The URL can be used to link to this page

Home My WebLink About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y Samantha Carlisle at 12:34 pm, Feb 25, 2022 'LJLWDOO\VLJQHGE\'DYLG +DDNLQVRQ '1FQ 'DYLG+DDNLQVRQ RX 8VHUV 'DWH 'DYLG+DDNLQVRQ 6)''65 0*50$5 %23(WHVWWRSVL$QQXODUWRSVL %23(VKHOOWHVWUHTXLUHGEHIRUHFDOOLQJRXW$2*&&LQVSHFWRUVWRZLWQHVV%23(WHVW 9DULDQFHWR$$&GLVDSSURYHG1RSURGXFWLRQSDFNHUUHTXLUHGLIZLWKLQZHHNVRI323%+3GURSVEHORZSSJ SUHVVXUHJUDGLHQW GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.03.02 15:48:31 -09'00' RBDMS SJC 030322 ^WŚĂŶŐĞŽƵƚ tĞůů͗DWh:ͲϭϬ tĞůůEĂŵĞ͗DWh:ͲϭϬ W/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϮϱϬϬͲϬϬͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗^ŚƵƚͲŝŶ΀&ĂŝůĞĚ^W΁ WĂĚ͗:ͲWĂĚ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ƉƌŝůϮϱƚŚ͕ϮϬϮϮ ZŝŐ͗^Zηϭ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍zĞƐ ĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗dŽŵ&ŽƵƚƐ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϵϲͲϭϱϲ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ĂǀŝĚ'Žƌŵ ;ϵϬϳͿϳϳϳͲϴϯϯϯ;KͿ ;ϱϬϱͿͲϮϭϱͲϮϴϭϵ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗dĂǇůŽƌtĞůůŵĂŶ ;ϵϬϳͿϳϳϳͲϴϰϰϵ;KͿ ;ϵϬϳͿͲϵϰϳͲϵϱϱϯ;DͿ &EƵŵďĞƌ͗:ŽďdǇƉĞ͗^WŚĂŶŐĞŽƵƚ ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗ϯ͕ϭϮϭƉƐŝΛϲ͕ϳϰϲ͛ds ^W'ĂƵŐĞϮͬϬϴͬϮϬϮϮͮϴ͘ϵƉƉŐ DĂǆŝŵƵŵǆƉĞĐƚĞĚ,W͗ϯ͕ϭϮϭƉƐŝΛϲ͕ϳϰϲds ^W'ĂƵŐĞϮͬϬϴͬϮϬϮϮͮϴ͘ϵƉƉŐ DW^W͗Ϯ͕ϰϮϭƉƐŝ 'ĂƐŽůƵŵ'ƌĂĚŝĞŶƚ;Ϭ͘ϭƉƐŝͬĨƚͿ DĂǆ/ŶĐůŝŶĂƚŝŽŶ ϯϵΣΛϯ͕Ϭϵϭ͛D DĂǆŽŐůĞŐ͗ϱΣͬϭϬϬĨƚΛϭ͕ϯϴϯ͛D WsWƌŽĨŝůĞ͗ϮͲϭͬϮ͟/tdǇƉĞ, ƌŝĞĨtĞůů^ƵŵŵĂƌǇ͗ DWh:ͲϭϬǁĂƐĚƌŝůůĞĚĂŶĚĐŽŵƉůĞƚĞĚǁŝƚŚĂŶ^WŝŶKĐƚŽďĞƌϭϵϵϰĂƐĂ<ƵƉĂƌƵŬƉƌŽĚƵĐĞƌ͘dŚĞǁĞůůŚĂƐďĞĞŶ ǁŽƌŬĞĚŽǀĞƌĞŝŐŚƚƚŝŵĞƐŝŶŝƚƐŚŝƐƚŽƌǇǁŝƚŚƚŚĞůĂƐƚďĞŝŶŐĞĐĞŵďĞƌϮϬϮϬ͘dŚĞ^WĨĂŝůĞĚƵŐƵƐƚϮϵƚŚ͕ϮϬϮϭ͕ĚƵĞ ƚŽĂďƌŽŬĞŶƐŚĂĨƚ͘ EŽƚĞƐZĞŐĂƌĚŝŶŐtĞůůďŽƌĞŽŶĚŝƚŝŽŶ x dŚĞϳ͟ĐĂƐŝŶŐǁĂƐƉƌĞƐƐƵƌĞƚĞƐƚĞĚƚŽϭ͕ϱϬϬƉƐŝǁŝƚŚϴ͘ϳƉƉŐďƌŝŶĞĨƌŽŵϳ͕ϱϮϰ͛DŽŶϯͬϮϯͬϭϱ͘ x KĨĨƐĞƚŝŶũĞĐƚŽƌƐǁŝƚŚƐƚĂƚƵƐ͗ o :Ͳϭϯʹ^/ŽŶϬϴͬϯϬͬϮϬϮϭ sĂƌŝĂŶĐĞZĞƋƵĞƐƚƚŽϮϬϮϱ͘ϮϬϬ;ĚͿĂŶĚKϯϵϬ͗ ZĞƋƵĞƐƚŝŶŐƚŽƌƵŶĂƉĂĐŬĞƌͲůĞƐƐ^WŽŶDW:ͲϭϬ͘dŚĞǁĞůůƐŚŽǁƐĂƐůŽǁďŽƚƚŽŵŚŽůĞƉƌĞƐƐƵƌĞďƵŝůĚƵƉ ŽǀĞƌƚŚĞĐŽƵƌƐĞŽĨƚŚĞĐƵƌƌĞŶƚϱŵŽŶƚŚƐŽĨƐŚƵƚͲŝŶƉĞƌŝŽĚƐƚĂƌƚŝŶŐŽŶϴͬϮϴͬϮϬϮϭ͘dŚĞ,WƚŽŽŬΕϯŵŽŶƚŚƐƚŽ ďƵŝůĚƵƉƚŽĂ,WŽĨϮ͕ϵϵϵƉƐŝ;ϴ͘ϱϱƉƉŐͿĂƚƚŚĞ^WŐĂƵŐĞ;ϲ͕ϳ ϰϲ͛dsͿ͘dŚĞĐƵƌƌĞŶƚ,WŝƐƐƚĂďŝůŝǌŝŶŐĂƚϯ͕ϭϮϭ ƉƐŝ;ϴ͘ϵƉƉŐͿ͘dŚŝƐǁĞůůƐŝƚƐŝŶĂŶŝƐŽůĂƚĞĚ<ƵƉĂƌƵŬďůŽĐŬǁŝƚŚŽŶĞŽĨĨƐĞƚŝŶũĞĐƚŽƌƚŚĂƚĐĂŶƐƵƉƉŽƌƚƚŚĞǁĞůů͘ĨƚĞƌ ƌĞƉĂŝƌŽĨƚŚĞĐƵƌƌĞŶƚ^WƉƌŽƉŽƐĞĚĨŽƌƉƌŝůϮϬϮϮ͕ƚŚĞ,WŝƐĞǆƉĞĐƚĞĚƚŽďĞĚƌĂǁŶďĂĐŬĚŽǁŶďĞůŽǁƚŚĞϴ͘ϱϱ ƉƉŐƚŚƌĞƐŚŽůĚǁŝƚŚŝŶϰǁĞĞŬƐ͘tŝƚŚƚŚĞƌŝƐŬƐŽĨƐŚƵƚƚŝŶŐĚŽǁŶĂ Ŷ^WƚŽĐŚĞĐŬƐƚĂƚŝĐ,W͕ƉůĂŶƚŽŵŽŶŝƚŽƌƚŚĞ ǁŝƚŚĚƌĂǁĂůƌĂƚĞƚŽďĂůĂŶĐĞŽƵƚƚŚĞŝŶũĞĐƚŝŽŶͬǁŝƚŚĚƌĂǁĂůƌĂƚŝŽƚŽďƌŝŶŐƚŚĞĐƵƌƌĞŶƚ,WĚŽǁŶ͘ KďũĞĐƚŝǀĞ͗ x WƵůůĨĂŝůĞĚ^WĐŽŵƉůĞƚŝŽŶ͘ x ZƵŶŶĞǁ^WĐŽŵƉůĞƚŝŽŶ͘ WƌĞͲZŝŐWƌŽĐĞĚƵƌĞ͗ ϭ͘ Zh>Z^͘ Ϯ͘ <ŝůůƚŚĞǁĞůůǁŝƚŚϵ͘ϯƉƉŐEĂů;ǀŽůƵŵĞƐ͗ƚƵďŝŶŐсϰϯďďůƐΘ/сϮϮϮďďůƐͿ Ă͘ d'ŝƌĐ͘WŽŝŶƚʹϳ͕ϯϯϳ͛D;ϲ͕ϱϮϳ͛dsͿ ď͘ ƵůůŚĞĂĚϮϱ>͛ƐĚŽǁŶƚŚĞ/ƚŽƉĞƌĨƐ͕ůŝŵŝƚƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞƚŽϴϬϬƉƐŝ͘ Đ͘ ϵ͘ϯƉƉŐEĂůƉƌŽǀŝĚĞƐΕϭϰϱƉƐŝdƌŝƉDĂƌŐŝŶ ϯ͘ ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘ ^WŚĂŶŐĞŽƵƚ tĞůů͗DWh:ͲϭϬ ϰ͘ Z>Z^͘ ϱ͘ ůĞĂƌĂŶĚůĞǀĞůƉĂĚĂƌĞĂŝŶĨƌŽŶƚŽĨǁĞůů͘^ƉŽƚƌŝŐŵĂƚƐĂŶĚĐŽŶƚĂŝŶŵĞŶƚ͘ ϲ͘ ZǁĞůůŚŽƵƐĞĂŶĚĨůŽǁůŝŶĞƐ͘ůĞĂƌĂŶĚůĞǀĞůĂƌĞĂĂƌŽƵŶĚǁĞůů͘ ϳ͘ ZhĐƌĂŶĞ͘^Ğƚd^sĂůǀĞ͘EdƌĞĞ͘/ŶƐƉĞĐƚƚŚĞůŝĨƚƚŚƌĞĂĚƐŽŶƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͘/ŶƐƚĂůůƚŚĞƉůƵŐŽĨĨ ƚŽŽůŝŶƚŽƚŚĞd^sĂůǀĞ͘ ϴ͘ Ehϭϭ͟KW͘ZƌĂŶĞ͘ ϵ͘ EhKWŚŽƵƐĞ͘^ƉŽƚŵƵĚďŽĂƚ͘ ZtKWƌŽĐĞĚƵƌĞ͗ ϭϬ͘ D/Zh,ŝůĐŽƌƉ^ZηϭtKZŝŐ͕ĂŶĐŝůůĂƌǇĞƋƵŝƉŵĞŶƚĂŶĚůŝŶĞƐƚŽƌĞƚƵƌŶƐƚĂŶŬ͘ ϭϭ͘ dĞƐƚKWƚŽϮϱϬͬϯ͕ϬϬϬƉƐŝ͕ĂŶŶƵůĂƌƚŽϮϱϬͬϮ͕ϱϬϬƉƐŝ͘ Ă͘ EŽƚŝĨǇK'ϮϰŚŽƵƌƐŝŶĂĚǀĂŶĐĞŽĨKWƚĞƐƚ͘ ď͘ ŽŶĨŝƌŵƚĞƐƚƉƌĞƐƐƵƌĞƐƉĞƌƚŚĞ^ƵŶĚƌǇŽŶĚŝƚŝŽŶƐŽĨĂƉƉƌŽǀĂů͘ Đ͘ dĞƐƚsZƌĂŵŽŶϮͲϳͬϴ͟ƚĞƐƚũŽŝŶƚ͘ Ě͘ ^ƵďŵŝƚƚŽK'ĐŽŵƉůĞƚĞĚϭϬͲϰϮϰĨŽƌŵǁŝƚŚŝŶϱĚĂǇƐŽĨKWƚĞƐƚ͘ ϭϮ͘ ZhƚŽƉƵůůϮͲϳͬϴ͟^WĐŽŵƉůĞƚŝŽŶ͘ ϭϯ͘ WƵůůƚŚĞƉůƵŐŽĨĨƚŽŽů͕ĐŚĞĐŬĨŽƌƉƌĞƐƐƵƌĞƵŶĚĞƌƚŚĞd^ǀĂůǀĞ͕ŝĨŶĞĞĚĞĚŬŝůůƚŚĞǁĞůůǁŝƚŚϵ͘ϯƉƉŐEĂů ĂŶĚƉƵůůƚŚĞd^ǀĂůǀĞ͘ ϭϰ͘ DhůĂŶĚŝŶŐũŽŝŶƚŽƌƐƉĞĂƌ͘K>^͕ƵŶƐĞĂƚƚŚĞƚƵďŝŶŐŚĂŶŐĞƌĂŶĚƉƵůůƚŽƚŚĞƌŝŐĨůŽŽƌ͘ Ă͘ Whtƚ͘ϲϴ<ͲůďƐůĂƐƚƉƵůůǁŝƚŚ^ZϭϮͬϭϰͬϮϬϮϬ ϭϱ͘ >ĂǇĚŽǁŶƚŚĞůĂŶĚŝŶŐũŽŝŶƚĂŶĚƚƵďŝŶŐŚĂŶŐĞƌ͘ZhƚŽƉƵůů^WĐĂďůĞŽǀĞƌƚŚĞƐŚĞĂǀĞƐƚŽƚŚĞƐƉŽŽůŝŶŐ ƵŶŝƚ͘ Ă͘ /ŶƐƉĞĐƚƚŚĞƚƵďŝŶŐŚĂŶŐĞƌĂŶĚŶŽƚĞĂŶǇĚĂŵĂŐĞ͘/ĨĂŶǇĚĂŵĂŐĞŝƐĨŽƵŶĚ͕ĐŽŶƚĂĐƚǁĞůůŚĞĂĚ ƐƉĞĐŝĂůŝƐƚĨŽƌƌĞĚƌĞƐƐŽƌƌĞƉůĂĐĞŵĞŶƚ͘ ϭϲ͘ WKK,ĂŶĚůĂǇĚŽǁŶƚŚĞϮͲϳͬϴ͟ƚƵďŝŶŐ͘>ĂǇĚŽǁŶ^WĂŶĚŵŽƚŽƌ͘ Ă͘ EŽƚĞĂŶǇĐŽƌƌŽƐŝŽŶ͕ƐĂŶĚŽƌƐĐĂůĞŽŶƚŚĞƚƵďŝŶŐǁŝƚŚĂƐƐŽĐŝĂƚĞĚĚĞƉƚŚƐĂŶĚ^WĐŽŵƉŽŶĞŶƚƐŽŶ ƚŚĞŵŽƌŶŝŶŐƌĞƉŽƌƚ͘ ď͘ >ŽŽŬĨŽƌŽǀĞƌͲƚŽƌƋƵĞĚĐŽŶŶĞĐƚŝŽŶƐĨƌŽŵƉƌĞǀŝŽƵƐƚƵďŝŶŐƌƵŶƐ͘ Đ͘ /ĨĂŶǇũŽŝŶƚ;ƐͿĂƉƉĞĂƌƐƵƐƉĞĐƚŽĨĚĂŵĂŐĞƚŽƚŚƌĞĂĚƐŽƌƚƵďŝŶŐ͕ƐĞŶĚƚŽ'Θ/ĨŽƌĚŝƐƉŽƐĂůĂŶĚ ƌĞƉůĂĐĞǁŝƚŚŶĞǁ͘ ƋƵŝƉŵĞŶƚŝƐƉŽƐŝƚŝŽŶ dƵďŝŶŐŚĂŶŐĞƌ sŝƐƵĂůůǇŝŶƐƉĞĐƚŽŶƐŝƚĞĂŶĚƌĞƵƐĞ dƵďŝŶŐΘWƵƉũŽŝŶƚƐ sŝƐƵĂůůǇŝŶƐƉĞĐƚŽŶƐŝƚĞĂŶĚƌĞƵƐĞ ^WĞƋƵŝƉŵĞŶƚͬWŽǁĞƌĂďůĞ ĞŶƚƌŝůŝĨƚƚŽƚĂŬĞƉŽƐƐĞƐƐŝŽŶĨŽƌŝŶƐƉĞĐƚŝŽŶĂŶĚƚĞĂƌĚŽǁŶ WƌŽƚĞĐƚŽƌůŝǌĞƌ;ϲͿ sŝƐƵĂůůǇŝŶƐƉĞĐƚŽŶƐŝƚĞĂŶĚƌĞƵƐĞ ĂŶŶŽŶĐůĂŵƉƐ;ϭϭϴͿ sŝƐƵĂůůǇŝŶƐƉĞĐƚŽŶƐŝƚĞĂŶĚƌĞƵƐĞ '>D sŝƐƵĂůůǇŝŶƐƉĞĐƚŽŶƐŝƚĞĂŶĚƌĞƵƐĞ &ůĂƚŐƵĂƌĚ;ϭͿ sŝƐƵĂůůǇŝŶƐƉĞĐƚŽŶƐŝƚĞĂŶĚƌĞƵƐĞ ^WŚĂŶŐĞŽƵƚ tĞůů͗DWh:ͲϭϬ ϭϳ͘ Wh͕DhĂŶĚZ/,ŶĞǁ^WŽŶϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐǁŝƚŚŶĞǁ^WĐĂďůĞĂŶĚϯͬϴ͟ĂƉ^ƚƌŝŶŐ͘ ^ĞƚďĂƐĞŽĨ^WĂƐƐĞŵďůǇĂƚцϳ͕ϱϲϳ͛D͘ Ă͘ DŽƚŽƌĐĞŶƚƌĂůŝǌĞƌ ď͘ DŽƚŽƌŐĂƵŐĞƵŶŝƚ Đ͘ ^WŵŽƚŽƌ Ě͘ >ŽǁĞƌƚĂŶĚĞŵƐĞĂů Ğ͘ hƉƉĞƌƚĂŶĚĞŵƐĞĂů Ĩ͘ WƵŵƉ Ő͘ WŽƌƚĞĚĚŝƐĐŚĂƌŐĞŚĞĂĚ Ś͘ ŽůƚŽŶĚŝƐĐŚĂƌŐĞŚĞĂĚ ŝ͘ ϭũŽŝŶƚϮͲϳͬϴ͟d' ũ͘ ϮͲϳͬϴ͟yEEŝƉƉůĞ Ŭ͘ ϭũŽŝŶƚϮͲϳͬϴ͟d' ů͘ ϮͲϳͬϴ͟'>D ŵ͘ yy:ŽŝŶƚƐϮͲϳͬϴ͟d' Ŷ͘ ϮͲϳͬϴ͟'>DΛнͬͲϭϱϬ͛D Ž͘ y:ŽŝŶƚƐϮͲϳͬϴ͟d' ϭϴ͘ WhĂŶĚDhƚŚĞϮͲϳͬϴ͟ƚƵďŝŶŐŚĂŶŐĞƌ͘DĂŬĞĨŝŶĂůƐƉůŝĐĞŽĨƚŚĞ^WĐĂďůĞƚŽƚŚĞƉĞŶĞƚƌĂƚŽƌ͕ĐŽŶŶĞĐƚ ϯͬϴ͟ĂƉƐƚƌŝŶŐ͕ĂŶĚĞŶƐƵƌĞĂŶǇĐŽŶƚƌŽůůŝŶĞƉŽƌƚƐĂƌĞĚƵŵŵŝĞĚŽĨĨ͘ ϭϵ͘ >ĂŶĚƚƵďŝŶŐŚĂŶŐĞƌǁŝƚŚĞǆƚƌĞŵĞĐĂƵƚŝŽŶƚŽĂǀŽŝĚĚĂŵĂŐŝŶŐƚŚĞ^WĐĂďůĞŽƌƉĞŶĞƚƌĂƚŽƌ͘Z/>^͘>ĂǇ ĚŽǁŶůĂŶĚŝŶŐũŽŝŶƚ͘ZĞĐŽƌĚWhĂŶĚ^KǁĞŝŐŚƚƐŽŶƚŚĞƚĂůůǇĂŶĚtĞůů͘ ϮϬ͘ ^ĞƚϮ͘ϱ͟d^sĂůǀĞ͘ WŽƐƚͲZŝŐWƌŽĐĞĚƵƌĞ͗ Ϯϭ͘ ZŵƵĚďŽĂƚ͘ZKWŚŽƵƐĞ͘DŽǀĞƚŽŶĞǆƚǁĞůůůŽĐĂƚŝŽŶ͘ ϮϮ͘ ZhĐƌĂŶĞ͘EKW͘/ŶƐƚĂůůƚŚĞƉůƵŐŽĨĨƚŽŽů͘ Ϯϯ͘ EhƚŚĞƚƵďŝŶŐŚĞĂĚĂĚĂƉƚĞƌĂŶĚEhϮͲϵͬϭϲ͟ϱDƚƌĞĞ͘ Ϯϰ͘ WdƚŚĞƚƵďŝŶŐŚĂŶŐĞƌǀŽŝĚƚŽϱϬϬͬϱ͕ϬϬϬƉƐŝ͘WdƚŚĞƚƌĞĞƚŽϮϱϬͬϱ͕ϬϬϬƉƐŝ͘ Ϯϱ͘ WƵůůƚŚĞƉůƵŐŽĨĨƚŽŽůĂŶĚWs͘ Ϯϲ͘ ZĐƌĂŶĞ͘DŽǀĞƌĞƚƵƌŶƐƚĂŶŬĂŶĚƌŝŐŵĂƚƐƚŽŶĞǆƚǁĞůůůŽĐĂƚŝŽŶ͘ Ϯϳ͘ ZĞƉůĂĐĞŐĂƵŐĞ;ƐͿŝĨƌĞŵŽǀĞĚ͘ Ϯϴ͘ dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶǀŝĂŚĂŶĚŽǀĞƌĨŽƌŵ͘ZhǁĞůůŚŽƵƐĞĂŶĚĨůŽǁůŝŶĞƐ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ KW^ĐŚĞŵĂƚŝĐ ϰ͘ DW:ͲϭϬ,WdƌĞŶĚ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗,ϮͲϮϮͲϮϬϮϮ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh:ͲϭϬ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϮͬϭϱͬϮϬϮϬ Wd͗ϭϵϰͲϭϭϬ dсϴ͕Ϯϲϱ͛;DͿͬdсϳ͕ϰϬϭ͛;dsͿ ϭϯͲϯͬϴ͟ 6KRUW-RLQW 0DUNHU-W# :/0 KƌŝŐ͘<ůĞǀ͗͘ϯϭ͘ϭ͛ ϳ͟ ϵͲϱͬϴ͟ .83%6DQGV Wdсϴ͕ϭϲϬ͛;DͿ ͬWdсϳ͕ϯϬϭ͛;dsͿ .83$ $ 6DQGV ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ ƌŝĨƚ/ dŽƉ ƚŵ ϭϯͲϯͬϴΗ ŽŶĚƵĐƚŽƌ ϱϰ͘ϱͬ<ͲϱϱͬEͬ Eͬ ^ƵƌĨĂĐĞ ϭϭϮΖ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬƚƌĐ͘ ϴ͘ϲϳϵ ^ƵƌĨĂĐĞ Ϯ͕ϲϲϰ͛ ϳΗ WƌŽĚƵĐƚŝŽŶ Ϯϲͬ>ͲϴϬͬE^ ϲ͘ϭϱϭ ^ƵƌĨĂĐĞ ϴ͕Ϯϰϳ͛ dh/E'd/> ϮͲϳͬϴΗ dƵďŝŶŐ ϲ͘ϱͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϰϰϭ ^ƵƌĨĂĐĞ ϳ͕ϱϳϲ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ ϭϯϮ '>DϮ͗ĂŵĐŽ͕ϮͲϳͬϴΗǆϭΗ<DDǁͬƵŵŵǇϬϴͲϮϵͲϮϭ Ϯ ϳ͕ϯϯϳ͛ '>Dϭ͗ĂŵĐŽ͕ϮͲϳͬϴΗǆϭΗ<DDǁͬsϭϮͲϭϵͲϮϬ ϯ ϳ͕ϰϱϴ͛ Ϯ͘ϯϭϯ͟yEͲEŝƉƉůĞ;Ϯ͘ϮϬϱ͟ŶŽͲŐŽͿ ϰ ϳ͕ϱϬϬ͛ WŽƌƚĞĚ^Ƶď͗ϱϭϯͬϱϯϴWWDW ϱ ϳ͕ϱϬϬ͘ϱ͛ ŝƐĐŚĂƌŐĞ,ĞĂĚ͗ϱϭϯϮͲϳͬϴyϴhϭϬϰϬ ϲ ϳ͕ϱϬϭ͛ WƵŵƉϮ͗ϱϯϴWD^yϭϯϳWϭϳD&ZEKͺWEd ϳ ϳ͕ϱϮϬ͛ WƵŵƉϭ͗ϱϯϴWD^yϭϭϵWϮϯD&ZEKͺWEd ϴ ϳ͕ϱϯϳ͛ 'ĂƐ^ĞƉĂƌĂƚŽƌ͗'^D^dZydZDϱϯϴ'^ ϵ ϳ͕ϱϰϮ͛ hƉƉĞƌdĂŶĚĞŵ^ĞĂů^ĞĐƚŝŽŶ͗'^ϯ,ϲ^ͬW&^ ϭϬ ϳ͕ϱϰϵ͛ >ŽǁĞƌdĂŶĚĞŵ^ĞĂů^ĞĐƚŝŽŶ͗'^ϯ,ϲ^ͬW&^ ϭϭ ϳ͕ϱϱϲ͛ DŽƚŽƌͲϱϲϮyWϮϱϬ,ƉͬϮ͕ϱϬϱsͬϲϭ ϭϮ ϳ͕ϱϳϯ͛ 'ĂƵŐĞΘĞŶƚƌĂůŝǌĞƌ͗ĞŶŝƚŚWdϬϬϳϱϮͲ ŽƚƚŽŵΛϳ͕ϱϳϲ͛ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ <ƵƉ͘^ĂŶĚƐ ϳ͕ϳϰϰ ϳ͕ϳϲϲ͛ ϲ͕ϵϬϲ͛ ϲ͕ϵϮϳ͛ ϮϮ ϭϬͬϯϭͬϭϵϵϰ KƉĞŶ <ƵƉ͘ϯΘϮ ^ĂŶĚƐ ϳ͕ϴϯϲ͛ ϳ͕ϵϭϬ͛ ϲ͕ϵϵϮ͛ ϳ͕ϬϲϮ͛ ϳϰ ϭϬͬϯϭͬϭϵϵϵ KƉĞŶ KWE,K>ͬDEdd/> ϭϯͲϯͬϴ͟ ϮϱϬƐǆŽĨƌĐƚŝĐƐĞƚ/;ƉƉƌŽǆͿŝŶϮϰ͟,ŽůĞ ϵͲϱͬϴΗ ϱϱϭƐǆW&͟͞ŝŶϭϮͲϭͬϰ͟,ŽůĞ ϳ͟ ϯϯϬƐǆůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟,ŽůĞ t>>/E>/Ed/KEd/> <KWΛϲϯϬ͛ DĂǆ,ŽůĞŶŐůĞсϯϵĚĞŐ͘Ĩͬϯ͕ϭϬϬ͛ DĂǆ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϮϬĚĞŐ͘ dZΘt>>, dƌĞĞ ϱD/tϮͲϵͬϭϲ͟ tĞůůŚĞĂĚ ϭϭ͟ǆϮͲϵͬϭϲ͟ϱDt<Dǁͬd&Ͳ^ͲϭƚďŐ,ĂŶŐĞƌ͕ϮͲ ϳͬϴ͟hϴƌĚdǆƚŚƌĞĂĚƐΘϮ͘ϱ/t͚,͛WsƉƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϱϬϬͲϬϬͲϬϬ ŽŝůŽŵƉůĞƚŝŽŶͲϭϬͬϯϭͬϭϵϵϰ ^WŽŵƉůĞƚŝŽŶďǇEĂďŽƌƐϰ^ʹϭϬͬϭϯͬϭϵϵϴ ^WZtKďǇEĂďŽƌƐϰ^ʹϭϭͬϭϬͬϮϬϬϬ ^WZtKďǇEĂďŽƌƐϰ^ʹϴͬϭϲͬϮϬϬϰ ^WZtKďǇEĂďŽƌƐϰ^ʹϵͬϮͬϮϬϬϲ ^WZtKďǇEĂďŽƌƐϰ^ʹϱͬϴͬϮϬϭϬ ŽǇŽŶϭϲZtKʹϱͬϮϵͬϮϬϭϯ ^WZtKďǇEŽƌĚŝĐϯʹϯͬϮϯͬϮϬϭϱ ^W^ǁĂƉďǇ^ZʹϭϮͲϭϱͲϮϬϮϬ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗,ϮͬϮϮͬϮϬϮϮ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh:ͲϭϬ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϮͬϭϱͬϮϬϮϬ Wd͗ϭϵϰͲϭϭϬ dсϴ͕Ϯϲϱ͛;DͿͬdсϳ͕ϰϬϭ͛;dsͿ ϭϯͲϯͬϴ͟ 6KRUW-RLQW 0DUNHU-W# :/0 KƌŝŐ͘<ůĞǀ͗͘ϯϭ͘ϭ͛ ϳ͟ ϵͲϱͬϴ͟ .83%6DQGV Wdсϴ͕ϭϲϬ͛;DͿ ͬWdсϳ͕ϯϬϭ͛;dsͿ .83$ $ 6DQGV ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ ƌŝĨƚ/ dŽƉ ƚŵ ϭϯͲϯͬϴΗ ŽŶĚƵĐƚŽƌ ϱϰ͘ϱͬ<ͲϱϱͬEͬ Eͬ ^ƵƌĨĂĐĞ ϭϭϮΖ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬƚƌĐ͘ ϴ͘ϲϳϵ ^ƵƌĨĂĐĞ Ϯ͕ϲϲϰ͛ ϳΗ WƌŽĚƵĐƚŝŽŶ Ϯϲͬ>ͲϴϬͬE^ ϲ͘ϭϱϭ ^ƵƌĨĂĐĞ ϴ͕Ϯϰϳ͛ dh/E'd/> ϮͲϳͬϴΗ dƵďŝŶŐ ϲ͘ϱͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϰϰϭ ^ƵƌĨĂĐĞ цϳ͕ϱϳϲ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ цϭϯϮ '>DϮ͗ĂŵĐŽ͕ϮͲϳͬϴΗǆϭΗ<DDǁͬƵŵŵǇϬϴͲϮϵͲϮϭ Ϯ цϳ͕ϯϯϳ͛ '>Dϭ͗ĂŵĐŽ͕ϮͲϳͬϴΗǆϭΗ<DDǁͬsϭϮͲϭϵͲϮϬ ϯ цϳ͕ϰϱϴ͛ Ϯ͘ϯϭϯ͟yEͲEŝƉƉůĞ;Ϯ͘ϮϬϱ͟ŶŽͲŐŽͿ ϰ цϳ͕ϱϬϬ͛ WŽƌƚĞĚ^Ƶď͗ ϱ цϳ͕ϱϬϭ͛ ŝƐĐŚĂƌŐĞ,ĞĂĚ͗ ϲ цϳ͕ϱϬϮ͛ WƵŵƉϮ͗ ϳ цϳ͕ϱϮϬ͛ WƵŵƉϭ͗ ϴ цϳ͕ϱϯϳ͛ 'ĂƐ^ĞƉĂƌĂƚŽƌ͗ ϵ цϳ͕ϱϰϮ͛ hƉƉĞƌdĂŶĚĞŵ^ĞĂů͗ ϭϬ цϳ͕ϱϰϵ͛ >ŽǁĞƌdĂŶĚĞŵ^ĞĂů͗ ϭϭ цϳ͕ϱϱϲ͛ DŽƚŽƌ͗ ϭϮ цϳ͕ϱϳϯ͛ 'ĂƵŐĞΘĞŶƚƌĂůŝǌĞƌͲŽƚƚŽŵΛцϳ͕ϱϳϲ͛ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ <ƵƉ͘ ϳ͕ϳϰϰ ϳ͕ϳϲϲ͛ ϲ͕ϵϬϲ͛ ϲ͕ϵϮϳ͛ ϮϮ ϭϬͬϯϭͬϭϵϵϰ KƉĞŶ <ƵƉ͘ϯΘϮ ϳ͕ϴϯϲ͛ ϳ͕ϵϭϬ͛ ϲ͕ϵϵϮ͛ ϳ͕ϬϲϮ͛ ϳϰ ϭϬͬϯϭͬϭϵϵϵ KƉĞŶ KWE,K>ͬDEdd/> ϭϯͲϯͬϴ͟ ϮϱϬƐǆŽĨƌĐƚŝĐƐĞƚ/;ƉƉƌŽǆͿŝŶϮϰ͟,ŽůĞ ϵͲϱͬϴΗ ϱϱϭƐǆW&͟͞ŝŶϭϮͲϭͬϰ͟,ŽůĞ ϳ͟ ϯϯϬƐǆůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟,ŽůĞ t>>/E>/Ed/KEd/> <KWΛϲϯϬ͛ DĂǆ,ŽůĞŶŐůĞсϯϵĚĞŐ͘Ĩͬϯ͕ϭϬϬ͛ DĂǆ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϮϬĚĞŐ͘ dZΘt>>, dƌĞĞ ϱD/tϮͲϵͬϭϲ͟ tĞůůŚĞĂĚ ϭϭ͟ǆϮͲϵͬϭϲ͟ϱDt<Dǁͬd&Ͳ^ͲϭƚďŐ,ĂŶŐĞƌ͕ϮͲ ϳͬϴ͟hϴƌĚdǆƚŚƌĞĂĚƐΘϮ͘ϱ/t͚,͛WsƉƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϱϬϬͲϬϬͲϬϬ ŽŝůŽŵƉůĞƚŝŽŶͲϭϬͬϯϭͬϭϵϵϰ ^WŽŵƉůĞƚŝŽŶďǇEĂďŽƌƐϰ^ʹϭϬͬϭϯͬϭϵϵϴ ^WZtKďǇEĂďŽƌƐϰ^ʹϭϭͬϭϬͬϮϬϬϬ ^WZtKďǇEĂďŽƌƐϰ^ʹϴͬϭϲͬϮϬϬϰ ^WZtKďǇEĂďŽƌƐϰ^ʹϵͬϮͬϮϬϬϲ ^WZtKďǇEĂďŽƌƐϰ^ʹϱͬϴͬϮϬϭϬ ŽǇŽŶϭϲZtKʹϱͬϮϵͬϮϬϭϯ ^WZtKďǇEŽƌĚŝĐϯʹϯͬϮϯͬϮϬϭϱ ^W^ǁĂƉďǇ^ZʹϭϮͲϭϱͲϮϬϮϬ DŝůŶĞWŽŝŶƚ ^ZZŝŐϭKW %23( Εϰ͘ϰϴΖ Εϰ͘ϱϰΖ Ϯ͘ϬϬΖ ϱϬϬϬηͬϭϭΗ ϮͲϳͬϴΗǆϱΗsZ ϱϬϬϬηͬϭϭΗ ůŝŶĚ ^͕ϭϭϱDyϳϭͬϭϲϱD;/ĨEĞĞĚĞĚͿ ϮϭͬϭϲϱD<ŝůů>ŝŶĞsĂůǀĞƐ ϮϭͬϭϲϱDŚŽŬĞ>ŝŶĞsĂůǀĞƐ ,ZDĂŶƵĂůDĂŶƵĂůDĂŶƵĂů ^ƚƌŝƉƉŝŶŐ,ĞĂĚ ϬϱϬϬϭϬϬϬϭϱϬϬϮϬϬϬϮϱϬϬϯϬϬϬϯϱϬϬϳͬϮϯͬϮϭ ϴͬϭϮͬϮϭ ϵͬϭͬϮϭ ϵͬϮϭͬϮϭ ϭϬͬϭϭͬϮϭ ϭϬͬϯϭͬϮϭ ϭϭͬϮϬͬϮϭ ϭϮͬϭϬͬϮϭ ϭϮͬϯϬͬϮϭ ϭͬϭϵͬϮϮ ϮͬϴͬϮϮ ϮͬϮϴͬϮϮWƌĞƐƐƵƌĞ;ƉƐŝͿĂƚĞDW:ͲϭϬ,Wϴ͘ϱϱWW' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 02/17/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU J-10 (PTD 194-110) 24 Arm Caliper 01/19/2022 Please include current contact information if different from above. 