MILNE PT FIRE DEPARTMENT. NOTIFIED AND RESPONDED SUPERINTENDANT NOTIFIED = NO DAMAGE TO BUILDING OR INJURY TO PERSONNEL - SAFETX`STAND DOWN TO DISCUSS INCIDENT 11:00 - 13:00 2.00 PULL P` DECOMP SAFETY MEETING. OJT. SPILL PREVENTION REGULATION TRAINING. - REVIEW MANAGING ACCUMULATION AREAS, SAA, RAA & UAA. 13:00 - 15:30 2.50 PULL N WSEO DEGOMP CLEAN AROUND RIG AND LOCATION. -CLEAN UP SPOOLER, SUCK OUT OPEN CONTAINMENTS AROUND RIG. -STATIC FLUID LOSS, 8 BBLS / HR. 15:30 - 18:30 3.00 PULL P DECOMP CONTINUE TO POOH W/ 2 7/8" ESP COMPLETION. - 126 STANDS, (4) SINGLES & GLM ASSEMBLY. 18:30 - 19:00 0.50 PULL ' P DECOMP SAFETY MEETING W/CHECK SIX. RIG ORIENTATION. 19:00 - 23:00 4.00 PULL P - DECOMP PJSM. UD ESP ASSEMBLY, CLEAR AND CLEAN RIG FLOOR_ - NORM AND LOAD OUT OLD ESP ASSEMBLY 23:00 - 00:00 1.00 PULL P DECOMP WEEKLY SAFETY MEETING W/ RIG CREW. REVIEW STOP CARDS. - REVIEW MANAGING ACCUMULATION AREAS, SAA, RAA & UAA. 7/27/2010 00:00 - 01:00 1.00 RUNCOM P RUNCMP PREP TO RUN ESP. BRING ESP EQUIPMENT IN TO SHED. - RIG DOWN ELEPHANT TRUNK AND DRAIN HOSE. 01:00 - 04:30 3.50 RUNCOM P RUNCMP PJSM. P/ FSP P IMP ASSEMBLY, PLUG IN AND SERVICE. -CHECK CONDUCTIVITY, OK 04:30 - 06:00 1.50 RUNCOM P RUNCMP RIH W/ 2 7/8" EUE 8 RND ESP COMPLETION, RUNNING STANDS OUT OF DERRICK. - USING BEST O LIFE 2000 PIPE DOPE, TORQUING TUBING TO 2300 FT/LBS. -CHECKING CONDUCTIVITY AND PUMPING 10 BBLS DOWN TUBING EVERY 20 STANDS 06:00 - 07:00 1.00 RUNCMM P RUNCMP RIG SERVICE -TEST ESP CABLE Printed 8/26/2010 1:51:30PM ' ~orth America -ALASKA - BP ~ Page 5 of s Operation Summary Report Common Well Name: MPF-93 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/19/2010 End Date: 7/28/2010 X4-0009E-E (525,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 6/23/2005 12:0O:OOAM Rig Release: 7/28/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292326600 Active Datum: MPF-93: @45.1ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:00 - 11:30 4.50 RUNCOM P RUNCMP RIH W/ 2 7/8" EUE 8 RND ESP COMPLETION. RUNNING STANDS OUT OF DERRICK. - USING BEST O LIFE 2000 PIPE DOPE, TORQUING TUBING 702300 FT/LBS. -CHECKING CONDUCTIVITY AND PUMPING t0 BBLS DOWN TUBING EVERY 20 STANDS -.20 SPM @ 700 PSI , -60 STANDS MAINTAINING CONT HOLE FILL DURING TRiP IN HOLE -AVG LOSS RATE - 6-8 BPH 11:30 - 12:30 1.00 RUNCMM P RUNCMP BOP DRILL - D1 ,KICK WHILE TRIPPING -KICK DRILL WAS INITIATED, RIG OPS WERE STOPPED AND THE OPEN TIW VALVE WAS INSTALLED. DRILLER SIMULATED OPENING THE HCR AND CLOSLNG THE ANNULAR. DRLLL WAS TIMED, 70 SECONDS WAS RECORDED FOR WELL TO BE SECURED. 12:30 - 13:30 1.00 RUNCOM P ` RUNCMP RIH W/ 2 7/8" EUE 8 RND ESP COMPLETION, RUNNING STANDS OUT OF DERRICK. - USING BEST O LIFE 2000 PIPE DOPE, TOROIJING TUBING 702300 FT/LBS. -CHECKING CONDUCTIVITY AND PUMPING 10 BBLS DOWN TUBING EVERY 20 STANDS - 17 SPM @ 640 PSI , ~ 80 STANDS -MAINTAINING CONT HOLE FILL DURING TRIP IN HOLE -AVG LOSS RATE - 6-8 BPH 13:30 - 15:30 2.00 RUNCOM P `RUNCMP REEL TO REEL SPLICE. -SPLICE OPERATION PERFORMED BY CENTRILIFT REP. - CONT HOLE FILL WAS MAINTAINED FOR WELL CONTROL DURING SPLICE OPERATIONS. 15:30 - 21:00 5.50 RUNCOM P RUNCMP RIH W/ 2 7/8" EUE 8 RND ESP COMPLETION, RUNNING STANDS OUT OF DERRICK. - USING BEST O LIFE 2000 PIPE DOPE, TORQUING TUBING TO 2300 FT/LBS. -CHECKING CONDUCTIVITY AND PUMPING 10 BBLS DOWN TUBING EVERY 20 STANDS - 19 SPM @ 700 PSI , ~ 100 STANDS -MAINTAINING CONT HOLE FILL DURING TRIP IN HOLE -AVG LOSS RATE ~ 6-8 BPH 21:00 - 22:00 1.00 RUNCMM P RUNCMP PJSM: PICK UP AND MAKE UP TUBING HANGER AND LANDING JOINT. - MU PENETRATOR IN TBG HANGER 22:00 - 23:00 1.00 RUNCOM P RUNCMP CENTRILIFT -MAKE UP PENETRATOR sum - LD ESP CABLE THROUGH THE SHEAVE 23:00 - 00:00 1.00 RUNCOM P RUNCMP QIGE&-e4ND 2-7/8" ESP COMPLETION. RUN IN LOCK DOWN SCREWS. -382 JOINTS OF 2-7/8" TUBING, MU TORQUE _ 2,300 FT-LBS. -PU WT = 66K LBS, SO WT = 38K LBS. -200 LASALLE CLAMPS, 3 FLAT GUARDS, AND 7 PROTECTOLIZERS Printed 8/26/2010 1:51:30PM ' ,~orth America -ALASKA - BP ~ Page 6 of Operation Summary Report -_--- - _ Common Well Name: MPF-93 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/19/2010 End Date: 7/28/2010 X4-OOQ9F-E (525,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 6/23/2005 12:0O:OOAM Rig Release: 7/28/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292326600 Active Datum: MPF-93: @45.1ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/28/2010 00:00 - 01:00 1.00 RUNCOM P RUNCMP LAND TUBING HANGER AND 2-7/8" ESP COMPLETION. -FMC REP TO RUN IN LOCK DOWN SCREWS. -382 JOINTS OF 2-7/8" TUBING, MU TORQUE _ 2,300 FT-LBS. -PU WT = 66K LBS, SO WT = 38K LBS. -200 LASALLE CLAMPS, 3 FLAT GUARDS, AND - 7 PROTECTOLIZERS 01:00 - 03:00 2.00 RUNCOM P RUNCMP .PJSM:. `FMC REP TO DRY ROD IN TWC. , -3500 PS1 FROM ABOVE FOR 10 CHARTED MINUTES. -500 PSI ROLLING TEST FROM BELOV~LFOR 10 CHARTED MINUTES -2 SPM, 570 PSJ , 32 BBLS TOTAL. 03:00 - 06:00 3.00 WHSUR P RUNCMP PJSM: -ND 13-5/8" BOP W/{4) RAM CONFIG -RD CONTROL LINES AND DRAIN STACK 06:00 - 11:30 5.50 WHSUR P. RUNCMP CREW CHANGE: PJSM TO'CONTINUE ND 13-5/8" BOP W/ (4) RAM CONFIG. -FINISH ND LOWER SINGLE GATE FROM MUD CROSS. -RU TO PICK ANNULAR, DOUBLE GATE, AND MUD CROSS. -PU AND STAND BACK ANNULAR, DOUBLE GATE, AND MUD CROSS ON CRADLE. -ND LOWER SINGLE GATE FROM DSA AND REMOVE FROM CELLAR. 11:30 - 15:30 4.00 WHSUR: P RUNCMP NIPPLE UP ADAPTER FLANGE AND TBEE -ORIENT TREE. -TEST ADAPTER FLANGE AND TREE TO 5000 PSI WITH DIESEL FOR 30 MIN -GOOD TEST. 15:30 - 16:30 1.00 WHSUR P RUNCMP PJSM: -RU LUBRICATOR AND TEST W/DIESEL TO 500 PSI. -PULL TWC AND INSTALL BPV . -TEST BPV FROM BEIaOW TO 500 PSI FOR 10 CHARTED MINUTES BY ROLLING THE PUMPS. -CENTRILIFT PERFORMED FINAL CHECKS. -BHP = 3048 PSI, MOTOR TEMP = 125.2F, INTAKE TEMP = 140.4E -4.2 PHASE TO PHASE, 500MG PHASE TO GROUND. 16:30 - 18:00 1.50 WHSUR P RUNCMP LAY DOWN LUBRICATOR -SECURE WELL AND CELLAR "* RIG RELEASED AT 18:00 "" 24 HR NOTIFICATION OF BOP TESTING GIVEN TO AOGCC FOR MPF-25 CHUCK SHEVE CALLED BACK AND ASKED FOR AN UPDATE IN THE MORNING Printed 8/26/2010 1:51:30PM UNDER EVALUATION: Producer ~-93 (PTD # 2050870) Sustained IA C~g Pressure Page 1 of 1 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Saturday, June 05, 2010 7:32 PM ~Qgc, ~ ICI ~~ To: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Regg, JameslBF (DOA); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES MPU Production Optimization Engineer; AK, OPS MPU Control Room; Cismoski, Doug A; Engel, Harry R Cc: AK, D&C Well Integrity Coordinator; Janowski, Carrie; Holt, Ryan P (ASRC); Wellman, Taylor T Subject: UNDER EVALUATION: Producer MPF-93 (PTD # 2050870) Sustained IA Casing Pressure Follow Up Flag: Follow up Flag Status: Blue Attachments: Producer MPF-93 06-05-2010 TIO Plot.doc; MPF-93 (PTD #2050870).pdf All, Producer MPF-93 (PTD #2050870) is an ESP completion that has been shut in due to a downhole motor failure. Since the ESP stopped operating, the IA pressure exceeded MOASP on 06/03/2010 with tubing/IA/OA pressures of 0/2050/0. Currently the well is scheduled for a rig workover to repair the ESP in mid-July, 2010. The well will be reclassified as Under Evaluation. Once the rig begins working over the ESP, the well will be reclassified as appropriate and notification sent out. ~, r Plan forward: ~ w` 1. WIE: Monitor TIO plot for IA pressure stabilization C`~ ~~ ~"~' 2. Rig workover to repair ESP A schematic and TIO plot are enclosed for reference. «Producer MPF-93 06-05-2010 TIO Plot.doc > «MPF-93 (PTD #2050870).pdf» '~ Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 ,., . ~ _.. s: t,~ ~_a .~ _. 8/20/2010 MPU F-93 PTD 2050870 6/5/2010 TIO Pressures Plot ~4rG00 ~rU~0 2rC~~10 1,U~]0 V~~II: M PF-93 li"~ }~ ~,~10 0 }~2 r X10 O~J'1 CI}1 CI ~~?2+~r~10 ~ ~r~l ~!'~ ~ ~ ~~ 22'1 l7 CI~~05~1 Ll -~- T ~~ --~-- I~ -~ ~~ ~ 0,~ ~ ~~~~ ~n C~ TREE: 2-9/16" - 5M FMC WELLHEAD: 11" x 2-9/16" SM FMC 1 Tub Hgr. 11" x 2-9116" TC-II T&B 2.5" CIW-H BPVT KOP @ 250' Angle passes 50° @ 2350' Max Angle in Tbg = 71° @ 8800` Angle thru liner = 18° 10 3/4" 45.5# L-80 BTC Csg. 7,825' Orig. DF 45.07 Doyon 14 Orig. GL EI . = 30.00 Doyon 14 Camco 2-7/8" x 1" KBMG-2 Camco 2-7/8" x 1" KBMG-2 Camco 2-7/8" x 1" KBMG-2 HES XN-Nipple (2.25" id) Model GPMTAR 1:1 Pump 74 stg. GC3500 82 stg. GC3500 12,010` 19 stg. GC8200 Tandem Intake -Gas Separator 12,034' GSTHVEVXH6 Tandem Seal Section, GS63DBFERHLH6SSCV SB/SBPFSA 040` 12 GSB3DBFERHLH6SSCVSB/SBPFSA , 7 5/8" X 3 1/2" Liner: Baker Tie back Sleeve Baker ZXP Packer 80-40 Seal Bore Ext. Top 80-40 Seal Bore Ext. Bottom Motor, 266 HP KMH 2345 volt / 69 amp, Re-Rated Motor, 225 HP KME-1 2190 volt / 59 amp, Pump Mate Sensor w/6 fin centralizer 139' 3,218' 11,826' 11,967` 12,054' 12,082' 4.5" X 3.5" X-Over Sub 13,335' Baker Locator sub 13,357' Baker 80-40 Seal assy (2.86 ID) 13,358' 4.5" X 3.5" X-Over Sub (2.ss2 ID) 13,372' 7 5/8" X 5 1/2" Liner: Baker ZXP Packer Baker HMC Liner Hanger Perfs SPF MD TVD 6 13847' - 13860' 7160' - 7172' 6 13866' - 13879' 7178` - 7191 ` 6 13887` - 13920' 7198' - 7230' 2 7/8" HSD, 38C CP Big Hole I Est. tap of fill @ 13,926' from Noes RWO / 7 5/8 "Float Collar 13,417' I ` 7 5/8" Weatherford Float Shoe 13,541 ` ~ 5 1/2 "Baker Insert Float Collar 13,737' 5 1/2 "Baker Float Collar 13,779' 5 1/2" Baker Float Shoe 13,782` 14,123` 14,155' 14,189' . 3.5" Baker Landing Collar 3.5" HES Float Collar 3.5" HES Float Shoe DATE REV. BY COMMENTS 7/21/05 Lee Hulme Drilled & Completed Doyon - 14 9/28/05 MDO FCO/ESP Completion DOYON - 14 6/12/06 MOR FCO/ESP Completion Nabors 4es 6/20/06 MDO RWO 4-ES / 3-S ESP Completion MILNE POINT UNIT WELL MPF-93 API NO: 50-029-23266-00' BP EXPLORATION UNDER THIS PAGE F:\LaserFiche\CvrPgs_InsertslMicrofiim_Marker.dc~c ~a ~~ ~~~~ DATA SUBMITTAL COMPLIANCE REPORT 10/29/2007 Permit to Drill 2050870 Well Name/No. MiLNE PT UNIT KR F-93 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23266-00-00 MD 14183 TVD 7482 Completion Date 9/29/2005 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes `~ DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, IFR/CASANDRA, RES, PW D, GURO (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D Asc Directional Survey 0 14183 Open 9/7/2005 IIFR D D Asc Directional Survey 0 14183 Open 9/7/2005 MWD ~' g Pressure 1 Blu 1 13887 13887 5/8/2006 Bottom Hole Pressure , Survey 4 Hour Shut In 23- Jul-05 "R pt 13928 LIS Verification 1-5 73 14183 6/8/2006 LIS 17-May-2006 // ~P~D D Lis 13928 'induction/Resistivity 1-5 73 14183 6/8/2006 GR EWR4 ROP PWD ' Geopilot ,~.. r-VED C Lis 15050VLrtduction/Resistivity 73 14134 Open 4/20/2007 LIS Veri, GR, ROP, FET w/Graphics EMF, PDF i Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFOR~ON - Well Cored? / N Daily History Received? Y / Chips Received? ~_ Formation Tops N Analysis Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 10/29/2007 Permit to Drill 2050870 Well Name/No. MILNE PT UNIT KR F-93 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23266-00-00 MD 14183 ND 7482 ompletion Date 9/29/2005 Completion Status 1-OIL Current Status 1-OI L UIC N Compliance Reviewed By: _ _ Date ___ _ ~ /) WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: MPF-93, April 18, 2007 AK-MW-3782167 MPF-93: Digital Log Images: 50-029-23266-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RET[JRNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO TAE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petro-technical Data Center LR2-1 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Ala.99518 Anchorage, Alaska 99508 . _ =~ ~ ~ ~ ''S Jj`E `i'7 Signed: Date: . z ,.a -~~~~l ~'~'. .._ _ -- aim ~.r+azr~ _= c~0 J ~ b~~ ~ ~S~S d RECEIVED STATE OF ALASKA A~ OIL AND GAS CONSERVATION COM~ION JUL 1 9 20016 REPORT OF SUNDRY WELL OPERATION~ska Oil & Gas Cons. Commission 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change-Out ESP ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 205-087 ' 3. Address: ^ Stratigraphic ^ Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23266-00-00 - 7. KB Elevation (ft): 45 07' 9. Well Name and Number: . MPF-93 8. Property Designation: ~sFa~a LL~ ~ /' 2 ~'~ 10. Field /Pool(s): 7 ~ ADL 35 Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 14183 feet true vertical 7482 ~ feet Plugs (measured) None Effective depth: measured 14150 feet Junk (measured) None true vertical 7451 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 113' 113' 1530 520 Surface 7890' 10-3/4" 7925' 4259' 5210 2480 Intermediate Production 13509' 7-5/8" 13541' 6868' 8160 7020 Liner 365' S-1/2" 13417' - 13782' 6750' - 7098' 7740 6280 Liner 861' 3-1/2" 13322' - 14183' 6659' - 7482' 10160 10530 Perforation Depth MD (ft): 13847' - 13920' Perforation Depth TVD (ft): 7160' - 7230' 2-7/8", 6.5# L-80 12082' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): S BFL AUG 0 9100E Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 1250 0 Subsequent to operation: 191 196 583 440 356 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after proposed work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after proposed work: ® Well Schematic Diagram ®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: Contact David Reem, 564-5743 Printed Name Sondra Stewman Title Technical Assistant Prepared By Name/Number: Si nature Phone 564-4750 Date ~- ~1-© Sondra Stewman 564-4750 Form 10-404 Revised 0412006 ~ ~ ~ (~ ~ Sub Original Only TREE: 2-9116" - 5M FMC WELLHEAD: 11" x 2-9/16" 5M hase 1 Tub Hgr. 11"x 2-9116" TC-If T& 2.5" CIW-H BPVT Conductor 112' KOP @ 250' Angle passes 50° @ 2350' Max Angle in Tbg = 71° @ 8800` Angle thru liner = 18° 10 314" 45.5# L-80 BTC Csg. 7,g25' Orig. v. = 45.07 Doyon 14 Orig. v. = 30.00 Doyon 14 ~amco 2-718" x 1" KBMG-2 139` Gamco 2-718" x 1" KBMG-2 3,218' Cameo 2-718" x 1" KBMG-2 HES XN-Nipple {2.25" id) Model GPMTAR 1:1 Pump 74 stg. GG3500 82 stg. GC3500 12,010` 19 stg. GC8200 Tandem Intake -Gas Separator 12,034' GSTHVEVXH6 Tandem Sea{ Section, GS63DBFERHLH6SSCV SBISBPFSA GSB3DBFERHLH6SSCVS8ISBPFSA 12,040' 7 5/8" X 3 1/2" Liner: Baker Tie back Sleeve Baker ZXP Packer 80-40 Seal Bore Ext. Top 80-40 Seal Bore Ext. Bottom 7 5/8" X 5 1/2" Liner: Baker ZXP Packer Baker HMC Liner Hanger Perfs SPF MD ND 6 13847` - 13860' 7160' - 7172` 6 13866' - 13879' 7178' - 7191' 6 13887` - 13920' 7198` - 7230` 2 7/8" HSD, 38C CP Big Hole Est, top of fill @ 13,926' from Noes RWO / Motor, 266 HP KMH 2345 volt ! 69 amp, 12,054` Re-Rated Motor, 225 HP KME-1 2190 volt / 59 amp, Pump Mate Sensor 12,082` w/6 fin centralizer 4.5" X 3.5" X-Over Sub 13,335` Baker Locator sub 13,357` Baker 80-40 Seal asst' (2.86 ID} 13,358` 4.5" X 3.5" X-Over Sub (2.992 ID) 13,372' 7 5/8 "Float Collar 11, 826' 11,967' 13,417' ~` 7 518" Weatherford Float Shoe 13,541' ~' 5 1/2 "Baker Insert Float Collar 13,737' 5 1 /2 "Baker Float Collar 13,779' 5 1I2" Baker Float Shoe 13,782' _ 3.5" Baker Landing Collar 14,123` 3.5" HES Float Collar 14,155` ~ 3.5" HES Float Shoe 14,189' DATE REV. BY COMMENTS 7/21!05 Lee Hulme Drilled & Completed Doyon - 14 9/28/05 MDO FCO/ESP Completion DOYON - 14 6/12/06 MOR FCO/ESP Completion Nabors 4es 6/20/06 MDO RWO 4-ES / 3-S ESP Completion MILNE POINT UNIT WELL MPF'-93 API NO: 50-029-23266-00 BP EXPLORATION BP EXPLORATION Page 1 of 3 Operations Summary Report Legal Well Name: MPF-93 Common Well Name: MPF-93 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 4ES ~ ~ i Date .From - To ~ Hours Task Code ~ NPT - ~- _ _~ 6/7/2006 00:00 - 17:30 17.50 MOB P 17:30 - 18:30 1.00 MOB P 18:30 - 20:00 1.50 MOB P 20:00 - 23:00 3.00 MOB P 23:00 - 23:30 I 0.501 KILL I P 23:30 - 00:00 I 0.501 KILL I P 6/8/2006 ~ 00:00 - 04:00 ~ 4.00 ~ KILL ~ P 04:00 - 06:00 I 2.00 I KILL I P 06:00 - 09:30 I 3.501 KILL I P 09:30 - 18:00 I 8.501 KILL I N I WAIT 18:00 - 22:00 I 4.001 KILL I P 22:00 - 00:00 I 2.001 KILL I P 6/9/2006 00:00 - 01:00 1.00 WHSUR P 01:00 - 02:00 1.00 WHSUR P 02:00 - 03:30 1.50 BOPSU P 03:30 - 06:00 2.50 BOPSU P 06:00 - 08:30 2.50 BOPSUF~ P 08:30 - 09:30 1.00 PULL P 09:30 - 10:30 1.00 W HSUR P 10:30-11:30 ~ 1.OO~WHSUR~P 11:30 - 12:00 I 0.501 PULL ~ P 12:00 - 15:30 I 3.501 PULL I P 15:30 - 16:00 0.50 PULL P 16:00 - 17:00 1.00 PULL P 17:00 - 21:00 I 4.001 PULL I N I WAIT Spud Date: 6/23/2005 Start: 6/6/2006 End: 6/12/2006 I Rig Release: 6/12/2006 Rig Number: 4ES Phase Description of Operations DECOMP Move Rig from GPBU to MPU F-pad. Berm and spot rig over well MPU F-93. Raise derrick and connect all services lines. DECOMP Conduct Well-site assessment with MPU F-pad Operations Team. Held ATP meeting with MPU Team and Rig Crews. DECOMP Scope Derrick, Level rig, Rig up floor. DECOMP Spot bleed tank, rig up circulating lines from tree to bleed tank. Take on heated seawater in pits. PT surface lines to 3,500 psi, OK.Rig up hi-pressure lubricator on tree. Pull BPV. Tbg pressure 1,300 psi. Lay down hi-pressure lubricator. DECOMP Held PJSM with rig crew on well killing and circulating operations. DECOMP Open well to bleed tank. Circulate well thru choke manifold at 3 bpm 1,650 psi taking returns to bleed tank. DECOMP Circulate 90 bbls seawater, clear tbg. Bullhead 37 bbls seawater to perfs. Circulate total 735 bbls seawater, observed clean returns at surface. Shut down. Close in well. SITP = 800 psi. DECOMP MI Mudplant mixing 11.OOppg KWB. Haul crude returns from bleed tank to MPU ORT. DECOMP First load of 11.0 Ib/gal arrives on location. Begin non-planned time waiting on the remaining Brine to be mixed and delivered. DECOMP Mi Mud Plant mixing 11.0 ppg KWB. Monitor well. SITP = 800 psi. Service rig. Take on KW B to pits. DECOMP Open well. Start circulating 11 ppg KWB down tubing taking returns thru choke manifild to bleed tank. Circulating rate 3.5 bpm at 1,400 psi. Observed 11 ppg KWB to surface after pumping 694 bbls. DECOMP Monitor well. Rig up jumper hose. U-tube well. No flow observed. Well stable. DECOMP Set and test TWC. Drain tree and circulating lines. DECOMP N/D Tree and adapter flange. Install cap on ESP penetrator. DECOMP N/U DSA, Test Spool, BOPE. DECOMP Test BOPE, 250/3,500 psi. AOGCC PI John Crisp waived witnessing BOP test. DECOMP Completed BOPE test. Rig-down test equipment. DECOMP Hang ESP sheave. Hang elephant trunk hose. Spot ESP Spooling Unit. DECOMP Pick-up lubricator and extention. Pull TWC. (Well on slight vacuum). Lay down same. DECOMP Pick-up Landing Joint. BOLDS. Pull Tubing Hanger to floor at 85K with no problems. DECOMP Pre-job safety and operations meeting with Crew just rotating back from days-off. DECOMP Start TOH with 2 7/8" Tubing and ESP Completion. Stop to change ESP Cable Reels. DECOMP Change Reels. DECOMP Resume pulling 2 7/8" ESP Completion. Have 91 stands pulled. Only have 33 bbls of Brine left in Pits. Additional Brine that was ordered at 09:00 hrs but due to Vac Truck shortage still has not arrived. Stop Operations and leave remaining Tubing in hole for possiple "kiN-string" until Brine arrives on location. DECOMP Wait on delivery of 11 ppg KWB from MI Mud Plant. Load 200 Printed: 6720/2006 12:16:34 PM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date j From - To 6/9/2006 117:00 - 21:00 21:00 - 00:00 6/10/2006 00:00 - 02:00 02:00 - 03:00 03:00 - 03:15 03:15 - 06:00 06:00 - 11:00 11:00 - 13:30 13:30 - 22:00 22:00 - 00:00 MPF-93 MPF-93 WORKOVER NABOBS ALAS KA DRILLING NABOBS 4ES Hours ' Task Code NPT - ~- i ` WAIT I 3.00 PULL P 2.00 PULL P 1.00 PULL P 0.25 CLEAN P 2.75 CLEAN P 5.00 CLEAN P 2.501 CLEAN I P 8.50 ~ CLEAN ~ N 2.001 CLEAN I P CLEAN 6/11/2006 00:00 - 04:00 4.00 CLEAN P CLEAN 04:00 - 05:00 1.00 CLEAN P CLEAN 05:00 - 06:00 1.00 BUNCO P RUNCMP 06:00 - 06:30 0.50 RUNCO~ RUNCMP 06:30 - 09:00 2.50 BUNCO P RUNCMP 09:00 - 12:00 3.00 BUNCO P RUNCMP 12:00 - 13:00 1.00 BUNCO P RUNCMP 13:00 - 13:30 0.50 BUNCO RUNCMP 13:30 - 14:00 0.50 BUNCO P RUNCMP 14:00 - 15:00 1.00 BUNCO P RUNCMP 15:00 - 19:00 4.00 BUNCO RUNCMP 19:00 - 22:30 3.50 BUNCO P RUNCMP 22:30 - 23:00 0.50 BUNCO RUNCMP 23:00 - 00:00 1.00 BUNCO P RUNCMP 6/12/2006 00:00 - 01:30 1.50 BUNCO P RUNCMP 01:30 - 03:00 1.50 BOPSU P WHDTRE 03:00 - 03:30 0.50 WHSUR P WHDTRE 03:30 - 04:00 0.50 WHSUR P WHDTRE 04:00 - 06:00 2.00 RIGD P PRE Paga 2 of 3 Spud Date: 6/23/2005 Start: 6/6/2006 End: 6/12/2006 Rig Release: 6/12/2006 Rig Number: 4ES Phase i Description of Operations DECOMP DECOMP DECOMP DECOMP CLEAN CLEAN CLEAN CLEAN WAIT CLEAN bbls 11 ppg KWB into pits. Resume pulling 2 7/8" ESP Completion. Rack tubing in derrick. Recovered K!O Tool. Total fluid {ost last 24 hrs. = 91 bbls. Avg fluid loss rate at 8 bbls per hour. POH with 2-7/8" ESP completion, Rack back tubing in derrick. Break out and lay down ESP assembly. Rig down ESP spooling unit, Remove cable sheave from derrick. Rig down elephant trunk. Set wear ring in wellhead. M/U 2-1/16" mule shoe. P/U & M/U 36 jts 2-1/16" CS hydril work string. RIH. Continue to Trip in with 2 7/8" tubing from the Derrick (414 Jts). Tag top of Carb-O-Cite at 13,881'. (bottom set of Perforations 13,887' - 13,920' are covered). Wash down to 13,926' (6 ft below bottom Perforation) at 3.0 bpm/1300 psi. Reverse circulate at 4.0 bpm/700 psi with 50 return losses. Reduced reverse circulating rate to 3.0 bpm/625 psi. Return losses continue at 40 - 60%. Finally got Carb-O-Cite returns to surface. Cleaned up Well with a total of -156 bbls loss. Discussed plan forward with MPU and Anchorage. Due to the cost per barrel of 11.0 Brine is was agreed by all to abort any further attempt to continue the clean-out. Pulled 26 Joints. Leave Tubing hang fora "kill-string". Begin waiting on equipment. ESP Spooler, handling equipment, and Centralift personel tied-up on Rig 3s pulling thier ESP completion. POH with 2.875" EUE 8rd tubing. Rack back in derrick. ESP spooler arrived on location from Nabors Rig 3S. POH with 2.875" Tubing rack back in derrick. POH, Lay down 36 joints 2.065" 3.25ppf CS Hydril clean out work string. Pull wear ring. Rig up to run ESP completion. Hang 42" sheave in derrick. Rig up ESP spooler to rig floor. Lub Rig. Inspect Derrick. Pick-up and service new ESP Assembly. Attach ESP cable to Motor. Check cable. Good. Run ESP completion on 2-7/8" tubing. Run pipe out of derrick. Repair bad spot in ESP cable armor. Run ESP completion on 2-7(8" tubing. Run pipe out of derrick. Repair bad spot in ESP cable armor. Run ESP completion on 2-7/8" tubing. Run pipe out of derrick. C/0 ESP cable reel in spooler. Make reel to ree{ slice in ESP cable. Run ESP completion on 2-7/8" tubing. Run pipe out of derrick. M/U landing joint and tubing hanger. Cut ESP cable. Splice ESP cable to tubing hanger. Install cap on penetrator. Land tubing. RILDS. Install and test TWC. N/D BOPE N/U Adapter flange, Test ESP penetrator. OK. N/U tree. Test to 5,000 psi. Pull TWC, Set BPV. Released Rig at 06:00 hrs. Prepare for Rig Move to L-20. Printed: 6/20/2006 12:16:34 PM Printed: 6/20/2006 12:16:34 PM BP EXPLORATION Operations Summary Report Legal Well Name: MPF-93 Common Well Name: MPF-93 Event Name: WORKOVER Start: 6/18/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/21/2006 Rig Name: NABOBS 3S Rig Number: N3S Date From - To ~ Hours ,I Task ~ Code I NPT Phase --- - -- _ - _- _l - - -. 6/18/2006 ~ 00:00 - 13:30 ~ 13.50 ~ MOB P ~ ~ PRE 13:30 - 16:30 3.00 RIGU P 16:30 - 17:00 0.50 RIGU P 17:00 - 21:00 4.00 RIGU P 21:00 - 23:00 2.00 WHSUR P 23:00 - 00:00 6/19/2006 100:00 - 00:30 00:30 - 02:45 1.00 KILL P 0.50 KILL P 2.25 KILL P 02:45 - 04:00 04:00 - 05:00 05:00 - 05:30 05:30 - 06:00 06:00 - 07:00 07:00 - 13:00 13:00 - 14:00 14:00 - 16:30 1.25 KILL P 1.00 KILL P 0.50 KILL P 0.50 KILL P 1.00 WHSUR P 6.00 WHSUR P 1.00 WHSUR P 2.50 WHSUR P DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP Page 1 of 2 Spud Date: 6/23/2005 End: Description of Operations De-Mob and move rig from MPC-24 to MPF-93. Only one PEAK Sow to move three loads which require Sow to move. Have to round trip to move all three. Rig on location. Lay Herculite and position carrier over well. Spot up and position rig. Turnbuckle on center port side jack of main carrier snapped. Removed and took to 4 ES shop to repair. Continue spotting Pit Module and Pipe Shed. Move in and spot Camp, Shop, and auxilliary equipment. PJSM re: Raising the Derrick. Raise Derrick, continue to RU. Notify AOGCC about impending ROPE test. Test witness waived by John Spaulding. Continue rig up .Start laying lines for Kill. Well services rigging up to pull BPV. Rig up inner annulus to choke manifold. Test line from choke to tank at 100 psi. Pull BPV and accept rig at 21:00. PJSM. Continue rig up. Spot brine trucks and rig up Little Red to tubing. PJSM for testing lines and killing well. Test lines to 3500 psi. (SITP = 1000psi, ISIAP = 500 psi. ISIOAP = 0 psi. Pressute kill line to 1000 psi and open tubing valve. Open choke and had very short vent of gas then fluid to tank with no gas .Start displacement and pump 75 bbl of 10.9 ppg Naar at 900 psi taking returns to tank with 500 psi on choke. Closed choke and flushed rat hole to formation. Bullheaded with 20 bbl clean 10.9 ppg Naar followed by 30 bbl recycled 10.9 ppg Naar at 2 bpm and 650 psi. Shut down and recorded SITP = 0 psi and SICP = 350 psi Opened choke and resumed displacement with recycled 10.9 ppg Naar. Held backpressure at 350 psi and brought rate to 3 bpm and 800 psi tubing pressure with full returns. Pumped at 3 bpm and 750 psi while following casing pressure schedule. Pumped 350 bll with full returns until final casing pressure was 240 psi at 3 bpm. Returns were 8.4 ppg water with a trace of oil. Shut down to empty returns tank. Pulled 290 bbl from returns tank in Vac truck for disposal. SICP = 260 psi. SITP = 0 psi. Resume pumping at 3 bpm with 800 psi tubing pressure and following casing pressure schedule. Pumped additional 190 bbl. 10.9 ppg brine (total of 540 bbl since bullhead) until final casing pressure of 60 psi and 800 psi tubing pressure. Final returns MW were 10.8 heavy. Shutdown and monitor well. SITP = 0 psi, SICP = 0 psi. Pumped total of 665 bbl brine. Recovered 610 bbl mixed water and freeze protect fluid. Monitor well and prepare to set TWC. Transfer remaining 111 bbl 10.9 ppg brine from trucks to rig pits. Rig down pump truck and RU to set TWC. Set TWC w/ Lubricator, Test to 2500 psi. Bleed Hgr packoff ports, ND Tree. PJSM re: NU 11" BOPE. NU SOPE. Call AOGCC for BOPS test. John Spaulding waived State Witness of test. SIMOPS w/ Nabors Rig 4ES re: venting of gas as they circulate well KiII on MPF-22. Continue NU BOPE. Connect Koomey unit and function test BOPE. Fill stack and check for leaks. Printed: 6/26/2006 7:12:31 AM BP EXPLORATfON Operations Summary Report Page 2 of 2 Legal Well Name: MPF-93 Common Well Name: MPF-93 Spud Date: 6/23/2005 Event Name: WORKOVER Start: 6/18/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6!21/2006 Rig Name: NABOBS 3S Rig Number: N3S I Date !From - To - -- - - ~- - 6/19/2006 16:30 - 21:30 21:30 - 23:00 23:00 - 23:30 23:30 - 00:00 6/20/2006 00:00 - 00:30 00:30 - 01:30 01:30 - 02:00 02:00 - 06:00 06:00 - 08:30 08:30 - 11:30 11:30 - 14:30 14:30 - 15:30 15:30 - 16:30 Hours I Task I Code I NPT 5.00 WHSUR P 1.50 WHSUR P 0.50 PULL P 0.50 PULL P 0.50 PULL P 1.00 PULL P 0.50 PULL P 4.00 PULL P 2.50 PULL P 3.00 BUNCO 3.00 BUNCO 1.00 BUNCO SFAL 1.00 BUNCO 16:30 - 21:00 4.50 22:00 - 00:00 2.00 Description of Operations Phase It - _- - - -- - - -- - - -- DECOMP Begin testing BOPE. Test all rams, valves amd chokes to 250 psi low / 3500 psi high. Test annular to 3500 psi. Perform accumulator drawdown test. RD BOP test lines. drain stack and blowdown choke manifold. DECOMP RU lubricator and Opso Lopso. Check annulus and confirmed well on vacuum. Pulled TWC. RD lubricator and Opso Lopso. DECOMP PJSM then rig ESP elephant trunk to Cable sheave. DECOMP MU tubing landing joint and TIW Valve. PJSM for unlanding tubing. DECOMP Plck up tubing hanger from landing spool. Started lifting at 60 K#. Pulled steadily at 92K#. Pulled to floor and filled hole. Took 34 bbl to fill and had slight flowback from tubing. DECOMP Disconnected and tested ESP cable. Layed down landing joint, tubing hanger, tubing pup and first full joint of tubing. DECOMP Monitored loss and confirmed 24 bph loss rate. Filled hole and had slight flowback from tubing. Mixed and pumped 10 bbl 11.5 ppg Naar slug. DECOMP Ordered 200 bbl 10.9 ppg brine from mud plant. Pull and stand back first stand. LD first GLM. POH with stands, spooling GLM cable. Pumping 2 bbl to hole, double calculated displacement, every 5 stands. Pulled 50 stands to second GLM. DECOMP POH laying down singles of 2 7!8" tubing. Fill hole with 13 bbls of 10.9 #/gaf Brine. Lay down total of 40 joints ~ avg of 31.09' (total layed down of 1244'). RUNCMP RBIH w/middle GLM and Tubing out of Derrick. Lay down 2 bad joints of Tbg. PU additional 1 joint of tubing below top GLM. RUNCMP PUMU Landing joint, Tbg hanger w/ TWC. MU to completion string. MU Centrilift connector. Unable to make up back threaded connection on connector (with Teflon compression ring). Call for new one to change out same. Lay down elephant trunk and release spooler to 4 ES. RUNCMP Install new connector to Centrilift cable. RUNCMP PU wt of 77K #'s, SO wt of 32K #'s, Final checks on ESP and Phoenix gauge. 3222 psi, i 28 def F, 4.0 balanced phase to phase, 450 KM phase to ground. RIH on landing joint. Land and RILDS. Test TWC to 2500 psi, OK. RUNCMP ND BOPE RUNCMP NU Tree. Test tubing head adapter and tree to 5000 psi. Final checks on ESP cable and sensor - OK. Set BPV w/ lubricator. Rig Released @ 12:00 midnight. Printed: 6!26/2006 7:12:31 AM • WELL LOG TRANSMITTAL • To: State of Alaska May 17, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPF-93, AK-MW-3782167 1 LIS formatted Disc with verification listing. API#: 50-029-23266-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 C~'~~;~1~tCB ,1UN u 8 2(lOG flil &Gass Cons. Gonunission And BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Signed: ~~ 205 -u~"~- ~ i3ga ~ ~o~ =a ~ ~- 05/05/06 Sc~tnm~erger NO. 3789 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambelt Street, Suite a0o ~, Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Helen Warman ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Lo Descri tion Date BL Color CD MPB-50 10980545 MULTI-FINGER CALIPER 04!19!05 1 MPB-50 10980546 WFL 04/20!05 1 MPF-93 N!A BHP SURVEY ;j - 07/23/05 1 MPJ-18 10987542 USIT 08!16/05 1 MPB-50 NIA USIT 03/08/05 1 Alaska Data 8 Consulting Services Petrotechnical Data Center LR2-1 2525 Gambelt Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503-2838 Anchorage, Alaska 99508 ATTN: Beth rlt' i `~; ; t,~ c~;t(~ ~ REGEIVEC t ~ _ ~ STATE OF ALASKA ~ JAN 0 3 2006 ALASKA OIL AND GAS CONSERVATION COM(~ION WELL COMPLETION OR RECOMPLETION REPORT AND LO~aska Oil &eAG,,,,as Gons. Gornmissior Revision 12/31/v9~~t~l~roduction 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 2oAAC 2s.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other ib. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 9/29/2005 12. Permit to Drill Number 205-087 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 6/23/2005 13. API Number 50-029-23266-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 7/15/2005 14. Well Name and Number: M PF-93 2260 FSL, 2818 FEL, SEC. 06, T13N, R10E, UM Top of Productive Horizon: 2364' FSL, 4375' FEL, SEC. 30, T14N, R10E, UM g, KB Elevation (ft): 45.07' 15. Field /Pool(s): Milne Point Unit / Kuparuk River Sands Total Depth: 2458' FSL, 4365' FEL, SEC. 30, T14N, R10E, UM 9. Plug Back Depth (MD+TVD) 14150 + 7451 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 541743 y- 6035711 ASP4 Zone- 10. Total Depth (MD+TVD) 14183 + 7482 Ft 16. Property Designation: ADL 355017 _ _ TPI: x- 540084 y- 6046365 Zone- ASP4 Total Depth: x- 540093 Y- 6046459 Zone- ASP4 11 • Depth where SSSV set N/A MD 17. Land Use Permit: -"--"---- --"---- ----1-------- -`--------- ff Thi k f P f t 20 18. Directional Survey ^ Yes ®No shore 19. Water depth, if o N/A MSL ness o erma ros . c 1800' (Approx.) 21. Logs Run: MWD , GR , IFR/CASANDRA , RES , PWD ,GYRO 2. CASING, LINER AND EMENTING RECORD CASING Er1'tNG EPTH MD ETTINCa EPTH 7VD HOLE MOUNT $IZE WT. PER FT.' GRADE OP TTOM OP TTOM `.SIZE CEMENTING RECORD PULLED 20" 94# H-40 35' 113' 35' 113' 42" 60 sx Arctic Set A rox. 10-3/4" 45.5# L-80 35' 7925' 35' 4259' 13-1/2" 90 sx AS Lite, 919 sx Class 'G' 7-5/8" 29.7# L-80 32' 13541' 32' 6868' 9-7/8" 54 sx Class 'G' 5-1/2" 17# L-80 13417' 13782' 6750' 7098' 6-3/4" 62 sx Class'G' 3-1/2" 9.2# L-80 13322' 14183' 6659' 7482' 6-3/4" 94 sx Class'G' 23. Perforations open to Produc tion (MD + TV D of Top and " " 24; TuswG RECOaq Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-i/2" Gun Diameter, 6 SPF 2-7/8", 6.5#, L-80 13290' MD TVD MD TVD 13847 - 13860' 7160' - 7172' 25. ACID, FRACTURE,sCEMENT'SQUEEZE, ETG, 13866' - 13$79' 7178' - 7191' 13887 1 92 ' 71 72 8' 0' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED - 3 0 9 - 3 13847' - 13920' Fractured A Sands with 178000 #'s 16/20 Carbolite placed 120000 #'s behind pipe, 58000 in Casing Freeze Protected with 96 Bbls of Diesel 26. PRODUCTION TEST Date First Production: November 7, 2005 Method of Operation (Flowing, Gas Lift, etc.): Electric Submersible Pump Date of Test 12/10/2005 Hours Tested 6 PRODUCTION FOR TEST PERIOD AIL-BBL 242.26 GAS-MCF 571.95 WATER-BBL 476.23 CHOKE SIZE GAS-~IL RATIO 2360.89 Flow Tubing Press. 33 Casing Pressure 300 CALCULATeD 24-HOUR RATE OIL-BBL 969 GAS-MCF 2287.8 WATER-BBL 1904.91 OIL GRAVITY-API (CORK) 2360.89 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". None e5 ~~~.,. I n al ~. ?OQG Form 10-407 Revised 12/2003 O ^ ~ (~ ~ ~q~rlr~uED ON REVERSE SIDE r~ 28. GEOLOGIC MARKERS 29' -ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". TUZC 5838' 3485' None TNA 7326' 4035' TOA 7772' 4206' Top of Colville 8569' 4466' TKUD 13644' 6966' LCU(fKUB i 3810' 7i 25' TKUA 13842' 7155' TKA3 13849' 7162' TKA2 13865' 7177' TKA1 13887 7198' TMLV 13944' 7253' 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondra S m Title Technical Assistant Date ~ ~, - (-~, MPF-93 205-087 Prepared By Name/Number.• Sondra Stewman, 564-4750 Well Number Permit No. / A royal No. Drilling Engineer: Skip Coyner, 564-4395 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. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Satt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a welt producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing 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 interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None°. Form 10-407 Revised 12/2003 Submit Original Only STATE OF ALASKA ALASKA IL AND GAS CONSERVATION COMNi~3~lON WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~f NDV ~ z Kati Alaska Oil & Gaa Gana Cott~mi~~111 linrhare8e 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 1b. Well Class: 2oAAC2s.~os 20AAC25.110 ®Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other ^ Stratigraphic ^ Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 9/29/2005 ~ 205-087 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 6/23/2005 ' S0-029-23266-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: ' ' 7/15/2005 MPF-93 2260 FSL, 2818 FEL, SEC. 06, T13N, R10E, UM 8. KB Elevation (ft): 15. Field /Pool(s): Top of Productive Horizon: 2364' FSL 4375' FEL SEC 30 T14N R10E UM 45.07' Milne Point Unit / Kuparuk River , , , , , . Sands Total Depth: 9. Plug Back Depth (MD+TVD) 2458' FSL, 4365' FEL, SEC. 30, T14N, R10E, UM 14150 + 7451 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD)~~ Z ass 16. Property Designation: Surface: x- 541743 ~' y- 6035711 ~` Zone- ASP4 ~ 14183 + j~lE3c "` a Ft ADL 355017 TPI: x- 540084 y- 6046365 Zone- ASP4 11 • Depth where SSSV set 17. Land Use Permit: Total Depth: x- 540093 y- 6046459 Zone- ASP4 N/A MD ' --------~-------- --~--------------- --------------- f 19. Water depth, if offshore rost 20. Thickness of Perma 18. Directional Survey ®Yes ^ No N/A MSL 1800 (Approx.) 21. Logs Run: MWD , GR , IFR/CASANDRA , RES , PWD ,GYRO 2. CASING, LINER AND EMENTING RECORD CASING NG EPTH'MD ETTING EPTH ND HOLE MOUNT $1ZE WT. f ER FT. GRADE ' OP TTOM OP TTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 35' 113' 35' 113' 42" 60 sx Arctic Set A rox. 10-3/4" 45.5# L-80 35' 7925' 35' 4259' 13-1/2" 90 sx AS Lite, 919 sx Class 'G' 7-5/8" 29.7# L-80 32' 13541' 32' 6868' 9-7/8" 354 sx Class 'G' 5-1/2" 17# L-80 13417' 13782' 6750' 7098' 6-3/4" 2 sx Class 'G' 3-1/2" 9.2# L-80 13322' 14183' 6659' 7482' 6-314" 94 sx Class'G' 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TuBIIVG RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 6 SPF 2-7/8", 6.5#, L-80 13290' MD TVD MD TVD 13847 - 13860' 7160' - 7172' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 13866' - 13879' 7178' - 7191' 13887 13920' 7198' 7230' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED - - 13847' - 13920' Fractured A Sands with 178000 #'s 16!20 Carbolite placed 120000 #'s behind pipe, 58000 in Casing Freeze Protected with 96 Bbls of Diesel 26• PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED E ~ll-$BL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) PreSS. 24-HOUR RAT 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". None FZBI~MS ~F~ NQV $ ~ 1005 ti:_.., :. ~aJ Form 10-407 Revised 12/2dQ~ ~ ~ ~ -••~ I ~~ ~ ~ONTINUED ON REVERSE SIDE r 28. GEOLOGIC MARKERS 29' -ORMATION TESTS Inc-ude and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". TUZC 5838' 3485' None TNA 7326' 4035' TOA 7772' 4206' Top of Colville 8569' 4466' TKUD 13644' 6966' LCUlTKUB 13810` 7125' TKUA 13842' 7155' TKA3 13849' 7162' TKA2 13865' 7177' TKAi 13887 7198' TMLV 13944' 7253' 30. List of Attachments: Summary of Daily Drilling Reports, We11 Schematic Diagram, Surveys, Post Rig Summary and aLeak-Off Test Summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si ned ~, g Sondra ~ewman ~ ,~~"s z~ ' ~ - :' ~_Title Technica{ Assistant Date , - ~ ~ ' ~, MPF-93 205-087 Prepared By NameMumber: Sondra Stewman, 564-4750 Well Number Permit No. / A royal No. Drilling Engineer: Skip Coyner, 564-4395 (NSTRUCT{ONS GeNeaAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). ITEM 8: The Kefly 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 APf 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 interval to be separately produced, showing the data pertinent to such interval). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-fn, 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 Submit Original Only TREE: 2-9/16" - 5M FMC WELLHEAD: 11" x 2-9/16" 5M , ase 1 Tub Hgr. 11" x 2-9116" TC-II T&B 2i5" CIW-H BPVT Conductor 112' KOP @ 250` Angle passes 50° @ 2350` Max Angle in Tbg = 71 ° @ 8800` Angle thru liner = 18° 10 3/4" 45.5# L-80 BTC Csg. 7,925' 2.875" 6.5#/ft, L-80 8rd. EUE (Drift Id = 2.347" cap. = 0.00579 bpf) 3.5" 9.2 #/ft L-80 IBT-M (Drift id = 2.867" cap = .0087 bpf) 7 5/8 " 29.7 ppf, L-80, BTC-Mod casing (drift ID = 6.75" cap. = 0.0459 bpf ) (cap wt 4 1/2" tbg inside = 0.0262 bpf) -A~~r Ori9: v. = 45.07 Doyon 1a y Ofl V. = 30.00 Doyon 14 ~, ~ ( (Camco 2-718" x 1" KBMG-2 149` I ~ Camco 2-7/8" x 1" KBMG-2 3,165' Camco 2-718" x 1" KBMG-2 13,073` I HES XN-Nipple (2.205" id) 13,163` 4.i~ KOT tool lost 10/18/05 (Top) 13,190` Pump 67 / 74 stg. GC3500 13 21 5' . , Model GPMTAR 1:1 Tandem Intake -Gas Separator 13 246` , GRSFTXAR Tandem Seal Section, 13 251` , GSB3DBUT AB/HSNPFSA GS63DBLTABIHSNPFSACLS Motor, 228 HP KMH 13 265` , 2305 volt / 60 amp, Pump Mate Sensor 13 284` ti , w/6 fin centralizer 7 5/8" X 3 1/2" Liner: 327 13 335' 13 " O S " ' Baker Tie back Sleeve , X 3.5 X- ver ub 4.5 Baker ZXP Packer 13,338' 13,357' L 80-40 Seal Bore Ext. Top 13,351 ` 80-40 Seal Bore Ext Bottom ~ ~ ocator sub Baker Baker 80-40 Seal assy (2.86 ID) 13,358' . 13,372` ' 4.5" X 3.5" X-Over Sub (2.ssz ID) 13,372` 7 5/8" X 5 1/2" Liner: Baker ZXP Packer 13,417` Baker HMC Liner Hanger 13,435` I 7 518 "Float Collar 13,417` Perfs SPF MD TVD 6 13847` - 13860' 71.60' - 7172` 6 13866` - 13879' 7178` - 7191' 6 13887` - 13920' 7198' - 7230' 2 7/8" HSD, 38C CP Big Hole 7 5/8" Weatherford Fioat Shoe 13,541 ` ~ 5 1/2 "Baker Insert Float Collar 13,737' ~ 5 112 ° Baker Float Collar 13,779` 5 112" Baker Float Shoe 13,782' i _ 3.5" Baker Landing Collar ~,411`c~ 1 3.5" HES Float Collar ~ ~ ~S(7 ~ 3.5" HES Float Shoe ~~~ ~ ~~~ DATE EV. BY COMMENTS MILNE POINT UNIT 7/21/05 Lee Hulme Drilled & Completed Doyon - 14 WELL MPF-93 9/28/05 MDO FCO/ESP Completion dOYON - 14 API NO: 50-029-23266-00 BP EXPLORATION • BP EXPLORATION Operations Summary Report Page 1 of 11 Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To MPF-93 MPF-93 DRILL+C Hours OMPLE Task TE Code PT Start Rig Rig Phase Spud Date: 6/23/2005 : 6/21/2005 End: 7/11/2005 Release: Number: Description of Operations 6/21/2005 18:00 - 19:30 1.50 MOB P PRE PJSM, Skid rig floor and prepare for moving off well 19:30 - 21:00 1.50 MOB P PRE PJSM, move rig to end of E pad 21:00 - 00:00 3.00 MOB P PRE PJSM, installing Booster wheels 6/22/2005 00:00 - 03:00 3.00 MOB P PRE PJSM, Repairing Booster wheels, 03:00 - 10:00 7.00 MOB P PRE PJSM, Moving rig to MPF-93 10:00 - 11:00 1.00 MOB P PRE PJSM, remove back booster wheels, put on cellar doors, put surface stack and mouse hole stand in to cellar area 11:00 - 12:00 1.00 MOB P PRE PJSM, Spot rig over well 12:00 - 13:00 1.00 MOB P PRE PJSM, Skid rig floor 13:00 - 14:00 1.00 RIGU P PRE PJSM, Rig up rig floor, spot rockwasher, spot tiger tank, rig accepted C~ 14:00 hrs 6/22/2005 14:00 - 17:00 3.00 RIGU P PRE PJSM, Nipple up Drilling nipple, load pipe shed with 5" pipe 17:00 - 00:00 7.00 DRILL P SURF PJSM, Picking up 5" drill pipe and standing in derrick 6/23!2005 00:00 - 03:00 3.00 DRILL P SURF PJSM, Finish picking up 5" pipe and standing in derrick 03:00 - 05:00 2.00 DRILL P SURF PJSM, Change out saver sub on top drive to 5", jaws, and bell guide 05:00 - 06:30 1.50 DRILL P SURF PJSM, Slip and cut drill line, service top drive 06:30 - 08:00 1.50 DRILL P SURF PJSM, Rig up GYRO, and bring BHA to floor 08:00 - 09:00 1.00 DRILL P SURF PJSM, Picking up BHA 09:00 - 09:30 0.50 DRILL P SURF PJSM, Fill stack and check for leaks 09:30 - 10:30 1.00 DRILL P SURF Pre Spud with Crews 10:30 - 12:00 1.50 DRILL P SURF PJSM, String High-line wire to rig., and hook up 12:00 - 12:30 0.50 DRILL P SURF Spud well. 112 to 220' 12:30 - 14:30 2.00 DRILL P SURF PJSM, stand back 5' HWDP make up MWD, UBHO sub,P/U 8" flex collars, Gyro 14:30 - 16:30 2.00 DRILL P SURF Drilling 220' to 405' with 450 gpm,1200 psi, 60 rpms, Gyro ever stand 16:30 - 18:30 2.00 DRILL N SFAL SURF PJSM, pull into conductor, repair conveyor bearing, run in hole 18:30 - 00:00 5.50 DRILL P SURF Drill 405' to 870' with 480 gpm, 1400 psi, 60 rpms Gyro ever stand ,AST 2.86, ART 4.33 6/24/2005 00:00 - 09:00 9.00 DRILL P SURF Drill 870' to 1460' with 480 gpm, 1400 psi, 60 rpms, Running Gyro to 1200 tt. 09:00 - 11:30 2.50 DRILL P SURF Circ, reaming out dog leg 8 to 5 degrees 1400 ft. 11:30 - 21:00 9.50 DRILL P SURF Drill 1460' to 2300' with 480 gpm, 1700 psi, 60 rpms, AST 8.74, ART 3.59 21:00 - 22:30 1.50 DRILL P SURF Circ, two bottoms with 480 Gpm 1700 psi, 60 rpms 22:30 - 23:30 1.00 DRILL P SURF Pumping out to HWDP with full drill rate 23:30 - 00:00 0.50 DRILL P SURF Service rig, and top drive 6/25/2005 00:00 - 00:30 0.50 DRILL P SURF PJSM, Trip to bottom, wash last stand to bottom 00:30 - 03:00 2.50 DRILL P SURF Drilling 2300' to 2580 with 500 gpm, 1800 psi, 60 rpms 03:00 - 04:30 1.50 DRILL P SURF PJSM, Pull up to 2420' reaming 6.8 degree dog leg 04:30 - 22:00 17.50 DRILL P SURF Drilling 2580 to 4466' with 550 gpm, 2100 psi, 80 rpms, AST 4.76, ART 7.7, Tq 10K 22:00 - 00:00 2.00 DRILL P SURF Circ, two bottoms up with 550 gpm 2100 psi, 80 rpms 6/26/2005 00:00 - 03:00 3.00 DRILL P SURF PJSM, Pumping out to HWDP with full drilling rate 03:00 - 04:00 1.00 DRILL P SURF PJSM, Stand back BHA, Down load MWD 04:00 - 07:30 3.50 DRILL P SURF PJSM, Pickup BHA #2, P/u bit and change motor to 1.15 degrees, pickup RES tool, surface test MWD 07:30 - 08:30 1.00 DRILL P SURF PJSM, Slip and cut drilling line, service rig and topdrive 08:30 - 10:00. i.50 DRILL P SURF PJSM, Rih, wash last stand to bottom 10:00 - 00:00 14.00 DRILL P SURF Drill 4466' to 5886' with 550 GPM, 2400 psi, 90 rpms, AST 2.39, ART 6.83, Tq 12 K 6/27/2005 00:00 - 03:30 3.50 DRILL P SURF Drill 5886' to 6260' with 550 GPM, 2400 psi, 90 rpms Printed: 7/25/2005 7:52:56 AM • BP EXPLORATION Operations Summary Report Legal Well Name: MPF-93 Common Well Name: MPF-93 Event Name: DRILL+COMPL ETE Contractor Name: Rig Name: Date I~ From - To Hours ~~~ Task ~I Code ~ NPT ~_ _! _ _- 6/27/2005 03:30 - 06:00 2.50 DRILL P 06:00 - 07:30 1.50 DRILL P 07:30 - 08:30 1.00 DRILL P 08:30 - 00:00 15.50 DRILL P 6/28/2005 00:00 - 07:30 7.50 DRILL P 07:30 - 08:00 0.50 DRILL N 08:00 - 16:00 8.001 DRILL ~ P 16:00 - 19:00 I 3.001 CASE I P 19:00 - 00:00 I 5.001 CASE I P 6/29/2005 00:00 - 02:30 2.501 CASE P 02:30 - 05:00 2.50 CASE P 05:00 - 09:30 4.50 CASE P 09:30 - 15:00 5.50 CASE P 15:00 - 17:00 2.00 CASE P 17:00 - 18:00 1.00 CASE P 18:00 - 19:00 1.00 CASE P 19:00 - 19:30 0.50 CASE P 19:30 - 00:00 4.50 CASE P 6/30/2005 100:00 - 03:30 3.501 CASE P 03:30 - 05:30 2.001 CASE P 05:30 - 06:00 0.50 CASE P 06:00 - 10:00 4.00 CASE P 10:00 - 14:30 I 4.501 CEMT I P 14:30 - 15:30 1.001 CEMT P 15:30 - 18:00 I 2.501 CEMT I P DFAL Page 2 of 11 Spud Date: 6/23/2005 Start: 6/21/2005 End: 7/11/2005 Rig Release: Rig Number: Phase ~ Description of Operations SURF Circ. two bottoms up with 550 gpm, 2400 psi, 90 rpms SURF PJSM, Pumping out to 4,300' with full drilling rate SURF PJSM, RIH wash last stand to bottom SURF Drill 6260' to 7545' with 550 GPM, 2400 psi, 100 rpm, AST 2.23, ART 10.11, Tq 15K SURF Drill 7545' to 7950' with 550 GPM, 2400 psi, 100 rpm SURF MWD not reading, pump 25 bbls H2O sweep thru Mwd trying to get MWD reading, No good, MWD failed SURF Drilling with out MWD, 7950' to 8256' TD, with 615 gpm, 2800 psi, 100 rpms SURF Circ, two bottoms up with 615 gpm 2700 psi, 100 rpms, TQ 14k, AST 1.93, ART 10.08 SURF PJSM, Pump out to 3150' with full drilling rate 615 gpms, no problems SURF PJSM, Pump out from 3150' to HWDP with full drilling rate 615 gpms, no problems SURF PJSM, Rih, washed fast stand to bottom ~ 8265' SURF.. Circ., Three botttoms up with 615 gpm, 2700 psi, 100 rpms SURF PJSM, Pump out to HWDP with full drilling rate 615 gpms, no problems SURF PJSM, stand back HWDP, laydown flex dc, MWD,Motor SURF PJSM, Clear floor, lay down Bha jewelery SURF PJSM, Rig up to run 10 3/4 csg, pickup franks tool SURF PJSM with Company rep, csg hand, crew SURF Picking up 10 3/4 L-80 45# BTC csg,to 4350' breaking Circ. every 1000 ft SURF PJSM. Picking up 10 3/4 L-80 45# BTC csg,to 7925', total of 187 jts, 186 jts below table, breaking circ. every 1000 ft, pipe was wall sticking for last 3 jts, had to pop free after make up, jt # 187 came free, we slack off 5' and it stuck again, sand C~? 7770' to 7880' shoe is ~ 7925' SURF Circ. with franks tool 7 bbls min. 600 psi, working csg Max pull 460,000, slack off to 50K, shoe @ 7925, Cementer 2504, 340 ft off bottom,( lower SB sand not cover top 8070' ) SURF PJSM, Rig down franks tool, Rig up cement head SURF Break circulation and stage pumps up to 7 bpm at 400 psi. Conditioned mud for cementing job., PJSM on cementing SURF Cement with Schlumberger, 10 bbls water, test lines 3500 psi, 20 bbls CW-100, 50 bbls mud push, mixed C~? 10.1, drop bottom plug,269.8 sx. Arctic set light, Yield 4.44, 213.3 bbls mixed C~3 10.7, Tailed 581.5 sxs Class G, Yield 1.17, 121.2 bbls mixed @ 15.8, drop top plug,Kicked out with 30 bbls water, displace with rig pumps with 482 bbls mud, 50 bbls water, 195.2 bbls mud, bump plug with 1170 psi, float held, cement was mixed and pumped 6 bbls min, displace with 7 bbls min.full return thru job, till just before bumping plug lost returns SURF PJSM, open cementer with 2550 psi, Circ with 7.5 bbls min. 220 psi, no cement or spacer to surface, full returns, PJSM on cementing SURF Cement Stage 2 with Schlumberger with 10 bbls water, test 3,500 psi, 20 bbls CW 100 with 2 gals dye, 50 bbls mud push mixed 10.1, 421 sxs. Arctic set light, yield 4.44, 333.1 bbls, mixed 10.7, tailed 338.8 sxs. Class G, 70.6 bbls, yield 1.17, Printed: 7/25!2005 7:52:56 AM • BP EXPLORATION Operations Summary Report Page 3 of 11 Legal Well Name: MPF-93 Common Well Name: MPF-93 Spud Date: 6/23/2005 Event Name: DRILL+COMPL ETE Start: 6/21/2005 End: 7/11/2005 Contractor Name: Rig Release: Rig Name: Rig Number: Date ;~ From - To Hours j Task ~ Code f NPT Phase I Description of Operations 6/30/2005 15:30 - 18:00 2.50 CEMT P SURF mixed C~ 15.8, drop closing plug. kicked out with 30 bbls water, Displace with rig pump 6 bbls min. 214 bbls mud, close cementer with 1560 psi, check to make sure cementer is close, full returns thru out job, 244 bbls of cement to surface 18:00 - 19:00 1.00 CEMT P SURF Flush stack with H2O, and flow lines 19:00 - 19:30 0.50 CASE P SURF Monitor Annulus, for 30 min.- well static, Rig down cement head 19:30 - 2i :00 1.50 CASE P SURF PJSM, Clear floor, nipple down flow line, pickup surface stack 21:00 - 22:30 1.50 CASE N DPRB SURF PJSM, Clean slip area, Pull 335k on csg, set slip with 285k on slip as per FMC, made rough cut 22:30 - 23:00 0.50 CASE N DPRB SURF PJSM, Break out Jt # 187 from cut jt of 30.00 ft. lay down both 23:00 - 00:00 1.00 CASE N DPRB SURF 7/1/2005 ~ 00:00 - 03:30 3.50 ~ CASE ~ N ~ DPRB ~ SURF 03:30 - 05:00 1.50'1 CASE N DPRB ~ SURF 05:00 - 11:00 ~ 6.00 ~ CASE ~ N ~ DPRB ~ SURF 11:00 - 12:00 I 1.001 CASE I P I I SURF 12:00 - 16:30 4.50 CASE P SURF 16:30 - 21:00 4.50 CASE P SURF 21:00 - 22:30 1.50 CASE P SURF 22:30 - 00:00 1.50 CASE P SURF 7/2/2005 100:00 - 01:30 I 1.501 CASE I P I A SURF 01:30 - 03:00 1.50 CASE P SURF 03:00 - 03:30 0.50 CASE P SURF 03:30 -04:00 0.50 CASE P SURF 04:00 - 10:00 6.00 CEMT P SURF 10:00 - 13:00 3.00 CASE P SURF 13:00 - 14:00 1.00 CASE P SURF 14:00 - 15:00 1.00 CASE P SURF 15:00 - 18:30 3.50 CEMT P SURF 18:30 - 20:00 I 1.501 CASE I P I I SURF 20:00 - 22:30 ~ 2.50 ~ CASE ~ P ~ ~ SURF PJSM, Nipple down surface riser, set back Hydrill, clean up 10 3/4 stump PJSM, Make final cut on csg, install Transition Nipple, pre heat Csg with hot head, weld on Transition Nipple, re heat with hot head, wrap for cool down PJSM,Change out bails, Check saver sub on top drive, chahge out same PJSM, Picking up 4" drill pipe in mouse hole, standing in derrick PJSM, Transition Nipple to 1600 psi for 10 min., Nipple up Starting head, test metal to metal seal 1000 psi for 10 min. PJSM, change out choke spool, Nipple up Bops, rig up to test PJSM, Test bops and manifold with 250-4000 psi, 5 min per test, Hydril 250-2500 psi 5 min. per test Chuck Scheve with AOOGC witness test. Test was witness by WSL, one failure 4" TIW would not pass 4000# test, will change out and test before drilling out. PJSM, Mobilize BHA to floor, Rig up Geo-Pilot Manifold PJSM, Making up BHA #3, bit, Geo-Pilot,Flex DC,Stab,GR/RES/PWD,Stab„HCIM,HOC,FIoat sub,3 flex DC,12 HWDP,Jars,5 Hwdp,Ghost reamer,XO PJSM, Finish picking up BHA #3, bit, Geo-Pilot,Flex DC,Stab,GR/RES/PWD,Stab„HCIM,HOC,FIoat sub,3 flex DC,12 HWDP,Jars,5 Hwdp,Ghost reamer,XO, Surface test MWD PJSM, Slip and cut Drill line, Service top drive PJSM, Trip in to 2475', Strapping 4" pipe Circ., Perform break in of Geo-pilot Drill out Halliburton Cementer C~3 2509 with 2-35K 50 rpms, 450 gals min., 1300 psi PJSM, RIH to landing collar @ 7837 Circ, Bottoms up from 7837 PJSM, Test CSG to 2000 psi for 30 min., good test Drill landing collar Float, shoe @ 7925, wash and ream to 8010, 400 gpm, 1800 psi, 80 rpms, bit acting like it was balled up or side tracked Circ, and displace hole with 60 bbls spacer and new 9.0 LSD mud, (Displace early so we could get two pumps on hole, and increase flow rate) Wash and ream old hole 8010' to 8265' with 5-10k 120 rpms, 560 gals min.2640 psi, surveys tracking old surveys Printed: 7(25/2005 7:52:56 AM • BP EXPLORATION Page 4 of 11 Operations Summary Report Legal Well Name: MPF-93 Common Well Name: MPF-93 Spud Date: 6/23/2005 Event Name: DRILL+COMPL ETE Start : 6/21/2005 End: 7/11/2005 Contractor Name: Rig Release: Rig Name: Rig Number: Date I From - To ~ Hours li Task I! Code ~ NPT Phase I! Description of Operations 7/2/2005 20:00 - 22:30 2.50 CASE P SURF reaming 100 ft per hr. 22:30 - 23:00 0.50 DRILL P INT1 Drilling 8265 to 8285 with 5-10k, 120 rpms, 560 gpm, 2640 psi, Drilling 80 ft per hr 23:00 - 00:00 1.00 DRILL P INT1 Circ. bottoms up with 560 gpm, 2640 psi, 120 rpms 7/3/2005 00:00 - 01:00 1.00 DRILL P INT1 PJSM, Pump out from 8285 to 7925' CSG shoe, Rig up for FIT test 01:00 - 01:30 0.50 DRILL P INT1 FIT, test tvd 4258, 9.0 MWT, 670 psi=12.0 EMWT, good test 01:30 - 02:00 0.50 DRILL P INT1 PJSM, RIH, wash last stand to bottom, Set Geo-Pilot parameters 02:00 - 22:00 20.00 DRILL P INTi Drill 8285' to 10717' with 160 rpms, 585 gpm 3600 psi, ECD 10.4 22:00 - 00:00 2.00 DRILL P INTi Circ, Two bottoms up with 160 rpms, 580 gpm, 3600 psi 7/4/2005 00:00 - 00:30 0.50 DRILL P INT1 Circ, Two bottoms up with 160 rpms, 580 gpm, 3600 psi 00:30 - 03:00 2.50 DRILL P INT1 PJSM, Pump out to csg shoe ~ 7925' with full drilling rate, no problems 03:00 - 04:00 1.00 DRILL P INT1 Circ, bottoms up from 7925' with 580 gpm, 3300 psi, 60 rpms 04:00 - 05:00 1.00 DRILL P INTi PJSM, RIH, wash last stand to bottom 05:00.- 16:00 11.00 DRILL P INT1 Drilling 10717 to 12030' with 160 rpms, 580 gpm, 3600 psi, ECD 10.7 (starting to see some packing off on corms.) 16:00 - 17:00 1.00 DRILL P INTi Circ, one+ bottoms up, with 3600 psi, 580 gpm, 150 rpms, (had clay balls on bottoms up) 17:00 - 18:30 1.50 DRILL P INT1 PJSM, Pump out to 10624' with full drilling rate, no problems 18:30 - 19:00 0.50 DRILL P INTi PJSM, RIH was last stand to bottom, 19:00 - 00:00 5.00 DRILL P INTi Drilling 12030' to 12780' with 150 rpms, 560 gpm, 3900 psi, TQ 17k, ECD 10.8, (with 9.6 Mwt clean hole ECD app. 10.54) 7/5/2005 00:00 - 10:00 10.00 DRILL P INT1 Drilling 12780' to 13553' - TD 7 5/8" hole - WOB 5 to 10 - 10:00 - 13:30 3.50 CASE P 13:30 - 18:30 5.00 CASE P 7/6/2005 18:30 - 20:00 20:00 - 21:30 21:30 - 00:00 00:00 - 00:30 00:30 - 04:30 04:30 - 09:30 09:30 - i 1:30 11:30 - 14:00 14:00 - 16:30 16:30 - 20:00 20:00 - 20:30 20:30 - 21:30 21:30 - 22:30 22:30 - 00:00 1.50 CASE P 1.50 CASE P 2.50 CASE P 0.50 CASE P 4.00 CASE P 5.00 CASE P 2.00 CASE P 2.50 CASE P 2.50 CASE P 3.50 CASE P 0.50 CASE P 1.00 CASE P 1.00 CASE P 1.50 CASE P RPM 150 - TO on 17K -off 14K -GPM 550 - PP on 3800 -off 3780 - PU 235 - SO 145 -ROT 182 -ECD 10.64 -Add Lubs up to 2.5% INTi CBU 3 X -GPM 560 - PP 3800 -RPM 150 -TO 5K -ECD 10.27 INTi Pump out from 13553' to 7900' -Pump at drlg rate 550' -Tight spot @ 8325' 40K over -Run back through tight spot - No over pull INTi CBU 1.5 X -GPM 550 - PP 3500 -ECD 10.35 INTi Rig service - Cut drlg line - INTi RIH from 7900' TO 12595' -Fill DP every 25 stands INT1 Con't RIH from 12595' to 13553' -Precautionary wash last stand to bottom INTi CBU 3 X -GPM 560 - ICP 3800 FCP 3640 -RPM 150 - TO 12.5K -ECD 10.27 -Flow check -Well static INT1 Pump out from 13553' to 7900' -GPM 550 - PP 3500 -Hole in good shape INT1 CBU 2 X -GPM 600 - PP 3650 -RPM 120 - TO 5K -Spot tube pill -Monitor well -Well static INTi Pump dry job -Lay down 66 joints 5" drill pipe INTi C/O handling equipment - POH stand back 4" DP INT1 C/O Handling equipment - LD 300' 5" DP - 5" HWT -Jars -Flex collars -Down load MW D - LD MW D -Geo-pilot -Bit INT1 Clear rig floor -Pull wear bushing -Install test plug INT1 PJSM -Change top VBR's to 7 5/8" casg rams -Test door seals to 1500 psi (test good) - Pul{ test plug INT1 Rig up 7 5/8" casg tools INT1 PJSM - MU float equipment -Check floats - (Floats good) - Printed: 7/25/2005 7:52:56 AM • BP EXPLORATION Page 5 of 11 Operations Summary Report Legal Well Name: MPF-93 Common Well Name: MPF-93 Spud Date: 6/23/2005 Event Name: DRILL+COMPLETE Start: 6/21/2005 End: 7/11/2005 Contractor Name: Rig Release: Rig Name: Rig Number: Date ;From - To Hours ~, Task ~ Code ~~' NPT ~, Phase CASE P INTi ~n 2005 ~ oo:oo - os:oo s.oo CASE P INTi 05:00 - 06:00 I 1.001 CASE I P I I INT1 06:00 - 11:00 I 5.001 CASE I P I I INTi 11:00 - 14:30 I 3.501 CASE I P I I INTi 14:30 - 15:30 ~ 1.00 ~ CEMT ~ P I ~ INT1 15:30 - 17:30 ~ 2.00 ~ CASE ~ P ~ ~ INT1 17:30 - 18:00 I 0.501 CASE I P I I INT1 18:00 - 19:00 1.001 CASE P INT1 19:00 - 20:00 1.00 CASE P INTi 20:00 - 21:00 1.00 CASE P INTi 21:00 - 21:30 0.50 CASE P INT1 21:30 - 00:00 2.50 CASE P INT1 7/8/2005 00:00 - 03:00 3.00 CASE P INTi 03:00 - 05:00 2.00 CASE P INT1 05:00 - 07:30 2.50 CASE P INTi 07:30 - 15:30 I 8.001 CASE I P I I INTi 15:30 - 16:30 1.00 CASE P INT1 16:30 - 18:30 2.00 CASE P INTi 18:30 - 20:00 1.50 DRILL P INT1 20:00 - 21:30 1.50 CASE P INTi 21:30 - 22:30 1.00 DRILL P INT1 Description of Operations Con't PU /Run 7 5/8" 29.7# L-80 BTC-M casg C~ 495' Con't PU /Run 7 5/8" casg from 495' to 4000' -Break circulation - Con't PU /Run from 4000' to 7900' Break circulation -Circulate one casg volume -Stage up pump to 7 bpm @ 720 psi Con't PU /Run 7 5/8" casg from 7900' to 13509' -Make up Hanger /landing joint -RIH land casging C~3 13541 Make up cementing head -Break circulation -Circulate two casg volumes -Condition mud for cementing 7 5/8" casg - Stage up pumps from 4.5 bpm to 7 bpm - @ 900 psi - Reciprocate pipe while circulating - PU 350 - SO 145 Give to Dowell Pump 5 bbls water Test lines to 3500 Pump 10 bbls CW-100 Pump 30 bbls Mud Push mixed ~ 11 ppg Drop bottom plug Mix and pump 63 bbls 354 sxs Class "G" yield 1.16 cu/sx C~3 15.8 PP9 Drop top plug Kick out with 30 bbls water Give to Rig Displace with 588 bbls 9.6 ppg LSND mud -Pump 7 bpm 600 psi -Last 10 bbls 3 bpm 860 psi -Bump plug with 1900 psi - 1000 over circulating pressure -Held for 3 mins -Bleed off pressure -Floats holding -Reciprocated pipe through out job - Good returns - Test casg to 3500 psi -Record on chart for 30 mins - (Test good) RD cementing head - LD landing joint -Flush stack - RD elevators /long bails Install FMC Pack-off -Test for 15 mins to 5K - (Test good) Install test plug -Change 7 5/8" casg to 2 7/8" X 5" VBR top rams - RU test equipment -Open annulus valves -Test to 250 low - 4000 high - 5 mins each test - (Test good) - RD test equipment -Pull test plug -Install wear ring -Close annulus valve RU floor to lay down 5" DP LD 5" DP Con't LD 5" DP Change out saver sub 5" to 4" - Moblize Short BHA to rig floor Make up bit -Motor -Stab -MWD -Orient -Program MWD - Make up Geo-Tap - DC's -Jar -Function test MWD RIH with BHA picking up 4" DP from pipe shed to 8373' - Circulate thru string every 1000' PJSM - Cut drlg line -Rig service -Top drive /Blocks service RIH with BHA from 8373' to 13417' -Fill every 25 stds -Wash last stand to bottom Drill float collar and shoe trac from 13428' to 13550' Dispace to 11 ppg LSND mud Drill shoe to 13551' -Clean out rat hole to 13553' -Drill 20' new hole to 13573' -Lost 45 bbls mud -Slow pump rate from 275 to 250 -Drill additional 20' hole to 13593' -Lost additional 30 bbls Printed: 7/25/2005 7:52:56 AM BP EXPLORATION Page 6 of 11 Operations Summary Report Legal Well Name: MPF-93 Common Well Name: MPF-93 Spud Date: 6/23/2005 Event Name: DRILL+COMPLETE Start: 6l21J2005 End: 7/11/2005 Contractor Name: Rig Release: Rig Name: Rig Number: Date ,From - To ~ Hours Task ~~~ Code NPT '~~ Phase Description of Operations 7/8/2005 21:30 - 22:30 1.00 DRILL P INTi 22:30 - 00:00 1.50 CASE P INT1 7/9/2005 00:30 - 01:00 0.50 EVAL P INT1 01:00 - 02:30 1.50 DRILL N DPRB PRODi 02:30 - 03:30 1.00 DRILL N DPRB PROD1 03:30 - 05:00 1.50 DRILL N DPRB PROD1 05:00 - 05:30 0.50 DRILL N DPRB PROD1 05:30 - 07:30 ~ 2.00 ~ DRILL ~ N ~ DPRB ~ PROD1 07:30 - 08:00 0.50 DRILL N DPRB PROD1 08:00 - 10:00 2.00 DRILL N DPRB PROD1 10:00.