37' (6HW Received By: 02/17/2022 By Abby Bell at 12:07 pm, Feb 17, 2022 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ESP Swap Hilcorp Alaska Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,265 feet 8,045 (Fill)feet true vertical 7,401 feet N/A feet Effective Depth measured 8,045 feet N/A feet true vertical 7,191 feet N/A feet 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 7,576' 6,749' Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone:777-8520 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 3,090psi 5,410psi Burst Surface Production N/A 5,750psi 7,240psi 13-3/8" 9-5/8" 7" 2,432' 7,384' Junk measured Length 112' 2,664' 8,247' Tubing Pressure 65 N/A measured N/A Casing Conductor Size 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-473 247 Authorized Signature with date: Authorized Name: Ian Toomey itoomey@hilcorp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 194-110 50-029-22500-00-00 Plugs ADL0025906 5. Permit to Drill Number: Milne Point Field / Kuparuk River Oil 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 00 MILNE PT UNIT KR J-10 Gas-Mcf 600 1,460 Oil-Bbl measured true vertical Packer 260 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 111 Casing Pressure WINJ WAG 0 Water-Bbl MD 112' 2,664' 8,247' TVD 112' Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:40 pm, Jan 20, 2021 Chad Helgeson (1517) 2021.01.20 15:00:15 - 09'00' DSR-1/21/21MGR18FEB2021 RBDMS HEW 1/27/2021 SFD 1/26/2021 _____________________________________________________________________________________ Revised By: TDF 12/16/2020 SCHEMATIC Milne Point Unit Well: MPU J-10 Last Completed: 12/15/2020 PTD: 194-110 TD =8,160’ (MD) / TD = 7,401’(TVD) 13-3/8” Short Joint Marker Jt @ 7,519 WLM Orig. KB Elev.: 31.1’ 7” 2 3 8 9 & 10 11 9 12 9-5/8” 1 KUP B Sands PBTD =8,203’ (MD) / PBTD = 7,342’(TVD) 6 & 7 4& 5 KUP A3 & A2 Sands CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8" Conductor 54.5 / K-55 / N/A N/A Surface 115' 9-5/8" Surface 40 / L-80 / Btrc. 8.679 Surface 2,664’ 7" Production 26 / L-80 / NSCC 6.151 Surface 8,247’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 7,576’ JEWELRY DETAIL No Depth Item 1 132 GLM 2: Camco, 2-7/8" x 1" KBMM w/ DV 2 7,337’ GLM 1: Camco, 2-7/8" x 1" KBMM w/ DV 3 7,458’ 2.313” XN-Nipple (2.205” no-go) 4 7,500’ Ported Sub: 513/538P PMP 5 7,500.5’ Discharge Head: 513 2-7/8X8 EUE1040 6 7,501’ Pump 2: 538PMSXD 137 P17 M FER NO_PNT 7 7,520’ Pump 1: 538PMSXD 119 P23 M FER NO_PNT 8 7,537’ Gas Separator: GAS MASTER EXTREME 538GS 9 7,542’ Upper Tandem Seal Section: GSB3DB H6 SB/AB PFSA 10 7,549’ Lower Tandem Seal Section: GSB3DB H6 SB/AB PFSA 11 7,556’ Motor - 562XP 250 Hp /2,505 V / 61 A 12 7,573’ Gauge & Centralizer: Zenith PT00752-Bottom @ 7,576’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. B Sands 7,744 7,766’ 6,906’ 6,927’ 22 10/31/1994 Open Kup. A3 & A2 Sands 7,836’ 7,910’ 6,992’ 7,062’ 74 10/31/1999 Open OPEN HOLE / CEMENT DETAIL 13-3/8” 250 sx of Arcticset I (Approx) in 24” Hole 9-5/8" 551 sx PF “E” in 12-1/4” Hole 7” 330 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 630’ Max Hole Angle = 39 deg. f/ 3,100’ Max Hole Angle through perforations = 20 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” x 2-9/16” 5M WKM w/ TDF-CS-1 tbg Hanger, 2- 7/8” EU 8rd T x B threads & 2.5 CIW ‘H’ BPV profile GENERAL WELL INFO API: 50-029-22500-00-00 Coil Completion - 10/31/1994 ESP Completion by Nabors 4ES – 10/13/1998 ESP RWO by Nabors 4ES – 11/10/2000 ESP RWO by Nabors 4ES – 8/16/2004 ESP RWO by Nabors 4ES – 9/2/2006 ESP RWO by Nabors 4ES – 5/8/2010 Doyon 16 RWO – 5/29/2013 ESP RWO by Nordic 3 –3/23/2015 ESP Swap by ASR – 12-15-2020 Well Name Rig API Number Well Permit Number Start Date End Date MP J-10 LRS / ASR 50-029-22500-00-00 194-110 12/10/2020 12/15/2020 12/11/2020 - Friday Continue to MIRU. Connect hydraulic lines. M/U glycol lines. Lay down Herculite. Spot Catwalk. Spot camps and get power and water. Fill pits with Source Water. Get 40 bbls of Fresh Water for BOP testing. Raise Mast. Cont. To RU ASR surface lines and winterize them. NU 6” Flow line, and spacer spools. Hang the sheave and the Elephant trunk. Went to fire up Glycol unit but could not start unit the glycol reservoir did not have enough fluid. Had to call and get fluid brought out. Fluid arrive, fill and start Glycol unit. Make up 2 7/8” test mandrill. Spot in the HPH and Pipe shed. CSIP: 100PSI @ 21:00hrs Opened up to Bleed off tank for 1 hr well at constant flow rate of 8.4GPM. Got ISIP 50 PSI. continued to bleed off staying at same 8.4GPM for 1.hr. shut in at 23:00hrs. ISIP 50psi total of total of 24 Bbls returned. Continue to