- 11:00 1.00 DRILL N DPRB PROD1 11:00 - 12:30 1.50 DRILL N DPRB PROD1 12:30 - 13:00 0.50 DRILL N DPRB PRODi 13:00 - 13:30 0.50 DRILL N DPRB PROD1 13:30 - 14:00 0.50 DRILL N DPRB PRODi 14:00 - 15:00 1.00 DRILL N DPRB PROD1 15:00 - 15:30 0.50 DRILL N DPRB PROD1 15:30 - 18:00 2.50 DRILL N DPRB PRODi 18:00 - 20:00 2.00 DRILL N DPRB PROD1 20:00 - 20:30 0.50 DRILL N DPRB PROD1 20:30 - 22:00 1.50 DRILL N DPRB PROD1 22:00 - 00:00 2.00 DRILL N DPRB PROD1 0/2005 00:00 - 05:00 5.00 DRILL N DPRB PROD1 05:00 - 09:00 4.00 DRILL N DPRB PROD1 09:00 - 10:00 1.00 DRILL N DPRB PROD1 10:00 - 10:30 0.50 DRILL N DPRB PROD1 10:30 - 11:00 0.50 DRILL N DPRB PROD1 11:00 - 14:00 3.00 DRILL P PROD1 14:00 - 15:30 I 1.501 DRILL I P I I PROD1 mud CBU 1 X -Condition mud for FIT Preform FIT - MD 13553' - TVD 6879 -MUD weight 10.9 - Surface pressure leak off 520 psi = EMW 12.3 Mix 20 ppb LCM Pill -Spot 5 bbls on bottom -Pull 2 stands Circ -GPM 170 - PP 1600 psi -Hole static -Increase pump rate to 212 GPM -Lost 22 bbls RIH to 13593' -Spot 15 bbl LCM pill) 20 ppb - POH to 13168' Circ Between 13168' and 13264' -Record losses -GPM 170 - PP 1500 -Loss 3 bbls in 15 mins -static for 15 mins Monitor well -well breathing -Flowed back a total of 24 bbls. Initial flow rate to trip tank was 20+ bbls per hour rate and slowed to 3.6 bbls per hour rate. Ran in hole with drill string to bottom of casing at 13541'. Circulated bottoms up. Started circulating at 4 bpm at 1520 psi and was losing mud. Slowed pump to 3.2 bpm at 1320 psi and finished circulating bottoms up. Lost 14 bbls of mud while. circulating bottoms up. No gas or oil cut. mud with bottoms up. Well breathing -monitored well and flowed back 8 bbls. Well flow decreased to 3.6 bbls per hour rate. Pumped out of hole from shoe at 1354i' to 12090'. Hole took 6 bbl while pumping out. Calculated fill was 7.9 bbls. Monitor well for flow -well flowed back .9 bbl in 30 minutes. Pumped out an additional 10 stands to 11141' at 3 bpm at 1000 psi. Hole took 6 bbls and calculated hole fill was 7.9 bbls. Monitored hole for 15 minutes to trip tank. No flow. Pulled 20 stands slowly without pumping. Hole was taking 2.4 bbl per 5 stands. Calculated was 2.65 bbls per 5 stands. Pumped slug Pulled out of hole on trip tank. From 9222 to BHA LD BHA -Jar -Flex Collars -Down-load MW D -Motor -Bit Clear rig floor - Moblize Rotary drilling BHA PJSM-PUBHA-Bit-Bitsub-XO-DC-XO-IBS-XO-11 DC's -Jars - XO RIH -from 416' to 3800' -Fill pipe every 25 stands CON't RIH from 3800' to 13593' -Fill every 20 stands Circulate lower mud weight from 10.9 ppg to 10.5 ppg - 3.5 bpm C~1 920 psi. Adding 40 gallons per minute to maintain pit level. Monitored well in trip tank. Well flowed back 11.4 bbls. Initial flowrate in 10 minute increments was 3.9 bbls decreasing to .6 bbl. Run in hole to bottom at 13593'. Broke circulation and brought rate up to 5 bpm (216 gpm). No losses. Increased rate to 6bpm (275 gpm). No losses. Drill from 13593' to 13660'. Pumping 6bpm (275 gpm) at 1740 psi -RPM 150 at 13k rotary torque - WOB 10K - 35K. Drill 80-90' per hour with 10 -15K weight on bit to 13644'. Had formation change and drilled with 35K weight on bit from 13644' to 13660'. - WOB 20 to 35 -RPM 140 - TO 14 on 16 off -GPM 254 - PP 1790 - PU 235 - SO 105 -ROT 140 Circulated hole clean at 6bpm at 1700 psi. Stripped out LCM in Printed: 7/25/2005 7:52:56 AM U BP EXPLORATION Operations Summary Report Page 7 of 11 Legal Well Name: MPF-93 Common Well Name: MPF-93 Spud Date: 6/23/2005 Event Name: DRILL+COMPLETE Start: 6/21/2005 End: 7/11/2005 Contractor Name: Rig Release: Rig Name: Rig Number: Date 'From - To ~ Hours ~~, Task ~ Code ~ NPT Phase Description of Operations 7/10/2005 14:00 - 15:30 1.50 DRILL P PRODi mud. 15:30 - 16:00 0.50 DRILL P PRODi Monitored well into trip tank. Flow IFB 1.6 bbls -decrease to .5 bbls -Total of 4.2 bbls in 30 mins 16:00 - 16:30 0.50 DRILL P PROD1 Performed FIT. MW 10.5 ppg -Shoe TVD 6879' -Leak off pressure 450 psi -LOT is calculated to be 11.76 PPG EMW. Bled off pressure. 16:30 - 17:00 0.50 DRILL P PROD1 Monitor well -Flow IFB 1.8 bbls decrease to .6 bbls -Total gained 2.7 bbls in 15 mins 17:00 - 18:00 1.00 DRILL P PRODi Drill from 13660' to 13678' - W 10 to 25 -RPM 140 - TQ on 5 - off 15 -GPM 254 - PP 1725 - PU 240 - SO 105 -ROT 140 18:00 - 18:30 0.50 DRILL P PROD1 Monitor well -Flow IFB 3.3 bbls decrease to .9 bbls -Total gained 6.3 in 20 mins 18:30 - 19:30 1.00 DRILL P PROD1 CBU -GPM 254 - PP 1710 -RPM 89 - TO 17K - No gas cut mud on bottoms up 19:30 - 00:00 4.50 DRILL P PRODi Drill from 13678' to 13719' - WOB 20 to 43 -RPM 150 - TO 14 -off 16 -GPM 254 - PP on 1820 -off 1730 - PU 235 - SO 105 - ROT 142 7/11/2005 00:00 -07:30 7.50 DRILL P PROD1 Drill from 13719' to 13782' - TD 6 3/4" Hole - WOB - 15 to 45 - RPM 150-TO on 14-off 16-GPM254-PPon-off-PU-SO -ROT 07:30 - 08:30 1.00 CASE P PROD1 CBU 1 X -GPM 254 - PP 2030 -RPM 120 - TO 16K 08:30 - 09:00 0.50 CASE P PRODi Pump out to shoe C~ drlg rate 09:00 - 09:30 0.50 CASE P PRODi Monitor well -Well static 09:30 - 11:00 1.50 CASE P PROD1 RIH to 13782' -Pump out to shoe ~ drlg rate -Pump additional 15 stands out to 12403' 11:00 - 11:30 0.50 CASE P PROD1 Monitor well -Well static -Pump dry job -Drop 1 15/16" drift 11:30 - 13:30 2.00 CASE P PROD1 POH from 12403' to 9000' 13:30 - 14:30 1.00 CASE P PROD1 PJSM -Cut drlg line -Rig service 14:30 - 17:30 3.00 CASE P PRODi Con't POH from 9000' to BHA C~ 414' 17:30 - 18:30 1.00 CASE P PRODi UD BHA -Jars -Collars -Bit 18:30 - 19:00 0.50 CASE P PROD1 Clear floor - RU to run 5 1/2" liner 19:00 - 21:30 2.50 CASE P PROD1 PU 5 1/2" liner -Make up Baker HMC Hanger -Backer ZXP Packer -Liner weight 6500 - Circ liner volume 21:30 - 00:00 2.50 CASE P PROD1 RIH with liner on 4" DP -from 373' to 4200' 7/12/2005 00:00 - 06:00 6.00 CASE P PROD1 Con't RIH with 5 1/2" liner from 4200' to 13550' 06:00 - 07:00 1.00 CASE P PROD1 Circulate drill pipe and liner volume - 2 bpm @ 900 psi -Make up Baker plug dropping head -Lay down on skate 07:00 - 08:00 1.00 CASE P PROD1 RIH to TD 13782' - PU Baker plug dropping head -Make up same 08:00 - 08:30 0.50 CASE P PROD1 Circulate DP /Liner volume - 3.5 bpm C 1300 psi 08:30 - 09:00 0.50 CEMT P PROD1 Give to Dowell Schlumberger Pump 5 bbls water - 3.5 bpm @ 1100 psi Test lines to 4500 psi - Pump 10 bbls CW 100 - 3.5 bpm @ 1050 Pump 20 bbls Mud Push Mixed at 11.4 ppg - 3.4 bpm @ 1090 psi Batch mix 13.3 bbls 62 sxs yield 1.20 cu/sx mixed at 15.8 ppg - 3.5 bpm ~ 950 psi Drop drill pipe dart Kick out with 5 bbls water - 3.5 bpm @ 960 psi Give to rig 09:00 - 10:00 1.00 CASE P PROD1 Displace with 10.4 ppg LSND mud -Pump at 3.5 bpm C~? 990 psi -Slow pump rate to 2 bpm ~ 700 psi last 20 bbls -Bump Printed: 7/25/2005 7:52:56 AM n u BP EXPLORATION Page 8 of 11 Operations Summary Report Legal Well Name: MPF-93 Common W ell Name: MPF-93 Spud Date: 6/23/2005 Event Nam e: DRILL+C OMPLE TE Start : 6/21/2005 End: 7/11/2005 Contractor Name: Rig Release: Rig Name: Rig Number: Date I ~ From - To Hours Task ' ~ Code , NPT Phase ~ i Description of Operations 7/12/2005 09:00 - 10:00 1.00 CASE P PRODi plug with 4000 psi to set hanger 10:00 - 10:30 0.50 CASE P PRODi Set down 50K to set hanger slips -Bleed off pressure -Check floats - PU to 90 K -Rotate 15 turns to right release off hanger - Pressure up to 1000 psi -Pull out hanger -Circulate cement up hole +- 1600' -Set 50K while rotating -Repeat 2nd time 10:30 - 11:00 0.50 CASE P PROD1 LD Baker plug dropping head 11:00 - 12:00 1.00 CASE P PROD1 CBU - 10 bpm C~1 3600 psi 12:00 - 13:00 1.00 CASE P PROD1 Con't LD plug dropping head -Clear rig floor -Pump dry job 13:00 - 18:30 5.50 CASE P PROD1 POH - LD 9 stands 4" excess drill pipe 18:30 - 19:00 0.50 CASE P PROD1 Service break - LD Baker running /setting tool 19:00 - 19:30 0.50 CASE P PROD1 Rig Service 19:30 - 20:30 1.00 CASE P PROD1 PuII wear bushing -Install test plug - RU test equipment -Open annulus valve 20:30 - 23:30 3.00 CASE P PROD1 Test BOP's -Annular 250 low 3500 high 5 mins each test -Top rams - Bolton rams -Blind rams -Choke manifold - HCR Kill / Choke -Manual Kill /Choke -Upper /Lower IBOP -Floor safety valves - 250 low 4000 high 5 mins each test -All tests good -Preform accumulator test -Lou Grimauldi with AOGCC waived witness of BOP test -All Test witnessed by WSL 23:30 - 00:00 0.50 CASE P PROD1 Rig down testing equipment -Pull test plug -Install wear ring - Close annulus valve 7/13/2005 00:00 - 01:00 1.00 CASE P PROD1 Preform FIT to confirm ZXP is set - MD 13551' -TVD 6879' - Mud weight 10.4 ppg -Surface 1300 =EMW 14 ppg -Bleed off -rig down testing equipement 01:00 - 01:30 0.50 CASE P PROD1 Rig up 2 7/8" handling tools 01:30 - 03:00 1.50 CASE P PROD1 PU 3 1/8" DC's - 2 7/8" DP 03:00 - 03:30 0.50 CASE P PROD1 Pump through string to clear out any scale -GPM 170 - PP 460 psi 03:30 -04:30 1.00 CASE P PROD1 POH rack 2 7/8" DP in derrick - LD 3 Flex Dc's 04:30 - 06:00 1.50 CASE P PROD1 MU BHA -Surface test MWD - 150 GPM - 2180 PSI 06:00 - 07:00 1.00 CASE P PROD1 RIH 2 7/8" DP - PU Jars - Circ sub - XO 07:00 - 13:00 6.00 CASE P PROD1 RIH from 926' to 13392' -Fill pipe -Survey 13:00 - 14:00 1.00 CASE P PROD1 PJSM - Cut drlg line -Top drive service -Rig service 14:00 - 17:00 3.00 CASE P PROD1 Wash drill from 13392' to 13740' -Due to pipe tally discrepancy drilled through landing collar - 17:00 - 17:30 0.50 CASE P PROD1 Attempt to test casg -Leaked off 17:30 - 18:00 0.50 CASE P PROD1 Con't wash to 13766' 18:00 - 22:00 4.00 CASE P PROD1 Raise mud weight with spike fluid to 11 ppg 22:00 - 22:30 0.50 DRILL P PROD1 Drill float collar @ 13768 -Shoe @ 13780' -Clean out to 13782' 22:30 - 23:30 1.00 DRILL P PROD1 Drill from 13782' to 13792' - WOB 2 to 8 -RPM 30 - TO on 13.5-off 12-GPM 150-PP on 3700-off 3550-PU245-SO 90 -ROT 135 23:30 - 00:00 0.50 CASE P PROD1 Circulate bottoms up 7114/2005 00:00 - 01:00 1.00 DRILL P PROD1 CBU -GPM 150 - PP 3400 - 30 RPM 14K 01:00 - 02:00 1.00 DRILL P PROD1 RU test equipment -FIT - MD 13782 -TVD 7098 -Mud weight 10.9 ppg -Surface pressure 1150 =EMW 14 ppg - RD Test equipment 02:00 - 00:00 22.00 DRILL P PROD1 Drill from 13792' to 14100' - WOB 10 to 15 -RPM 33 - TO on 14K -off 13-GPM 150 - PP on 3800 -off 3610 - PU 240 - SO 95 -ROT 140 7/15/2005 00:00 - 08:30 8.50 DRILL P PROD1 Drill from 14100' to 14182' - WOB 10 to 15 -RPM 30 - TQ on 14-off 16-GPM150-PPon3800-off3610-PU240-SO Printed: 7/25/2005 7:52:56 AM • BP EXPLORATION Page 9 of 11 Operations Summary Report Legal Well Name: MPF-93 Common Well Name: MPF-93 Spud Date: 6/23/2005 Event Name: DRILL+COMPLETE Start: 6/21/2005 End: 7/11/2005 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To i Hours ' Task Code NPT Phase 7115!2005 00:00 - 08:30 8.50 DRILL P PROD1 08:30 - 09:00 0.50 DRILL P PROD1 09:00 - 09:30 0.50 DRILL P PROD1 09:30 - 10:00 0.50 DRILL P PROD1 10:00 - 12:30 2.50 DRILL P PROD1 12:30 - 13:00 0.50 DRILL N DPRB PROD1 13:00 - 19:00 6.00 DRILL N DPRB PROD1 19:00 - 19:30 0.50 DRILL N DPRB PROD1 19:30 - 21:30 2.00 DRILL N DPRB PRODi 21:30 - 00:00 2.50 DRILL N DPRB PROD1 7/16/2005 100:00 - 02:00 I 2.00 DRILL N DPRB PROD1 02:00 - 02:30 0.50 DRILL P PROD1 02:30 - 03:00 0.50 DRILL P PROD1 03:00 - 03:30 0.50 DRILL P PROD1 03:30 - 05:30 2.00 DRILL P PROD1 05:30 - 06:00 0.50 DRILL P PROD1 06:00 - 10:30 4.50 DRILL P PROD1 10:30 - 11:00 0.50 DRILL N DFAL PRODi 11:00 - 15:30 4.50 DRILL N DFAL PROD1 15:30 - 19:00 3.50 DRILL N DFAL PROD1 19:00 - 19:30 0.50 DRILL N DFAL PROD1 19:30 - 20:00 0.50 DRILL N DFAL PROD1 20:00 - 20:30 0.50 DRILL N DFAL PROD1 20:30 - 21:00 0.50 DRILL N DFAL PROD1 21:00 - 21:30 0.50 DRILL N DFAL PROD1 21:30 - 00:00 I 2.501 DRILL I N I DFAL I PROD1 7/17/2005 100:00 - 02:00 I 2.001 CASE I N I DFAL I PROD1 02:00 - 02:30 0.50 CASE N DFAL PROD1 02:30 - 08:00 5.50 CASE N DFAL PROD1 08:00 - 08:30 0.50 CASE N DFAL PROD1 08:30 - 10:00 1.50 CASE N DFAL PRODi 10:00 - 11:30 1.50 CASE N DFAL PROD1 11:30 - 12:00 0.50 CASE N DFAL PRODi 12:00 - 13:00 1.00 CASE N DFAL PRODi 13:00 - 18:30 5.50 CASE N DFAL PROD1 18:30 - 22:00 3.50 CASE N DFAL PROD1 22:00 - 23:00 I 1.001 CASE I N I DFAL I PROD1 23:00 - 23:30 0.50 CASE N DFAL PRODi 23:30 - 00:00 0.50 CASE N DFAL PROD1 Description of Operations 95 -ROT 140 Pump out to shoe from 14182' to 13782 -Pump C~ Drlg rate Monitor well -Slight flow RIH to 14182' CBU 35 spm - PP 3850 psi -RPM 30 - TO 15K Increase in flow and vol -Gas cut mud to surface 11 ppg to 9.9 ppg - SPM increased -Pump pressure decreased -Shut in well with annular Weight up kill mud -from 11 ppg to 12 ppg -Circ kill mud around -Move string every 20 mins Shut down -Bleed off equipment -Monitor well -Open bag CBU 1 X -GPM 212 -ICP 2970 FCP 2730 - Monitor well -Slight flow -weight up from 12 ppg to 12.5 ppg ~ con't circ GPM 170 -RPM 30 TO 12K -ICP 1700 -FCP 1640 Con't circulate increasing mud weight to 12.5 PPG -GPM 148 - PP 1640 -RPM 30 - TO 12 -Flow check 15 mins -Well static Pump out from 14182' to 13772' Monitor well for 30 mins -Fluid dropped 1" in bell nipple Pump out from 13772' to 13390' -Monitor well 15 mins 1"gain ' in bell nipple CBU 1 X -RPM 30 - TO 12 -GPM 148 -ICP 1540 -FCP 1510 Monitor well for 30 mins -Well Static POH from 13390' to 5700' -Found washout on stand 90 Change washed out joint -Pump down drill pipe to test integrity of remaining string - 148 GPM - 3680 psi RIH from 5700' to 14182' -Filling every 25 stds CBU -Condition mud -RPM 30 - TO 12K -GPM 148 -ICP 3740 -FCP 3620 - (Mud cut from 12.5 ppg to 10.6 ppg) Monitor well 15 mins -Well static Pump out 5 stands from 14182' to 13770' Monitor well 30 mins -Well static Pump out from 13770' to 13377' Monitor well 15 mins -Well static -Drop ball to open circulating sub - CBU -GPM 357 -ICP 3830 -Pump 35 bbl Hi-Vis sweep -RPM 30 - TO 10K -Massive amount tube barite sludge coming over shakers Con't CBU tube barite sludge 5 X -RPM 30 - TO 10K -GPM 357 -FCP 3720 Flow check 30 mins -Well static Pump dry job - POH from 13377' to BHA @ 926' RU 2 7/8" handling tools LD 2 7/8" drill pipe LD BHA Rig down 2 7/8" equipment -Clear rig floor PU BHA - MU 6 3/4" Bit - 4 3/4" DC's -Jars - XO RIH from 222' to 12500' -Break circulation every 25 stands Wash from 12500' to 13400' -RPM 150 - TO 10 -GPM 348 - ICP 3860 -Wash from 13400 to 13417' TOL with out rotation Pump nut plug sweep -GPM 348 PP 3830 -RPM 150 - TO 10 -Circ 7353 stks -Shakers clean - Flow check 30 mins -Well static Pump out 5 stands -From 13400' to 12920' -GPM 300 - PP Printed: 7/25/2005 7:52:56 AM BP EXPLORATION Page 10 of 11 Operations Summary Report Legal Well Name: MPF-93 Common Well Name: MPF-93 Spud Date: 6/23/2005 Event Name: DRILL+COMPLETE Start: 6/21/2005 End: 7/11/2005 Contractor Name: Rig Release: Rig Name: Rig Number: Date ~ From - To Hours Task ~ Code NPT ~ Phase Description of Operations 7/2005 23:30 - 00:00 0.50 CASE N DFAL PRODi 3000 8/2005 00:00 - 01:30 1.50 CASE N DFAL PROD1 Cut drlg line -Rig service 01:30 - 06:00 4.50 CASE N DFAL PROD1 Pump dry job - POH from 12920' to BHA ~ 221' 06:00 - 07:00 1.00 CASE N DFAL PRODi Lay down BHA 07:00 - 07:30 0.50 CASE P PROD1 Clear rig floor 07:30 - 08:00 0.50 CASE P PROD1 RU Liner Running equipment 08:00 - 10:00 2.00 CASE P PRODi PU 3 i/2" IBT-M 9.3# L-80 Liner -Make up Baker Seal Bore 10:00 - 17:00 I 7.001 CASE I P 17:00 - 19:00 2.00 CASE P 19:00 - 20:00 I 1.001 CASE I P 20:00 - 00:00 4.00 CASE P 9/2005 100:00 - 01:00 1.001 CASE P 01:00 - 02:30 I 1.501 CEMT I P 02:30 - 03:00 0.501 CASE ~ P 03:00 - 04:30 I 1.501 CASE I P 04:30 - 05:00 0.501 CASE P 05:00 - 05:30 0.50 CASE P 05:30 - 08:30 3.00 CASE P 08:30 - 09:30 1.00 CASE P 09:30 - 10:30 1.00 CASE P 10:30 - 22:30 12.00 CASE P 22:30 - 23:00 0.50 CASE P 23:00 - 23:30 0.50 CASE P 23:30 - 00:00 0.50 CASE P 7/20/2005 100:00 - 10:30 I 10.501 RU Extension -Baker HMC liner hanger -Baker ZXP Liner top packer -Circ Liner vol -Check Floats - PU 205 - SO 95 PROD1 RIH with liner on 4" DP - TO 13417' -Fill 1st 20 stands then every 15 stands on trip in PRODi Lay down single from string -Make up Baker plug dropping head - LD on skate -Circ drill pipe / liner vol ~ 3 BPM 1230 psi PRODi Con't RIH with liner from 13417' to 14167' -Make up plug dropping head -Cementing lines PROD1 Break circulation 2 BPM ~ 1250 psi -stage up to 3 BPM C 1450 psi- PU 225 - SO 100 -Mud weight in 12.5 -Air /gas cut to 12.2 -Non pressured scale 11.6 PROD1 Circulate level mud weight -BPM 3 - PP 1450 - PU 220 - SO 105 -Mud weight i2.5 in - i2.5 out -Non pressured scale 12.0 ppg - (PJSM Cementing) PROD1 Give to Dowell Schlumberger Pump 5 bbls water Test Lines to 4000 psi Pump 10 bbls CW-100 Pump 10 bbls Mud Push 11 -Mixed at 13.8 ppg Batch mix and pump 20 bbls 15.8# Class "G" Cement Yield 1.20 cu/sx Drop dart Displace with 40 bbs Viscosified pill 15 bbls water 103.6 bbls 12.5 ppg LSND mud Bump plug with 3500 psi to set hanger PROD1 Rotate 15 rounds to right -Pressure up to 1000 psi -Pick up 11' -Circulate 250 strokes C~1 7.5 bpm 3500 psi -Slack off rotating 15 RPM - 50K set ZXP Packer -Pick up 30 feet PROD1 Circulate out cement - Purf pill -Good cement back 6 bbls 1.6 bbls contaminated cement - 7.5 bpm 3500 psi PROD1 RU to test casg -Test casg /ZXP Packer - 1500 psi -Hold for 10 mins - RD test equipment PROD1 RD Baker cementing head PRODi Displace well with 30 bbl High Vis. sweep, 260 bbls Sea Water, 30 bbls High Vis sweep, 790 bbls 9.6 Brine. PROD1 Observe well for flow, mixed up Brine PRODi Circ, Bottoms up with 100 spm, 3000 psi PROD1 Laying down drill pipe, and running tool PROD1 Pull wear ring, rig up to run tubing PROD1 PJSM on picking up tubing PROD1 Picking up, 4" Seal assy with No-go, X nipple, XD Duro Sliding Sleeve and 4.5 12.6# L-80 IBT-M. tubing RUNCMP Picking up 4.5 L-80 12.6# IBT Tubing, Total 319 jts, space out Printed: 7/25/2005 7:52:56 AM BP EXPLORATION Page 11 of 11 Operations Summary Report Legal Well Name: MPF-93 Common W ell Name: MPF-93 Spud Date: 6/23/2005 Event Nam e: DRILL+C OMPLE TE Start : 6/21/2005 End: 7/11/2005 Contractor Name: Rig Release: Rig Name: Rig Number: Date ~ From - To ~~ Hours Task Code ~ NPT ~ Phase ~ ` Description of Operations 7/20/2005 00:00 - 10:30 10.50 BUNCO RUNCMP with 20K on no-go, P/U 170k, S/O 97K 10:30 - 11:00 0.50 BUNCO RUNCMP Install TWC and test to 1000 psi from top 11:00 - 12:00 1.00 BUNCO RUNCMP PJ5M,SIip and cut drilling line 12:00 - 18:30 6.50 BUNCO RUNCMP PJSM, Nipple down bops, pull all rams, clear floor of Tubing tools 18:30 - 20:00 1.50 BUNCO RUNCMP PJSM, Nipple 11 x 4" 5000# Adapter flange and CIW 4" 5000# tree, test adapter and shell test tree to 5,000 psi for ten min. 20:00 - 21:00 1.00 BUNCO RUNCMP PJSM, Puil TWC, rig up to test Tubing 21:00 - 00:00 3.00 BUNCO RUNCMP Test Tubing for 3,500 psi for 30 min good test, bleed tubing to 2000 psi, pump annulus to 4000 psi, ,pressure equalized with tubing to 3600 psi in 10 min. Change pumping lines configeration to isolate leak, retest annulus still leaked, remove tubing pressure line, retest test annulus to 4,000 psi with 2000 psi on tubing, still equalizedt to tubing in 10 min., bleed off pressure in tubing and annulus, test annulus to 3500 psi with tubing open, pressure was dropping 100 psi per min, bleed down to 3,000 psi.flow thru Tubing, bleed pressure off and retest tubing to 3,500 psi for 30 min. with annulus valve open, good test 7/21/2005 00:00 - 03:00 3.00 BUNCO DFAL RUNCMP Waiting on Slick line unit 03:00 - 06:00 3.00 BUNCO DFAL RUNCMP Rigging up Slick line unit, wire line BOPS, lubricator 06:00 - 08:00 2.00 BUNCO DFAL RUNCMP Running slick line to pull dummy out of GLM C~3 3142, not enought wt to latch up, POH 08:00 - 09:30 1.50 BUNCO DFAL RUNCMP Pickup more wt. bars, Trip in pull dummy valve 09:30 - 11:00 1.50 BUNCO DFAL RUNCMP Rih with new dummy valve, set with 300 psi and release, Poh with running tool 11:00 - 12:00 1.00 BUNCO DFAL RUNCMP Pressure up on annulus with 1500 psi, flow out tubing, bleed off, Pressure up on tubing with 3500 psi, no flow out annulus, pressure held on tubing. bleed off tubing pressure 12:00 - 14:30 2.50 BUNCO DFAL RUNCMP Rih with Wire line shifting tool to insure sliding sleeve (~ 13217 is closed., pulled on shifting tool to shut sliding sleeve 3 times, 14:30 - 16:00 1.50 BUNCO DFAL RUNCMP Pressure up on annulus to 1000 psi, no flow thru tubing pressure held for two mins., bleed pressure off, pull wire line tools 16:00 - 17:30 1.50 BUNCO DFAL RUNCMP Pressure up on tubing to 3500 psi for 30 min., good test, bleed tubing to 2,000 psi, pressure up on Annulus to 4000 psi for 30 min., good test 17:30 - 18:30 1.00 BUNCO DFAL RUNCMP Rig down Lubricator and wire line BOPs 18:30 - 19:30 1.00 BUNCO RUNCMP Install BPV, Secure well, clean out cellar, Rig release for Summer Maintenance 19:30 hrs 7/21/2005 Printed: 7/25/2005 7:52:56 AM I~ BP EXPLORATION Page 1 of 3 Operations Summary Report Legal Well Name: MPF-93 Common Well Name: MPF-93 Spud Date: 6/23/2005 Event Name: RECOMPLETION Start: 9/8/2005 End: Contractor Name: Rig Release: Rig Name: Rig Number: Date 9/21 /2005 9/22/2005 From - To ,Hours _~_ 18:00 - 20:00 2.00 MOB P 20:00 - 23:00 3.00 MOB P 23:00 - 00:00 1.00 MOB P 00:00 - 05:00 5.00 KILL P Task !Code ', NPT Phase ~', Description of Operations PRE Skid floor, Move rig off MPF-91 PRE Move mats, Move rig on MPF-93, Skid rig floor PRE Hook up service lines, spot and hook up rock washer DECOMP Rig up lines to Bleed tank, Pull BPV, Rig up lines to tree and choke, Test kill and choke lines to 3,000 psi, bleed lines to 1000 psi., Rig accept @ 00:01 9/22/2005 DECOMP Spud meeting, PJSM, Starting pressure 1300 psi on tubing, 1300 psi on annulus, Killing tubing with 30 bbls Safe Surf-o, 35 bbls Hi-Vis sweep, 12.0 ppg sodium bromide, tubing volume 200 bbls, Annulus volume 345 bbls DECOMP Monitor well, no flow DECOMP Spot 100 bbls 12.0# Hi-Vis pill, 60 spm 1080 psi, Monitor well, no flow DECOMP Install TWC, attempt to test to 5,000 psi, pull and redress TWC, install and test to 5,000 psi DECOMP PJSM, Nipple down tree DECOMP PJSM, Nipple up BOPS DECOMP PJSM, Rig up to test bops, test BOP and manifold 250-5000 psi, annluar 250-2500 psi, 5 min per test, test witness By Chuck Scheve AOOGC, and WSL, chasing leaks DECOMP Test BOP and manifold 250-5000 psi, annluar 250-2500 psi, 5 min per test, test witness By Chuck Scheve AOOGC, and WSL, Fixed leaking choke fine API ring, Kill line HCR failed retest passed, Upper IBOP failed retested passed, floor dart valve failed will replace,( Lower pipe rams not tested will test when we get tubing layed down) DECOMP Picking up lubricator and pull TWC, no pressure on tubing DECOMP PJSM, Rig up cross overs, make up to Tubing hanger, Back out lockdowns DECOMP Attempt to pull Tubing free, work pipe up to 280k max 80 tensile, without success DECOMP land tubing on hanger, rig down crossover assem. DECOMP W/O Schlumberger E-line truck with Chemical cutter DECOMP Rig up and reverse circ. out Biozan high-Vis pill, with 500 psi 5 bbls min, save in Pit #4, 104 bbls total, DECOMP PJSM, Rig up Lubricator joint from hanger to floor, rig up Schlumberger E-line truck DECOMP Running Schlumberger Chemical cutter, didn't have to pump down, Cut tubing C~3 13180, pulling out with E-{ine DECOMP Finish pulling E-line, Rig down Schlumberger DECOMP Rig up to pull Tubing, pull free with 185K, p/u 160K, pull hanger to floor DECOMP Circ bottoms up with 360 gpm 850 psi DECOMP Laying down Tubing, total 317 jts, 14.20 cut jt., top of fish 13,180' DECOMP Install test plug and test lower rams with 250-5000 psi, 5 min. per test, test witness by WSL DECOMP Install wear ring, mobilize fishing BHA DECOMP Picking up BHA #1, Overshot,pump out sub,bumper sub,jars,9-4.75 DC,Accel jar. xo DECOMP Picking up 4" drill pipe out of pipe shed to 4639' DECOMP Picking up 4" drill pipe out of pipe shed, Run 30 stands out of derrick, 05:00 - 09:30 ~ 4.50 ~ KILL ~ P 09:30 - 10:00 0.50 KILL P 10:00 - 13:30 3.50 KILL P 13:30 - 16:00 I 2.50 I KILL I P 16:00 - 17:30 1.50 KILL P 17:30 - 22:00 4.50 KILL P 22:00 - 00:00 2.00 KILL P 9/23/2005 100:00 - 04:30 I 4.501 KILL I P 04:30 - 07:00 2.50 PULL P 07:00 - 07:30 0.50 PULL P 07:30 - 08:30 I 1.001 PULL I P 08:30 - 09:00 0.50 PULL P 09:00 - 13:00 4.00 PULL P 13:00 - 14:00 1.00 PULL P 14:00 - 16:00 2.001 PULL P 16:00 - 00:00 I 8.001 PULL I P 9/24/2005 00:00 - 02:30 2.50 PULL P 02:30 - 03:30 1.00 PULL P 03:30 - 04:30 1.00 PULL P 04:30 - 16:30 12.00 PULL P 16:30 - 18:00 I 1.501 PULL I P 18:00 - 18:30 0.50 PULL P 18:30 - 20:30 2.00 PULL P 20:30 - 00:00 3.50 PULL P 9/25/2005 00:00 - 05:00 5.00 PULL P Printed: 10/3!2005 3:11:14 PM BP EXPLORATION Page 2 of 3 Operations Summary Report Legal Well Name: MPF-93 Common Well Name: MPF-93 Event Name: RECOMPLETION Contractor Name: Rig Name: Date From - To 'Hours Task ~~ Code' NPT - --- ~ - - ~_ _ I 9/25/2005 05:00 - 06:00 1.00 PULL ~P 06:00 - 06:30 0.50 PULL P 06:30 - 08:30 2.00 PULL P 08:30 - 09:30 i 1.001 PULL ~ P 09:30 - 10:00 0.50 ~ PULL P 10:00 - 11:30 I 1.501 PULL I P 11:30 - 17:00 5.50 PULL P 17:00 - 19:00 2.00 PULL P 19:00 - 20:00 1.00 CLEAN P 20:00 - 22:00 2.00 CLEAN P 22:00 - 00:00 2.00 CLEAN P 9/26/2005 00:00 - 02:30 2.50 CLEAN P 02:30 - 05:30 3.00 CLEAN P 05:30 - 20:00 14.50 CLEAN P 20:00 - 20:30 0.50 CLEAN P 20:30 - 21:30 1.00 CLEAN P 21:30 - 00:00 I 2.501 CLEAN I P 9/27/2005 00:00 - 01:00 1.00 CLEAN P 01:00 - 01:30 0.50 CLEAN P 01:30 - 02:30 1.00 CLEAN P 02:30 - 07:30 5.00 CLEAN P 07:30 - 10:30 3.00 CLEAN P 10:30 - 11:00 0.50 CLEAN P 11:00 - 12:30 1.50 CLEAN P 12:30 - 14:30 2.00 CLEAN P 14:30 - 19:30 5.00 BUNCO 19:30 - 00:00 4.50 BUNCO 9/28/2005 100:00 - 17:00 I 17.00 Spud Date: 6/23/2005 Start: 9/8/2005 End: Rig Release: Rig Number: Phase Description of Operations DECOMP Cut drill line, service top drive DECOMP Break circulation with 3 bpm at 400 psi. Pick up weight 185K Slack off weight 110K Rotating weight 137K. Wash over fish and latched fish. DECOMP Jar fish with 285K then pulling 400K (75% of tensile strength of tubing). Jarred the seal assembly from 13357 to 13337'. DECOMP Spotted 100 bbl baVanced high vis pill. Picked up on pipe and found fish to be free. DECOMP Monitor well. Observed small amount of gas percolating and small amount of flow. DECOMP Closed annular perventor. No drill pipe or casing pressure. Circulated bottoms up through gas buster with 4 bpm at 650 psi. Hole stable. No gains or losses. DECOMP Laid down single jt of drill pipe and monitor well. No flow. Pulled out of hole with 4" drill pipe and fish. DECOMP Lay down, fish assm. and fish, little sand on top of pump, none in tail pipe DECOMP Clear tool of fishing tools DECOMP Picking up 27 jts, 820 ft, 2 1/16 hydril drill pipe an mule shoe, change out handling eq. DECOMP Rih with 4" pipe to 7245' DECOMP RIH to 13,327' DECOMP Reverse circ. @ 13,327' and spot 3 -20 bbls hi-vis pills in annulus, cir till first sweep at surface, leaving 2 in annulus 200 bbls apart, first pill brought up frac sand. circ @ 3.6 bbls min. 850 psi. DECOMP Ran in liner to 13,361', 34 ft., set down. on sand, rig up to rev., wash 45 ft and reverse bottoms and ever 45 ft there afer, spotting 20 bbls sweeps in annulus ever 200 bbls of reverse circ. Wash from 13361 to 13860' 3 bbls min. 650 psi, losses started, when we uncover perfs. at 13847 to 13860', starting loss pumping, 120 bbls hr pumping 2 bbls min, pull above perfs and monitor well filling from top 120 bbls hr to start, slowing to 60 bbls hr., DECOMP Pull out above liner to 13,285' DECOMP Mixing 135 bbl High-Vis pill, monitor well, mud lost slow to 24 bbls hr. DECOMP Spotted 115 bbls hi-vis pipe outside drill pipe, @ 13285', 2 bbls min, loss increase to 48 bbls hr pumping 2 bbls min. slowing down to 10 bbls hr., Total mud lost 160 bbls last 24 hrs DECOMP Trip in to 13,860' and tag up on sand with 2k DECOMP Poh to 13285 DECOMP Monitor well for loss 1/2 to 1 bbls hr. DECOMP Lay down 4" drill pipe from 13285 - to 8585' DECOMP PJSM -Stand back 4" DP in derrick DECOMP C/O pipe handling equipment to 2 1116" Drill pipe DECOMP PJSM - LD 2 1/16" dp -Mule shoe DECOMP Clear rig floor - C/O Handling equipment -Pull wear bushing RUNCMP PJSM - MU ESP Pump and control line - RUNCMP Run 2 7/8" ESP Completion 60 jts @ +- 2000' -Pump 1.5 bpm @ 1580 psi -Check ESP cable RUNCMP Con't Run 2 7/8" L-80 8rd EUE tubing to 13289' -Fill every 2000' -Check continuity on cable Printed: 1013/2005 3:11:14 PM • BP EXPLORATION Operations Summary Report Page 3 of 3 Legal Well Name: MPF-93 Common Well Name: MPF-93 Spud Date: 6/23/2005 Event Name: RECOMPLETION Start: 9/8/2005 End: Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task I! Code ~ NPT I, Phase Description of Operations 9/28/2005 17:00 - 19:30 2.50 BUNCO RUNCMP MU Hanger with TWC installed - MU cable to hanger -test cable continuity 19:30 - 20:00 0.50 BUNCO RUNCMP RIH land hanger - RILDS -Test TWC from top to 1000 psi - LD landing joint 20:00 - 20:30 0.50 BUNCO RUNCMP Clear floor 20:30 - 22:00 1.50 BUNCO RUNCMP PJSM - ND BOP stack 22:00 - 23:00 1.00 BUNCO RUNCMP NU FMC adapter - CIW 2 1/16 production tree - 23:00 - 00:00 1.00 BUNCO RUNCMP Test pack-off to 5000 psi - 10 mins -Test tree 5000 psi 5 mins - Test ESP cable -all test good 9/29/2005 00:00 - 00:30 0.50 BUNCO RUNCMP RU lubricator -Pull TWC 00:30 - 01:30 1.00 BUNCO RUNCMP RU Little Red Pumping Service -Test lines to 3500 psi - Freeze protect tubing and IA with 96 bbls diesel -Pump rate / pressure 5 bbls pumped @ 2 bpm 500 psi 20 bbls pumped @ 2 bpm 700 psi 40 bbls pumped @ 2 bpm 825 psi 60 bbls pumped @ 2 bpm 1000 psi 80 bbls pumped @ 2 bpm 1100 psi 96 bbls pumped @ 2 bpm 1250 psi Shut down pressure 625 psi 01:30 - 02:30 1.00 BUNCO RUNCMP Cut drlg line - U-Tube diesel -Shut in tubing pressure 300 psi - Shut in Annulus pressure 300 psi 02:30 - 03:00 0.50 BUNCO RUNCMP RU lubricator -Install BPV -Rig down Little Red pumping _ service 03:00 - 03:30 0.50 BUNCO RUNCMP Secure well -Clean cellar 03:30 - 11:00 7.50 BUNCO RUNCMP PJSM - LD 4" DP from derrick 1 X 1 11:00 - 12:00 1.OO BUNCO RUNCMP Prepare to move rig -Release rig from MPF-93 @ 12:00 Printed: 10/3!2005 3:11:14 PM • • Well: MPF-93 Accept: 06/22/2005 Field: Milne Pt. Unit / Kuparak River Sands Spud: 06/23/2005. API: 50-029-23266-00-00 Release: 09/29/2005 Permit: 205-087 Riq: Doyon 14 POST-RIG WORK 07/22/05 PERFORATE 2.5 13920-13887 HSD HMF 07/23/05 RUN BOTTOM HOLE PRESSURE AT 13880 THEN PERF 2.5 HSD 13866-79 13847-60 6 SPF 07/25/05 DUE TO THE ANOMALIES SEEN ON THE PERFORATING LOGS AND THE FACT THE SSD LEAKED DURING THE INITIAL COMPLETION. WE WILL PT THE IA TO INSURE INTEGRITY. T/1/0=0l0l0. PRESSURE ON IA TO 3000 PSI. HOLD PRESSURE FOR10 MINUTES. BLEED lA PRESSURE OWN TO 500 PSI. FWP=0/500/0. 07/26/05 T/I/0=S-(/500/240. MAINTAIN 3500 PSI ON IA DURING FRAC JOB. BLEED IA PRESSURE DOWN TO 500 PSI. FW P=S-1/500/260. FRAC KUPARUK A SAND PERFS 13847'-13920', W/178K # OF 16/20 CARBOLITE, YF 130LG GEL SYSTEM, PLACE 120K#S BEHIND PIPE, 58K# IN CASING, EST TOS AT 6983', FLUSH W/ 8 BBLS, WELL IS NOT FREEZE PROTECTED, MAX TREAT 8200 PSI, AVERAGE TREAT 6029 PS1, LOAD TO RECOVER 1296 BBLS, LOST SMALL PIECE OF TREE- SAVER CUP, 1 "X1 "X 0.025" 07/27/05 CTU #9 W/1.75" CT. MIRU. MU 2.0" BDJSN. RIH TO REVERSE OUT SAND. 07/28/05 XCTU 9 -CONTINUE REVERSING OUT FROM SURFACE TO 740' CTM AND RAN INTO HARD BRIDGE. SWAP DIRECTIONS ON COIL AND JET THROUGH, REVERSE COIL DIRECTION AND CONTINUE TO REVERSE. REVERSE DOWN TO 6950' CTM AND STARTED SEEING SEVERAL HARD SPOTS BUT WORK THROUGH WITHOUT PROBLEM. REVERSED DOWN TO -8900' AND DID NOT SEE SIGNIFICANT AMOUNTS OF CARBOLITE BUT DID SEE SEVERAL DUNES. CONTINUED REVERSING AND ENCOUNTERED HEAVY CARBOLITE AGAIN AT -11370' CTM. WELL STARTED TAKING FLUID AT PERFS REVERSED OUT TO 13950'. PUH ABOVE PERFS REGAINED 1:1 RETURNS BUT NO SAND TO SURFACE, STOP AT 13710 CIRCULATE TWO COIL VOL TO CLEAN WELL AND COIL WITH NO SAND TO SURFACE. POH AND FP WELL. 8/8/2005 XT/I/0=250/250/500 FREEZE PROTECT WELL. PUMPED 80 BBLS DIESEL DOWN IA, ASRC WILL U-TUBE. FINAL WHP=250!500/500 08/10/05 ATTEMPTED TO PULL JET PUMP, PICKUP WEIGHTS ABOUT 850#, BEAT ON PUMP AT 2000# FOR 40-45 M1N. STARTED BEATING DOWN ALSO. FINALLY RELEASEDATTEMPTED TO RBIH, STARTED BOUNCING AROUND AT ABOUT 3200' SLM. SAT DOWN AT 7200' SLM. LOST JARS. STARTED BLEEDING TUBING DOWN. TOOLS MOVING AT 2000# LINE PULL. TOOLS BEGAN TO MOVE ON THERE OWN AT 7098' SLM. CONFER W/COMPANY REP. NOTE** TUBING & IA PRESSURES CAME BACK UP TO 1250# AFTER BLEEDING. COMMUNICATION VERIFIED ACROSS JET PUMP M P F-93 • Page 2 • 8/18/2005 CTU # 9. W/1.75" COIL. PULL JET PUMP. RU AND DRIFT NEW COIL WITH 1.25" BALL. PERFORM BOP TEST. 8/19/2005 RIH WITH BAKER 4" GS SPEAR. HI T& WORK THROUGH ICE SLUSH AT 616' -1169'. SAND DUNE AT 4540' WORK THROUGH. IAP DROPS RAPIDLY. LATCH PUMP UP AT 13202' CTM .JARS GOING OFF INTERMITTENTLY. PUMP OFF AND LINE UP FOR FLO PRO SWEEP. RE-LATCH PUMP. HIT 20 (15K JAR LICKS), PULL FREE. POOH. DID NOT RECOVER JET PUMP. CUT 150' OF COIL OFF. RIH WITH FISHING STRING, ADDED A WT BAR AND ACCELERATOR. SET DOWN AT 13207' CTMD. HIT 33 JAR LICKS AT 15K OVER. PUMP OFF AND THEN LATCH BACK IN ONE MORE TIME. FINISH WITH 7 MORE LICKS. PUMP OFF AND PERFORM FCO FROM PUMP UP TO SURFACE WITH 5 BBLS FLO PRO CHASE OUT AT 80%. CUT 250' OF PIPE. RIH WITH FISHING STRING, ADDED ONE MORE WEIGHT BAR TO THE PREVIOUS TOOL STRING AND INSTALLED NEW BOW EN JARS. 8/20/2005 RIH W ITH BAKER 4" GS. LATCH INTO JET PUMP AND COMPLETE 50 (15K OVER JAR LICKS ), PUMP OFF.HAVE HIT A TOTAL OF 120 JAR LICKS. POOH, UNABLE TO JAR PUMP FREE. DISCUSS OPTIONS, ELECT TO RDMO. FREEZE PROTECT IA WITH 69 BBLS 50/50 METH. RIH AND CIRCULATE FREEZE PROTECT TUBING WITH 56 BBLS 50/50 METH. THERE IS COMMUNICATION BETWEEN IA AND TUBING. VERY LITTLE INJECTIVITY TO FORMATION. RDMO. NOTIFY PAD OP OF WELL STATUS. 09/06/05 DRIFT W/ 3.625" GAUGE RING TO 13,169' SLM. ASSIST SLICKLINE TO GET DOWNHOLE. PUMPED 155 BBLS DIESEL DOWN TBG. 09/07/05 ATTEPMTED TUBING PUNCH. UNABLE TO GET BELOW 8600'. ASSIST E-LINE PUMPED 35 BBLS DIESEL/EP-CUBE AND 95 BBLS DIESEL DOWN TBG 09/10/05 CTU #9 TUBING PUNCH/THAW ICE PLUG IN IA *'`'` CONTINUATION OF WSR ON 9-9-2005 "** RIH W.SLB TUBING PUNCH. TAG TOP OF JET PUMP @ 13215' CTMD. ATTEMPT TO FIRE GUNS FROM 13197' TO 13201' CTMD W/ E-FIRE FLOW FIRING HEAD - NO INDICATION THAT GUN FIRED. UNABLE TO ESTABLISH TXIA CIRCULATION. POOH TO INSPECT GUNS. GUNS FIRED. RIH W/ 2" JSN TO 5000' CTMD. CIRCULATE 160 DEG F 1%KCL WATER TO THAW ICE PLUG IN IA. 09/11 /05 CIRCULATED 226 BBLS OF 160 DEG F 1%KCL FROM 5000' CTMD, DOWN CT, UP TUBING. BLEED IA TO 0 PSI. PRESSURE UP TUBING TO 2250 PSI. NO INDICATION OF COMMUNICATION. CONTINUE CIRCULATING 173 BBLS 160 DEG F 1%KCL FROM 7000' CTMD. PRESSURE UP IA TO 3000 PSI W/ 15 BBLS OF NEAT MEOH. WORKED 4 MORE BBLS OF NEAT MEOH INTO IA BEFORE ICE PLUG BROKE FREE. CIRCULATED A TOTAL OF 78 BBLS NEAT MEOH DOWN IA, RETURNS UP TUBING TO MPF-94 FLOWLINE. FINAL CIRCULATING RATE WAS 1.7 BPM @ 520 PSI. POOH WHILE FREEZE PROTECTING COIL AND TUBING TO 6670' CTMD W/DIESEL. 10/12/05 SET DGLV IN EMPTY SPM @ 3165' MD PULLED DPSOV FROM SPM @ 13073' MD, SET DGLV 10/18/05 M P F-93 • Page 3 ATTEMPT TO PULL DGLV @ 3165' MD. PART WIRE PULLING THRU TOP GLM. RUN LIB, IMPRESSION OF WIRE. BEAT ON FISH W/BLIND BOX, IMPRESSION OF ROPE SOCKET. RUN 2"JUC SPLIT SKIRT, LATCH FISH @ 13163' SLM PUH TO 13098' SLM. SHEAR OFF. i 0119105 RUN 2"JUC, LATCH FISH @ 13099' SLM, JAR FEW X, SHEAR OFF. RUN 2"JDC, LATCH FISH @ 13099' SLM. BEAT FOR 1 HOUR. RUN 2"JDC, LATCH FISH @ 13122' SLM. BEAT FOR 1 HOUR. PU 5' RISER, ADD 5' OF STEM. RUN JDC. LATCH @ 13122' SLM. BEAT FOR 1 HOUR. RUN 2" JUC. BEAT DOWN FOR 145 MINUTES, FREEING FISH FROM XN NIPPLE. SHEAR TOOL WHILE TRYING TO WORK THRU NIPPLE. 10/21/05 PUMP 90 BBLS SOURCE WATER @ 170" INTO FLOWBACK TANK. ATTEMPT TO PULL FISH, NO LUCK. SET SLIP-STOP CATCHER SUB @ 3320' SLM. 10/23/05 RAN 2" JDC, SAT DOWN LATCHED FISH @ 13,135 SLM. JARRED 1 1/2 HRS. NO LUCK RAN 2 " JDC SAT DOWN @ 13,100 SLM, LATCHED FISH,JARRED 3 1/2 HRS. NO LUCK. RAN 2"JDC , LATCHED FISH @ 13,116 SLM. JARRED TWO HOURS. TOOL STRING BROKE AT THE KINLEY SW IVEL ABOVE THE KOT. 10/24/05 RAN 2.25 LIB SAT DOWN @13,123 BLM. NO FISH MARKS. RAN 2.0 LIB. SAT DOWN @ 13,154 BLM. REC MARKS OF FISH. RAN 2 "JUC SAT DOWN @ 13,167 BLM. LATCHED FISH,SHEARED OFF, RAN 2"JDC , TO 13,167 BLM JARRED UP 40 MIN. JDC SHEARED. 10/25/05 RAN 2 "JDC SAT DOWN @ 13.038 BLM. JARRED UP 45 MIN. NO LUCK. RAN 2"JDC SAT DOWN @ 13,171 BLM. JARRED UP,1 HR. NO LUCK RAN 2"JDC JARRED UP FOR ONE HOUR @ 13,157 BLM 10/26/05 RAN 2" JDC SAT DOWN @ 13,159 SLM. LATCHED SHEARED TOOL RAN i.90 OVERSHOT, GOT HUNG UP @ 1210 SLM. WIRE, BIRD NEST,POOH, RDMO. HEAT FLOW-BACK TANK. OFF- LOADED/CIRCULATE 90 BBLS OF 180'` SOURCE WATER INTO TANK. 10/28/05 SET CATCHER SUB @ 1500' SLM, PULL DGLV FROM 149' ,SET 1" DPSOV @ 149', 10/29/05 RUN 2" LIB TAG @ 1,641' SLM, RECOVERED TOOL STRING AND KOT, PULL SLIP STOP @ 1,668' SLM, RUN KOT W/ 1 1/4" LIB POCKET EMPTY, SET 1" DPSOV TO 3,165' (BK LATCH) 11/03/05 T/I/0=1400/1300/60 SPOT EMI-920 (LUBRICANT) IN TBG, PRE-COIL WORK. PUMPED 5 BBLS DIESEL, 62 BBLS EMI-920 LUBE, AND 25 BBLS METH INTO TBG. FINAL WHP'S=1500/1550/100 11/08/05 POH W/OVERSHOT... DID NOT RECOVER FISH... LEFT @ 13,190 (CTM) LD WEATHERFORD BHA.. RD f p~;'I? 'iTIVE ~. % car pear,/-Ur1 Milne Point Unit BPXA MPF-93 Job No. AKZZ3782167, Surveyed: 15 July, 2005 r ., r u 3 August, 2005 Your Ref: AP1500292326600 Surface Coordinates: 6035711.46 N, 541742.62E (70° 30' 30.5388" N, 149° 39' 30.4568" VV) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 45.07ft above Mean Sea Level ~RtLLintG srvRVtCES Survey Ref:svy1532 A Halliburton Company Halliburton Sperry-Sun Survey Report for MPF-93 • Your Ref: API 5002923 26600 Job No. AKZZ3782967, Surveye d: 95 July, 2005 6PXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 0.00 ~ 0.000 0.000 -45.07 0.00 0.00 N ~ 0.00E _ 6035711.46 N 541742.62E 0.00 ~ BP High Accuracy Gyro - Wellnav Gyro 77.00 0.320 253.000 31.93 77.00 0.06 S 0.21 W ' 6035711.40 N 541742.41E 0.416 -0.03 170.40 0.360 254.300 125.33 170.40 0.22 S 0.74 W 6035711.24 N 541741.88E 0.044 -0.11 260.40 1.660 336.840 215.31 260.38 0.90 N 1.52 W 6035712.35 N 541741.09E 1.836 1.12 351.00 3.800 348.440 305.81 350.88 5.05 N 2.64 W 6035716.50 N 541739.95E 2.428 5.39 . 468.92 6.430 353.280 423.25 468.32 15.44 N 4.20 W 6035726.88 N 541738.34E 2.258 15.89 558.64 7.020 353.230 512 °5 557.42 25.87 N 5.43 W 6035737.30 N 541737.04E 0.658 26.39 651.00 8.590 352.440 603.85 648.92 38.32 N 7.00 W 6035749.74 N 541735.40E 1.704 38.93 7'5.00 10.310 352.26C C~ ". ` r 741.64 53.61 P~! 9.06 W 6035765.02 f~l ~:-`.1 733.26E 1.830 54.36 Iv1WG+iIFR+MS+SAG 840.88 10.880 358.600 79Q82 835.89 71.16 N 10.44 W 6035782.56 N 541731.78E 1.352 71.92 936.12 14.390 2.390 88::':.7 4 928.81 91.98 N 10.16 W 6035803.38 N 541731.94E 3.785 92.46 1028.82 17.670 2.070 972.82 i 017.89 117.55 N 9.17 W 6035828.96 N 541732.79E 3.540 117.60 1122.74 20.370 1.710 106 i .61 1106.68 148.14 N 8.17 W 6035859.55 N 541733.62E 2.877 147.70 1218.66 22.380 359.850 1150.93 1196.00 183.09 N 7.72 W 6035894.51 N 541733.87E 2.211 182.19 1312.33 25.460 356.970 1236.54 1281.61 221.04 N 8.83 W 6035932.45 N 541732.55E 3.516 219.88 1404.07 30.130 355.620 1317.68 1362.75 263.71 N 11.63 W 6035975.10 N 541729.50E 5.136 262.49 1448.52 30.610 355.660 1356.03 1401.10 286.12 N 13.34 W 6035997.50 N 541727.67E 1.081 284.90 1498.37 30.030 356.190 1399.06 1444.13 311.22 N 15.13 W 6036022.59 N 541725.74E 1.281 309.99 1542.95 28.950 355.360 1437.86 1482.93 333.11 N 16.75 W 6036044.47 N 541724.00E 2.590 331.87 1593.59 29.340 353.050 1482.09 1527.16 357.64 N 19.24 W 6036068.99 N 541721.37E 2.351 356.50 1684 65 410 32 348 540 1560 25 1605 32 403.72 N 26 79 W 6036115.02 N 541713.56E 4.220 403.19 . 1779.43 . 35.120 . 346.330 . 1639.04 . 1684.11 455.12 N . 38.28 W 6036166.35 N 541701.78E 3.139 455.72 • 1825.30 35.770 346.080 1676.41 1721.48 480.95 N 44.63 W 6036192.15 N 541695.29E 1.452 482.21 1871.60 35.970 346.950 1713.93 1759.00 507.33 N 50.95 W 6036218.50 N 541688.82E 1.183 509.24 1917.89 34.770 346.560 1751.67 1796.74 533.41 N 57.09 W 6036244.54 N 541682.53E 2.638 535.95 1965.38 33.720 345.700 1790.93 1836.00 559.36 N 63.49 W 6036270.45 N 541675.99E 2.434 562.56 2060.50 36.920 343.820 1868.53 1913.60 612.39 N 77.98 W 6036323.41 N 541661.20E 3.553 617.17 2152.54 41.400 341.430 1939.89 1984.96 667.82 N 95.38 W 6036378.74 N 541643.49E 5.135 674.58 2198.53 42.630 341.430 1974.06 2019.13 697.00 N 105.19 W 6036407.86 N 541633.52E 2.674 704.90 2243.35 44.320 340.840 2006.58 2051.65 726.18 N 115.16 W 6036436.98 N 541623.38E 3.878 735.24 3 August, 2005 - 95:27 Page 2 of 7 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPF-93 Your Ref: API 500292326600 Job No. AKZZ3782167, Surveyed: 15 July, 2005 Milne Point Unit Measured Depth (ft) 2337.49 2431.97 2480.54 2523.29 2569.32 2618.55 2664.08 2710.82 2767.24 2813.55 2852.84 2901.16 2947.84 2995.19 3043.81 3090.91 3184.16 3276.59 3372.08 3465.20 3559.39 3654.03 3748.11 3843.34 3938.90. 4032.44 4128.06 4223.98 4317.65 4409.66 4501.47 4596.17 4689.75 4784.58 4879.42 Incl. 49.660 50.620 50.740 51.910 53.400 56.110 58.210 60.340 62.920 64.640 66.050 66.640 67.260 68.340 69.650 70.050 69.160 69.640 69.190 69.600 68.790 69.680 69.540 68.570 68.950 68.550 68.220 68.850 68.260 68.340 68.230 66.820 66.660 67.090 69.080 True Azim 341.690 343.380 343.200 343.190 343.540 344.600 345.310 34 7.0~' - 349.480 353.1 SC ~54.r :;i' 354.53E 354.270 353.240 353.050 353.440 352.720 352.640 353.730 353.500 354.170 354.260 355.020 354.000 352.540 352.620 353.450 353.770 352.860 352.320 352.740 351.960 350.710 350.060 Sub-Sea Depth (ft) 2070.77 2131.33 2162.10 2188.82 2216.74 2245.15 2269.84 2293.72 2320.53 234G.99 2357.38 2376.77 2395.04 2412 93 2430.36 2446.59 2479.08 2511.60 2545.18 2577.95 2611.40 2644.96 2677.74 2711.78 2746.40 2780.30 2815.53 2850.63 2884.87 2918.89 2952.86 2989.06 3026.02 3063.26 3098.66 Vertical Depth (ft) 2115.84 2176.40 2207.17 2233.89 2261.81 2290.22 2314.91 2338.79 2365.60 2386.06 2402.45 2421.84 2440.11 2458.00 2475.43 2491.66 2524.15 2556.67 2590.25 2623.02 2656.47 2690.03 2722.81 2756.85 2791.47 2825.37 2860.60 2895.70 2929.94 2963.96 2997.93 3034.13 3071.09 3108.33 3143.73 Local Coordinates Northings Eastings (ft) (ft) 791.36 N 137.24 W 860.53 N 159.00 W 896.52 N 169.80 W 928.47 N 179.45 W 963.53 N 189.93 W 1002.19 N 200.95 W 1039.13 N 210.88 W 1078.14 N 220.47 W 1126.74 N 230.56 W C;..74 N 237.25 W i 203.14 f`J 241.87 W 1247.16 Pd 246.53 W 1289.92 N 250.55 W 1333.55 N 254.82 W 1378.67 N 259.76 W 1422.57 N 265.04 W 1509.37 N 275.32 W 1595.26 N 285.75 W 1683.92 N 297.14 W 1770.47 N 307.48 W 1857.97 N 317.27 W 1945.95 N 326.77 W 2033.68 N 335.66 W 2122.23 N 343.97 W 2210.89 N 352.49 W 2297.46 N 362.71 W 2385.61 N 374.19 W 2474.22 N 385.01 W 2560.86 N 394.71 W 2645.77 N 404.67 W 2730.35 N 415.67 W 2817.12 N 427.04 W 2902.32 N 438.49 W 2988.54 N 451.63 W 3075.28 N 466.33 W Global Coordinates Northings Eastings (ft) (ft) 6036502. 03 N 541600. 93 E 6036571. 09 N 541578. 79 E 6036607. 01 N 541567. 78 E 6036638. 91 N 541557. 95 E 6036673. 91 N 541547. 28 E 6036712. 51 N 541536. 04 E 6036749. 39 N 541525. 90 E 6036788. 35 N 541516. 09 E 6036836. 89 N 541505. 73 E 60366- . 35 N 541498. 81 E 603691323 N 541493.99 E 6036957.21 N 541489.0,9 E 6036999.95 N 541484.83 E 6037043.56 N 541480.31 E 6037088.65 N 541475.11 E 6037132.52 N 541469.59 E 6037219.26 N 541458.82 E 6037305.08 N 541447.91 E 6037393.68 N 541436.03 E 6037480.17 N 541425.20 E 6037567.61 N 541414.91 E 6037655.54 N 541404.92 E 6037743.22 N 541395.54 E 6037831.72 N 541386.73 E 6037920.33 N 541377.71 E 6038006.85 N 541367.01 E 6038094.93 N 541355.03 E 6038183.48 N 541343.71 E 6038270.07 N 541333.52 E 6038354.92 N 541323.09 E 6038439.44 N 541311.62 E 6038526.13 N 541299.75 E 6038611.27 N 541287.83 E 6038697.41 N 541274.20 E 6038784.07 N 541259.02 E Dogleg Vertical Rate Section Comment (°/100ft) 5.711 802.98 1.708 874.63 0.378 911.83 2.737 944.86 3.293 981.10 5.779 1020.97 4.795 1058.98 5.558 1098.99 5.949 1148.55 6.057 19C.C9 4.594 1225.78 3.164 1270.OC 1.385 1312.88 2.337 1356.66 3.342 1402.01 0.930 1446.21 1.032 1533.57 0.895 1620.05 0.478 1709.42 1.181 1796.54 0.890 1884.52 1.150 1972.93 0.174 2061.01 1.262 2149.80 1.071 2238.74 1.516 2325.87 0.354 2414.75 1.039 2503.98 0.706 2591.10 0.923 2676.54 0.559 2761.81 1.544 2849.30 0.785 2935.26 1.294 3022.47 2.192 3110.44 ~r~XF~ • 3 Augusf, 2005 - 75;27 Page 3 of 7 DrillQuest 3,03.06.008 Halliburton Sperry-Sun Survey Reporf for MPF-93 Your Ref: API 500292326600 Job No. AKZZ3782167, Surveyed: 15 July, 2005 Milne Poinf Unit E3F:CA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 4972.47 68.780 349.820 3132.11 3177.18 3160.78 N 481.49 W ~ 6038869.48 N 541243.37E 0.402 3197.24 5068.18 69.270 350.520 3166.37 3211.44 3248.83 N 496.75 W 6038957.45 N 541227.62E 0.854 3286.58 5161.57 69.420 350.280 3199.32 3244.39 3334.99 N 511.32 W 6039043.53 N 541212.56E 0.289 3373.96 5256.00 68.440 350.860 3233.26 3278.33 3421.92 N 525.76 W 6039130.37 N 541197.64E 1.186 3462.06 5347.70 69.670 350.800 3266.04 3311.11 3506.46 N 539.41 W 6039214.84 N 541183.51E 1.343 3547.70 5440.03 69.680 349.560 3298.11 3343.18 3591.77 N 554.18 W 6039300.06 N 541168.27E 1.259 3634.26 5534.37 69.410 349.560 3331.08 3376.15 3678.70 N 570.19 W 6039386.90 N 541151.76E 0.286 3722.60 5629.28 68.900 349.260 3364.86 3409.9.' 3765.89 N 586.49 W 6039473.99 N 541134.97E 0.613 3811.25 5722.47 68.890 349.740 3398.41 3443.; 3851.37 N 602.34 W 6039559.39 N 541118.65E ':-.481 3898.14 5817.02 68 ~:Z .;4.830 3432.67 ?~' ~ .' ~-;. r.97 ~I 618.68 ~:V . Ci396~'.5.89 N 541101 82 E. ;~8~ 3986.21 5910.60 68.2F,0 249.150 3467.03 3512.1 ~ 402 3.42 N 635.26 W 6039731.24 N 541084.77E ~~~ ' 55 4073.17 8004.76 69.110 349.930 3501.24 3548.3' 4 i 09.68 N 651.18 ~,N 6039817.42 N 541068.36E i 72 4160.85 6098.46 69.440 350.530 3534.40 3579.=~' 4196.05 N 666.05 W 6039903.70 N 541053.00E 0.695 4248.47 6192.08 69.620 356.180 3567.14 361221 4282.52 N 680.75 W 6039990.08 N 541037.82E 6.400 4336.16 6286.68 68.620 351.820 3600.86 3645.93 4369.81 N 694.58 W 6040077.30 N 541023.50E 1.934 4424.54 6378.34 68.440 352.050 3634.41 3679.48 4454.27 N 706.54 W 6040161.69 N 541011.06E 0.305 4509.84 6473.09 68.630 351.280 3669.08 3714.15 4541.51 N 719.33 W 6040248.86 N 540997.79E 0.782 4598.01 6566.19 68.950 351.140 3702.76 3747.83 4627.29 N 732.59 W 6040334.56 N 540984.04E 0.371 4684.81 6660.57 67.840 353.130 3737.52 3782.59 4714.20 N 744.60 W 6040421.40 N 540971.54E 2.286 4772.54 6752.08 67.380 353.210 3772.37 3817.44 4798.21 N 754.66 W 6040505.36 N 540961.01E 0.509 4857.11 6844.63 67.110 354.140 3808.17 3853.24 4883.04 N 764.07 W 6040590.13 N 540951.13E 0.971 4942.39 6935.24 67.820 353.590 3842.90 3887.97 4966.25 N 773.01 W 6040673.29 N 540941.71E 0.963 5026.00 7030.24 67.880 353.510 3878.72 3923.79 5053.68 N 782.90 W 6040760.66 N 540931.34E 0.100 5113.93 7123.00 67.990 353.090 3913.56 3958.63 5139.06 N 792.93 W 6040845.98 N 540920.83E 0.436 5199.85 7217.68 67.300 352.360 3949.57 3994.64 5225.92 N 804.01 W 6040932.78 N 540909.25E 1.020 5287.39 7313.53 68.430 352.090 3985.69 4030.76 5313.89 N 816.02 W 6041020.68 N 540896.75E 1.207 5376.16 7406.65 68.160 352.960 4020.13 4065.20 5399.67 N 827.28 W 6041106.39 N 540885.01E 0.915 5462.66 7499.30 66.380 353.160 4055.93 4101.00 5484.49 N 837.61 W 6041191.16 N 540874.21E 1.931 5548.08 7593.55 66.650 351.630 4093.49 4138.56 5570.17 N 849.05 W 6041276.77 N 540862.29E 1.516 5634.50 7687.06 68.070 350.500 4129.48 4174.55 5655.42 N 862.46 W 6041361.95 N 540848.40E 1.884 5720.80 7779.93 68.610 350.560 4163.76 4208.83 5740.56 N 876.66 W 6041447.00 N 540833.72E 0.585 5807.11 7874.59 70.560 350.780 4196.78 4241.85 5828.10 N 891.04 W 6041534.46 N 540818.85E 2.071 5895.81 7967.26 69.680 350.340 4228.29 4273.36 5914.06 N 905.33 W 6041620.34 N 540804.07E 1.049 5982.95 8061.92 69.150 349.070 4261.57 4306.64 6001.25 N 921.16 W 6041707.44 N 540787.75E 1.375 6071.52 8155.70 68.270 347.880 4295.63 4340.70 6086.87 N 938.62 W 6041792.96 N 540769.81E 1.509 6158.78 • v 3 August, 2005 - 15:27 Page 4 of 7 DrillQuest 3.03.06.008 Milne Point Unif Measured True Sub-Sea 1:'ertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 8240.15 68.390 347.790 4326.81 4371.88 8330.48 67.450 348.000 4360.76 4405.83 8425.01 66.540 348.540 4397.71 4442.78 8518.65 69.210 354.250 4433.00 4478.07 8611.32 70.330 357.440 4465.05 4510.12 8705.76 70.850 356.940 4496.43 4541.50 8799.57 71.240 356.660 4526.90 4571.97 8894.48 69.780 354.780 4558.57 4603.64 8988.74 ~=8.670 353.610 4592.C i =637.08 9G8<.~: ~ ~;.8~C 352.6'!0 46~r; ~" ..71.22 9177.3' ',?.460 352.310 4661 ^ ~ ~'~06.38 9270.95 ('-6.140 351.820 4698.1 c -.74325 9363.60 65.870 351.480 4735.86 4780.93 9458.85 67.140 352.280 4773.83 4818.90 9551.62 68.220 352.830 4809.06 4854.13 9645.09 68.210 351.970 4843.75 4888.82 9740.39 68.490 351.290 4878.91 4923.98 9834.39 68.960 351.250 4913.02 4958.09 9929.83 68.530 350.840 4947.62 4992.69 10026.05 67.720 350.420 4983.47 5028.54 10118.79 10214.71 10310.57 10404.18 10495.96 10590.50 10685.96 10778.54 10873.86 10968.12 11061.57 11157.10 11251.82 11345.28 11435.92 Nalliburton Sperry-Sun Survey Report for MPF-93 Your Ref.• API 500292326600 Job No. AKZZ3782167, Surveyed: 15 July, 2005 t_ocal Coordinates Global Coordinates .Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 6163.58 N 955.16 W 6041869.58 N 540752.84 E 6245.43 N 972.71 W 6041951.32 N 540734.83 E 6330.62 N .990.40 W 6042036.42 N 540716.66 E 6416.34 N 1003.33 W 6042122.06 N 540703.25 E 6503.05 N 1009.62 W 6042208.74 N 540696.47 E 6592.02 N 1013.99 W 6042297.68 N 540691.60 E 6680.60 N 1018.94 W 6042386.23 N 540686.15 E 6769.82 N 1025.61 W 6042475.41 N 540678.98 E 6857.49 N 103°,.52 W 6042563.03 N 540669.58 E 6944.63 N I ~.',_ '_ ; .. 6042650.' 1 N . -0~..~.6~. i_ 7031.50 N 10 6.~:" bN 6042736.91 N 540646.5? '` 7116.72 N 106c.4 ~ W 6042822.06 N 540634.22 E 7200.46 N 108C.72 W 6042905.74 N 540621.46 E 7286.94 N 1093.05 W 6042992.14 N 540608.64 E 7372.03 N 1104.17 W 6043077.17 N 540597.04 E 7458.06 N 1115.65 W 6043163.14 N 540585.08 E 7545.70 N 1128.54 W 6043250.70 N 540571.69 E 7632.28 N 1141.84 W 6043337.20 N 540557.91 E 7720.14 N 1155.68 W 6043424.98 N 540543.57 E 7808.24 N 1170.22 W 6043513.00 N 540528.54 E 7892.61 N 1185.00 W 6043597.29 N 540513.29 E 7979.88 N 1200.21 W 6043684.47 N 540497.59 E 8067.46 N 1214.92 W 6043771.97 N 540482.39 E 8153.29 N 1229.42 W 6043857.71 N 540467.41 E 8237.75 N 1243.38 W 6043942.10 N 540452.97 E 8324.92 N 1257.12 W 6044029.18 N 540438.74 E 8412.93 N 1271.01 W 6044117.12 N 540424.36 E 8498.45 N 1284.54 W 6044202.56 N 540410.34 E 8586.75 N 1297.71 W 6044290.78 N 540396.67 E 8674.05 N 1310.64 W 6044378.01 N 540383.25 E 8760.22 N 1323.25 W 6044464.11 N 540370.17 E 8847.61 N 1335.88 W 6044551.42 N 540357.04 E 8933.59 N 1348.17 W 6044637.33 N 540344.27 E 9018.31 N 1359.93 W 6044721.99 N 540332.04 E 9100.95 N 1371.51 W 6044804.56 N 540319.99 E FsPXA Dogleg Vertical Rate Section Comment (°/100ft) 0.173 6237.11 1.063 6320.66 1.097 6407.54 6.327 6494.23 3.449 6580.91 0.743 6669.53 0.503 6757.86 2.419 6847.07 1.653 6935.09 1.002 7022.82 1.470 7110.43 1.490 7196.47 0.444 7281.11 1.540 7368.46 1.287 7454.26 0.854 7541.04 0.725 7629.61 0.502 7717.21 0.603 7806.15 0.934 7895.43 0.896 7981.07 0.913 8069.63 0.435 8158.42 0.706 8245.46 0.527 8331.06 0.398 8419.30 0.408 8508.40 0.655 8594.98 0.661 8684.26 0.550 8772.51 1.603 8859.60 1.211 8947.89 1.388 9034.74 0.708 9120.27 1.055 9203.71 3 August, 2005 - 15:27 Page 5 of 7 DrillQuest 3.03.06.008 67.210 67.680 68.090 68.750 68.990 68.940 69.010 69.520 69.460 69.400 68.080 67.050 65.930 66.540 67.490 349.710 350.510 350.430 350.390 350.840 351.240 350.830 351.180 351.850 351.300 352.060 351.490 352.240 351.960 352.080 5019.01 5055.80 5091.89 5126.32 5159.41 5193.34 5227.59 5260.37 5293.76 5326.88 5360.77 5397.23 5435.01 5472.67 5508.07 5064.08 5100.87 5136.96 5171.39 5204.48 5238.41 5272.66 5305.44 5338.83 5371.95 5405.84 5442.30 5480.08 5517.74 5553.14 • Halliburton Sperry-Sun Survey Report for MPF-93 Your Ref: API 500292326600 Job No. AKZ7_4 782167, Surveyed: 15 July, 2005 Milne Point Unit P~irasurec' True 3ua-8ea Vertical t_acal Cc;., rdinates Cepth Incl. Azim. Cepth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 11528.44 68.020 352.630 5543.09 5588.16 9185.82 N 1382.90 W 11622.57 68.560 351.640 5577.91 5622.98 9272.45 N 1394.87 W 11717.90 68.950 352.320 5612.46 5657.53 9360.43 N 1407.27 W 11810.97 68.880 351.400 5645.94 5691.01 9446.39 N 1419.56 W 11906.31 67.810 351.730 5681.12 5726.19 9534.04 N 1432.56 W 11998.20 67.090 351.610 5716.36 5761.43 9618.01 N 1444.86 W 12093.45 65.590 351.160 5754.58 5799.65 9704.27 N 1457.92 W 17_ i 87.05 63.250 350.810 5794.99 5840.06 9787.65 N 1471.15 W ~C.94 60.810 350.030 58; ` C~3 5884.10 9869.'11 ii 1484.94 W _:.5; 5.8.520 350.180 593202 ~~~ C.C~ I ~2C2 V~,~ ~.3- 56.170 348.59G 5~:" .°8 5981.95 10026.65 h! 1513.35 W . ~,~3.40 52.650 348.530 5c: ~.~IB 6037.25 10102J9 iJ 1528.68 W 12E ,5.42 47.820 348.780 6051.02 6096.09 10171.72 N 1542.59 W 12; =15.85 42.900 349.120 61 i 6.65 6 i 61.72 10236.94 N 1555.34 W 12842.75 37.980 348.510 6188.09 6233.16 10296.68 N 1567.13 W 12933.25 34.140 349.020 6261.24 6306.31 10348.91 N 1577.52 W 13026.34 29.230 349.610 6340.43 6385.50 10396.94 N 1586.60 W 13119.34 24.140 350.790 6423.50 6468.57 10438.08 N 1593.74 W 13211.96 19.610 352.730 6509.43 6554.50 10472.21 N 1598.74 W 13306.82 17.390 355.090 6599.38 6644.45 10502.13 N 1601.97 W 13401.92 17.000 359.370 6690.23 6735.30 10530.19 N 1603.34 W 13495.66 17.210 359.600 6779.83 6824.90 10557.76 N 1603.59 W 13522.75 17.230 358.970 6805.70 6850.77 10565.78 N 1603.69 W 13547.29 17.420 359.320 6829.13 6874.20 10573.08 N 1603.80 W 13643.47 17.430 0.570 6920.90 6965.97 10601.88 N 1603.83 W 13742.15 17.590 1.840 7015.00 7060.07 10631.57 N 1603.20 W 13836.44 17.440 3.050 7104.92 7149.99 10659.92 N 1601.99 W 13935.04 16.190 6.490 7199.31 7244.38 10688.33 N 1599.65 W 14030.29 15.770 9.580 7290.88 7335.95 10714.29 N 1596.00 W 14127.48 16.830 8.740 7384.16 7429.23 10741.22 N 1591.66 W 14183.00 16.830 8.740 7437.30 7482.37 -- 10757.11 N 1589.22 W Global Coordinates Northings Eastings (ft) (ft) 6044889.36 N 540308.12 E 6044975.92 N 540295.66 E 6045063.83 N 540282.77 E 6045149.73 N 540270.00 E 6045237.30 N 540256.51 E 6045321.20 N 540243.74 E 6045407.38 N 540230.19 E 6045490.69 N 540216.49 E 6045572.37 N 540202.24 E 6045652.97 Iv ; ~ 018 7 .7'I E 6045729.45 N 6045805.1 G N 6045874.35 N 6045939.50 N 6045999.17 N ;40172.95 E 540157.20 E 540142.89 E 540129.78 E 540117.65 E 6046051.35 N 6046099.32 N 6046140.42 N 6046174.52 N 6046204.42 N 6046232.47 N 6046260.04 N 6046268.06 N 6046275.36 N 6046304.16 N 6046333.85 N 6046362.20 N 6046390.63 N 6046416.61 N 6046443.56 N 6046459.46 N All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to MPF-93. Northings and Eastings are relative to MPF-93. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. 540106.97 E 540097.62 E 540090.25 E 540085.05 E 540081.66 E 540080.13 E 540079.73 E 540079.58 E 540079.43 E 540079.24 E 540079.70 E 540080.75 E 540082.93 E 540086.44 E 540090.63 E 540092.98 E Dogleg 1%eriicai Rate Section (°/100ft) 0.794 9289.33 1.133 9376.78 0.781 9465.62 0.925 9552.46 1.167 9641.07 0.793 9725.93 1.633 9813.17 2.523 9897.59 2.700 998C.~": `: 2.417 '~~OUc;2.~~ 2.923 1 C 140.2 3.704 1 C2° 7.35 5.253 10288.02 5.272 10354. 5.256 10415.25 4.256. 10468.45 5.285 10517.30 5.502 10559.04 4.952 10593.53 2.469 10623.60 1.392 10651.55 0.235 10678.84 0.692 10686.79 0.883 10694.03 0.389 10722.51 BPXA Comment 0.420 10751.76 0.418 10779.61 1.620 10807.36 0.996 10832.48 1.117 10858.46 0.000 10873.80 Projected Survey • • 3 August, 2005 - 95:27 Page 6 of 7 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPF-93 Your Ref: API 500292326600 Job i`do. AKZZ3782967, Surveyed: 75 July, 2005 Milne Point Unif The Dogleg Severity is in Cegrees per 100 feet (US Survey). Vertical Section is from MPF-93 and calculated along an Azimuth of 351.400° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14183.OOft., The Bottom Hole Displacement is 10873.86ft., in the Direction of 351.596° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 14183.00 7482.37 i G757.11 IV 1589.22 W F=rojected Survey „~. n- ~~~irv~e'~r tool pr~a~r~ .3- .~: _~: From To Measured Vertical Measured Vertical Depth Depth L!epth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 745.00 741.64 BP High Accuracy Gyro - Wellnav Gyro 745.00 741.64 14183.00 7482.37 MWD+IIFR+MS+SAG t3Fkn • C~ 3 August, 2005 - 95:27 Page 7 of 7 DriilQuest 3.03.06.008 ~~~~~LW Milne Point Unit BPXA MPF-93 (mwd) Job No. AKMW3782167, Surveyed: 15 July, 2005 ~, ~.,. ~ ~ ,. 3 August, 2005 Your Ref: API 500292326600 Surface Coordinates: 6035711.46 N, 541742.62E (70° 30' 30.5388" N, 149° 39' 30.4568" VV) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 45.07ft above Mean Sea Level ~RILL[N~z SERVIC`EIS A Halliburton Company Survey Ref: svy1533 • Halliburton Sperry-Sun ' Survey Report for MPF-93 (mwd) Your Ref: API 5002923 26600 Job No. AKMW3782967, Surveyed: 75 July, 2005 FsfiXA Milne Point Unit Measured True Sub-sea Vertical Local Coo rdinates Global Coo rdinates Dogleg Vertical Depth incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 0.00 0.000 0.000 -45.07 0.00 0.00 N 0.00E 6035711.46 N 541742.62E ~ 0.00 BP High Accuracy Gyro - Wellnav Gyro 77.00 0.320 253.000 31.93 77.00 0.06 S 0.21 W 6035711.40 N 541742.41E 0.416 -0.03 170.40 0.360 254.300 125.33 170.40 0.22 S 0.74 W 6035711.24 N 541741.88E 0.044 -0.11 260.40 1.660 336.840 215.31 260.38 0.90 N 1.52 W 6035712.35 N 541741.09E 1.836 1.12 351.00 3.800 348.440 305.81 350.88 5.05 N 2.64 W 6035716.50 N 541739.95E 2.428 5.39 . 468.92 6.430 353.280 423.25 468.32 15.44 N 4.20 W 6035726.88 N 541738.34E 2.258 15.89 558.64 7.020 353.230 512.35 557.42 25.87 N 5.43 W 6035737.30 N 541737.04E 0.658 26.39 651.OC 8.5~G 352.-440 603.85 648.92 38.32 N 7.00 W 6035749.74 N 541735.40E 1.704 38.93 745.00 1 C ",' C 352 260 696.57 741.6? 53.61 N 9.06 '~-~~ 6035765.02 N 541733.26E 1.830 54.36 MWD N ayn~;ic 840.88 11.180 359.110 790.77 835.84 71.41 N 10.36 W 6035782.81 N 541731.86E 1.610 72.15 936.12 14.7CCi 3.230 883.58 928.65 92.71 N 9.82 ~1~ 6035804.12 N 541732.28E 3.818 93.14 1028.82 17.~i9(! ?_.770 972.52 101 7.55 118.76 N 8.4i ~'V 6035830.17 N 541733.49E 3.552 118.69 1122.74 20.700 2.090 1061.13 11 G6.20 149.84 N 7.16 W 6035861.26 N 541734.62E 2.895 149.23 1218.66 22.720 0.240 1150.25 1195.32 185.31 N 6.47 W 6035896.73 N 541735.11E 2.223 184.19 1312.33 25.810 357.080 1235.63 1280.70 223.78 N 7.43 W 6035935.19 N 541733.93E 3.577 222.37 1404.07 30.490 355.830 1316.50 1361.57 266.96 N 10.14 W 6035978.36 N 541730.98E 5.141 265.47 1448.52 30.950 355.920 1354.71 1399.78 289.61 N 11.77 W 6036000.99 N 541729.22E 1.040 288.11 1498.37 30.380 356.480 1397.59 1442.66 314.97 N 13.46 W 6036026.35 N 541727.39E 1.279 313.44 1542.95 29.290 355.660 1436.26 1481.33 337.10 N 14.98 W 6036048.47 N 541725.75E 2.611 335.55 1593.59 29.690 353.660 1480.34 1525.41 361.92 N 17.30 W 6036073.27 N 541723.29E 2.098 360.43 1684.65 32..780 348.780 1558.21 1603.28 408.53 N 24.59 W 6036119.84 N 541715.74E 4.384 407.61 1779.43 35.470 346.610 1636.66 1681.73 460.46 N 35.95 W 6036171.71 N 541704.08E 3.115 460.66 • 1825.30 36.130 346.470 1673.87 1718.94 486.55 N 42.20 W 6036197.77 N 541697.69E 1.450 487.39 1871.60 36.320 347.020 1711.22 1756.29 513.19 N 48.47 W 6036224.37 N 541691.27E 0.813 514.66 1917.89 35.130 346.780 1748.80 1793.87 539.51 N 54.60 W 6036250.66 N 541684.99E 2.589 541.61 1965.38 34.080 345.890 1787.88 1832.95 565.72 N 60.96 W 6036276.83 N 541678.48E 2.454 568.47 2060.50 37.290 344.450 1865.14 1910.21 619.34 N 75.19 W 6036330.37 N 541663.95E 3.488 623.62 2152.54 41.780 341.930 1936.11 1981.18 675.38 N 92.18 W 6036386.31 N 541646.64E 5.179 681.57 2198.53 42.990 342.260 1970.08 2015.15 704.88 N 101.71 W 6036415.76 N 541636.95E 2.675 712.17 2243.35 44.680 341.810 2002.40 2047.47 734.41 N 111.29 W 6036445.23 N 541627.20E 3.834 742.79 3 August, 2005 - 95:28 Page 2 of 7 DrillQuest 3.03.06.008 Milne Paint Unit Py"ensure:' [Je ptil (ft) 2337.49 2431.97 2480.54 2523.29 2569.32 2618.55 2664.08 2710.82_ ~~ ...,. 285284 24'01 " 294- .<,,-. 2995.1 ~' 3043.81 3090.91 3184.16 3276.59 3372.08 3465.20 3559.39 3654.03 3748.11 3843.34 3938.90 incl. 50.040 50.960 51.110 52.280 53.780 56.490 58.570 60.730 6:i.2 J~' 65.010 66.430 67.000 Ei7.640 68.730 70.030 70.420 69.520 70.020 69.570 69.970 69.160 70.030 69.900 68.920 69.330 True Azim. 342.480 343.930 343.900 343.970 344.130 345.420 346.220 348.000 350.510 352.440 354.200 355.270 354.920 354.270 353.490 353.570 353.750 352.940 352.870 354.600 354.260 354.990 354.370 355.460 354.450 Sub-Sea Depth (ft) 2066.15 2126.25 2156.79 2183.29 2210.97 2239.11 2263.55 2287.17 2309.96 23.~,~.5& 2349.73 2368.84 2386.8 2404.43 2421.55 2437.49 2469.43 2501.39 2534.37 2566.57 2599.46 2632.45 2664.68 2698.18 2732.23 4032. 44 68. 920 353.070 2765. 56 4128. 06 68. 600 353 .060 2800. 20 4223. 98 69. 230 354 .310 2834. 71 4317. 65 68. 630 354 .200 2868. 38 4409. 66 68. 720 353 .260 2901. 84 4501. 47 68. 370 352 .830 2935. 43 4596. 17 66. 940 353 .200 2971. 43 4689. 75 66. 780 352 .530 3008. 20 4784. 58 67. 230 351 .240 3045. 25 4879. 42 69. 200 350 .570 3080. 45 Hailiburton Sperry-Sun Survey Report for MPF-93 (mwd) Your Ref.• AP/ 500292326600 Job No. AKlVtW37£t2107, Surveyed: 15 July, 2005 BP.YA Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 2111.22 800.30 N 132.50 W 2171.32 870.09 N 153.56 W 2201.86 906.38 N 164.02 W 2228.36 938.62 N 173.30 W 2256.04 973.98 N 183.41 W 2284.18 1012.95 N 194.01 W 2308.62 1050.19 N 203.41 W 2332.24 1089.50 N 212.40 W 235--^:,97 1131.50 N 2:'0.36 W 2378.65 1179.84 N __2'.60 1N 2394.80 1215.41 N 231.76 W 2413.91 1259.60 N :;5.84 VV 2431.90 1302.51 N '%:9.52 W 2449.50 1346.28 N 243.66 VV 2466.62 1391.52 N 248.51 W 2482.56 1435.56 N 253.51 W 2514.50 1522.63 N 263.18 W 2546.46 1608.78 N 273.23 W 2579.44 1697.70 N 284.30 W 2611.64 1784.55 N 293.84 W 2644.53 1872.40 N 302.40 W 2677.52 1960.71 N 310.71 W 2709.75 2048.71 N 318.90 W 2743.25 2137.51 N 326.81 W 2777.30 2226.45 N 334.66 W 2810.63 2313.33 N 344.16 W 2845.27 2401.80 N 354.92 W 2879.78 2490.75 N 364.76 W 2913.45 2577.72 N 373.51 W 2946.91 2662.92 N 382.87 W 2980.50 2747.73 N 393.22 W 3016.50 2834.67 N 403.87 W 3053.27 2920.05 N 414.56 W 3090.32 3006.47 N 426.88 W 3125.52 3093.43 N 440.81 W Global Coordinates Northings Eastings (ft) (ft) 6036511. 01 N 541605.63 E 6036580. 68 N 541584.18 E 6036616. 91 N 541573.51 E 6036649. 09 N 541564.04 E 6036684. 39 N 541553.74 E 6036723. 30 N 541542.92 E 6036760. 49 N 541533.31 E 6036799. 75 N 541524.10 E 6036841. 71 N 541515.90 E 6036890. 00 N 541508.39 E 6036925. 54 N 541504.03 E 6036969. 72 N ..541499.71 E 6037012. 61 N 541495 79 E 6037056. 35 N 541491.40 E 6037101. 56 N 541486.29 E 6037145. 57 N 541481.05 E 6037232. 59 N 541470.89 E 6037318. 68 N 541460.35 E 6037407. 54 N 541448.78 E 6037494. 33 N 541438.76 E 6037582. 13 N 541429.70 E 6037670. 39 N 541420.90 E 6037758. 35 N 541412.21 E 6037847. 10 N 541403.81 E 6037935. 99 N 541395.45 E 6038022.82 N 541385.47 E 6038111.23 N 541374.21 E 6038200.12 N 541363.87 E 6038287.04 N 541354.63 E 6038372.18 N 541344.79 E 6038456.94 N 541333.97 E 6038543.82 N 541322.83 E 6038629.14 N 541311.66 E 6038715.49 N 541298.85 E 6038802.36 N 541284.44 E Dogleg Vertica! Rate Secticn Ccr~~ment (°/100ft) 5.718 811.12 1.533 883.27 0.313 920.72 2.740 953.98 3.271 990.45 5.910 1030.57 4.803 1068.80 5.670 1109.02 6.993 1151.73 4.501 1200.60 5.453 1236.40 2.351 1280.70 1.536 1323.69 2.631 1367.58 3.067 1413.04 0.843 1457.33 0.982 1544.87 0.984 1631.55 0.476 1721.13 1.795 1808.43 0.924 1896.57 1.169 1985.12 0.634 2073.37 1.486 2162.34 1.077 2251.46 1.446 2338.78 0.335 2427.87 1.382 2517.29 0.650 2604.59 0.957 2690.23 0.579 2775.64 1.553 2863.19 0.680 2949.21 1.339 3036.50 2.178 3124.56 • • 3 August, 2005 - 15:28 Page 3 of 7 DrildQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPF-93 (mwd) Your Ref.• API 500292326600 Job IVo. ~,,~iM?h'3782167, Surveyed: 75 July, 2GU5 N(iine Point Unit Pa+ieasured Depth (ft) 4972.47 5068.18 5161.57 5256.00 5347.70 5440.03 5534.37 5629.28 ~1 .G~ Incl 68.900 69.400 69.560 68.550 69.780 69.820 69.550 69.040 69.000 68.760 5910.60 6004.76 6098.46 6192.08 6286.68 6378.34 6473.09 6566.19 6660.57 6752.08 6844.63 6935.24 7030.24 7123.00 7217.68 7313.53 7406.65 7499.30 7593.55 7687.06 7779.93 7874.59 7967.26 8061.92 8155.70 68.410 69.240 69.570 69.760 68.730 68.570 68.770 69.090 67.950 67.510 67.250 67.950 68.010 68.110 67.440 68.580 68.280 66.500 66.790 68.200 68.740 70.690 69.680 69.150 68.270 True A~ir~. 350.410 351.060 350.870 351.610 351.570 350.280 350.110 349.750 3~G.3~0 349 .,", 349.770 356.950 351.91E 351.460 352.020 352.550 351.690 351.65E 353.670 353.760 355.120 354.350 354.020 353.810 352.940 352.510 353.460 353.690 352.420 351.240 351.360 351.440 350.890 349.580 348.700 ~:'~..Cea i~' ~Ni}1 (ft) 3113.72 3147.78 3180.52 3214.27 3246.89 3278.77 3311.53 3.'.,45.08 %; ;6.68 .,-, ~J.7u . , ', 3.66 3:;46.19 3579.72 3613.09 ^F,n.7.55 3 ~ ~ i .02 C715.58 3 r 50.26 3785.86 3820.39 3856.01 3890.67 3926.48 3962.37 3996.60 4032.22 4069.59 4105.38 4139.46 4172.28 4203.69 4236.97 4271.02 Vertical Depir (ft) 3158.79 3192.85 3225.59 3259.34 3291.96 3323.84 3356.60 3390.15 3423.52 3457.59 3491.75 3525.77 3558.73 3591.26 3624.79 3658.16 3692.62 3726.09 3760.65 3795.33 3830.93 3865.46 3901.08 3935.74 3971.55 4007.44 4041.67 4077.29 4114.66 4150.45 4184.53 4217.35 4248.76 4282.04 4316.09 Local Coordinates Northings Eastings (ft) (ft) 3179.13 N ~ 455.16 W 3267.41 N 469.56 W 3353.79 N 483.30 W 3440.94 N 496.73 W 3525.72 N 509.27 W 3611.29 N 522.93 W 3698.47 N 538.00 W 3785.88 N 553.52 W 3571.5E ?~~ 568.56 W •~ J, - .;8.' „ 533.92 W 4044.14 ~.' 599.54 W 4130.,'0 f'.' 614.24 W 4217.43 i~~~ 627.31 W 4304.29 h! 640.00 W 4391.84 N 652.71 W 4476.43 N 664.17 W 4563.86 N 676.27 W 4649.82 N 688.86 W 4736.91 N 700.09 W 4821.09 N 709.36 W 4906.11 N 717.63 W 4989.53 N 725.32 W 5077.15 N 734.25 W 5162.71 N 743.37 W 5249.77 N 753.48 W 5337.92 N 764.73 W 5423.87 N 775.31 W 5508.86 N 784.88 W 5594.75 N 795.34 W 5680.26 N 807.63 W 5765.66 N 820.69 W 5853.44 N 833.97 W 5939.59 N 847.36 W 6026.92 N 862.39 W 6112.73 N 878.85 W Global Gor,rdinates Northings Eastin gs (ft) (ft) 6038887.98 N 541269 .60 E 6038976.18 N 541254 .70 E 6039062.48 N 541240 .48 E 6039149.56 N 541226 .56 E 6039234.27 N 541213 .55 E 6039319.75 N 541199 .40 E 6039406.85 N 541183 .85 E 6039494.17 N 541167 .83 E 6039579.'C 's 54 i 152 32 E 60396c,C ~:: ; ' 541 i 36 .46 E 6039752.17 N 541120 .37 E 6039833.64 '. 54'i 105 .18 E 6039925.30 by 541691 .62 E 6040012.09 N 541078 .44 E 6040099.56 N 541065 .24 E 6040184.09 N 541053 .30 E 6040271.44 N 541040 .71 E 6040357.33 N 541027 .64 E 6040444.36 hJ 541015 .93 E 6040528.49 N 541006 .18 E 6040613.46 N 540997 .43 E 6040696.84 N 540989 .27 E 6040784.40 N 540979 .85 E 6040869.91 N 540970 .25 E 6040956.91 N 540959 .65 E 6041045.00 N 540947 .90 E 6041130.89 N 540936 .84 E 6041215.82 N 540926 .79 E 6041301.65 N 540915 .85 E 6041387.09 N 540903 .09 E 6041472.41 N 540889 .54 E 6041560.12 N 540875 .77 E 6041646.19 N 540861 .90 E 6041733.44 N 540846 .38 E 6041819.16 N 540829 .44 E BPXA Dogleg Vertical Rate Sec-icri Commen# (°/100ft) 0.360 3211:45 0.822 3300.88 0.256 3388.35 1.296 3476.53 1.342 3562.24 1.312 3648.88 0.332 3737.33 0.644 3826.08 0.603 °;, ~ ~.~~" 0.801 4GC' .~= 0.419 4088.32 1.464 ~ 176. ~~~ '. 1.022 4263.x,,_ 0.494 4351.60 1.221 4440.06 0.566 4525.42 0.871 4613.67 0.346 4700.5== 2.329 4788.34 0.489 4872.96 1.385 4958.26 1.102 5041.89 0.328 5129.86 0.236 5215.82 1.106 5303.41 1.260 5392.26 1.002 5478.83 1.935 5564.29 1.275 5650.78 1.906 5737.16 0.594 5823.55 2.062 5912.34 1.225 5999.52 1.411 6088.11 1.283 6175.42 • 3 August, 2005 - 15;28 Page 4 of 7 DrillGtuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPF-93 (mwd) Your Ref: API 500292326600 ~~:~ i','+~. Ai">1~7W3782167, Surveyecr: ?5 Ju,';~, 2005 Milne Point Unit Measured Depth (ft) 8240.15 8330.48 8425.01 8518.65 8611.32 8705.76 8799.57 8894.48 8988.'4 :;682.92 9177.34 ~JL7 6.95 9363.66 9458.85 9551.62 9645.09 9740.39 9834.39 992283 10026.05 10118.79 10214.71 10310.57 10404.18 10495.96 10590.50 10685.96 10778.54 10873.86 10968.12 11061.57 11157.10 11251.82 11345.28 11435.92 Incl 68.390 67.450 66.520 69.180 70.300 70.820 71.210 69.760 68.650 58.7 90 67.450 66.126 65.840 67.110 68.190 68.180 68.460 68.930 68.510 67.700 67.180 67.650 68.070 68.720 68.970 68.910 68.990 69.500 69.430 69.370 68.060 67.030 65.910 66.510 67.460 True 348.460 349.200 349.040 355.610 358.770 357.230 356.810 355.080 35^.-.,. ~52.4~ ~, ~, 352.99(! 353.550 352.440 352.180 352. i 2G 351.370 350.760 350.140 350.400 350.460 351.080 351.090 352.000 351.360 351.770 352.740 351.930 352.800 351.710 352.750 352.340 352.280 Sub-Sea Lepth (ft) 4302.21 4336.16 4373.12 4408.46 4440.55 4471.99 4502.51 4534.21 ~' 567.68 4 ov' .86 4637.04 4673.94 47;'.66 4749.68 4784.95 4819.69 4854.90 4889.05 4923.69 4959.57 4995.15 5031.99 5068.11 5102.58 5135.70 5169.68 5203.96 5236.77 5270.21 5303.37 5337.30 5373.79 5411.60 5449.30 5484.74 Vertical De~tr, (ft) 4347.28 4381.23 4418.19 4453.53 4485.62 4517.06 4547:58 4579.28 4612.75 4646.93 4682.11 4719.01 4756.73 4794.75 4830.02 4864.76 4899.97 4934.12 4968.76 5004.64 5040.22 5077.06 5113.18 5147.65 5180.77 5214.75 5249.03 5281.84 5315.28 5348.44 5382.37 5418.86 5456.67 5494.37 5529.81 '...oval Coordinates c ii,~.io~gs Easfings (ft) (ft) 6189.66 N 894.39 W 6271.78 N 910.60 W 6357.22 N 927.02 W 6443.11 N 938.55 W 6529.93 N 942.80 W 6618.92 N 945.91 W 6707.51 N 950.53 W 6796.74 N 956.85 W "~-x.47 ~,! 965.04 W . ~" ..5r ~~~ 974.96 W 7058.59 N 986.00 W "i•;3.89 iti 997.11 W %~.?7.71 N 1008.80 W 7314.26 N 1020.42 W 7399.47 N 1030.47 W 7485.60 N 1041.05 W 7573.36 N 1052.90 W 7660.11 N 1064.86 W 7748.12 N 1077.63 W 7836.32 N 1091.50 W 7920.78 N 1105.70 W 8008.07 N 1120.67 W 8095.62 N 1135.43 W 8181:53 N 1149.39 W 8266.09 N 1162.66 W 8353.35 N 1175.63 W 8441.50 N 1188.52 W 8527.14 N 1201.22 W 8615.59 N 1213.25 W 8703.03 N 1225.02 W 8789.33 N 1236.59 W 8876.81 N 1248.48 W 8962.85 N 1260.23 W 9047.65 N 1271.32 W 9130.32 N 1282.49 W Cicual Coordinates rdof~t~.ir,gs Eastin gs (ft) (ft) 6041896.00 N 540813. 47 E 6041978.02 N 540796. 79 E 6042063.37 N 540779 .89 E 6042149.19 N 540767 .88 E 6042235.99 N 540763. 14 E 6042324.97 N 540759. 53 E 6042413.52 N 540754 .42 E 6042502.72 N 540747 .60 E 8r~: c~ ~0 ~d 540738 .91 E 6C,: 4 N 540728 .50 E 604276.39 N 540716 .97 E 6G42S-'+x.04 N 540705. 38 E 6042° ' 39 N 540693. 23 E 6043019.87 N 540681. 12 E 6043105.02 N 540670. 59 E 6043191.09 N 540659 .52 E 6043278.78 N 540647. 18 E 6043305.47 N 540634. 73 E 6043453.41 N 540621 .47 E 6043541.52 N 540607 .11 E 6043625.90 N 540592 .42 E 6043713.10 N 540576. 97 E 6043800,57 N 540561 .71 E 6043886.40 N 540547 .27 E 6043970.88 N 540533 .53 E 6044058.07 N 540520 .07 E 6044146.15 N 540506 .68 E 6044231.71 N 540493 .50 E 6044320.09 N 540480 .98 E 6044407.47 N 540468 .72 E 6044493.70 N 540456 .66 E 6044581.11 N 540444 .28 E 6044667.09 N 540432 .05 E 6044751.82 N 540420 .47 E 6044834.43 N 540408 .85 E Dogleg ~lertival Fate Section Comr ent (°/100ft) 0.300 6253.81 1.288 6337.43 0.996 6424.36 7.091 6511.01 3.420 6597.49 1.633 6685.95 0.593 6774.23 2.299 6863.40 1_q4<_ ~5; '8 1.420 7126.66 1.453 ~ 2i2.u Q76~ <S7 ~9 1.815 7384.61 1.291 7470.37 1.103 7557.11 0.388 7645.65 0.504 7733.22 0.854 7822.15 1.027 7911.43 0.834 7997.06 0.550 8085.61 0.442 8174.38 0.928 8261.41 0.273 8347.01 0.900 8435.23 0.631 8524.32 0.689 8610.89 0.956 8700.14 0.807 8788.36 1.649 8875.42 1.508 8963.69 1.553 9050.53 0.757 9136.03 1.050 9219.44 L'Fk' C: • 3 August 2005 - 15:28 Page 5 of 7 ®rillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPF-93 (mwd) Your Ref: AP/ 500292326600 .;~„~ r1lc~, AKMW'3782167, Serve,^s~c,': 15 July, 7005 Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Pate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 11528.44 67.990 353.100 5519.81 5564.88 9215. 24 N 1293.38 W ' 6044919.29 N 540397.48E 1.000 9305.03 11622.57 68.540 352.120 5554.67 5599.74 9301. 95 N 1304.63 W 6045005.93 N 540385.74E 1.130 9392.45 11717.90 68.930 353.200 5589.24 5634.31 9390. 06 N 1315.98 W 6045093.98 N 540373.90E 1.132 9481.27 11810.97 68.850 352.050 5622.76 5667.83 9476. 16 N 1327.12 W 6045180.02 N 540362.27E 1.156 9568.07 11906.31 67.790 352.150 5657.98 5703.05 9563. 92 N 1339.30 W 6045267.70 N 540349.60E 1.116 9656.66 11998.20 67.070 352.180 5693.25 5738.32 9647. 98 N 1350.86 W 6045351.69 N 540337.56E 0.784 9741.50 12093.45 65.580 351.380 5731.50 5776.57 9734. 31 N 1363.33 W 6045437.96 N 540324.61E 1.743 9828.73 12187.05 63.230 351.040 5771.93 5817.06 9817. 73 N 1376.23 W 6045521.30 N 540311.24E ''.532 9913.14 12280.94 6G £0~; L C;?C 5815.99 £1 L" ,.~Ce. . ~~7 N 1389.50 `,iV J156C3.D6 N 540297 ,;^: E "" ,<. 0996.04 12375.84 :v.51;_ .,C.c:; C 5863.93 , zG9.~l .:;8Q 36 N 1462.88 bV ,.,,:<+;;683.?8 PJ 540283.Frz E 6 '0077.92 12468.37 56.166 349.040 5913.87 5958.9 i 0057. 03 N 1416.58 W £045760.37 N 540269.55E "x.941 10155.78 12563.40 52050 :;48.38v 5969.17 601':.-'; 1Gi32 86 N 1431.37 VV 6645836.12 N 540254.33E ~.c96 10232.97 12655.42 47.830 349.240 6028.01 6073.08 10202. 29 N 1444.80 W 6045905.47 N 540240.51E [ .247 10303.63 12748.85 42.910 349.880 6093.62 6138.69 10267. 66 N 1456.86 W 6045970.77 N 540228.08E x.288 10370.07 12842.75 37.990 349.160 6165.06 6210.13 10327. 55 N 1467.92 W 6046030.60 N 540216.69E 5.263 10430.93 12933.25 34.140 349.690 6238.20 6283.27 10379. 91 N 1477.71 W 6046082.90 N 540206.61E 4.268 10484.17 13026.34 29.240 349.960 6317.39 6362.46 10428. 03 N 1486.35 W 6046130.97 N 540197.69E 5266 10533.04 13119.34 24.166 350.9 i C 6400.44 6445.5"1 i 0469. 21 N 1493.32 W 60461 1'2.11 N 540190.49E x,.48 i 10574.86 13211.96 19.630 352.860 6486.36 6531.4? 10563. 38 N 1498.25 W 6046206.26 N 540185.37E ~ 253 10609.33 13306.82 17.410 355.246 6576.30 662 i .3 ~ 10533. 34 N 1501.41 W 0046236.20 N 540182.04E x.472 10639.42 13401.92 17.000 359.430 6667.15 6712.22 10561. 42 N 1502.73 W 6046264.27 N 540180.56E 1.372 10667.38 13495.66 17.200 359.650 6756.75 6801.82 10588. 98 N 1502.95 W 6046291.83 N 540180.19E 0.224 10694.67 13522.75 17.220 359.040 6782.62 6827.69 10597. 00 N 1503.04 W 6046299.84 N 540180.05E 0.670 10702.61 13547.29 17.420 359.320 6806.05 6851.12 10604. 30 N 1503.15 W 6046307.15 N 540179.91E 0.883 10709.85 13643.47 17.430 0.570 6897.82 6942.89 10633. 10 N 1503.18 W 6046335.95 N 540179.72E 0.389 10738.33 13742.15 17.590 1.840 6991.93 7037.00 10662. 78 N 1502.55 W 6046365.63 N 540180.17E 0.420 10767.58 13836.44 17.560 3.160 7081.82 7126.89 10691. 23 N 1501.31 W 6046394.08 N 540181.26E 0.424 10795.52 13935.04 16.300 6.480 7176.14 7221.21 10719. 83 N 1498.93 W 6046422.70 N 540183.48E 1.610 10823.44 14030.29 15.880 9.580 7267.66 7312.73 10745. 96 N 1495.25 W 6046448.85 N 540187.01E 1.004 10848.73 14127.48 16.940 8.860 7360.89 7405.96 10773. 06 N 1490.86 W 6046475.97 N 540191.25E 1.111 10874.87 14183.00 16.940 8.860 7414.00 7459.07 10789. 05 N 1488.36 W 6046491.97 N 540193.65E 0.000 10890.30 Projected Survey All data is in Feet (US Survey) unless otherwise stated . Directions and coordinates are r elative to True North. Vertical depths are relative to MPF-93. Northings and Eastings are relative to MPF-93. Global Northings and Eastings are rela tive to NAD27 Alaska State Planes, Zo ne 4. E> FXA • 3 August, 2005 - 15:28 Page 6 of 7 DrillQuest 3.03.06.008 Hai/iburton Sperry-Sun ' Survey Report for MPF-93 (mwd) Your Ref: API ,500292326600 Jc~b Nc. AKMlNs`7fi'21E7, ~~vnneyed: 95 July, 2005 Milne Point Unit The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from MPF-93 and calculated along an Azimuth of 351.400° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14183.OOft., The Bottom Hole Displacement is 10891.22ft., in the Direction of 352.146° (True). Comments BF'XA Measured Station Coordinates • Depth TVD Northings Eastings Comment (ft} (ft) (ft) {ft} 14183.00 7459.07 10789.05 N 1488.36 W Projected Survey Survey toot program for iVlf'l=-J;3 (rr~w~) From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft} (fi) (ft) (f~) 0.00 O.OG 745.00 741.64 BP High Accuracy Gyro - Wellnav Gyro 745.00 741.64 14183.00 7459.07 MWD Magnetic • 3 August, 2005 - 15:28 Page 7 of 7 DrillQuest 3,43.06.008 Printed: 7/25/2005 7:52:47 AM Re: MPF-93 • • Subject: Re: MPF-93 From: Thon~.as ~~~~~launeler <1om i7~aunder(~admin.state.ak.us> Date: Thu, ?? Seh ~f)0~ 1 ;:~6:?G -OS00 To: "Coyner, Skip (N~1TCH IQ)" <coy~is0(zBP.co~n~ CC: AOGCC North Slope OFfice <ao~cc~~rudhoe_bav(i~.admin.state.ak.us? Thank you for the information. Your request not to install rams to cover you cleanout BHA is acceptable. Please make sure a copy of this message is available on the rig. Tom Maunder, PE AOGCC Coyner, Skip (NATCHIQ) wrote, On 9/22/2005 1:48 PM: Yes, the pipe rams are both VBR's but they don't go that small. We'll have a X-O for the stabbing valve. Skip Coyner 907-564-4395 BPXA 907-748-3689 cell From: Thomas Maunder [mailtoaommaunder@admin.state.ak.us] Sent: Thursday, September 22, 2005 12:15 PM To: Coyner, Skip (NATCHIQ) Subject: Re: MPF-93 :~~ s o ~'~ Skip, I presume that the 2 pipe rams will cover the normal drill pipe and that an XO from the 2-1/16 to the stabbing valve is available. Please confirm. Tom Maunder, PE AOGCC Coyner, Skip (NATCHIQ) wrote, On 9/22/2005 12:10 PM: Tom, Doyon 14 moved back onto MPF-93 last night under the original drilling permit. After we get out of the hole with the sanded up jet pump and tubing, we plan to make a clean out run. Part of that run includes a 2-1/6" Hydril CS stinger (+/- 660') to clean out the 3-1/2" liner. The question is do we have to install & test 2-1/16" rams or does this stinger count as BHA as per 20 AAC 25.035 (e) (1) (B) (i)? By this email, we are requesting an administrative waiver to installing 2-1/16" rams. Procedure attached. I'll convert the diagram to Adode and send it. Skip ~'oyner 907-564-4395 BPXA 1 of ~., 9/22/2005 1:56 PM • s '~~ __ ~, ~~ .~ ~, • MPF-93 RWO DOYON 14 AFE Number: Days: 5 AFE Amount: s~~l o s-~ ~-'~ Estimated Start Date: 21 September 2005 Prepared By: S. Coyner Approved by: Ops. Drilling Engineer Date Senior Drilling Engineer Date Drilling Team Leader Distribution: Doyon 14 M. Miller D. Kara S. Coyner D. Johnson L. Vendl D. Ohms BPX Drilling Stores Centrilift M-I Doyon MPU -Well Ops Coordinator 91 Copies, 1 original 6 Copies 1 Copy 1 Copy 1 Copy 1 Copy 1 Copy e-mail e-mail e-mail e-mail e-mail e-mail Original for well file Date Asset Team Leader Date WELL OBJECTIVES: 1. NO ACCIDENTS, SPILLS OR ENVIRONMENTAL VIOLATIONS. 2. NO POLICY OR REGULATORY VIOLATIONS. 3. REVIEW AND FOLLOW ALL PROCEDURES. 4. PULL EXISTING ESP COMPLETION. 5. RUN NEW ESP COMPLETION. 0 onion of this wank is so urgent that the time cannot ke taken to o it without injurin yourself or ethers The orkover 1=1~ is to a used only through rig release, and only for items authorized by the rillin Supervisor. • Contact List • Contacts Name Work Cell Home Drilling Team Leader Mike Miller 564-5066 240-8066 348-0595 Sr. Drilling Engineer Dan Kara 564-5667 240-8047 345-6665 Op. Drilling Engineer Skip Coyner 564-4395 748-3689 344-2447 Op. Drilling Engineer Dave Johnson 564-4171 632-5806 622-0943 Rig 14 Company Representatives Darrell Green .John Willoughby • Eddie Vaughn • Lewis Brown 670-3268 fax 3269 943-1134 943-5005 rig floor Petroleum Engineer Ali Gurbanov 564-5032 830-5450 349-8867 Artificial Lift Coordinator Mark Dauve 564-4660 348-6128 Project Lead Danielle Ohms 564-5759 345-2477 Centrilift: Anchorage Victor Lyon Rick Armstrong Dan Benson 564-4924 349-3731 360-0418 360-0404 360-0419 Centrilift: Milne Point Ron Laudick Roy Miller James Mills Buster Crail 670-3352 670-3471 Pgr #546 Pgr #189 Pgr #112 Pgr #512 670-3435 670-3416 MI Mud Products Mark Fairbanks 274-5508 748-6275 MI Rig 943-1100 Tool Services 659-4634 AOGCC Tom Maunder 793-1250 Doyon Drilling Todd Driskill 565-4249 223-0537 746-1440 Materials D King /Les Peck 659-4003 Well Name: MPF-93 RWO MPF-93 RWO Program Page 2 • • Workover Plan Summary AFE Number: Ri Do on 14 Estimated Start Date: Se t 21S 2005 O eratin da s to com lete: 5 Ob'ective: Pull the frac strin .Clean out LNR. Install an ESP Current Well Information Well Name: MPF-93 API Number: 50-029-23266-00 AOGCC: 205-087 Well Type: Kuparuk "A" Sand Producer Current Status: Post Frac clean up and production using a jet pump BHP Calculations: After perforating the Kuparuk A sands at 7244' TVD: MW = 9.6 ppg, SITP = 650 psi, BHP = 4266psi, EMW =11.33 ppg BHT: 176° F @ 7244' TVD. Mechanical Condition: Tubing: 319 joints of 4-1/2", 12.6#, IBT-M. Casing: See Current schematic. Well Depth: 14182' MD / 7482' TVD Kick Off Point: 250' MD Maximum Angle: 71.24° at 8800' MD / 4572' Max Doglegs of interest: 5° - 6°/100' from 2618' MD to 2814' MD 5°J100' at 2152' MD Wellhead: 11" x 11" 5M FMC Gen VI Tree: Cameron 4-1/16" 5M BPV Profile: CIW H BPV profile Perforations: See schematic for details Workover Fluid: Kill Weight Brine 11.8 ppg. Re-calculate after jet pumping Materials Required for Workover Operations New Equipment 1 2-9/16" x 5000#, Carbon Tree for a MPU, ESP completion 1 2-9/16" x 11"Tubing Head Adaptor with ESP cable port (pig tail) 1 Tubing Hanger with ESP port for 2-7/8" EUE-Mod tubing 1 GLM: 2-7/8" x 1"with dummy valve and handling pups 1 2-7/8" XN Nipple with 2-7/8" EUE-Mod cplgs with handling pups ±13,300' 2-7/8" 6.5#/ft L-80 EUE-Mod tubing (class A or B) ±13,300' #1 New CEBER SS ESP Cable with clamps & bands as appropriate 1 Centrilift ESP Assembly -See program for details 1 Penetrator 1 Lower connector (as needed) 1 Upper pigtail Short Scope 1. MIRU. Kill the well with 12 ppg brine, and 12 ppg, hi-vis, solids-free, hi-vis Biozan pill. MPF-93 RWO Program Page 3 • • 2. ND tree. NU and test BOPE. 3. POOH with existing, 4-1/2" frac string. 4. RIH with 2-1/16" stinger on DP and clean out to PBTD. LDDP. 5. Run new ESP completion on 2-7/8" tubing. 