monitor SIP. while waiting for equipment to heat pick up test mandrill set in stack and hook up the Kelly hose, fill the stack and work any air out of the system. Begin shell test, slow leak off chase down leak to a Greylock. tighten up. did not work. blow down lines and replace grey lock Gasket 12/9/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 12/10/2020 - Thursday MIRU LRS. T/I/O = 60/750/0 psi. P/T lines to 250 psi low and 2,500 psi high. Bleed off gas on IA from 750 psi to 50 psi over 25 minutes. Bleed off gas on tubing from 60 psi to 0 psi over 5 minutes. T/I/O = 0/50/0 psi. Circulate 10 bbls of 110 degree diesel at 1 BPM down tubing while taking returns out of the IA to the return tank. Tubing fluid packed after pumping 8 bbls. T/I/O = 40/55/0 psi. Circulate 310 bbls of 80 degree Source Water at 3 BPM down tubing while taking returns out of the IA and to the return tank. See returns at tank immediately. 1:1 returns through duration of circulation at 75% open choke. NOTE: choke needs to be replaced, extremely difficult to turn. See clean Source Water returns out of needle valve in circulation skid at 310 bbls away. Shut down and monitor well. T/I/O = 38/38/0 psi. Total fluid circulated = 320 bbls. Total returns in return tank= 308 bbls. Bullhead 20 bbls down tubing at 2.5 BPM and 600 psi. T/I/O = 130/124/0 psi after monitoring for 60 minutes and still falling at 1 psi every 2-3 minutes. Attempt to bleed tubing and IA pressures to 0 psi by opening both to the return tank. T/I/O = 1/1/0 psi when open and there is slight flow into tank. Returned 5 bbls over 60 minutes. Shut In and monitor. T/I/O = 5/5/0 psi. Freeze protect tubing and IA lines. RD LRS. Decision made to progress with the rig up process as winds are forecasted to exceed 25-30 mph. Install BPV with lubricator. Suck tree dry. N/D Tree. Install test plug. Test plug tested to 5,300 psi. Spot well hut. Crane in BOPE. N/U BOPE. Place Rig Floor. Spot Mud Boat. Spot Rig. Spot Pusher Shack and lay hydraulic lines from Accumulator. Spot Pits. T/I/O = BPV/100/0 psi. Well Name Rig API Number Well Permit Number Start Date End Date MP J-10 LRS / ASR 50-029-22500-00-00 194-110 12/10/2020 12/15/2020 Hilcorp Alaska, LLC Weekly Operations Summary Continue to attempt to get a good BOP Shell test. 1502 block valve leaking on back deck of rig. Replace 1502 valve. IBOP thawed and proceed with BOP Test. Get good Shell Test to 250 psi low and 2,500 psi. BOPE test to 250 psi low and 2,500 psi high w/ 2-7/8" test joint: Test #1: Blind Rams, C-12,C-14, C-16. Test #2: 2-7/8" x 5" VBRs, C1, K1, TIW. Test #3: 2-7/8" x 5" VBRs, TIW, HCR Choke, K2. Test #4:2-7/8" x 5" VBRs, TIW, C5, C6, C9, K3. Test #5:2-7/8" x 5" VBRs, C4, C7, C11, K3. Test #6:2- 7/8" x 5" VBRs, C8, C10, C13, C14, C15, K3. Test #7: Annular, IBOP, C12, C14, C16. Test #8: Choke bleed off. Finish the draw down. Prep to Pull Test plug and the BPV. Pick up the T-Bar install retrieving tool. Pull the Test Plug, stab into the BPV and monitor fluid rising in the stack RU to pump 50 Bbls down the tbg up the IA. Circulate 50 Bbls down the TBG @ 1.5BPM 180psi. returning up the IA getting 1:1 returns. Stab back into the BPV monitor. Some pressure under BPV Bleed off pressure and Pull BPV. Shut Blinds and monitor pressure. 75psi on the tbg and 80psi IA. Start Pump bring up to 3BPM at 700psi pump pressure. 200psi on IA open choke to full open getting 3 BPM at 150 psi. pump pressure at 600psi circulate 240 Bbls total with a loss of 12 bbls . shut down pumps bleed back pump pressure and shut in to monitor the pressure. pressure stabilize at 125 PSI IA and TBG. Consult with town and order Kill fluid. 8.9PPG Brine. Transfer Source water from pits to flow back tank. Service and inspect equipment while waiting on the KWF. 12/12/2020 - Saturday 12/13/2020 - Sunday Load pits with 8.9 ppg brine. Spot vac trucks for well kill. T/I/O = 100/105/0. Begin circulating 8.9 ppg brine up to 3 BPM. pump pressure at 3 BPM is 700 psi. IA pressure once 3 BPM obtained is 100 psi. Circulate at 3 BPM while taking returns out the IA and to the Tiger Tank. Crack choke open at 25% and maintain 100 psi on IA while circulating. At 45 bbls away (tubing volume), T/I/O = 450/100/0 at 3 BPM. Maintain pump pressure of 450 psi for duration of circulation by opening choke gradually over the course of circulating an additional 295 bbls. Choke at 50% at 160 total bbls away. Choke at 50% at 160 total bbls away. Choke at 75% at 240 total bbls away. Choke at 100% at 270 total bbls away. Circulated a total of 320 bbls of 9.8 ppg brine and returned 309 bbls to tiger tank. Shut down pump when 8.8+ brine was seen in returns. Monitor well. Tubing was static at 0 psi. IA was on a slight vac at 0 psi. Blow down lines and empty Tiger Tank. M/U TIW to 2-7/8" landing joint and bring to Rig Floor. BOLDS. Check Tubing and IA pressures. Tubing static. IA on a slight vac. Open Blind Rams. Can see fluid level above hanger is static. M/U landing joint to Hanger with 10 turns. Pull Hanger to the Floor. 68k-lbs to unseat Hanger. Fill hole with 8 bbls tofluid pack to surface. 8 bbls lost in 90 minutes (~5 bbls per hour). Inspect hanger and found it to be in good shape. Send to Wellhead shop to be redressed. Break and L/D penetrator. Filled hole with 3 bbls. (3 BPH loss rate). Send ESP Cable and cap string over sheave and through elephant trunk into Spoolers. Filled hole with 4 bbls (4 BPH loss rate). POH w/ 2-7/8" EUE ESP completion while spooling ESP cable and cap string. Find ESP cable blowout at 165'. Find multiple other bad spots in the cable from 175' - 200'. 1,921' out at crew change. Crew change, sevice and inspect rig and equipment. Cont. POH w/ 2-7/8" EUE ESP completion while spooling ESP cable and cap string to 5,747'. Continuous hole fill w/ 8.9ppg. (6.5 BPH loss rate) Up Wt @ 3,573'/ 31K, 5,747' 15K. Order additional 100Bbls of 8.9# Brine. TBG and clamps look good. Conduct well control Drill with crew, Let Crew eat lunch. Cont. POH w/ 2-7/8" EUE ESP completion while spooling ESP cable and cap string to Pump equipment. continuous hole fill w/ 8.9ppg. (6.5 BPH loss rate). Kicked out a total of 10 jnts with bad threads. Continue to POH w/ 2-7/8" completion to ESP. L/D ESP. Well Name Rig API Number Well Permit Number Start Date End Date MP J-10 LRS / ASR 50-029-22500-00-00 194-110 12/10/2020 12/15/2020 Hilcorp Alaska, LLC Weekly Operations Summary Held JSM, Discussed daily activities. Centrilift preforming final Penetrator Splice. Landed ESP Completion with 39k down on Tbg Hanger with Umbilical Cord attached to Penetrator. Final surface checks good. RILDS. BO/LD Landing Jt and Installed BPV. M/U ESP: Centralizer, Motor Gauge, Motor, Lower Tandem Seal, Upper Tandem Seal, Gas Separator, Pump 1, Pump 2, Discharge Head, Ported Sub. Move Spooler in order to change out Reels. Change out Reels. Spot Spooler. Filling hole w/ 8.9 brine while MU ESP. Protectolizer Clamp on ESP will not bolt up properly. Convoy to A-Pad in Phase 2 to get new Protectolizer and Bolt. TIH w/ New ESP Assembly on 2-7/8" 6.5 L-80 EUE 8rd tbg t/ 2,306' testing cable every 2,000' and clamping every other joint. Total of 71 jt in the hole. PJSM, Service and inspect Rig and equipment. TIH w/ New ESP Assembly on 2-7/8" 6.5 L-80 EUE 8rd tbg t/ 3,900' and clamping every other joint. Down wt.21K Test cable and Tally TBG. TIH w/ New ESP Assembly on 2-7/8" 6.5 L-80 EUE 8rd tbg t/ 6,235' and clamping every other joint. Down wt.29K Test cable and Tally TBG. Let crew take lunch. TIH w/ New ESP Assembly on 2-7/8" 6.5 L-80 EUE 8rd tbg clamping every other joint to TBG hanger depth. Found a Cable splice that ended up landing on a collar. Add 10' Tbg sub to space splice off collar inbetween Jnts 226-227. GLM, Camco, 2-7/8" x 1" KBMM with SOV installed between jnts 234-235 131.76' MD. Cont RIH to Hanger depth. Total of 237 jts in the hole. SOW 38k. PU Landing Jt and Tbg Hanger. Centrilift brought out wrong Penetrator. Waiting on Penetrator to arrive for Centrilift shop on A pad. 12/15/2020 - Tuesday 12/14/2020 - Monday Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 12/21/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU J-10 (PTD 194-110) Multi Finger Caliper Log 11/03/2020 Please include current contact information if different from above. PTD: 1941100 E-Set: 34447 Received by the AOGCC 12/22/2020 Abby Bell 12/23/2020 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 Swap 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 8,265'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name:Ian Toomey Operations Manager Contact Email:itoomey@hilcorp.com Contact Phone: 777-8520 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): COMMISSION USE ONLY Authorized Name: Authorized Title: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025906 194-110 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22500-00-00 Milne Point Field / Kuparuk River Oil Hilcorp Alaska LLC Length Size 7,401' 8,045' 7,191' C.O. 432D PRESENT WELL CONDITION SUMMARY 2,032 8,045 Fill MILNE PT UNIT KR J-10 112'112' 6.5#/ L-80/ EUE 8rd TVD Burst 7,508' MD N/A 5,750psi 7,240psi 2,432' 7,384' 2,664' 8,247' N/A and N/A 112'13-3/8" 9-5/8" 7" 2,664' 8,247' N/A and N/A Tubing Size: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 12/5/2020 2-7/8" Perforation Depth MD (ft): See Schematic See Schematic ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Chad A Helgeson 2020.11.05 17:13:44 -09'00' By Samantha Carlisle at 9:33 am, Nov 06, 2020 320-473 BOPE test to 2500 psi DSR-11/10/2020 10-404 SFD 11/6/2020MGR09NOV2020C n Required? Yes 11/12/2020 dts 11/12/2020 JLC 11/12/2020 RBDMS HEW 11/12/2020 ESP Changeout Well: MPU J-10 Date: 11-02-2020 Well Name:MPU J-10 API Number:50-029-22500-00-00 Current Status:Shut-in [Failed ESP]Pad:F-Pad Estimated Start Date:December 5 th, 2020 Rig:ASR #1 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:196-156 First Call Engineer:Ian Toomey (907) 777-8520 (O) (907) 903-3987 (M) Second Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) AFE Number:Job Type:ESP Changeout Current Bottom Hole Pressure:2,530 psi @ 6,682’ TVD SBHP Survey 11/02/2020 |7.3 ppg Maximum Expected BHP:2,700 psi @ 6,682’ TVD 30 day PBU Extrapolation |7.8 ppg MPSP:2,032 psi Gas Colum Gradient (0.1 psi/ft) Max Inclination 39° @ 3,091’ MD Max Dogleg:5°/100ft @ 1,383’ MD BPV Profile:2-1/2” CIW Type H Brief Well Summary: MPU J-10 was drilled and completed with an ESP in October 1994 as a Kuparuk producer. The well has been worked over seven times in its history with the last being March 2015. The ESP failed in October 2020 due to a downhole ground. Notes Regarding Wellbore Condition x The 7” casing was pressure tested to 1,500 psi with 8.7 ppg brine from 7,524’ MD on 3/23/15. x Offset injectors with status: o J-13 – SI on 10/30/2020 Objective: x Pull failed ESP completion. Determine source of electrical ground (if possible). x Run new ESP completion. Pre-Rig Procedure: 1. RU LRS. 2. Kill the well with 8.3 ppg source water (volumes: tubing = 44 bbls & IA = 237 bbls) 3. Confirm well is dead. 4. RD LRS. 5. Clear and level pad area in front of well. Spot rig mats and containment. 6. RD well house and flowlines. Clear and level area around well. 7. RU crane. Set 2-1/2” HP BPV. ND Tree. Inspect the lift threads on the tubing hanger. Install the plug off tool into the BPV. 8. NU BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. 194-110 SFD 11/6/2020 J-Pad ESP Changeout Well: MPU J-10 Date: 11-02-2020 RWO Procedure: 10. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to returns tank. 11. Test BOPE to 250/2,500 psi, annular to 250/2,500 psi. a. Notify AOGCC 24 hours in advance of BOP test. b. Confirm test pressures per the Sundry Conditions of approval. c. Test VBR ram on 2-7/8” test joint. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Contingency: If BOPE test fails 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. 12. RU to pull 2-7/8” ESP completion. 13. Pull the plug off tool, check for pressure under the BPV, if needed kill the well with 8.3 ppg source water and pull the BPV. 14. MU landing joint or spear. BOLDS, unseat the tubing hanger and pull to the rig floor. a. SO = 75K and PU = 100K when landed in 8.7 ppg seawater by Nordic 3 (block weight = 35K) in 2015. 15. Lay down the landing joint and tubing hanger. RU to pull ESP cable over the sheaves to the spooling unit. a. Inspect the tubing hanger and note any damage. If any damage is found, contact well head specialist for redress or replacement. 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. 16. POOH and lay down the 2-7/8” tubing. Lay down ESP and motor. a. Note any corrosion, sand or scale on the tubing with associated depths and ESP components on the morning report. b. Look for over-torqued connections from previous tubing runs. c. If any joint(s) appear suspect of damage to threads or tubing, send to G&I for disposal and replace with new. ESP Changeout Well: MPU J-10 Date: 11-02-2020 Equipment Disposition Tubing hanger Visually inspect on site and reuse Tubing & Pup joints Visually inspect on site and reuse ESP equipment/Power Cable Centrilift to take possession for inspection and teardown Capillary Tubing Junk Protectorlizer (3)Visually inspect on site and reuse Cannon clamps (120)Visually inspect on site and reuse Flat guard (1)Visually inspect on site and reuse 17. PU, MU and RIH new ESP on 2-7/8”, 6.5#, L-80, EUE 8rd tubing with new ESP cable. Set base of ESP assembly at ± 7,567’ MD. a. Motor centralizer b. Motor gauge unit c. ESP motor d. Lower tandem seal e. Upper tandem seal f. Pump g. Ported discharge head h. Bolt on discharge head 18. PU and MU the 2-7/8” tubing hanger. Make final splice of the ESP cable to the penetrator and ensure any control line ports are dummied off. 19. Land tubing hanger with extreme caution to avoid damaging the ESP cable or penetrator. RILDS. Lay down landing joint. Record PU and SO weights on the tally and WellEZ. 20. Set 2.5” HP BPV. Post-Rig Procedure: 21. RD mud boat. RD BOPE house. Move to next well location. 22. RU crane. ND BOPE. Install the plug off tool. 23. NU the tubing head adapter and NU 2-9/16” 5M tree. 24. PT the tubing hanger void to 500/5,000 psi. PT the tree to 250/5,000 psi. 25. Pull the plug off tool and BPV. 26. RD crane. Move returns tank and rig mats to next well location. 27. Replace gauge(s) if removed. 28. Turn well over to production via handover form. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic _____________________________________________________________________________________ Created By: TDF 11/3/2020 SCHEMATIC Milne Point Unit Well: MPU J-10 Last Completed: 5/29/2013 PTD: 194-110 TD =8,160’ (MD) / TD = 7,401’(TVD) 13-3/8” Short Joint Marker Jt @ 7,519 WLM Orig. KB Elev.: 31.1’ 7” 2 3 6 7 8 9 9 9-5/8” 1 KUP B Sands PBTD =8,203’ (MD) / PBTD = 7,342’(TVD) 5 4 KUP A3 & A2 Sands CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8" Conductor 54.5 / K-55 / N/A N/A Surface 115' 9-5/8" Surface 40 / L-80 / Btrc. 8.679 Surface 2,664’ 7" Production 26 / L-80 / NSCC 6.151 Surface 8,247’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 7508’ 3/8” Capstring Stainless Steel N/A Surface 7,508’ JEWELRY DETAIL No Depth Item 1138GLM(Dummy 11-3-20) 2 7,293’ GLM (Open pocket 11-3-20) 3 7,438’ 2-7/8” XN-Nipple 4 7,449’ GPDIS Discharge Head - GPDIS 5 7,450’ Pump - 137P17 SXD 6 7,469’ Gas Separator - 538GSTHVEV H6 7 7,473’ Tandem Seal Section - GSB3DBUT SB/SB PFSA : GSB3DBLT SB/SB PFSA CL5 8 7,487’ Motor - MSP1-325 150hp/ 2,205 V/ 41A 9 7,504’ WellLift Sensor w/ Centralizer / Bot. 7,508’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. B Sands 7,744 7,766’ 6,906’ 6,927’ 22 10/31/1994 Open Kup. A3 & A2 Sands 7,836’ 7,910’ 6,992’ 7,062’ 74 10/31/1999 Open OPEN HOLE / CEMENT DETAIL 13-3/8” 250 sx of Arcticset I (Approx) in 24” Hole 9-5/8" 551 sx PF “E” in 12-1/4” Hole 7” 330 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 630’ Max Hole Angle = 39 deg. f/ 3,100’ Max Hole Angle through perforations = 20 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” x 2-9/16” 5M WKM w/ TDF-CS-1 tbg Hanger, 2- 7/8” EU 8rd T x B threads & 2.5 CIW ‘H’ BPV profile GENERAL WELL INFO API: 50-029-22500-00-00 Coil Completion - 10/31/1994 ESP Completion by Nabors 4ES – 10/13/1998 ESP RWO by Nabors 4ES – 11/10/2000 ESP RWO by Nabors 4ES – 8/16/2004 ESP RWO by Nabors 4ES – 9/2/2006 ESP RWO by Nabors 4ES – 5/8/2010 Doyon 16 RWO – 5/29/2013 ESP RWO by Nordic 3 –3/23/2015 _____________________________________________________________________________________ Created By: IAT 11/03/2015 PROPOSED Milne Point Unit Well: MPU J-10 Last Completed: 5/29/2013 PTD: 194-110 TD =8,160’ (MD) / TD = 7,401’(TVD) 13-3/8” Short Joint Marker Jt @ 7,519 WLM Orig. KB Elev.: 31.1’ 7” 2 3 6 7 8 9 9 9-5/8” 1 KUP B Sands PBTD =8,203’ (MD) / PBTD = 7,342’(TVD) 5 4 KUP A3 & A2 Sands CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8" Conductor 54.5 / K-55 / N/A N/A Surface 115' 9-5/8" Surface 40 / L-80 / Btrc. 8.679 Surface 2,664’ 7" Production 26 / L-80 / NSCC 6.151 Surface 8,247’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface ±7508’ JEWELRY DETAIL No Depth Item 1 ±138 GLM, 2-7/8” x 1” with OV 2 ±7,293’ GLM, 2-7/8” x 1” with DV 3 ±7,438’ 2.313” XN-Nipple (2.205” no-go) 4 ±7,449’ GPDIS Discharge Head - GPDIS 5 ±7,450’ Pump - 137P17 SXD 6 ±7,469’ Gas Separator - 538GSTHVEV H6 7 ±7,473’ Tandem Seal Section - GSB3DBUT SB/SB PFSA : GSB3DBLT SB/SB PFSA CL5 8 ±7,487’ Motor - MSP1-325 150hp/ 2,205 V/ 41A 9 ±7,504’ WellLift Sensor w/ Centralizer / Bottom at ±7,508’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. B Sands 7,744 7,766’ 6,906’ 6,927’ 22 10/31/1994 Open Kup. A3 & A2 Sands 7,836’ 7,910’ 6,992’ 7,062’ 74 10/31/1999 Open OPEN HOLE / CEMENT DETAIL 13-3/8” 250 sx of Arcticset I (Approx) in 24” Hole 9-5/8" 551 sx PF “E” in 12-1/4” Hole 7” 330 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 630’ Max Hole Angle = 39 deg. f/ 3,100’ Max Hole Angle through perforations = 20 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” x 2-9/16” 5M WKM w/ TDF-CS-1 tbg Hanger, 2- 7/8” EU 8rd T x B threads & 2.5 CIW ‘H’ BPV profile GENERAL WELL INFO API: 50-029-22500-00-00 Coil Completion - 10/31/1994 ESP Completion by Nabors 4ES – 10/13/1998 ESP RWO by Nabors 4ES – 11/10/2000 ESP RWO by Nabors 4ES – 8/16/2004 ESP RWO by Nabors 4ES – 9/2/2006 ESP RWO by Nabors 4ES – 5/8/2010 Doyon 16 RWO – 5/29/2013 ESP RWO by Nordic 3 –3/23/2015 Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 5000#Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head RECEIVED EIVED STATE OF ALASKA aI'� 0 2015 AL ,CA OIL AND GAS CONSERVATION COM. JION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Well U Plug Perforations LJ Perforate U Other U ESP Change-out Performed: Alter Casing ❑ Pull Tubing❑� Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑ Exploratory ❑ 194-110 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-029-22500-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025906 MILNE PT UNIT KR J-10 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Point Field/Kuparuk River Oil 11.Present Well Condition Summary: Total Depth measured 8,265 feet Plugs measured 8,045 feet true vertical 7,401 feet Junk measured N/A feet Effective Depth measured 8,045 feet Packer measured N/A feet true vertical 7,191 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 13-3/8" 112' 112' 3,580psi 2,090psi Surface 2,664' 9-5/8" 2,664' 2,432' 5,750psi 3,090psi Intermediate Production 8,247' 7" 8,247' 7,384' 7,240psi 5,410psi Liner SCANNED 44 2 0 2D1 Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 7,508' 6,686' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A 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: 6 0 62 260 240 Subsequent to operation: 142 10 1,064 240 221 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development❑ Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ 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: 315-115 Contact Chris Kanyer Email ckanver(a.hilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signature‘7----:7-___ %off F44,-- -,Cr- CW K , Phone 907-777-8377 Date 4/30/2015 yie5 --1 --iy RBDMS,A MAY - 6 2015 Form 10-404 Revised 10/2012 749- .4r---- - . Submit Original Only Milne Point Unit Well: MPU J-10 1 E4 SCHEMATIC Last Completed: 5/29/2013 llilcurp Alaska,LLC PTD: 194-110 CASING DETAIL Orig.KB Elev.:31.1' Size Type Wt/Grade/Conn Drift ID Top Btm i,,' , .