6. Freeze protect to 2500' TVD. 7. Set BPV. RDMO. Hazards and Contingencies 1) Hydrogen Sulfide • Standard Operating Procedures for HZS precautions should be reviewed and followed at all times. All H2S readings at F-pad have been less than 50 ppm. Reference: Hydrogen Sulfide Standard Qperating Procedures 2) Well Control Pressures • Max anticipated BHP: 4500 psi (12.0 ppg EMW) @ 7244' TVD • Max surface pressure: 3776 psi (based on BHP & full gas column at 0.1 psi/ft) • Circulate the well with Kill Weight Brine and check for flow before ND fhe tree. 3) All fluids pumped down hole must be clean. Clean the "active pits", pass the brine/seawater over 230 mesh screens, and use clean trucks. Workover Program Overview Rig Move issues and Shut-in Requirements: There are no surface shut-in requirements for the rig move to MPF-93. Workover Fluid Program: Sodium/Bromide brine at ± 12.0 ppg Offset Injector Information: Well Name BHP Pressure ( si _ I _ EMW _ Well Status ~ 51 Date - - - F-30i 5000 ~ 13.4 ppg SI ~ 6/2005 MPF-93 RWO Detailed Operations * Complete apre-rig inspection with the Pad Operator before the rig moving on the well *Notify the AOGCC representative 24 hours in advance to witness BOP testing * Pre-Rig Work: 1. Perforate circulation holes above the jet pump. (Done) Rig Workover: 1. MIRU Doyon 14. R/U hard lines for circulating the tubing and IA taking returns through the choke manifold. Tie-in the return line to tiger tank for receiving hydrocarbons (if any). Test all lines to 5000 psi. 2. Kill the well with 12.0 ppg brine. Flow check. Spot Hi-Vis on bottom. 3. Install and test a TWC. ND TREE and NU BOP stack and flow line. Test BOPE to 250 psi low / 5000 psi high. Pull the TWC. MPF-93 RWO Program Page 4 • 4. P/U landing joint and screw in to the tubing hanger. BOLDS's. P/U > 20' to pull out of the PBR. Check for flow / U-Tube. Check for flow. L/D the 4-1/2" tubing. Keep the hole full at all times. Monitor the trip tank closely for gains or losses. 5. PU + 660' of 2-1/6", Hydril CS tubing and X-O to 4" DP. RIH with DP. Displace the work string with Hi-Vis brine. 6. Wash out the 3-1/2" liner using Hi-Vis 12.0 ppg brine. Keep the flow rates low due to the small annular area: 2.992" ID x 2.375" OD cplgs. Watch for sticking. 7. CBU x 3 at maximum rate. POOH. LD the work string. Keep the hole full. 8. Verify the size and horse power of the ESP as per the proposed program for this well (diagram attached). Verify that the length of the motor lead flat cable will place the splice between the discharge head and the 10' handling pup collar. A Centrilift rep shall be on the rig floor at all times during the running of the ESP. 9. Install the ESP cable in the spooling unit. Makeup new ESP assembly with new motor lead extension, seal section and motor (see attached ESP Assembly Schematic for details). 10. Run the 2-7/8" ESP Completion: Reference Running an ESP Completion RP (attached). • Centrilift ESP Assembly -pump intake at ±13,282' MD • 10' 2-7/8" 6.5#, L-80 Pup Joint • 2-7/8" 6.5#, L-80 EUE 8rd tubing • 10' 2-7/8" 6.5#, L-80 Pup Joint • 2-7/8" XN nipple at ±13,200' MD • 10' 2-7l8" 6.5#, L-80 Pup Joint • +328 joints of 2-7/8" 6.5#, L-80 EUE-Mod tubing • 10' 2-7/8" 6.5#, L-80 Pup Joint • GLM 2-7/8" x 1" Side Pocket KBMM at +3,160' MD / 2,500' TVD • 10' 2-7/8" 6.5#, L-80 Pup Joint +102 joints of 2-7/8" 6.5#, L-80 EUE-Mod tubing • Tubing Hanger with ESP Port • Pig Tail and Dual Penetrator A. Check the conductivity of ESP cable every 2,000' and every new splice while running in hole. B. Use La Salle Cast Cable Protectors on the first nine joints and then every second joint on the round cable, also on all the GLM pups but not on the tubing hanger pup joint. C. Use Best-O-Life 2000 pipe dope for the EUE 8 round or EUE A/B MOD cplgs. D. The make up torque values for 2-7/8" L-80 6.5# EUE 8rd tubing are: Minimum: 1,730 ft-Ib, Optimum: 2,300 ft-Ib, and maximum: 2,800 ft-Ib. E. The 2-7/8" L-80 6.5# EUE 8rd tubing performance properties are: Body Yield: 145,000#, Burst: 10,570 psi, Collapse: 11,160 psi. Maximum allowable Pick up weight: 145,000# x 70% =101,500# 11. Fill tubing while splicing cable -mid-cable splices and tubing hanger splices. After tubing is full, break circulation by pumping 10 bbls down the tubing to clear any debris. 12. Record PU and SO weights before landing hanger and record on daily operations report. 13. Install abrass-shipping cap on the ESP penetrator. Land tubing with extreme care to minimize damaging the ESP penetrator, pigtail and alignment pin. RILDS. 14. Install TWC and test to 4,000 psi. ND BOPE and NU lock down flange, tubing head adapter, and tree. Pressure test tubing head adapter and tree to 5,000 psi. 15. Pull TWC with lubricator. Set BPV. 16. Freeze protect after Doyon 14 moves off. MPF-93 RWO Program Page 5 • ~ 14-Aug-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Weli MPF-93 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 0.00' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 14,183.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ ~ r r~.~,~'{ + Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • • 14-Aug-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPF-93 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 0.00' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 14,183.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 . ~ ~ , ~~ ~ f ~, Date '~ . ~L~ J Signed ~`' ^ r ' ~.. ~%t~~t%.,.~( Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) I ~' ~~ ~ ) ~ ~,'°~,~ , I 3~~ ~,. ; ~'~ ~} ;~,~ ~`; ~~ FRANK H. MURKOWSK/, GOVERNOR ~~~r ~+ ~~ 0~ ~ u0-7 ~f 333 W. 7T" AVENUE, SUITE 100 C0~~7~RQA~~1~ CQr~IISSio~ V~ PHONE~(907) 279-1433 501-3539 FAX (907) 276-7542 Dan Kara Senior Drilling engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Milne Point MPF-93 BP Exploration (Alaska) Inc. Permit No: 205-087 Surface Location: 2260' FSL, 2818' FEL, SEC. 06, T13N, RlOE, UM Bottomhole Location: 2445' FSL, 4399' FEL, SEC. 30, T14N, R10E, UM Dear Mr. Kara: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or 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. 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 fitness any required test. Contact the Commission's petroleum field inspector at (907 59-3 ager). DATED this l~ day of June, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. a ~ ~ ~~ ~ ~ ~ j~id ~ g.~~ <~~ ~ 7~ ~~ ~ °~~ ` ~%'~~ " ~,~7 i'°' ' ~~ ' ~ ~ ~' ~ ~~ FRANK H. MURKOWSKI, GOVERNOR ~ `~ ~ ? i ~~~ OI~ ~ ~ ~ 333 W. 7"' AVENUE, SUITE 100 CO1~T5ERQA'rIOIQ COMh'II55IOIQ ~ ANCHORAGE, ALASKA 99501-3539 ~~ PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Skip Coyner Drilling Engineer BP Exploration (Alaska) Inc. June 9, 2005 ACT PO Box 196612 Anchorage, AK 99519 Request for Waiver of Diverter Requirements at 20 AAC 25.035 (c) Milne Point Unit F-93...205-087 Dear Mr. Coyner: We have received your request for exception to the Diverter requirements at 20 AAC 25.035 (c) for Milne Point F-93. In support of this request, you relate information regarding the number of wells drilled on MPU F Pad including the surface hole strata anticipated, structural setting for the Schrader Bluff formation in the area and the absence of any indications of shallow gas (free or hydrate) or over-pressure while drilling prior wells. The majority of wells on F Pad are completed in the Kuparuk River formation with a few wells completed in the Sag River. There are no Schrader Bluff wells and the nearest Schrader injection well is some 3.5 miles to the SE. The Commission agrees that the record does not reveal any known problems with natural pressure or shallow gas on F Pad. A possibility does exist for production operations to "induce" shallow hazards if there is a compromise to a well's integrity during normal operations. At this time, the Commission has not been notified that an integrity problem exists for any production or injection well on F Pad. One prior communication issue (T x IA) on MPF-83 i was repaired with a workover in summer 2004. Regardless of the past drilling history in the F Pad area, the operator must be prepared to accommodate drilling hazards that may develop over time. Each well should be carefully monitored to detect any developing drilling hazards, and subsequent operations conducted accordingly. Dialogue with Milne Point operations should be ongoing so that any changes in injection well performance are highlighted. Your request to waiver of the dverter requirements for MPF-93 (205-087) is approved. This approval is specifically for MPF-93. If waivers for additional wells on MPF pad are desired, your request should be included with the Permit to Drill as done here a contact Tom Maunder, PE at 793-1250 with any questions. /T Si STATE OF ALASKA ~'~ ALASKA~L AND GAS CONSERVATION CO~ISSION PERMIT TO DRILL ~?' ~`1~+~5 ~/~ 20 AAC 25.005 ~~~~~~~ ~ ;~ ~.. ,~ _ s, 1a. Type of work ®Drill ^ Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ®Development 01 '"' ` `' ~'t`f~St ^ Stratigraphic Test ^ Service ^Development Gad': ,1~", ; Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 2S100302630-277 ' 11. Wel! Name and Number: MPF-93 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 14149 ' TVD 7473' 12. Field / Pool(sj: Milne Point Unit / Kuparuk River 4a. Location of Well (Governmental Section): Surtace: 2260' NSL 2818' WEL SEC T13N 06 R10E UM ~ 7. Property Designation: ADL _~559i'l~ >~~ b / ' Sands , , . , , , Top of Productive Horizon: 2348' NSL, 4385' WEL, SEC. 30, T14N, R10E, UM 8. Land Use Permit; ~ ~,~,° 13. Approximate Spud Date: June 15, 2005 Total Depth: 2445' NSL, 4399' WEL, SEC. 30, T14N, R10E, UM 9. Acres in Property: ~~ .~'~sG~~'. ~ ~ j`~' 14. Distance to Nearest Property: 8150' ~ 4b. location of Well (State Base Plane Coordinates): Surface: x- 541743 ' - 6035711 ' Zone- ASP4 10. KB Elevation (Height above GL): Plan 4T feet 15. Distance to Nearest Well Within Pool 1340' from MPF-45 ' 16. Deviated Wells: Kickoff Depth: 275' feet Maximum Hole Angle: 68.3 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3993 ' Surface: 3275 j i s. asing rogram: Size Specffications Setting. Depth - T Bottom uantdy o ement c.f. or sacks Hole Casin Wei ht Grade Cou fin Len th MD TVD MD TVD includin sta a data 42" 20" 92# H-40 Welded 80' 34' 34' 114' 114' 60 sx Arctic Set A rox. 13-1/2" 10-3/4" 45.5# L-80 BTC 8126' 30' 30' 8156' 4595' 1022 sx AS Lite, 234 sx Class 'G' 9-7/8" 7-5/8" 29.7# L-80 BTC-M 13508' 30' 30' 13538' 6845' 161 sx Class 'G' 6-3/4" 4-1/2" 12.6# L-80 IBT-M 761' 13388' 6744' 14149' 7473' 132 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Rednll AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth ND (ft); Junk (measured): Casin Len th Size Cement Volume MD ND r n ct r Pro c i n 'n Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ® Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Skip Coyner, 564-4395 Printed Name Dan Kara Title Senior DriNing Engineer Prepared By Name/Numbar: Si nature ^~-._._ Phone 564-5667 Date 5 17 ps Terrie Hubble, 564-4628 Commission Use Only Permit To Drill _ Number: Z~S °~-~~~ API Number: 50- C~~.~" w ~.~ ~~ '~~ Permit Approval Da#e: ~ ~ ~ See cover letter for other requirements Conditions of Approval: Sam les Required d gen Sulfide Measu s Other: '~O~ S ~ ~~ c,,s ~~p.11 K~ , A rove ^ Yes f No Mud Log Required ^ Yes :~No ,Yes ^ No Directional Survey Required ''Yes r ' No APPROVED BY ~ lD ~~ THE COMMISSION Date Form 10-401 Rev+sed~004 ~~ ~ ~ ~ ~ ~~ ~ L /~ubryfit In Duplicate ~ • May 25`i', 2005 Tom Maunder Alaska Oil & Gas Conservation Commission 333 W. 7~' Avenue, Suite 100 Anchorage, AK 99501 Re: Request for Exception to 20 AAC 25.035 (c) MPU F-Pad /MPF-93 Mr. Maunder: BP Exploration (Alaska) Inc. ("BP") hereby to requests an exception to 20 AAC 25.035(c) in accordance with 20 AAC 25.035(h)(2) allowing Doyon 14 to drill the surface hole without using a diverter. The requested exception pertains to the drilling of MPF-93, a Kuparuk A3 sand producer. -' The MPF-93 well plan includes 10-3/4" surface casing to be set through the Schrader Bluff sands. It is this hole section for which this exception is requested. In excess of 50 wells have been drilled from MPU F-Pad. According to drilling records and the Pad Data Sheet, none of the F-Pad wells have experienced gas, gas hydrates or abnormal pressure in this geologic section. Furthermore, the only hydrocarbon show noted in this hole section was a Schrader Bluff heavy oil show in MPF-50 back in 1997. No subsequent shows have been reported even though the subsequent wells have drilled this hole section with 9.5 ppg mud or (in most cases) less. The only potential hydrocarbon bearing zone in this hole section is the Schrader Bluff "O" sands. The Schrader Bluff "O" sands that underlie F-Pad are low on structure, and in most cases, water bearing. Any potential oil bearing sands would contain heavy, viscous oil with extremely low GOR and low mobility. An oil bearing sand in this hole section would not be capable of flow to surface. Additionally, the nearest Schrader Bluff injection well, MPJ-15i, is located 3.5 miles away and it's surrounded by producers (see attached map). If you have any questions or require any additional information, please contact the undersigned at 564-4395, or Dan Kara at 564-5803. ,~ Sincerely, Ski oyne Drilling Engineer BPXA /ACT .~r S ~~~ \ ac~ Pzc'SOnG\~~' ~QS~~2~C'~\`\h C~t~ ~~C~ wcc \. ~ S r~rt \ \~ c~ ~ rte, t-l ~ hQ \'~i~i~. ~ o Sw~-~co:L~c ~cl~ rc C,45 ~t ~ oMG~~ SCE v'C-Crc vJGS !c`t~ p2..t'~E ~L~C. ~ . ~~s~~ t~D~ Jw1c~,`~ S ~ G.~~ ~1j~ ic~~ n~,~ ~~ kjscacvl~.cc ~ c~- `CJC7.~ - 003 w~~~ hop~O~`~N.S.c~s J~Q.~~. Q~\~E~rwc,:~v~v~ w~.~ ~~ ~ ~~ -~~~ ~~~--may <ao\- \~01,~~~-s~-~ ~ ~- ~~cc c6 w ~~\ S r~zn~ t-e. cL~~ \~ t ~c ~ ~~~ . ~ °c ov~`~`~u~~-.j ~~.~ c~. ~.~tio v~G ` .~c%.~Ecs v.3~c~ct~ -~o v ~ ~ • ~ ~v~ ~ • • TOp Schrader Time-Structure Ma with current Schrader Bluff injectors ~~~,~~ea~,~ \~1 ~~ ~\~~ ~~~~,~\; ~~~~ ,~ ~, F i ~~ ~% ~! . L F-Pad is 3.5 m Schrader Bluff infector MYJ-151 1 ~~ ,~ ~i • • by ~7~i71 Well Name: MPF-93 Kuparuk A Sand Producer Drilling and Completion Plan Summary T e of Well: Ku aruk A Sand Producer - Surface Location: 2260' FSL and 2818' FEL Section 6, T13N, R10E UM ' E = 541,743' N = 6,035,711' ' Top Kuparuk D at 13,697' MD 2348' FSL and 728' FWL Section 30, T14N, R10E UM E = 540,074' N = 6,046,349' Z = 7032' TVD T1, Kuparuk A at 13,949' MD 2404' FSL and 719' FWL Section 30, T14N, R10E UM E = 540,065' N =x,046,405' Z = 727T TVD BHL at 14,149' MD 2445' FSL and 713' FWL Section 30, T14N, R10E UM E = 540,059' - N = 6,046,446' ~ Z = 7473' TVD Distance to Pro a line 8,150' Distance to nearest well 1,340' from MPF-45 AFE Number: Estimated Start Date: 6/15/2005 Ri Do on 14 Ri da s to com lete: 20 MD: 14,149' TVD: 7,473' Max Inc: 68.3° KOP: 275' KBE: 47' Well Desi n: "S-Curve", Ku arukA sd, Frac'd Producer with Intermediate Casin Ob'ective: Ku aruk A Sand Mud Program: 13-1/2" Surface Hole (0' - 8156'): `..J LSND Dens PV YP HTHP H API Filtrate LG Solids 8.6-9.3 10-20 25-30 10- 11 9.0-9.5 <6 < 15 9-7/8" Intermediate Hole (8156' -13538'): LSND Densi PV YP HTHP H API Filtrate LG Solids 8.8-9.6 10-20 20-30 10-11 9.0-9.5 <6 <15 6-3/4" Kuparuk Section (13538' -14149'): LSND Densi PV YP HTHP H API Filtrate LSRV 9.8-11.0 8-15 20-28 10-11 9.0-9.5 <6 >20000 Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. Recommended Bit Program: BHA Hole Size Depth (MD) Footage BfType TFA GPM 1 13.50 i n Surf - 8,156' 8,156' MXC 1 .75 - .90 450 - 650 2 9.875 in 8,156' - 13,538' 5,382' PDC .50 - .75 400 - 550 3 6.75 in 13,538' -14,149' 611' PDC .30 - .50 250 - 300 CasinglTubing Program Hole Size Csg / T O.D. Wt/Ft Grade Conn Length Top MD / TVD Bottom MD / TVD 42" 20" 92# H-40 Welded 80' 34' 114' / 114' 13.5" 10.75" 45.5# L-80 BTC 8,126' 30' 8,156' / 4,595' 9.875" 7.625" 29.7# L-80 BTC-M 13,508' 30' 13,538' / 6,845' 6.75" 4.5" 12.6# L-80 IBT-M 761' 13,388'/6,744' 14,149' / 7,473' Evaluation Program: 13-1/2" Section Open Hole: MWD/GR - IFR/CASANDRA S er InSite G ro as needed 9-7/8" Section Open Hole: MWD/GR/RES/PWD IFR/CASANDRA S er InSite 6-3/4" Section Open Hole: MWD/GR/RES IFR/CASANDRA S er InSite 2 • • Cement Program: Casin Size f 0-3/4", 45.5, L-80, BTC Surface Casin at 8,156' MD Basis Excess from B/Permafrost to Surface = 150% over gauge hole. Use 30% excess below the B/Permafrost. Tail cement = 500' MD. Total Cement Volume: 858 bbl Wash 10 bbl water 25 bbl CW 100 S acer 75 bbl of MudPush Lead 808 bbl, 1022 sx of Arctic Set Lite: 10.7 ppg and 4.44 ft3/sx Tail 50 bbl, 234 sx "G" mixed at 15.8 Ib/ al & 1.20 ft /sx Tem Casin Point BHST 80 F estimated b Dowell Casin Size 7-5/8", 29.7#, L-80, BTC-M Intermediate Casin at 13,538' MD Basis Top of cement to be 500' MD above the shoe: 50% excess. Shoe Joint = 125 ft TOC = 13,038' MD Total Cement Volume: 34.4 bbl Wash 5-bbl water 25 bbl CW 100 S acer 40 bbl of MudPush Tail 34.4 bbl, 161 sx "G" mixed at 15.8 Ib/ al & 1.20 ft /sx Tem BHST =150°F from Schlumber er Chart Liner Size 4-1/2", 12.6#, L-80, IBT-M Production Liner: 13,388' to 14,149' MD Basis Top of cement to be 100' above the TOL. Liner Lap > 150'. O en Hole excess = 40%. Shoe Joint = 125 ft. TOC = 13,288' MD Total Cement Volume: 28.2 bbl Wash 5-bbl water 20 bbl CW 100 S acer 20 bbl of MudPush Tail 28.2 bbl, 132 sx "G" mixed at 15.8 Ib/ al & 1.20 ft /sx Tem BHST =174°F from Schlumber er Chart Formation. Markers: Formation Tops MD ft TVD (ft) Pore Pressure si EMW Ib/ al BPRF 2,000' 1,847' 8.30 TUZC 5,722' 3,447' 1,476 8.30 T/Schrader Bluff 7,223' 4,002' 1,717 8.30 T/Schrader Bluff "OA" 7,697' 4,177' 1,793 8.30 Deepest SB Sand 8,021' 4,297' 1,845 8.30 HRZ n/a n/a B/Colville 13,645' 6,982' 3,011 8.30 T/Kuparuk D 13,697' 7,032' 3,033 8.30 T/Kuparuk B 13,842' 7,152' 3,510 9.50 T/Kuparuk A3 13,847' 7,177' 3,522 9.50 T/Kuparuk A2 13,862' 7,192' 3,530 9.50 T/Kuparuk Al 13,888' 7,217' 3,542 9.50 T/Miluveach 13,949' 7,277' 3 Well Control: Intermediate/Production hole: • Maximum possible BHP: • Maximum surface pressure: • Planned BOP test pressure: • BOP Test Interval: • Integrity tests: Kick tolerance: • Planned completion fluid: • d 3,993 psi at 7,177' TVD (Kup A3 /based on MPF-87A) 3,275 psi at (Based on a full column of gas at 0.1 psi/ft) ~ 4,000 psi ~ Not to exceed 14 days - FIT to 11.3 Ib/gal 20' below the 10-3/4" shoe. 52-bbl with 10.0 Ib/gal mud at below the 10-3/4" shoe. - ~- °-- Kill Weight Brine with diesel cap. Drilling Hazards & Contingencies: • Hydrates have not been reported on any of the F-Pad wells and are not expected in MPF-93. ' • Tight hole and stuck pipe due to gravel beds, reactive clays and poor hole cleaning have all occurred in F Pad wells. Lost Circulation • We do not expect losses while drilling this well if there is good hole cleaning. • Losses are possible, however, while running and cementing the surface casing. Expected Pressures The Schrader Bluff sands are expected to be normally pressured: 8.35 ppg. The Kuparuk sands are most likely pressured up to 9.5 ppg EMW, however, F-87A ~ encountered Kuparuk A3 sand with an EMW of 10.7 ppg. Pad Data Sheet • Please Read the MPF-Pad Data Sheet thoroughly. Breathing Hazards • None expected, however, some H2S has been detected from wells on the pad (see below). • Appropriate precautions will be employed while drilling (ie: wind socks, H2S detectors, etc.) Hydrocarbons • Hydrocarbons may be encountered in the Ugnu through the Schrader Bluff sands, and will be encountered in the Kuparuk sands. Faults • This well path should not intersect any faults although it parallels several faults. Hydrogen Sulfide • MPF Pad is not designated as an H2S Pad, however, lo_ w concentrations of H2S have been ~ detected from Kuparuk wells on the pad: MPF-88i 7 ppm 9/2003 MPF-30i 32 ppm 9/2003 The highest concentration of H2S on MPF: MPF-53 47 ppm 9/2003 Anti-collision Issues • MPF-93i passes the Major Risk Criteria, however, gyro surveys will be required for close approach issues and magnetic interference down to ± 1000 ft MD. 4 • • Distance to Nearest Property • MPF-93 is 8,150 ft from the nearest Milne Point property line. - Distance to Nearest Well Within Pool • MPF-93 is 1,340 ft from the nearest Kuparuk sand penetration in MPF-45. DRILL & COMPLETION PROCEDURE Pre-Riq Operations 1. The 20" conductor will be installed pre-rig. 2. Secure waiver from AOGCC for diverter variance Drilling: 1. MIRT. PUDP, etc. 2. Drill 13.5" surface hole through all of the Schrader Bluff sands. 3. Run and cement 10.75" surface casing. 4. Install wellhead and NU/Test BOPE. 5. Drill 9.875" intermediate hole into the Kalubik. 6. Run and cement 7-5/8" intermediate casing. 7. Drill 6-3/4" hole through the Kuparuk sands and into the Miluveach. ' 8. Run and cement a 4.5" liner with HGR, ZXP &PBR. 9. Displace the well with kill weight brine. LDDP. 10. Run a 4-1/2" temporary "Frac" completion and sting into the PBR. 11. ND BOP/NU Tree. 12. Freeze Protect. 13. RD & MO Doyon 14. Post-Riq: 1. RU SLU. Drift & Tag run to PBTD. RD SLU. 2. RU E-Line. Perforate Kuparuk A sand(s) as directed (based on LWD's). RD E-Line. 3. Clean up the wellbore by swabbing, flowing or with CTU. 4. Frac the Kuparuk A sand(s). 5. RU SLU. Run a jet pump assembly. 6. Put the .well on production. 5 / ~ I \ r ~ z \ yp, 35'19'21" i \ O o \ a \ ''- LEGEND ~ I ~ -N- AS-BUILT WELL CONDUCTOR ~ I ^ EXISTING CONDUCTOR I I ~ 98 ~ I I ~ 97 ~ ^ 78 ^ 77 I I 96 ~ ^ 70 ^ 69 I I 94 ~ ^ 66 ^ 65 S[MPSON LAGOON 6 F PAD 5 4 -N- I Z ~ ~ L PAD ? ~ 7 ~8 9 ~ ~ N ~ a Q ~ 1 ou+5~'t 1 ^ ' 6 NOTES I ~~r~ ~ I 1. DATES OF SURVEY: APRIL 15-16, 1998 2. REFERENCE FIELD BOOK: MP98-03 Pgs. 11-20 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. I 93.E ~ 58 ~ 57 I 4. GEODETIC COORDINATES ARE NAD 1927. ~ I 92 ~ ~ 5. PAD SCALE FACTOR [S 0.99990199. I ^ 91 ^ 54 ^ 53 6. HORIZONTAL/VERTICAL CONTROL [S BASED ^ 90 ^ 50 ^ 49 ON MONUMENTS F-1 SOUTH AND F-2 I ^ 46 ^ 45 NORTH. ^ 89 I ^88 ^42 ^41 I . OF A I I ^ 86 ^ 34 ^ 33 I •~P `~ ° C~s'f' ~ ° ^ 30 ^ 29 °°9 ° I ^ 85 ^ 26 ^ 25 ~t a ~ °°° ~ ^ 84 ° ^ 22 ^ 21 ~ °°° °°° ° °° °° °°°°° °e°°° I ^ 83 ^18 ^17 I I ^82 ° ° ° I ^ a1 ^ 14 ^ 13 I ~ °°° STEPHEN STOLL ° ~ ' ° ' ^ 80 ^ 10 ^ 9 I ~ i _ ~ ° ~' 6726-S sT I ^ 79 ^ 6 2 ^ 5 °° ~~ F,~F°° aO D p ^ ^ 1 i R~ESS I ONA~ ~P ~ I SURVEYOR'S CERTIFICATE [ HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA ANO THAT ~ ' THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT ` F PAD J I " 1 DIMENS ONS AND OTHER DETAILS ARE ~ ~ , ~ I ~ CORRECT AS OF APRIL 16, 1998. LOCATED WI THW PRnTRACTFn SFC' OIR 7 13 N R 1G1 F IIMfAT MFRIf1TGN DI GCKA ''~ WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS F-92 Y=6,035,686.89 N=10,405.17 70'30'30.298" ' " 70.5084161' 11 5 2,236' FSL ' X= 541,725.37 E= 4,774.88 149'39 30.969 149.6586025' ' FEL 2,835 F-93 Y= 6,035,711.46 ~ N 10,435.20 70'30'30.539" ' " 70.5084831' 11 1 2,260' FSL ' X= 541,742.62 E= 4 774.75 149'39 30.457 149.6584603' ' FEL 2,818 F-94 Y=6,035,735.77 N=10,464.57 70'30'30.777" 70.5085492' 11 0 2 284' FSL X= 541,759.11 E= 4 774.14 149'39'29.967" 149.6583242' ' 2,801' FEL F-95 Y=6,035,760.07 N=10,494.89 70'30'31.015" ' " 70.5086153' 11 5 2,308' FSL ' X= 541,777.25 E= 4 774.90 149'39 29.429 149.6581747' ' 2,783 FEL F-96 Y=6,035,784.76 N10,525.24 70'30'31.257" ' " 70.5086825' 10 6' 2,333'- FSL ' X= 541,794.91 E= 4 775.03 149'39 28.905 149.6580292' . 2,765 FEL F-97 Y=6,035,809.28 N=10,555.09 70'30'31.497" ' 70.5087492' 11 5' 2,357' FSL X= 541,811.93 E= 4 774.74 149'39 28.399" 149.6578886' ' 2,; 48' FEL F-98 Y=6,035,833.80 N=10,585.17 70'30'31.737" ' " 70.5088158' 11 4' 2,382' FSL ' X= 541,829.34 E= 4,774.77 149'39 27.882 149.6577450' . FEL 2 730 i F. Robert °R""" STOLL CHECKED:LOH ; . gp EXPLORATION ~ °~'~ 4 19 98 " DRAM7N0i MPUFAB SHEET: ~ ,~ „D, MILNE POINT UNIT F-PAD t~lJlho x,~ AS-BUILT WELL CONDUCTORS 0 ISSUED F R INFORMATION °"°°"°'"'°"""'°" WELLS F-92 THROUGH F-98 1 or 1 ia. ~ 1~cwzo„ " ••, "`~° ,,•` 1 " = 200' sr aMC +b+~ .... •~ Tree: 4-1(16" - 5M FMC MPF-93 Proposed ~t. DF elev. = 47.0' D 14) Wellhead: 11" x 4.5" 5M Gen 6 ng. GL. eiev.= 11.1' w/ 4.5" TCII T&B Tubing Hanger CIW "H" BPV profile KOP @ 500` 20" 91.1-Ib/ft H-40 112` Max hole angle = 68.30 Camco 4.5" x 1" GLM 2000` ' 10.75-in 45.5-Ib/ft L-80 BTC casing 8156` J l 4.5" 12.6# L-80 IBT-M tubing 'Reverse Ciculelvn' Jel Pump CoMigurelion u i i'roeu ~ Flutl ~I ~ ~I a1 ' 81 1 1 ®~ ® 4.5" CMD sliding sleeve 13,268` 1 i 1 e [[ Yom/ I .'fur S m ~: 4.5" HES XN-Nipple 13,318` Reservoir FNk PBR w/ Seal Nipple 13,368` LNR HGR & ZXP at 13,388' 7.625-in 29.7-Ib/ft L-80 IBT-M casing 13 538` ( drift ID = 6.750", cap = 0.0459-bbl/ft) 4.5.-in Liner Shoe at 14,149` - ~ DATE REV. BY COMMENTS 26 May '05 SC Proposed Completion Perforate and frac Kuparuk A-sands ~ Estimated T/Kup A3 - 13,847` MD MILNE POINT UNIT WELL MPF-93 API NO: - BP EXPLORATION (AK) by ~ _~.. .___ _ ~ T.R ~r ~; - BP EXPLORATION . j M P F-93 Field: Milne Point Kuparuk A Sand ENG: S. Coyner Pad: F-Pad Producer RIG: Doyon 14 RKB: 47 ft DIR / LWD OH FORM DEPTH HOLE CASING MUD INFO MWD LOGS MD TVD SIZE SPECS PIT INFO INFO NONE NONE Permafrost 20.000-in Wellhead 91.1-Ib/ft H-40 FMC Gen 5 112' 42" Welded Insul " " MWD/GR , 20 x 11 5K NONE Gyro as needed Lead Cement Test Csg to 808 Bbls, 1022 sx 2000 psi 10.7 ppg 4.44 ft3/sx Base Penafrost 2,000' 1,847' 68.3° Surtace Csa 10-3/4" TUZC 5,722' 3,447' 45.5# L-80, BTC 150% Excess In Pennafrosj Int. Yield 5210 psi Collaspse 2470 psi Tail Cement T/Schrader Bluff 7,223' 4,002' S0 bbls, 234 sx 30°~ Excess ~~'- 15.8 PP9 B/Schrader Bluff 8,021' '°~~ 4,297' r 1.21 ft3/sx 1% BWOC CaCl2 Casing Point 8,156' 4,347 "';~:j3~ 68.3° 13.5" MWD/GR/R ES NONE PWD IFR/Cas 68.3° Inter. Casino Cement Slurry 50% Excess 7-5/8" 34.4 bbls, 161 sx 29.7 Ibs/ft 15.8 ppg L-80, BTC-M 1.20 ft3/sx Test Csg to 68.3° Int. Yield 6890 psi Class "G` 3500 psi Collaspse 4790 psi Top of Cement 13,038' 6426 23° Top/LNR2XP/PBR 13,388' 6,744' Casin Point 13,538' 6,882' 23° 9 875" MWD/GR/RES ' . B/Colville Top / Kuparuk D 13,697 7,032' Prod Liner Top / Kuparuk B 13,821' 7,152' 12° a-1/2" , 12.6#, L-80 Test LNR to Top / Kuparuk A 13,847' 7,177' Liner Cement 3500 psi IFR/Cas Top /Miluveach 13,949' 7,277' 28 bbl, 132 sx 40% Excess rv n,nw,n w , Liner Point 14,149' 7,472' 12° 6.75" Class G, 15.8# Miluveach `~~~"'~~'~ MPF-93 Well Plan Schematic.xls COMPANY DET.ULS joky; BP.irtoco (, j [1[~ Glculanon Medal Minimum Cmwme ~1~F Emx SYS•n^: ISCWSA Scan Method: Tmv Cylialer North Enor Surface: Elliptical-C ~ blaming Method Rules Based na L i i I Coardinaa: (N.'EI Reference: We0 Cmre: Ran MPF-93, Tme Nash Veniral lTVDIR~ 12.]'34347.00 Saxon (VSI Reference: Sbl- IO.OON.O.OOEI Meuurdl Depth Reference: 12.7 * J63 47.00 Cakulanon MetM3 Mmimw Cmvazwe CASING DETAILS TVD MD Name N Size o. I I I 1 4347.00 8156.31 10 3/4" 10.750 I 2 6882.00 13537.80 7 5/8" 7.625 3 7471.74 14148.00 (ICI/2" 5.500 r ~ 390 - - ~ I 1 L - I la D - u -- ~''~ - -~-._._ -- -- _.. L __ .. ... - - ~_ l I. I I I {I~ > I ~ -- I --- - - -- i- _. 2 i -- - t ~ - 1 I 520 _- _ _: - i n SURVEY PROGR4M Plan: MPF-93 wp05 (Plan MPF-93/MPF-93) Deem Fm Depla T O SuneyPlm Tool CreatedB Di rte! Business Cliem User Dare: S/19/2005 Y: 8 3430 120!1.00 PhvmaG MPF-97 wp05 V36 CBf.YRO-SS Cheek ed: Date: 1200.00 16148.9 1 Plano t MPFA7 wp05 V74 MWD-IFR~MS Reviewed: Dat<: SECTION DETAILS Sec MD Inc .4zi TVD +N/-S +E/-W DLeg TFace VSec Target 1 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 2 275.00 0.00 0.00 275.00 0.00 0.00 0.00 0.00 0.00 3 475.00 3.00 350.00 474.91 5.16 -0.91 1.50 350.00 5.23 4 675.00 7.00 350.00 674.11 22.32 -3.94 2.00 0.00 22.66 5 1708.33 38.00 350.00 1617.18 407.02 -71.77 3.00 0.00 413.17 6 2130.69 38.00 350.00 1950.00 663.09 -116.92 0.00 0.00 673.12 7 2888.78 68.30 351.54 2399.38 1255.15 -211.50 4.00 2.83 1272.66 8 12055.29 68.30 351.54 5788.62 9679.30 -1465.20 0.00 0.00 9789.57 9 13187.80 23.00 351.45 6559.82 10459.56 -1581.67 4.00 -179.95 10578.48 10 13537.80 23.00 351.45 6882.00 10594.80 -1602.00 0.00 0.00 10715.23 I1 13812.71 12.00 351.50 7143.78 10676.43 -1614.25 4.00 179.95 10797.78 IZ 13948.91 12.00 351.50 7277.00 10704.45 -1618.43 0.00 0.00 10826.11 MPF-93 Tl 13 14148.91 12.00 351.50 7472.63 10745.59 -1624.58 0.00 0.00 10867.70 TARGET DETAILS Name TVD +N/-S +E/-W Northing Easting Shape MPF-93 Tt 7277.00 10704.45 -(61 8.43 6046405.02 5401165.05 Circle (Radius: 120) j I I it WELL DETAILS - -- -- ~ Narre *N/-S -FJ-W NoNtirg F ang Lazimdc Longinuk Slog _- _ - - i ~' ~ PIan MPF-97 5]10.41 995452 M1J5710.68 561 ]47A5 ]0°3030.531N 149°39'J0.432W N~A - I I {. j [- +-- 1I.. - _ I i ~ ~~, I 'I I 1 ~ jll FORMATION TOP DETAILS -- f ~ I ~ I ~ { i No. TVDPath MDPath Formation { ----- I 1847.00 1999.98 BPRF ', '', ; I 2 3447.00 5722.17 TUZC I - - + - _ ~ 3 4002.00 7223.22 Top Schrader ~q 1 I 4 4177.00 7696.52 TSBD-OA '~` i i I _ ~ _ ~ 5 4297.00 8021.08 Lowest Schrader Sand 8000 ` t _ - ~- 6 6982.00 13644.84 Base Colville ~ 8500 `'~.; ? r 7 7032.00 13697.32 TKUD Il ~, . 8 7152.00 13821.12 TKUB QOQO 9 7172.00 13841.56 TKUA ' ~ 9300 _ I { ~ ' 10 7177.00 13846.68 TKA3 i I ', ', . II 7192.00 13862.01 TKA2 t 12 7217.00 13887.57 TKAI ' I i 13 7277.00 13948.91 TMLV - - - - IDS '. ~ i i 14 0.00 0.00 Kup "A" OWC -{ 1 1 . 11 I ,..,, - i .. - 2 ' 1 V - - 1 _i i 3ta Dir tt /1IX M Y :1 055 29 _ D; 5 8862 _ D 12Slkl 75/8" +~ - - -- - l ~ End r : 13187.8' Mb, 6 559.82' 7 V - - - _ . ~ - Base Co o Ile I _ '-, - - ~`-~~ --` a ~ TKUD { - -- l Stan Dir 4/1 00': 13531.' ,6882'TVD MD `, j ~ -:--~ 1300' 2600 3900 5200 6500 7800 9100 10400 11700 Vertical Section at 351.40° [1300Nin] 1)f I COMPANY DETARS BP Amoco REFEREN Coonk,ute IN'EI Rafererce: CE M W'ellC FOR rnu M.4 e: Pl TION m MPF A3, Tme NaW SURVEY PROGRAM Plan: MPF-9J wp05 (PlanMPF-93/MPF-93) Depth Fm Depth To Survey~'P6x T9ol Created By: Digiul Business Clim User Date: 5/19/2005 CakuWion Method: Mmmnvn Curvmme Vertical I tVDI Ruferetas: Section lVSl Re( e. 12.] - Std-( 343 O.OO 47. N.O f0 .fOEI 34J0 1200.00 Platmd: MPFA3 wp05 VJ4 CB-GYRO-SS Checked: Dale: Error Symem: ISCWSA Srax Method: Tnv Cylivda North Measured l]eph Retererce: Ca4vlatnn Method 12.7 - Mmmu 34J m C un 4].011 ame 1200.00 14148.91 Flamed MPFA3 x705 V34 MWD-IFR-MS Ena SuRxe: EOipir I-Casing WELL DET.4LLS Wammg Method: Ruka Based Nmrc -WS -F/-W Nathvg Ftvbng IJtixih longitude Sbt PIan MPF-9J 5]10.41 995432 6035710.88 511711.45 ]0°3VJO.SJ7N 149°3930.432w W.4 TARGET DETAILS Name TVD +N/-S +E/-W Northing Fasting Shape i I fF~93~w~0# ! i ~ i ~ ~ I ~! i I ~ ~ ~ ~ ~ MPF-93 TI 7277.00 10704.45 -1618.43 6046405.02 540065.05 Circle (Radius: 120) 1200 , ~ 1 ~ ~ ~ ~ ~ ~ 1 MPF-93 Fault( 7347.00 9527.47 -1290.02 6045230.01 540400.05 Polygon ' I "F Dpp I oral! ~ 92.63 14145.511' ~MD, 4 TVD ~ -- _ - !-- ~ ~ ~'~ ~ ~ MPF-93 Fault2 7347.00 IOI26.39 -1086.62 6045830.01 540600.05 Polygon - , i i l ~ '' - -- - I ~ - - MPF-93 Fault3 7347.00 9406.67 -1150.68 6045110.01 540540.05 Polygon MP;= 93 Eljd ~i :93$12.71' MD, 7143.78' VD -- I MPF-93 Fault 4 7347.00 10705.48 -913.35 6046410.01 540770.05 Polygon Start 7 4/100' :13537.8' MD,:6 2T{[D~ _ ~ ''~, SECTION DETAILS 5;1/2" - MPFA3 TI I II 1 ~ i - -- - ~ _ ._ I ~ Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Tazget 1 ~ ~ i ~ ~ -- ' - I( I 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 7 S/8" ~ _. ! MPF-93 Fault4 ! ~ ~ - - --- 1 - -- 1 2 275.00 0.00 0.00 275.00 0.00 0.00 0.00 0.00 0.00 L50 350 00 5 23 0 9 1000 ' ~ ~ ~ -- End Dir :13187 81 '6~54 8Z' TVIh i ~ ~ ~ ~' . . I 3 475.00 3.00 350.00 474.91 5.16 - . 1 4 675.00 7.00 350.00 674.1 I 22.32 -3.94 2.00 0.00 22.66 r 60 i . . , i 5 1708.33 38.00 350.00 1617.18 407.02 -71.77 3.00 0.00 4(3.17 MPF 93 F l 2- ' ~ ~ ' ~ 6 2130.69 38.00 350.00 1950.00 663.09 -I 16.92 0.00 0.00 673.12 - au t . i ', ~ . - 7 2888.78 68.30 351.54 2399.38 1255.15 -211.50 4.00 2.83 1272.66 ~ i 8 12055.29 68.30 351.54 5788.62 9679.30 -1465.20 0.00 0.00 9789.57 I li ~ i '~, M1yF-93 Fault( _ ~ ~ i _ { 9 13187.80 23.00 351.45 6559.82 10459.56 -1581.67 4.00 -179.95 10578.48 , ' ~ _ 10 13537.80 23.00 351.45 6882.00 10594.80 -1602.00 0.00 0.00 10715.23 ~, ( 1 j 15 F-93 Fault3 , ~ ''~ II 13812.71 ]2.00 351.50 7143.78 10676.43 -1614.25 4.00 179.95 10797.78 II Stgrt ~ ir4/Id0'; 12055291M D 62'TVD ~ ~ 5788 ~ i 12 13948.91 12.00 351.50 7277.00 10704.45 -1618.43 0.00 0.00 10826.11 MPF-93 T1 ; i , . , _. ~ i 13 14148.91 12.00 351.50 7472.63 10745.59 -1624.58 0.00 0.00 10867.70 800 ' ' , I : - - ' . j ~' SOt10 I i ` I ! ', '--- '-~ -- - i - ' - ~ FORMATION TOP DETAILS ' ~ ' I ~ - -1 , i + r - ~ ~ - 1 i ~' t~ - ~ t TVDPath MDPath FormatioD No ~ . - ~ , - . ~ - . 1 I ~ I 1 i f . ~ ~ - ~ ~ 10 %4k ~ - ~ ~ - ~ 1 1847.00 1999.98 BPRF ° ) I ~ ~ ~ -- 2 3447.00 5722.17 TUZC -~ - -- i -_ { - -- l ~ -• ' ~ _I. -- i - ~ 1 3 4002.00 7223.22 Top Schrader + - -- ~ ~ ' r 1 r 4 4177.00 7696.52 TSB0.0A r 600 ! i I - -- ~, -- 5 4297.00 8021.08 Lowest Schrader Sand + -+ - _ j _I. 6 6982.00 13644.84 Base Colville ~ ~ _ ~ - - -- _ ~ --- - ~ - -- - -- ~ 7 7032.00 13697.32 TKUD 00 13821 12 TKUB 8 7152 i - ~ - - - 4! ~ ` -- --- - - - _ - - - , -- - - ~ r r- -i . . 9 7172.00 13841.56 TKUA ~ o r ~ _ _ ~ .-i 10 7177.00 13846.68 TKA3 ~' - fL-- ~ RO l-O . -- - - - - _~ 1 I I 7192.00 13862.01 TKA2 `I _ I _ __ __ _ _ _ 12 7217.00 13887.57 TKAI -. -- _- ; ~ ,. ~ ~ - ,, ~ - _ _ - 13 7277.00 13948.91 TMLV - - - I ~ __ i - i ~ 14 0.00 0.00 Kup "A" OWC I 400 I I 1 - _ _ + I _ . _ ~ 35 0 i - - - ~ ~ - - - i - - _ - ~ I _' - I - - CASING DETAILS _ I :r I - - - - I - -- - - _ .. . 1 - .-.,- -- - - 1 - ,- ~ ~ ~. ~ 1-- : ! - ~ ~ 1 1 I ~ No. TVD MD Name Sia _ __ ._ _ 1 ~ i _~ 1 4347.00 8156.31 10 3/4" 10.750 End Dlr .2888. MD, 2399.38 TVD - ~ 2 6882.00 13537.80 7 5/8" 7.625 ~- ' 3040 Di 4/1 S 69' MD 1950'T 2130 ' V : -~' i ' - - _ ~ _~~ 3 7471 74 14148 00 5 (/2 5 500 . . ... - - - tart r .. ; . : .-- - ~ - 200 - - - .'1 I 633' MD 1617 IB' TVD 1 .- -~-- r - - - -- +- -- - -- - - -- - F- - -. i . l - _ { , I I T ~` 1 -- - _ .. "- --- ~ Dir Stlart 100' :475 MD 474 4I '-- -- ~ - - ~ o , . ~ I I 4 3/100" 75' D 6 &1 ~! - -- I- - - - -- - ~ I 1 ~ ! Start . :8 ; r Y M - --- I - - ~ ~ ~ - , ' 2 ~ Sta Dir 1.51100' :275' MD, 2 'TVD ~.. - _ L - _ -_ _- _ I '- 0 2000 4000 6000 8000 10000 West(-)/East(+) [2000ft/in] Sperry-Sun BP Planning Report Company: BP Amoco Date: 5/1 9120 05 Time: 15:50:18 Page: 1 Feld: Milne Point Co-ordinate(NE) Reference: W e11: Plan MPF-93, True North Site: M Pt F Pad Vertical (TVD) Reference: 12.7 +34.3 47.0 Well: Plan MPF-93 Section (VS) Reference: Well (O.OON,O.OOE,351.40Azi) VVellpath: .MPF-93 Survey Calculation Method: Minimum Curvature Db: Oracle Plan: MPF-93 wp05 Date Composed: 3/30/2005 Version: 34 Principal: Yes Tied-to: From: Definitive Path Field: Milne Point North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: M Pt F Pad TR-13-10 UNITED STATES :North Slope Site Position: Northing: 6029958.49 ft Latitude: 70 29 34.438 N From: Map Easting: 531814.44 ft Longitude: 149 44 23.616 W Position Uncertainty: 0.00 ft North Reference: True Ground LeveL• 0.00 ft Grid Convergence: 0.25 deg WeU: Plan MPF-93 Slot Name: MPF-93 WeU Position: +N/-S 5710.41 ft Northing: 6035710.88 ft Latitude: 70 30 30.533 N +E/-W 9954.52 ft Easting : 541743.45 ft Longitude: 149 39 30.432 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 8156.31 4347.00 10.750 13.500 103/4" 13537.80 6882.00 7.625 9.875 7 5!8" 14148.00 7471.74 5.500 6.750 5 1 /2" Formations MD ft TVI) ft Formations Lithology Dip Angle deg. Dip Direction deg 1999.98 1847.00 BPRF 0.00 0.00 5722.17 3447.00 TUZC 0.00 0.00 7223.22 4002.00 Top Schrader 0.00 0.00 7696.52 4177.00 TSBD-OA 0.00 0.00 8021.08 4297.00 Lowest Schrader Sand 0.00 0.00 13644.84 6982.00 Base Colville 0.00 0.00 13697.32 7032.00 TKUD 0.00 0.00 13821.12 7152.00 TKUB 0.00 0.00 13841.56 7172.00 TKUA 0.00 0.00 13846.68 7177.00 TKA3 0.00 0.00 13862.01 7192.00 TKA2 0.00 0.00 13887.57 7217.00 TKA1 0.00 0.00 13948.91 7277.00 TMLV 0.00 0.00 0.00 Kup "A" OWC 0.00 0.00 Map Map << Latitnde -> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Fasting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft MPF-93 T1 7277.00 10704.45 -1618.43 6046405.02 540065.05 70 32 15.806 N 149 40 18.168 W -Circle (Radius: 120) -Plan hit target MPF-93 Fault 1 7347.00 9527.47 -1290.02 6045230.01 540400.05 70 32 4.232 N 149 40 8.475 W -Polygon 1 7347.00 9527.47 -1290.02 6045230.01 540400.05 70 32 4.232 N 149 40 8.475 W -Polygon 2 7347.00 10430.63 -1835.00 6046130.01 539850.05 70 32 13.113 N 149 40 24.553 W -Plan out by 1236.71 at 7347.00 10719.17 -1620.63 6046419.72 540062.77 70 32 15.951 N 149 40 18.233 W MPF-93 Fault 2 7347.00 10126.39 -1086.62 6045830.01 540600.05 70 32 10.122 N 149 40 2.480 W -Polygon 1 7347.00 10126.39 -1086.62 6045830.01 540600.05 70 32 10.122 N 149 40 2.480 W -Poygon 2 7347.00 10430.63 -1835.00 6046130.01 539850.05 70 32 13.113 N 149 40 24.553 W -Plan out by 797.84 at 7347.00 10719.17 -1620.63 6046419.72 540062.77 70 32 15.951 N 149 40 18.233 W i • Sperry-Sun BP Planning Report Company: BP Amoco Date: 5/19/2005 Time: 15:50:18 Page: 2 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPF-93, True North i Site: M Pt F Pad Vertical (TVD) Reference: 12.7 +34.3 47.0 Well: Plan MPF-93 Section (VS) Reference: Wel{ (O.OON,O .OOE,351.40Azi~ Wellpath: MPF-93 Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map <- Latitude -> <- Longitude -> Name Description TVD +N/-S +E/=W Northing Eastin g Deg Min Sec Deg Min Sec Dip. Dir.. ft ft ft ft ft MPF-93 Fault 3 7347.00 9406.67 -1150.68 6045110.01 540540 .05 70 32 3.044 N 149 40 4.365 W -Polygon 1 7347.00 9406.67 -1150.68 6045110.01 540540.05 70 32 3.044 N 149 40 4.365 W -Polygon 2 7347.00 10795.27 -872.85 6046500.01 540810 .05 70 32 16.701 N 149 39 56.177 W -Plan out by 1394.10 at 7347.00 10719.17 -1620.63 6046419.72 540062 .77 70 32 15.951 N 149 40 18.233 W MPF-93 Fault 4 7347.00 10705.48 -913.35 6046410.01 540770 .05 70 32 15.818 N 149 39 57.371 W -Polygon 1 7347.00 10705.48 -913.35 6046410.01 540770 .05 70 32 15.818 N 149 39 57.371 W -Polygon 2 7347.00 11419.87 -1679.42 6047120.01 540000 .05 70 32 22.842 N 149 40 19.971 W -Plan out by 707.42 at 7347.00 10719.17 -1620.63 6046419.72 540062 .77 70 32 15.951 N 149 40 18.233 W Plan Section Information MD Inel Azim TVD +NJ-S +E/-W 'DLS Build Turn TFO Target ft deg deg ft ft tt degl100ft deg1100ft deg/100ft deg 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 0.00 275.00 0.00 0.00 275.00 0.00 0.00 0.00 0.00 0.00 0.00 475.00 3.00 350.00 474.91 5.16 -0.91 1.50 1.50 0.00 350.00 675.00 7.00 350.00 674.11 22.32 -3.94 2.00 2.00 0.00 0.00 1708.33 38.04 350.00 1617.18 407.02 -71.77 3.00 3.00 0.00 0.00 2130.69 38.00 350.00 1950.00 663.09 -116.92 0.00 0.00 0.00 0.00 2888.78 68.30 351.54 2399.38 1255.15 -211.50 4.00 4.00 0.20 2.83 12055.29 68.30 351.54 5788.62 9679.30 -1465.20 0.00 0.00 0.00 0.00 13187.80 23.00 351.45 6559.82 10459.56 -1581.67 4.00 -4.00 -0.01 -179.95 13537.80 23.00 351.45 6882.00 10594.80 -1602.00 0.00 0.00 0.00 0.00 13812.71 12.00 351.50 7143.78 10676.43 -1614.25 4.00 -4.00 0.02 179.95 13948.91 12.00 351.50 7277.00 10704.45 -1618.43 0.00 0.00 0.00 0.00 MPF-93 T1 14148.91 12.00 351.50 7472.63 10745.59 -1624.58 0.00 0.00 0.00 0.00 Survey MD IACI A~rm_ T'VD SysTVD N/S E/VV DLS MapN MapE TooUComme t ft deg deg ft ft ft ft deg/100ft ft ft 34.30 0.00 0.00 34.30 -12.70 0.00 0.00 0.00 6035710.88 ~ 541743.45 ' CB-GYRO-SS 100.00 0.00 0.00 100.00 53.00 0.00 0.00 0.00 6035710.88 541743.45 CB-GYRO-SS 200.00 0.00 0.00 200.00 153.00 0.00 0.00 0.00 6035710.88 541743.45 CB-GYRO-SS 275.00 0.00 0.00 275.00 228.00 0.00 0.00 0.00 6035710.88 541743.45 Start Dir 1.5/1 300.00 0.38 350.00 300.00 253.00 0.08 -0.01 1.50 6035710.96 541743.44 CB-GYRO-SS 400.00 1.88 350.00 399.98 352.98 2.01 -0.36 1.50 6035712.89 541743.08 CB-GYRO-SS 475.00 3.00 350.00 474.91 427.91 5.16 -0.91 1.50 6035716.03 541742.51 Start Dir 2/100 500.00 3.50 350.00 499.87 452.87 6.55 -1.16 2.00 6035717.42 541742.26 CB-GYRO-SS 600.00 5.50 350.00 599.56 552.56 14.28 -2.52 2.00 6035725.14 541740.85 CB-GYRO-SS 675.00 7.00 350.00 674.11 627.11 22.32 -3.94 2.00 6035733.17 541739.39 Start Dir 3!100 700.00 7.75 350.00 698.90 651.90 25.48 -4.49 3.00 6035736.33 541738.81 CB-GYRO-SS 800.00 10.75 350.00 797.59 750.59 41.31 -7.28 3.00 6035752.14 541735.94 CB-GYRO-SS 900.00 13.75 350.00 895.30 848.30 62.20 -10.97 3.00 6035773.01 541732.13 CB-GYRO-SS 1000.00 16.75 350.00 991.77 944.77 88.10 -15.53 3.00 6035798.88 541727.42 CB-GYRO-SS 1100.00 19.75 350.00 1086.73 1039.73 118.94 -20.97 3.00 6035829.69 541721.81 CB-GYRO-SS 1200.00 22.75 350.00 1179.92 1132.92 154.63 -27.26 3.00 6035865.34 541715.32 MWD+IFR+MS 1300.00 25.75 350.00 1271.08 1224.08 195.07 -34.40 3.00 6035905.73 541707.96 MWD+IFR+MS 1400.00 28.75 350.00 1359.97 1312.97 240.16 -42.35 3.00 6035950.77 541699.76 MWD+IFR+MS 1500.00 31.75 350.00 1446.35 1399.35 289.76 -51.09 3.00 6036000.32 541690.73 MWD+IFR+MS 1600.00 34.75 350.00 1529.97 1482.97 343.75 -60.61 3.00 6036054.25 541680.91 MWD+IFR+MS 1700.00 37.75 350.00 1610.60 1563.60 401.98 -70.88 3.00 6036112.41 541670.32 MWD+IFR+MS 1708.33 38.00 350.00 1617.18 1570.18 407.02 -71.77 3.00 6036117.45 541669.40 End Dir :1708 1800.00 38.00 350.00 1689.41 1642.41 462.60 -81.57 0.00 6036172.96 541659.29 MWD+IFR+MS 1900.00 38.00 350.00 1768.22 1721.22 523.23 -92.26 0.00 6036233.53 541648.26 MWD+IFR+MS 1999.98 38.00 350.00 1847.00 1800.00 583.84 -102.95 0.00 6036294.08 541637.23 BPRF 2000.00 38.00 350.00 1847.02 1800.02 583.86 -102.95 0.00 6036294.09 541637.23 MWD+IFR+MS 2100.00 38.00 350.00 1925.82 1878.82 644.49 -113.64 0.00 6036354.66 541626.20 MWD+IFR+MS i ~ Sperry-Sun BP Planning Report Company: BP Amoco Date: 5/19/2005 Time: 15:50:18 Page: 3 Field: Milne Ppint Co-ordinate(NE) Reference: Well: Plan MPF-93, True North Site: M Pt F Pad Vertical (TVD) Reference: 12.7 +34.3 47.0 .Well: Plan MPF-93 Section (VS) Reference: Well (O.OON,O.OOE,351.40Azi) Wellpath: MPF-93 Survey Calculation Method: Minimum Curvature Db: Oracle Survey °MD Incl Azim TVD Sys TVD N/S E/W DLS MapN MapE TooUComme t ft deg deg ft ft ft ft deg/10pft ft ft 2130.69 38.00 350.00 1950.00 1903.00 663.09 -116.92 0.00 6036373.24 541622.82 Start Dir 4/100 2200.00 40.77 350.21 2003.57 1956.57 706.42 -124.48 4.00 6036416.52 541615.02 MWD+IFR+MS 2300.00 44.77 350.47 2076.96 2029.96 773.34 -135.86 4.00 6036483.37 541603.26 MWD+IFR+MS 2400.00 48.76 350.70 2145.45 2098.45 845.20 -147.77 4.00 6036555.16 541590.95 MWD+IFR+MS 2500.00 52.76 350.90 2208.69 2161.69 921.64 -160.14 4.00 6036631.52 541578.15 MWD+IFR+MS 2600.00 56.76 351.09 2266.39 2219.39 1002.29 -172.92 4.00 6036712.09 541564.92 MWD+IFR+MS 2700.00 60.75 351.25 2318.25 2271.25 1086.76 -186.03 4.00 6036796.47 541551.33 MWD+IFR+MS 2800.00 64.75 351.41 2364.02 2317.02 1174.63 -199.43 4.00 6036884.25 541537.44 MWD+IFR+MS 2888.78 68.30 351.54 2399.38 2352.38 1255.15 -211.50 4.00 6036964.69 541524.92 End Dir :2888 2900.00 68.30 351.54 2403.53 2356.53 1265.46 -213.04 0.00 6036975.00 541523.32 MWD+IFR+MS 3000.00 68.30 351.54 2440.50 2393.50 1357.36 -226.72 0.00 6037066.81 541509.13 MWD+IFR+MS 3100.00 68.30 351.54 2477.48 2430.48 1449.26 -240.39 0.00 6037158.62 541494.94 MWD+IFR+MS 3200.00 68.30 351.54 2514.45 2467.45 1541.16 -254.07 0.00 6037250.44 541480.75 MWD+IFR+MS 3300.00 68.30 351.54 2551.42 2504.42 1633.06 -267.75 0.00 6037342.25 541466.56 MWD+IFR+MS 3400.00 68.30 351.54 2588.40 2541.40 1724.96 -281.42 0.00 6037434.07 541452.37 MWD+IFR+MS 3500.00 68.30 351.54 2625.37 2578.37 1816.87 -295.10 0.00 6037525.88 541438.17 MWD+IFR+MS 3600.00 68.30 351.54 2662.35 2615.35 1908.77 -308.78 0.00 6037617.69 541423.98 MWD+IFR+MS 3700.00 68.30 351.54 2699.32 2652.32 2000.67 -322.45 0.00 6037709.51 541409.79 MWD+IFR+MS 3800.00 68.30 351.54 2736.30 2689.30 2092.57 -336.13 0.00 6037801.32 541395.60 MWD+IFR+MS 3900.00 68.30 351.54 2773.27 2726.27 2184,47 -349.81 0.00 6037893.14 541381.41 MWD+IFR+MS 4000.00 68.30 351.54 2810.24 2763.24 2276.37 -363.48 0.00 6037984.95 541367.22 MWD+IFR+MS 4100.00 68.30 351.54 2847.22 2800.22 2368.27 -377.16 0.00 6038076.77 541353.02 MWD+IFR+MS 4200.00 68.30 351.54 2884.19 2837.19 2460.18 -390.84 0.00 6038168.58 541338.83 MWD+IFR+MS 4300.00 68.30 351.54 2921.17 2874.17 2552.08 -404.52 0.00 6038260.39 541324.64 MWD+IFR+MS 4400.00 68.30 351.54 2958.14 2911.14 2643.98 -418.19 0.00 6038352.21 541310.45 MWD+IFR+MS 4500.00 68.30 351.54 2995.11 2948.11 2735.88 -431.87 0.00 6038444.02 541296.26 MWD+IFR+MS 4600.00 68.30 351.54 3032.09 2985.09 2827.78 -445.55 0.00 6038535.84 541282.07 MWD+IFR+MS 4700.00 68.30 351.54 3069.06 3022.06 2919.68 -459.22 0.00 6038627.65 541267.87 MWD+IFR+MS 4800.00 68.30 351.54 3106.04 3059.04 3011.58 -472.90 0.00 6038719.46 541253.68 MWD+IFR+MS 4900.00 68.30 351.54 3143.01 3096.01 3103.48 -486.58 0.00 6038811.28 541239.49 MWD+IFR+MS 5000.00 68.30 351.54 3179.98 3132.98 3195.39 -500.25 0.00 6038903.09 541225.30 MWD+IFR+MS 5100.00 68.30 351.54 3216.96 3169.96 3287.29 -513.93 0.00 6038994.91 541211.11 MWD+IFR+MS 5200.00 68.30 351.54 3253.93 3206.93 3379.19 -527.61 0.00 6039086.72 541196.92 MWD+IFR+MS 5300.00 68.30 351.54 3290.91 3243.91 3471.09 -541.28 0.00 6039178.53 541182.72 MWD+IFR+MS 5400.00 68.30 351.54 3327.88 3280.88 3562.99 -554.96 0.00 6039270.35 541168.53 MWD+IFR+MS 5500.00 68.30 351.54 3364.86 3317.86 3654.89 -568.64 0.00 6039362.16 541154.34 MWD+IFR+MS 5600.00 68.30 351.54 3401.83 3354.83 3746.79 -582.31 0.00 6039453.98 541140.15 MWD+IFR+MS 5700.00 68.30 351.54 3438.80 3391.80 3838.70 -595.99 0.00 6039545.79 541125.96 MWD+IFR+MS 5722.17 68.30 351.54 3447.00 3400.00 3859.07 -599.02 0.00 6039566.14 541122.81 TUZC 5800.00 68.30 351.54 3475.78 3428.78 3930.60 -609.67 0.00 6039637.60 541111.77 MWD+IFR+MS 5900.00 68.30 351.54 3512.75 3465.75 4022.50 -623.35 0.00 6039729.42 541097.57 MWD+IFR+MS 6000.00 68.30 351.54 3549.73 3502.73 4114.40 -637.02 0.00 6039821.23 541083.38 MWD+IFR+MS 6100.00 68.30 351.54 3586.70 3539.70 4206.30 -650.70 0.00 6039913.05 541069.19 MWD+IFR+MS 6200.00 68.30 351.54 3623.67 3576.67 4298.20 -664.38 0.00 6040004.86 541055.00 MWD+IFR+MS 6300.00 68.30 351.54 3660.65 3613.65 4390.10 -678.05 0.00 6040096.67 541040.81 MWD+IFR+MS 6400.00 68.30 351.54 3697.62 3650.62 4482.01 -691.73 0.00 6040188.49 541026.61 MWD+IFR+MS 6500.00 68.30 351.54 3734.60 3687.60 4573.91 -705.41 0.00 6040280.30 541012.42 MWD+IFR+MS 6600.00 68.30 351.54 3771.57 3724.57 4665.81 -719.08 0.00 6040372.12 540998.23 MWD+IFR+MS 6700.00 68.30 351.54 3808.54 3761.54 4757.71 -732.76 0.00 6040463.93 540984.04 MWD+IFR+MS 6800.00 68.30 351.54 3845.52 3798.52 4849.61 -746.44 0.00 6040555.74 540969.85 MWD+IFR+MS 6900.00 68.30 351.54 3882.49 3835.49 4941.51 -760.11 0.00 6040647.56 540955.66 MWD+IFR+MS 7000.00 68.30 351.54 3919.47 3872.47 5033.41 -773.79 0.00 6040739.37 540941.46 MWD+IFR+MS 7100.00 68.30 351.54 3956.44 3909.44 5125.31 -787.47 0.00 6040831.19 540927.27 MWD+IFR+MS ~ i Sperry-Sun BP Planning Report Company:. BP Amoco Date: 5/19/2005 Time: 15:50:18 Page: 4 Field: Mil ne Point Co-ordinate(NE) Reference: Well: Plan MPF-93, True North Site: M Pt F Pad Vertic al (TVD) Reference: 12.7 ~ 34.3 47.0 Well: Plan MPF-93 Section (VS) Reference: W eli (O.OON,O.OOE,351.40Azi) Wellpath: MPF-93 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD Pi/S E/V1' DLS MapN MapE TooUComme t ft' deg deg ft fl ft ft deg/100k ft ft 7200.00 68.30 351.54 3993.41 3946.41 5217.22 -801.14 0.00 6040923.00 540913.08 MWD+IFR+MS 7223.22 68.30 351.54 4002.00 3955.00 5238.56 -804.32 0.00 6040944.32 540909.79 Top Schrader 7300.00 68.30 351.54 4030.39 3983.39 5309.12 -814.82 0.00 6041014.81 540898.89 MWD+IFR+MS 7400.00 68.30 351.54 4067.36 4020.36 5401.02 -828.50 0.00 6041106.63 540884.70 MWD+IFR+MS 7500.00 68.30 351.54 4104.34 4057.34 5492.92 -842.17 0.00 6041198.44 540870.51 MWD+IFR+MS 7600.00 68.30 351.54 4141.31 4094.31 5584.82 -855.85 0.00 6041290.26 540856.31 MWD+IFR+MS 7696.52 68.30 351.54 4177.00 4130.00 5673.53 -869.05 0.00 6041378.88 540842.62 TSBD-OA 7700.00 68.30 351.54 4178.29 4131.29 5676.72 -869.53 0.00 6041382.07 540842.12 MWD+IFR+MS 7800.00 68.30 351.54 4215.26 4168.26 5768.62 -883.21 0.00 6041473.88 540827.93 MWD+IFR+MS 7900.00 68.30 351.54 4252.23 4205.23 5860.53 -896.88 0.00 6041565.70 540813.74 MWD+IFR+MS 8000.00 68.30 351.54 4289.21 4242.21 5952.43 -910.56 0.00 6041657.51 540799.55 MWD+IFR+MS 8021.08 68.30 351.54 4297.00 4250.00 5971.$0 -913.44 0.00 6041676.86 540796.56 Lowest Schrade 8100.00 68.30 351.54 4326.18 4279.18 6044.33 -924.24 0.00 6041749.33 540785.36 MWD+IFR+MS 8156.31 68.30 351.54 4347.00 4300.00 6096.07 -931.94 0.00 6041801.02 540777.37 103/4" 8200.00 68.30 351.54 4363.16 4316.16 6136.23 -937.91 0.00 6041841.14 540771.16 MWD+IFR+MS 8300.00 68.30 351.54 4400.13 4353.13 6228.13 -951.59 0.00 6041932.96 540756.97 MWD+IFR+MS 8400.00 68.30 351.54 4437.10 4390.10 6320.03 -965.27 0.00 6042024.77 540742.78 MWD+IFR+MS 8500.00 68.30 351.54 4474.08 4427.08 6411.93 -978.94 0.00 6042116.58 540728.59 MWD+IFR+MS 8600.00 68.30 351.54 4511.05 4464.05 6503.84 -992.62 0.00 6042208.40 540714.40 MWD+IFR+MS 8700.00 68.30 351.54 4548.03 4501.03 6595.74 -1006.30 0.00 6042300.21 540700.21 MWD+IFR+MS 8800.00 68.30 351.54 4585.00 4538.00 6687.64 -1019.97 0.00 6042392.03 540686.01 MWD+IFR+MS 8900.00 68.30 351.54 4621.97 4574.97 6779.54 -1033.65 0.00 6042483.84 540671.82 MWD+IFR+MS 9000.00 68.30 351.54 4658.95 4611.95 6871.44 -1047.33 0.00 6042575.65 540657.63 MWD+IFR+MS 9100.00 68.30 351.54 4695.92 4648.92 6963.34 -1061.00 0.00 6042667.47 540643.44 MWD+IFR+MS 9200.00 68.30 351.54 4732.90 4685.90 7055.24 -1074.68 0.00 6042759.28 540629.25 MWD+IFR+MS 9300.00 68.30 351.54 4769.87 4722.87 7147.14 -1088.36 0.00 6042851.10 540615.06 MWD+IFR+MS 9400.00 68.30 351.54 4806.84 4759.84 7239.05 -1102.04 0.00 6042942.91 540600.86 MWD+IFR+MS 9500.00 68.30 351.54 4843.82 4796.82 7330.95 -1115.71 0.00 6043034.72 540586.67 MWD+IFR+MS 9600.00 68.30 351.54 4880.79 4833.79 7422.85 -1129.39 0.00 6043126.54 540572.48 MWD+IFR+MS 9700.00 68.30 351.54 4917.77 4870.77 7514.75 -1143.07 0.00 6043218.35 540558.29 MWD+IFR+MS 9800.00 68.30 351.54 4954.74 4907.74 7606.65 -1156.74 0.00 6043310.17 540544.10 MWD+IFR+MS 9900.00 68.30 351.54 4991.72 4944.72 7698.55 -1170.42 0.00 6043401.98 540529.91 MWD+IFR+MS 10000.00 68.30 351.54 5028.69 4981.69 7790.45 -1184.10 0.00 6043493.79 540515.71 MWD+IFR+MS 10100.00 68.30 351.54 5065.66 5018.66 7882.36 -1197.77 0.00 6043585.61 540501.52 MWD+IFR+MS 10200.00 68.30 351.54 5102.64 5055.64 7974.26 -1211.45 0.00 6043677.42 540487.33 MWD+IFR+MS 10300.00 68.30 351.54 5139.61 5092.61 8066.16 -1225.13 0.00 6043769.24 540473.14 MWD+IFR+MS 10400.00 68.30 351.54 5176.59 5129.59 8158.06 -1238.80 0.00 6043861.05 540458.95 MWD+IFR+MS 10500.00 68.30 351.54 5213.56 5166.56 8249.96 -1252.48 0.00 6043952.86 540444.76 MWD+IFR+MS 10600.00 68.30 351.54 5250.53 5203.53 8341.86 -1266.16 0.00 6044044.68 540430.56 MWD+IFR+MS 10700.00 68.30 351.54 5287.51 5240.51 8433.76 -1279.83 0.00 6044136.49 540416.37 MWD+IFR+MS 10800.00 68.30 351.54 5324.48 5277.48 8525.66 -1293.51 0.00 6044228.31 540402.18 MWD+IFR+MS 10900.00 68.30 351.54 5361.46 5314.46 8617.57 -1307.19 0.00 6044320.12 540387.99 MWD+IFR+MS 11000.00 68.30 351.54 5398.43 5351.43 8709.47 -1320.87 0.00 6044411.93 540373.80 MWD+IFR+MS 11100.00 68.30 351.54 5435.40 5388.40 8801.37 -1334.54 0.00 6044503.75 540359.60 MWD+IFR+MS 11200.00 68.30 351.54 5472.38 5425.38 8893.27 -1348.22 0.00 6044595.56 540345.41 MWD+IFR+MS 11300.00 68.30 351.54 5509.35 5462.35 8985.17 -1361.90 0.00 6044687.38 540331.22 MWD+IFR+MS 11400.00 68.30 351.54 5546.33 5499.33 9077.07 -1375.57 0.00 6044779.19 540317.03 MWD+IFR+MS 11500.00 68.30 351.54 5583.30 5536.30 9168.97 -1389.25 0.00 6044871.00 540302.84 MWD+IFR+MS 11600.00 68.30 351.54 5620.28 5573.28 9260.88 -1402.93 0.00 6044962.82 540288.65 MWD+IFR+MS 11700.00 68.30 351.54 5657.25 5610.25 9352.78 -1416.60 0.00 6045054.63 540274.45 MWD+IFR+MS 11800.00 68.30 351.54 5694.22 5647.22 9444.68 -1430.28 0.00 6045146.45 540260.26 MWD+IFR+MS 11900.00 68.30 351.54 5731.20 5684.20 9536.58 -1443.96 0.00 6045238.26 540246.07 MWD+IFR+MS • i Sperry-Sun BP Planning Report Company: BP Amoco Date: 5/19/2005 Time: 15:50;18 Page: 5 .Field: Mil ne Point Co-ordinate(NE) Reference: Well: Plan MPF-93, True North Site: M Pt F Pad Vertical (TVD) Reference: 12.7 +34.3 47.0 WeU: Plan MPF-93 Section (VS) Reference: Well (O.OON,O.OOE,351.40Azi) WeUpath; MPF-93 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TW Sys TVD N/S E/W DLS MapN MapE TooUComme t ft deg deg ft ft ft ft deg1100ft ft ft 12000.00 68.30 351.54 5768.17 5721.17 9628.48 -1457.63 0.00 6045330.07 540231.88 MWD+IFR+MS 12055.29 68.30 351.54 5788.62 5741.62 9679.30 -1465.20 0.00 6045380.84 540224.03 Start Dir 4/100 12100.00 66.51 351.53 5805.79 5758.79 9720.12 -1471.27 4.00 6045421.63 540217.73 MWD+IFR+MS 12200.00 62.51 351.53 5848.81 5801.81 9809.39 -1484.56 4.00 6045510.81 540203.94 MWD+IFR+MS 12300.00 58.51 351.53 5898.03 5851.03 9895.46 -1497.38 4.00 6045596.80 540190.63 MWD+IFR+MS 12400.00 54.51 351.52 5953.19 5906.19 9977.94 -1509.67 4.00 6045679.20 540177.88 MWD+IFR+MS 12500.00 50.51 351.52 6014.04 5967.04 10056.40 -1521.37 4.00 6045757.59 540165.74 MWD+IFR+MS 12600.00 46.51 351.51 6080.27 6033.27 10130.48 -1532.43 4.00 6045831.59 540154.28 MWD+IFR+MS 12700.00 42.51 351.51 6151.57 6104.57 10199.80 -1542.78 4.00 6045900.85 540143.54 MWD+IFR+MS 12800.00 38.51 351.50 6227.58 6180.58 10264.03 -1552.37 4.00 6045965.02 540133.58 MWD+IFR+MS 12900.00 34.51 351.49 6307.94 6260.94 10322.87 -1561.17 4.00 6046023.80 540124.45 MWD+IFR+MS 13000.00 30.51 .351.48 6392.25 6345.25 10376.01 -1569.13 4.00 6046076.89 540116.19 MWD+IFR+MS 13100.00 26.51 351.47 6480.10 6433.10 10423.21 -1576.21 4.00 6046124.05 540108.85 MWD+IFR+MS 13187.80 23.00 351.45 6559.82 6512.82 10459.56 -1581.67 4.00 6046160.37 540103.19 End Dir :1318 13200.00 23.00 351.45 6571.05 6524.05 10464.28 -1582.38 0.00 6046165.07 540102.45 MWD+IFR+MS 13300.00 23.00 351.45 6663.10 6616.10 10502.92 -1588.19 0.00 6046203.68 540096.43 MWD+IFR+MS 13400.00 23.00 351.45 6755.15 6708.15 10541.55 -1593.99 0.00 6046242.28 540090.40 MWD+IFR+MS 13500.00 23.00 351.45 6847.20 6800.20 10580.19 -1599.80 0.00 6046280.88 540084.38 MWD+IFR+MS 13537.80 23.00 351.45 6882.00 6835.00 10594.80 -1602.00 0.00 6046295.47 540082.10 7 5/8" 13600.00 20.51 351.46 6939.76 6892.76 10617.60 -1605.43 4.00 6046318.25 540078.55 MWD+IFR+MS 13644.84 18.72 351.46 6982.00 6935.00 10632.48 -1607.66 4.00 6046333.12 540076.23 Base Colville 13697.32 16.62 351.47 7032.00 6985.00 10648.23 -1610.02 4.00 6046348.85 540073.78 TKUD 13700.00 16.51 351.47 7034.57 6987.57 10648.99 -1610.14 4.00 6046349.61 540073.66 MWD+IFR+MS 13800.00 12.51 351.50 7131.36 7084.36 10673.77 -1613.85 4.00 6046374.36 540069.81 MWD+IFR+MS 13812.71 12.00 351.50 7143.78 7096.78 10676.43 -1614.25 4.00 6046377.03 540069.39 End Dir :1381 13821.12 12.00 351.50 7152.00 7105.00 10678.16 -1614.51 0.00 6046378.76 540069.13 TKUB 13841.56 12.00 351.50 7172.00 7125.00 10682.37 -1615.13 0.00 6046382.96 540068.47 TKUA 13846.68 12.00 351.50 7177.00 7130.00 10683.42 -1615.29 0.00 6046384.01 540068.31 TKA3 13862.01 12.00 351.50 7192.00 7145.00 10686.57 -1615.76 0.00 6046387.16 540067.82 TKA2 13887.57 12.00 351.50 7217.00 7170.00 10691.83 -1616.55 0.00 6046392.41 540067.01 TKA1 13900.00 12.00 351.50 7229.16 7182.16 10694.39 -1616.93 0.00 6046394.97 540066.61 MWD+IFR+MS 13948.91 12.00 351.50 7277.00 7230.00 10704.45 -1618.43 0.00 6046405.02 540065.05 MPF-93 T1 14000.00 12.00 351.50 7326.97 7279.97 10714.96 -1620.01 0.00 6046415.52 540063.42 MWD+IFR+MS 14020.48 12.00 351.50 7347.00 7300.00 10719.17 -1620.63 0.00 6046419.72 540062.77 MPF-93 Fault 1 14100.00 12.00 351.50 7424.79 7377.79 10735.53 -1623.08 0.00 6046436.07 540060.23 MWD+IFR+MS 14148.00 12.00 351.50 7471.74 7424.74 10745.40 -1624.56 0.00 6046445.93 540058.70 51/2" 14148.91 12.00 351.50 7472.63 ~ 7425.63 10745.59 -1624.58 0.00 6046446.12 540058.67 -MWD+IFR+MS Nure +WS ~F/-W Nafhkp Eaanfg Laakde Imgitude Skx Plan MPF-9J 5710.41 9954.52 6035710.88 54170.05 70%R70.533N 149%9'30.432W WA 8 3 ANTICOLLISION SETTINGS Interpolation MethodMD Interval: 25.00 Depth Range From: 34.30 To: 14148.91 Maximlun Range: 1611.46 Reference: Plan: MPF-93 wp05 -t. 13 ''• ~----mil ~/ ~~ ~~~\~ BP Amour Deg6 Fm Oryfh To Sursey/Plen Tool Cakvlalion McOud MIf1®wCurwfule x.70 120000 P6ffoed: MPFA3 svpDS VJS CB43YROSS Erfw S59em: ISCWSA 1200.00 Id148.91 Plam~k MPFA7 wT05 VJS MWD-IFR-MS Son Melhod T1av CyONer NoM Ertor Surf Ell~tii d -Casing Wamklg Mahod Rules Bored From Colour To MD 34 500 500 1000 1000 1500 1500 2000 2000 2500 2500 3000 r~" 3000 ---- 3500 3500 4000 4000 4500 4500 5000 5000 5500 5500 , 6000 6000 `Zr .,, 7000 _ '• -'a~ ,~ - ~~ 7000 _---_ 8000 ~r ~ 8000 ' 9000 ~y ~ r - f ~ ~ ~ 10000 10500 _ 0500 11000 000 11500 00 12000 O ~ l8~ - "` Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [25ft/in] MPF-9J ~ Ilef. o I:.7 - w a.ooR v.s«ona aigo algm smta~¢ A1>Qle ~WS ~fJ-W Ffm'IVD 7sl.em o.oo ooo x~o -- MPF-2z (MPF-zzl, wjor wsk MPFJO (MPF-301. Major Risk MPFJ8IMPF-381. hLp Risk MPF-02IMPF-021. Major Risk sssf~ MPF-0S IMPF-031. Map Risk '- MPF-06 /MPF-0bl. Malar Risk MPF-50IMPF-501. Major Risk MPF-541MPF-517, Map Risk -- - MPF-S8IMPF-581. Major Risk MPFb21MPFb21. Map Risk MPFf6.4IAIPFfi6.41. Map Risk MPFfi61MPFb61. hLjor Risk MPFfi6P81 IMPFb6PB11, Megor Risk -- MPF-701MPF-70), Major Risk ~ MPF-741MPF-76), Major Risk MPF-7A 181PF-78). Map Risk MPF-851MPF-851. Map Risk MPFS61MPF-86111Lwr Risk MPF-871MPF-N7AI, Major Rifle MPF-S8IMPF-N81. Major Riak MPP-901MPF-901. Map Rick MPF-901MPF-90PBI). Major Risk ~ MPF-421MPF-921. Major Risk MPFA6 /MPFAaI. Major Riek MPFAS IMPF-951. Major Risk PIsn MPF-891MPF-89). Major Risk Pqn MPF-91 (MPF-91), Msja Rif ~ Plan Phclpe (MPF-Phelpsl. Meer Ridgy •~ MPF-91 -- MPF-93 evD05 SECTION DETAIfS Set MD Iac A» TVD *WS ~EJ-W Dlq TFace VSec Tacgef 1 wo o.ao ooo x3o o.oo o.oo o.oo o.ao o.Bo z ns.ao o.oo our ns.ao o.oo o.oo o.ao o.ao o.oo 3 475.00 3.00 750.00 174.91 5.16 -0.91 ISO 750.00 527 4 673.011 7.00 350.00 67d.11 2272 -7.91 2.00 0.00 Y2.66 s 170637 78.00 350.00 1617.16 407.02 -71.77 7.00 0.00 {D.17 6 2130.69 78.00 750.00 1950.00 663.09 -I Ib.92 0.00 0.00 1573.12 7 2888.]6 W30 75134 239936 1255.15 -211.50 {.00 2.63 1272.156 B 1205529 15930 75734 3788.62 9fi7930 -146530 0.00 0.00 978937 9 11187.80 23.00 JSI.dS 6559.62 106593fi -1581.157 1.00 -179.95 10576.48 10 1)577.80 23.00 151.45 6683.00 10596.80 -I602.OD 0.00 0.00 Im1523 II 1)812.71 12.00 75130 7143.78 10676.47 -1611.25 1.00 179.93 10797.]8 12 1390A.91 13.00 75130 7277.00 10704.45 -1616.67 0.00 0.00 10626.11 MPF-93 T1 Il 1/148.91 12.00 75130 7171.63 1074539 -1624.58 0.00 0.00 10867.70 Sperry-Sun Anticollision Report Company: BP Amoco Date: 5!19/2005 Time: 15:57:OS Page: 1 Field: Milne Point Reference Site: M Pt F Pad Coordinate(NE) Reference: Well: Plan MPF-93, True North Reference Well: Plan MPF-93 Vertical (1'YD) Reference: 12.7 + 34.3 47.0 Reference Wellpath: MPF-93 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 34.30 to 141 48.91 ft Scan Method: Trav Cylinder North Maximum Radius: 1611.46 ft Erro r Surface: Ellipse + Casing Survey Program for DeSnitive Wellpath Date: 3/30/2005 Validated: No Version: 1 Planned From To Survey Toolcode Tool Name ft ft 34.30 1200.00 Planned: MPF-93 wp05 V35 CB-GYRO-SS Camera based gyro single shots 1200.00 14148.91 Planned: MPF-93 wp05 V35 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 8156.31 4347.00 10.750 13.500 103/4" 13537.80 6882.00 7.625 9.875 75/8" 14148.00 7471.74 5.500 6.750 51/2" Summary Offset Wellpath Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft M Pt F Pad MPF-22 MPF-22 V3 480,43 500.00 364.58 9.83 354.75 Pass: Major Risk M Pt F Pad MPF-30 MPF-30 V1 298,08 300.00 318.41 5.46 312.94 Pass: Major Risk M Pt F Pad MPF-38 MPF-38 V4 10612,17 11350.00 593.29 575.66 17.63 Pass: Major Risk M Pt F Pad MPF~2 MPF-42 V6 577,44 600.00 263.64 11.78 251.86 Pass: Major Risk M Pt F Pad MPF-45 MPF~5 V3 344.32 350.00 351.48 6.79 344.69 Pass: Major Risk M Pt F Pad MPF-46 MPF-46 V4 439.79 450.00 249.17 9.18 239.99 Pass: Major Risk M Pt F Pad MPF-50 MPF-50 V6 298.67 300.00 237.64 6.43 231.21 Pass: Major Risk M Pt F Pad MPF-54 MPF-54 V3 5583.08 6050.00 353.84 178.26 175.58 Pass: Major Risk M Pt F Pad MPF-58 MPF-58 V1 1506.26 1600.00 137.64 29.42 108.22 Pass: Major Risk M Pt F Pad MPF~2 MPF-62 V1 395.28 400.00 224.85 7.95 216.90 Pass: Major Risk M Pt F Pad MPF-66A MPF~6A V8 299.16 300.00 231.39 6.01 225.38 Pass: Major Risk M Pt F Pad MPF-66 MPF-66 V12 299.16 300.00 231.46 6.54 224.92 Pass: Major Risk M Pt F Pad MPF-66P61 MPF-66PB1 V5 299.16 300.00 231.46 6.54 224.92 Pass: Major Risk M Pt F Pad MPF-70 MPF-70 Vt 493.59 500.00 237.21 9.68 227.53 Pass: Major Risk M Pt F Pad MPF-74 MPF-74 V1 299.44 300.00 248.39 6.05 242.34 Pass: Major Risk M Pt F Pad MPF-78 MPF-78 V1 544.40 550.00 260.03 10.37 249.65 Pass: Major Risk M Pt F Pad MPF-85 MPF-85 V28 298.93 300.00 242.76 6.66 236.10 Pass: Major.Risk M Pt F Pad MPF-86 MPF-86 V18 395.37 400.00 212.17 9.94 202.23 Pass: Major Risk M Pt F Pad MPF-67 MPF-87 V11 395.98 400.00 182.27 9.37 172.90 Pass: Major Risk M Pt F Pad MPF-87 MPF-87A V3 395.98 400.00 182.27 9.37 172.90 Pass: Major Risk M Pt F Pad MPF-88 MPF-88 V3 4209.66 4250.00 130.18 110.90 19.27 Pass: Major Risk M Pt F Pad MPF-90 MPF-90 V1 397.98 400.00 90.94 7.62 83.33 Pass: Major Risk M Pt F Pad MPF-90 MPF-90PB1 V31 397.98 400.00 90.94 7.62 83.33 Pass: Major Risk M Pt F Pad MPF-92 MPF-92 V15 1186.19 1200.00 45.30 26.04 19.26 Pass: Major Risk M Pt F Pad MPF-94 MPF-94 V17 751.61 750.00 22.98 14.22 8.76 Pass: Major Risk M Pt F Pad MPF-95 MPF-95 V16 905.70 900.00 59.33 21.01 38.32 Pass: Major Risk M Pt F Pad Plan MPF-89 MPF-89 V3 Plan: MPF-89 735.57 750.00 124.84 16.83 108.01 Pass: Major Risk M Pt F Pad Plan MPF-91 ~ MPF-91 VO Plan: MPF-91 398.63 400.00 61.52 9.71 51.81 Bass: Major Risk M Pt F Pad Plan Phelps MPF-Phelps V2 Plan: Ph 1215.05 1200.00 84.11 31.80 52.31 Pass: Major Risk I I I .. I I , I I ~`~ - I 46 00 W 149 44 00 W 149 42 00 W 149: ?¢0:,04 W 149 38 00 W ' 149 2~ 2~ MPU F-93 Q MPU -9 ~ Proposed 1-Oil o l,IF..: ° Kuparuk "A" Sand N w l.IPU F 9s 26 ~, ~ 25 ! ~~ 3v 2050870 '~ ~I f ~ r l.Iw~ - Confidential wells are red U ': /i l,IPU F-9o :,; ~ I /j SFD 6/01/2005 i ~ ~ MPV -CPU: ~',- . :~ lAPU 29 't li ti. PU F-9~ MP~F-74 ~ ~` I' A U 50 11 a~ ~IPU -70 I r / , '!, r I 1 ~~ ~ 7 i~ ° P~ g"__ i t~ ~~~ o f~ f W .,,, ,: tit MPV F~ + rv - • ~~ .I.IPU F 1s ,~,~ 00 +PU ~i •arr ~ •. f ~ z \~. '. II1 ~ U 57 I ~ ~ ~ 1/ 7 MP -26 RIP id F-4i f.. -- ~ ~~ # ~ F, l.I~rj`F 3~- ~ ~~ 1.J' it ;' 32 \ '1~ ~ / / ,~ ,' y MPU~F ~` ~ MPU F `,~'~,? ~~ CSO ~ ~ `t ~~ ~ - \ \ ~ ~( ( ~ ~'1 aV ~ IPU 3 , l.IPU F ~F ~~~, J k MP l~L- c' 1 PU F , 4 ~~~ La\ ,V AI I ~~~I ~\ \ ~ `'S 7 VO I U 14 AI~-18 '.MPU••'- ,;~ . ~~ ~ ~{ ~ ~l.IP U G=4~ ~ ~ 61PV F--.,~ !'1 (' _ ~V F-~{ 1 ~ ~.~\~AI('.U _8 ~ .~y'1 ~ Q '^a, p 1 ti, ~ ` ,' S1 ~ I .3 - .. ~ . ~ I i ~ I HF I ~.r{JS' ~~ .• ~'`~ ~~ Y.~ I ~~ ~ ~ ~ ~~~ -~ 11PU L'-~~' ldFU~G~-19 \ '\ MPU L- \` -,.~~_ \~\`~) I i ( ~`i ! APU L- ~ 1 ~ \ - RIPU F 4 ~~ .ji1P'.f~k jc{1,. ~ ,~~ t~' ~' :,'fl! ;~ 13N, ;~t10E, UM . P~y4.4 ~ ,~~~ ~ .r - ~ Id ll .. '~.- ~ FFet ,,~` ' ~, -n.~. _ yy - I.IPII! Flftl `..,- '1 1y'~ I ~ 0 1,OOfl 2,000 3,000 4,000 ~`\ - f 40;000._ \. \~~~\ ` 1~ I IP L }»`' 550,004 = 530,000 --_- ~` `t~, ( I ` RE: MPF-93 /Diverter Waiver • Subject: RE: MPF-93 /Diverter Waiver From: "Coyner, Skip (NATCHIQ)" <coyns0@BP.com> Date: Mon, 06 Jun 2005 16:08:14 -0800 To: Thomas Maunder <tom maunder@admin.state.ak.us> Yes, it was Mike Miller's idea. Skip Coyner 907-564-4395 BPXA 907-748-3689 cell ~ ~~~~~. w ~~F v"~j~ ~~~ ~,CC vlf~-S ~E ~y~~ From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, June 06, 2005 3:46 PM To: Coyner, Skip (NATCHIQ) Cc: Johnson, David A. (Fairweather) Subject: Re: MPF-93 /Diverter Waiver Skip, One further thought with regard to the diverter waiver. Has this "idea" already been approved internally by BP?? Tom Maunder, PE AOGCC Thomas Maunder wrote: Skip, Standard refers to using the diverter at F pad. I can see that it probably was an oversight with 87 and 88. 90 is the surprising one since Steve Shultz did request a waiver for 94 which looks to have been drilled immediately prior to 90. I suspect that the "continuity" might have been broken with different engineers doing the plans. Have you looked at what was done for MPF-94?? On your schedule, will you be doing the 3 wells consecutively?? Tom Maunder, PE AOGCC Coyner, Skip (NATCHIQ) wrote: To answer your questions from 6/3/05: 1. You asked if there is a "standard" for MPF Pad. Since I don't know what "standard" you're asking about, I'd say probably not, but please clarify. 2. I asked the ODE's for MPF-90, MPF-87 &MPF-88 why they did not request a diverter waiver. None of them can remember why not but they indicate that it was most likely an oversight. 3. We plan to drill three (3) wells on MPF Pad this summer: MPF-93, MPF-91 &MPF-89. We will request diverter waivers for all three wells. Skip Coyner 907-564-4395 BPXA 907-748-3689 cell 1 of 2 6/9/2005 11:23 AM Re: MPF-93 /Surface Casing Cement • • Subject: Re: MPF-93 /Surface Casing Cement From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Fri, 03 Jun 2005 07:44:39 -0800 To: "Coyner, Skip (NATCHIQ)" <coyns0@BP.com> Thanks Skip. I will put this information in the well file. Nothing further is needed. Tom Maunder, PE AOGCC Coyner, Skip (NATCHIQ) wrote: Subsequent to filing the 10-401 form for MPF-93, we decided to cement the 10-3/4" surface casing in two stages. See the attached schematic and let me know if you have any further questions. «MPF-93 Well Plan Schematic.ZlP» Skip ~'oyner 907-564-4395 BPXA 907-748-3689 cell 6/3/2005 7:44 AM tt:':+:.. .~•: ____ . ::. . ~. :.:.f; . ..... MPF-93 Field: Milne Point KUp81'UK A Sand ENG: S. Coyner Pad: F-Pad PPO(~UC@C RIG: Doyon 14 RKB: 47 ft DIR / LWD OH DEPTH HOLE CASING MUD INFO MWD LOGS FORM MD TVD SIZE SPECS PIT INFO INFO 20.000-in Wellhead NONE NONE Permafrost 91.1-Ib/ft H-40 FMC Gen 5 112' 42" Welded, Insul 20" x 11" 5K MWD/GR NONE Gyro as needed Sta a II 150% Excess Base Permafrost 2,000' 1,847' ~ 349 bbls, 441 sx of In Permafrost H-ES Cementer 2,800' 2,364' iE#?.: 64.5° ~ ~ ~ ASL at 4.44 cf/sx ~~~~ ~~ ~ ~~ ~; 50.3 bbls, 235 sx of Class G + CaCl2 68.3° Surface Csg Test Csg to .. ;:. 10-3/4" 2000 psi TOC / Stage I 5,222' ;.: 3,262' I •>~ 45.5# TUZC 5,722' 3,447' :;<~?~~ L-80, BTC Int. Yield 5210 p ' Stage ~ Collaspse 2470 si 200 bbls, 259 sx of T/Schrader Bluff 223' 7 Ff~% ~~~ 4 002' :l;' f ~ ~ ~{ }}~ ASL at 4.44 cf/sx 30°~ Excess , , ~% iii 50.3 bbls, 235 sx of is!{~ iii Class G + CaCl2 B/Schrader Bluff 8,021' ~i •::.. 4,297' ;?~i ~~~ iii 85 ft Shoe Track :::::.:.::.:::::::::::.::::::.. .........:...... ...::: . .. .... ~ :+ ...:. .. i.: :,r:: ... .. ....... r. :::::~ 68 3 >: ...... ~.. H:~i:^ 13.5.: :::: :~i:~i:~i:~i::4:~::::~i.::~::.:::i~ii':'i ::::::::::::::::::::::::::::::::: '. .::.::::::::::w::.:.:.:::.:::.. :.::..:::::::::::::::::::::::::::::. ...::::::::: iiiiii?iiii:<.ii:i ::::::::::::::::::::::::::::: MWDlGR/RES NONE PWD IFR/Cas 68.3° Inter. Casing Cement Slurry 50% Excess 7-5/8" 34.4 bbls, 161 sx 29.7 Ibs/ft 15.8 ppg L-80, BTC-M 1.20 ft3/sx Test Csg to 68.3° Int. Yield 6890 psi Class "G" 3500 psi Collaspse 4790 psi Top of Cement 13,038' 6426 23° Top/LNR/ZXP/PBR 13,388' 6,744' i f i, ;: .:., ::., ::. ~a~f . 4: , :_ ' :::::::. :. ° V.: .::::i::i:~ MWD/GR/RES Top / Kuparuk D 13,697' ... 7,032' .,. Prod Liner Top / Kuparuk B 13,821' 7,152' 12° 4-1 /2" , 12.6#, L-80 Test LNR to Top / Kuparuk A 13,847' 7,17T Liner Cement 3500 psi IFR/Cas Top / Miluveach 13,949' 7,277' 28 bbl 132 sx 40°k Excess >::>::>::>::>: ::: .L~xl~~i~oi~t 1d•,'E~~. : .2',x7'2.:; ; 12° 67~... ....~i~s'[5,~3#..> .......... (t~l-~fxrreac]!- :::: [10/04/04] MPF-93 Well Plan Schematic.xls - ,: i, 7ERRIE L H UB BLE BP EXPLORATION AK 'INC PO BOX. 196612 MB 7.5 Mastercar ;, as-sii2sz ANCHORAGE, AK 89519-6612 d Check 205 PAY YO THE DATE ~~~ (^ ORDER' OF ~_ f%m `~ First National Bank q~ ~• aska A n ch or a 9e, AK 9950.1 DOLLARS MEMO ~: L 25 200060~:gq lti~.~6 2 2 7..~ 5561'' 0205 • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/pARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME _ , PTD# ~-l"~~j '~~c~~ CHECK WHAT ADD-ONS "CLUE" APPLIES OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (p)er records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/SO) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to produce/infect is contingent perforate and , upon issuance of a conservation order approving a spacing exception. (Comaanv Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE 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. Rev: 04/01/05 C\jody\transmittai_checklist WELL PERMIT CHECKLIST Field & Pool MILNE POINT, KUPARUK RIVER OIL - 525100 Wel! Name: MILNE PT UNIT KR F-93 _~Program DEV ,Well bore seg PTD#:2050870 Company BP EXPLORATION ~tASKA) INC Initial Class/Type _ DEV I PEND GeoArea 890 Unit 11328 OnlOff Share On Annular Disposal Administration 1 Permit fee attached- _ - _ _ _ . _ - Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 Lease numberappropriate- - - - - - - - - - - - - - - No- - - - , .Correction made to_1Q407:.Top Prod Int &_TD in ADL 355018; surfacetocation-inADL 25599.- - - - - 3 Unique well-name and number - - - - - - - - - - - - -Yes - - ~ - - - ~ ~ - - - - - - - - - 4 Well located in a_tlefined_pool- - - Yes _ - _ Kuparuk River Oil Pool, governed by Conservation Order No. 4320 5 Well located proper distance from drilling unit_boundary_ - , - - Yes _ - - -Conservation Order No. 4320 Contains no spacing restrictions with respect to drilling unit boundaries. - - - - - . - 6 Well located proper distance_from otherwells_ - , _ Yes - - - , -Conservation Order No. 4320 has no in_terwell_spacing_restrictions, _ _ _ - _ - _ 7 Sufficient acreage available in-drilling unit_ - Yes _ - - - Conservation Order No. 4320 has no intenvell_spaeing_restrictions, Wellbor-e will be-more than 500' from - - . _ 8 If deviated, iswellboreplatincluded__________________________ _________Yes-___-- _-__-__--_-,-, 9 Operator only affected party Yes - 10 Operator has.appr9priate_bond in force . _ _ _ _ _ _ ~ _ _ _ _ _ _ _ Ye$ _ _ _ _ _ _ _ ~ _ ~ ~ _ _ _ _ _ _ ~ _ _ - - ~ _ - - _ - - ------------- 11 Permit-can be issued without conservation order_____ _____________ ___-._--Yes_.__, __ ___-_-__---. -_- -__-_,__---.--_.-----_-_-.-._-,--__---- -__-, Appr Date 12 Permitcanbeissuedwithoutadministrative_approval_______ ________ __------Yes___--- -__-_-____-_---.--_.--_-_,-__--_---------,__.--------,_--_-----, SFD 6/1/2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authprized by-Injecfion Order# (put_1O# in-comments)-(For_ NA_ - _ - - - - 15 All wells-within 1/4.mile area of review identified (For service well only)- - - - - - - - - - - - - - - NA- _ _ _ _ - , - _ - 16 Pre-produced injector; duration of pre production Less than_ 3 months-(For service well only) - - NA_ - _ _ _ - ~17 ACMP-Finding of Consistency-has been issued-for this project- . _ - NA- --------------------------------------------------------------------- Engineering r 18 Condu_clo[ string-provided - Yes 19 Surface casing-protects all known_ USDWs , _ - . - - . Yes _ - Surface casing will be cemented below Schrader Buff, Anyshallower zones_will be isolated. - 20 CMT_vol_adequate-tocircul_ate_on conductor&surfcsg--- --- ------- -- Yes_-_-_ -_-- -________-___--_.-__-___ -_ _- _---_-- - --_ 21 CMT_vol_ adequate,to tie-i_n long string to surf csg_ _ _ _ - _ _ _ - - _ _ _ - - _ _ _ - - _ - . - No_ _ _ _ - _ _ No hydrocarbon_ zones, known in this hole_ section_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ - _ - _ - _ - _ _ _ _ _ 22 CMT_will Coverall known-productive horizons- Yes - Liner planned to be_fully_cemented. - - - - - , . - - - 23 CasingdesgnsadegyateforC,_T,B&_permafrost----------------- -- _-,--Yes------ .------.------ ---------------- ---------------------------- -.-- 24 Adequate tankage_or reserve pit - - - _ _ Yes _ - Rig is_equipped with steel-pits. No_ rese_rve_pitplanned, All waste to approved disposal wells._ , 25 If_a_ re-drill, has-a_ 10-403 for abandonment been approved - - - - - - - . - . NA_ - 26 Adequate wellbore separation_proposed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - _ - - _ . -Proximity analysis perfo[me_d, Traveling cylinder path calculated, Close approaches identified, Gyrgs planne - - _ 27 If_diverfer required, does it meet regulations, - NA_ BP has_applied for diverter waiver._ No shallow problems have been reported at F-pad. Waiver recommendad• Appr Date 28 Drilling fluid_ program schematic & equip listadequate_ Yes - - - - Maximum expected formation pressure 9,5-EMW~ although MPF-87A experienced 10.7 EMW: MW up 11.0 plann_ TE 6/212005 29 BOPEs,-do the meet reu_lation_ ___ y 9 ---.--, -Yes__.__ ___- -___-_ --------------- - - - - - - ~` 30 BOPE_press racing appropriate; test i_o_(put psig in comments)- Yes - - - - - -- - --- - MSP calculated_at3275 psi based on 10.7 EMW. Planned BOP test 4000 psi. - . 31 Chgke-manifold complies wlAPI_ RP-53 (May 84} - Yes - - I 32 Work willoccurwithoutoperationshutdown______ ____ __________ ____ ____Yes-__.__ _-_-_ ----_-__,-_-_--_---__-- -,_- I 33 Is presence-of H2$ gas_ probable - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - _ - - _ - - _ Minor-H2S-has been reported at F_pad.-Rig is_equipped with sensors and alarms._ - _ _ - _ - _ _ - _ 34 Mechanical condition of wells within AOR verified GFor. service well only) _ - NA- Geology 35 Permit_can be issued w/o hydrogen sulfide measures - - - - _ - - - - No- - - - - _H2S has been_ measured in_quantities-exceeding 20 ppm from MPU F-Pad, _ - - 36 Data-presented on_pote_ntial overpressure zones- _ - . - - _ - - - - - - - Yes _ . - -Expected pressure may be a high as 10.7 ppg_EMW,will bedrilled_with 11.Oppg mud-- - Appr Date 37 Seismic analysis of shallpwgas-zones_ - NA_ - - - - - - - - - - - - - -More than 50 wells have_ been drilled from the MPU, F-Pad_without encountering hydrates, shallow gas, or - - SFD 6/112005 38 Seabed condition survey (if off-shore) - NA - - - abnormal pressure. - - - - - - 39 Contact name/phone_for weekly progress.reports (exploratory only]- NA_ _ _ . - Geologic Commissioner: Engineering Date: Date Commissioner: mm' ner Date n ~, ~~ • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify rending information, information of this nature is accumulated at the end of the fife under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed May 17 14:33:28 2006 Reel Header Service name .............LISTPE Date .....................06/05/17 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/05/17 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. aoS- b'~s~- 139S~r Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS WELL NAME: MPF-93 API NUMBER: 500292326600 OPERATOR: BP Exploration (Alaska) Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 17-MAY-06 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: MW0003782167 MW0003782167 MW0003782167 LOGGING ENGINEER: C. ZAWADSKI C. ZAWADZKI C.A. DEMOSKI OPERATOR WITNESS: D. GREEN D. GREEN E. VAUGHN MWD RUN 4 MWD RUN 5 JOB NUMBER: MW0003782167 MW0003782167 LOGGING ENGINEER: C.A. DEMOSKI J. BOBBITT OPERATOR WITNESS: E. VAUGHN D. GREEN SURFACE LOCATION SECTION: 6 TOWNSHIP: 13N RANGE: l0E FNL: FSL: 2260 FEL: 2818 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 45.07 GROUND LEVEL: 11.10 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT S~ (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13.500 2ND STRING 9.875 3RD STRING 6.750 PRODUCTION STRING 4.750 REMARKS: 20.000 114.0 10.750 7925.0 7.625 13541.0 5.500 13780.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUNS 2 - 5 COMPRISED DIRECTIONAL, DGR, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) MWD RUN 3 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD) AND GEOPILOT ROTARY-STEERABLE BHA (GP) MWD RUN 4 ALSO INCLUDED GEO-TAP (FORMATION TESTER). DUE TO LOST CIRCULATION PROBLEMS IN MWD RUN 4 (AFTER ONLY 40' OF DRILLING), THE BHA WAS PULLED AND THE MWD TOOLS WERE REMOVED. THE INTERVAL 13593'MD-13782'MD WAS DRILLED W/O MWD. SROP DATA, AND SGRC DATA ACQUIRED THROUGH CASING WHILE RIH FOR MWD RUN 5, FOR THIS INTERVAL WERE MERGED WITH RUN 5 MWD DATA. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL DATED 5/10/2006 FROM DOUG DORTCH (SAIC/BP) TO BUSTER BRYANT (SDS), QUOTING AUTHORIZATION FROM MICAELA WEEKS (BP GEOSCIENTIST) MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-5 REPRESENT WELL MPF-93 WITH API#: 50-029-23266-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14183'MD/7482'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05f17 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 73.5 14123.5 ROP 115.5 14183.0 RPM 4417.0 14134.5 FET 4417.0 14134.5 RPD 4417.0 14134.5 RPX 4417.0 14134.5 RPS 4417.0 14134.5 • BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) :- --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD s BIT RUN NO MERGE TOP 1 73.5 2 4466.0 3 8265.0 4 13553.0 5 13593.0 REMARKS: MERGED MAIN PASS. MERGE BASE 4466.0 8265.0 13553.0 13593.0 14183.5 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FTfH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 73.5 14183 7128.25 28220 73.5 14183 RPD MWD OHMM 0.96 2000 16.7316 19081 4417 14134.5 RPM MWD OHMM 0.69 2000 14.2018 19080 4417 14134.5 RPS MWD OHMM 0.1 2000 7.24002 19080 4417 14134.5 RPX MWD OHMM 1.05 14 67.66 3.85657 19080 4417 14134.5 FET MWD HOUR 0.13 106.7 2.08645 19080 4417 14134.5 GR MWD API 19.77 1 28.61 77.9484 28101 73.5 14123.5 ROP MWD FT/H 0.~ 1636.87 189.248 28136 • 115.5 14183 First Reading For Entire File..........73.5 Last Reading For Entire File...........14183 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/17 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/17 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 73.5 4423.0 ROP 115.5 4466.0 LOG HEADER DATA DATE LOGGED: 25-JUN-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4466.0 TOP LOG INTERVAL (FT) 114.0 BOTTOM LOG INTERVAL (FT) 4466.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 70.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 120557 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 13.500 DRILLER'S CASING DEPTH (FT) .0 BOREHOLE CONDITIONS MUD TYPE: SPUD MUD DENSITY (LB/G) ~ 9.30 • MUD VISCOSITY (S) 85.0 MUD PH: 8.0 MUD CHLORIDES (PPM): 600 FLUID LOSS (C3) 10.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 68.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 ROP MWDO10 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 73.5 4466 2269.75 8786 73.5 4466 GR MWDO10 API 19.77 120.25 65.818 8700 73.5 4423 ROP MWDO10 FT/H 19.05 1636.87 186.806 8702 115.5 4466 First Reading For Entire File..........73.5 Last Reading For Entire File...........4466 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/17 Maximum Physical Record..65535 .File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number..........~0.0 • Date of Generation.......06/05/17 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 4417.0 8214.5 RPM 4417.0 8214.5 RPX 4417.0 8214.5 RPD 4417.0 8214.5 RPS 4417.0 8214.5 GR 4423.5 8222.0 ROP 4466.5 8265.0 LOG HEADER DATA DATE LOGGED: 28-JUN-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8265.0 TOP LOG INTERVAL (FT) 4466.0 BOTTOM LOG INTERVAL (FT) 8265.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 67.1 MAXIMUM ANGLE: 70.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 175785 EWR4 ELECTROMAG. RESIS. 4 63122 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 13.500 DRILLER'S CASING DEPTH (FT) .0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): SPUD 9.20 85.0 8.0 600 9.0 4.700 75.0 3.600 100.1 4.500 75.0 5.100 75.0 EWR FREQUENCY (HZ) REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame 5pacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4417 8265 6341 7697 4417 8265 RPD MWD020 OHMM 0.96 17.66 3.71061 7596 4417 8214.5 RPM MWD020 OHMM 0.94 17.31 3.61587 7596 4417 8214.5 RPS MWD020 OHMM 0.97 17.77 3.50896 7596 4417 8214.5 RPX MWD020 OHMM 1.05 16.9 3.46586 7596 4417 8214.5 FET MWD020 HOUR 0.18 12.98 0.868922 7596 4417 8214.5 GR MWD020 API 22.36 1 19.05 67.9489 7598 4423.5 8222 ROP MWD020 FT/H 2.13 3 97.35 164.076 7598 4466.5 8265 First Reading For Entire File.... .......4417 Last Reading For Entire File...........8265 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/17 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/17 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record ~ • FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 8215.0 13508.0 RPX 8215.0 13508.0 RPM 8215.0 13508.0 RPS 8215.0 13508.0 RPD 8215.0 13508.0 GR 8222.5 13515.0 ROP 8265.5 13553.0 LOG HEADER DATA DATE LOGGED: 05-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 13553.0 TOP LOG INTERVAL (FT) 8265.0 BOTTOM LOG INTERVAL (FT) 13553.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 17.0 MAXIMUM ANGLE: 71.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 097054 EWR4 ELECTROMAG. RESIS. 4 125889 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 7925.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: LSND 9.35 55.0 8.0 400 4.8 2.400 72.0 1.240 146.3 4.500 72.0 2.600 72.0 Data Format Specification Record Data Record Type ..................0 Data Specification B1ock~pe.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8215 13553 10884 10677 8215 13553 RPD MWD030 OHMM 1.78 16.02 3.54643 10587 8215 13508 RPM MWD030 OHMM 1.71 24.96 3.40654 10587 8215 13508 RPS MWD030 OHMM 1.73 16.36 3.2953 10587 8215 13508 RPX MWD030 OHMM 1.73 12.78 3.22158 10587 8215 13508 FET MWD030 HOUR 0.13 106.7 1.50424 10587 8215 13508 GR MWD030 API 58.86 128.19 94.3388 10586 8222.5 13515 ROP MWD030 FT/H 5.22 487.99 227.271 10576 8265.5 13553 First Reading For Entire File..........8215 Last Reading For Entire File...........13553 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/17 Maximum Physical Recard..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/17 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 13508.5 13554.5 RPX 13508.5 13554.5 RPS 13508.5 13554.5 RPD 13508.5 13554.5 RPM 13508.5 13554.5 GR 13515.5 13547.5 ROP 13553.5 13593.0 LOG HEADER DATA DATE LOGGED: 08-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 13593.0 TOP LOG INTERVAL (FT) 13553.0 BOTTOM LOG INTERVAL (FT) 13593.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 17.2 MAXIMUM ANGLE: 17.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 130908 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 13541.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G) 11.00 MUD VISCOSITY (S): 57.0 MUD PH: 8.0 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3) 5.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 5.000 75.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.590 151.1 MUD FILTRATE AT MT: 4.000 75.0 MUD CAKE AT MT: 6.000 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units .............•....... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13508.5 13593 13550.8 170 13508.5 13593 RPD MWD040 OHMM 2.24 2000 1209.53 93 13508.5 13554.5 RPM MWD040 OHMM 2.14 2000 1589.35 93 13508.5 13554.5 RPS MWD040 OHMM 2.08 15 79.66 75.8385 93 13508.5 13554.5 RPX MWD040 OHMM 2.04 770.5 32.3202 93 13508.5 13554.5 FET MWD040 HOUR 84 84.56 84.2718 93 13508.5 13554.5 GR MWD040 API 52.1 65.31 58.9515 65 13515.5 13547.5 ROP MWD040 FT/H 0.3 1 26.69 63.3611 80 13553.5 13593 First Reading For Entire File..........13508.5 Last Reading For Entire File...........13593 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/17 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/17 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13548.0 14124.5 ROP 13593.5 14183.5 RPD 13732.5 14134.5 RPX 13733.0 14134.5 FET 13733.0 14134.5 . • RPM 13733 14134.5 RPS 13733.0 14134.5 LO G HEADER DATA DATE LOGGED: 15-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 14183.0 TOP LOG INTERVAL (FT) 13593.0 BOTTOM LOG INTERVAL (FT) 14183..0 BIT ROTATTNG SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 15.8 MAXIMUM ANGLE: 17.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 78012 EWR4 ELECTROMAG. RESIS. 4 171169 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 4.750 DRILLER'S CASING DEPTH (FT) 13780.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 11.00 MUD VISCOSITY (S) 60.0 MUD PH: 11.0 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3) 6.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.400 74.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.340 138.0 MUD FILTRATE AT MT: 1.970 74.0 MUD CAKE AT MT: 3.200 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 ~ RPS MWD050 OHMM 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13548 14183.5 13865.8 1272 13548 14183.5 RPD MWD050 OHMM 1.68 2000 175.202 805 13732.5 14134.5 RPM MWD050 OHMM 0.69 2000 74.1656 804 13733 14134.5 RPS MWD050 OHMM 0.1 2000 86.499 804 13733 14134.5 RPX MWD050 OHMM 1.68 1467.66 12.6171 804 13733 14134.5 FET MWD050 HOUR 0.85 70.84 11.7493 804 13733 14134.5 GR MWD050 API 31.82 128.61 86.0099 1154 13548 14124.5 ROP MWD050 FT/H 1 761.85 37.0688 1181 13593.5 14183.5 First Reading For Entire File..........13548 Last Reading For Entire File...........14183.5 File Trailer Service name.... .......STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/17 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06j05/17 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/05/17 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF Scientific Technical Services Scientific Technical Services End Of LIS File