� F 13-3/8" Conductor 54.5/K-55/N/A N/A Surface 115' '" 9-5/8" Surface 40/L-80/Btrc. 8.679 Surface _ 2,664' 13-3/8" .t. i* �� 7" Production 26/L-80/NSCC 6.151 Surface 8,247' 1 ;, TUBING DETAIL 2-7/8" Tubing _ 6.5/L-80/EUE 8rd 2.441 Surface 7508' 3/8" Capstring Stainless Steel N/A Surface 7,508' " 4 JEWELRY DETAIL No Depth Item A 1 138 GLM IV2 7,293' GLM 3 7,438' 2-7/8"XN-Nipple 1; 9 4 7,449' GPDIS Discharge Head-GPDIS 5 7,450' Pump-137P17 SXD 4; . b- 6 7,469' Gas Separator-538GSTHVEV H6 7 7,473' Tandem Seal Section-GSB3DBUT SB/SB PFSA:GSB3DBLT SB/SB PFSA CLS 4 t, 8 7,487' Motor-MSP1-325 150hp/2,205 V/41A 9 7,504' WeIILift Sensor w/ Centralizer/Bot.7,508' iF J' ; �4 PERFORATION DETAIL k.iti1" Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status 9-5/8" ll It Kup.B Sands 7,744 7,766' 6,906' 6,927' 22 10/31/1994 Open Kup.A3&A2 7,836' 7,910' 6,992' 7,062' 74 10/31/1999 Open Sands WELL INCLINATION DETAIL KOP @ 630' Max Hole Angle=39 deg.f/3,100' Max Hole Angle through perforations=20 deg. OPEN HOLE/CEMENT DETAIL 13-3/8" 250 sx of Arcticset I(Approx)in 24"Hole y 9-5/8" 551 sx PF"E"in 12-1/4"Hole 7" 330 sx Class"G"in 8-1/2"Hole i• #; TREE&WELLHEAD Short Joint Tree 5M CIW 2-9/16" 11"x 2-9/16"5M WKM w/TDF-CS-1 tbg Hanger,2- / 7,519 ��,, 3 41.0.1. Wellhead 7/8"EU 8rd T x B threads&2.5 CIW'H'BPV profile G 4 GENERAL WELL INFO 97 t API:50-029-22500-00-00 5 Coil Completion -10/31/1994 ESP Completion by Nabors 4ES—10/13/1998 6 ESP RWO by Nabors 4ES—11/10/2000 7 ESP RWO by Nabors 4ES—8/16/2004 ESP RWO by Nabors 4ES—9/2/2006 ESP RWO by Nabors 4ES-5/8/2010 $ Doyon 16 RWO—5/29/2013 + 4 ESP RWO by Nordic 3—3/23/2015 9 ►it KLP B Sands iN XP- ? t KLP &A2 to ? Sands 6. TD=8,160'(MD)/TD=7,401'(TVD) PBTD=8,203'(MD)/PBTD=7,342'(TVD) Created By:TDF 4/30/2015 Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MPJ-10 50-029-22500-00-00 194-110 3/20/2015 3/24/2015 Daily Operations: 3/18/15-Wednesday No operations to report. 3/19/15-Thursday No operations to report. 3/20/15-Friday MIRU Pull BPV RU Hardline and Kill tank,Off load 500 bbls 8.5 ppg hot seawater.SITP 310 psi SICP 410 psi. BOP test witness was waived by AOGCC Jeff Jones 3/20/15 @ 0900. Blow down lines and pressure test 250psi low/2,500psi high. Blow down well to 0 psi repairing valve on pomp manifold found leaking during PT. 3/21/15-Saturday SITP 310 psi SICP 410 psi. Circ.8.5 ppg down tbg 3bpm,48 bbls caught circ in 3 bbl, reverse out 335 bbls SW to surface. Monitor well well flowing.Circ down tubing 43 bbls,monitor,flowing. Roll hole volume @ 2.5 300 psi bpm through gas buster. Monitor well SITP 30 psi. Build 130 bbls 8.7#NaCl pump and repeat until hole 8.7 ppg in/out. Monitor well slight vacuum, RD hoses.Set BPV, ND Tree. NU BOP Pull BPV install TWC. Fill stack purge lines,shell test.Test BOP per sundry requirements.Witness waived by AOGCC/Jeff Jones 0913 hrs 3/21.Test all BOPE 250psi low/3,000psi high.Test annular 250psi low/2,500psi high. Perform accumulator draw down all OK. Pull TWC well is static install landing joint, POOH with hanger and decomplete ESP penetrator. Rig up for production retrieval. 3/22/15-Sunday PJSM string ESP cable over sheave POOH with 2-7/8"tubin_g_GLMS and XN. BO LD ESP assy heavy packed sand scale somewhat in appearance from x nipple through the lower seal, pump/motors sand packed and locked up. Bottom end through centraizer is clean no scale evidence at all.Suspect pump sanded off housing packed off with sand/scale in casing collar.Clean off floor prepare for TIH w scraper.Samples tested w 7% HCL indicate a scale presence. PU MU 3.5" muleshoe and 7"casing scraper RIH to 7,714' reverse circ.2 tubing volumes @ 470psi. Dirty black,oily water no solids in returns. POOH w scraper hole is balanced,slow trip prevent swabbing hole,fill volumes indicate small influx. LD scraper. PU MU 7"Champ packer. RIH to 7,524'.Check hole full,set packer,test to 1,500psi and record for 30 minutes. Test is good. Bleed off,open bypass, release packer. POOH slow to prevent swabbing,5 stands, POOH w Packer. 3/23/15-Monday POOH LD champ packer tool, looks good no damage.Clean floor prepare for ESP completion deployment. PU MU ESP assembly and service same. RIH with same to 7,507.93'checking cable and capillary evey 2,000'. Final cap check 4,400psi.Completion hanger/pup,4 jts 2-7/8 6.5#L-80 tbg, 1pj,GLM 138' 1 pj,229 jts tbg, 1 pj,GLM 7,293', 1pj,4 jts tbg, XN 7,438', Discharge head 7,449',Pump 7,450',Gas Separator 7,469',Motor 7,487' Pumpate 7,504' and Centralizer TD 7,508'. Hardware 100 cannon clamps 1 flat bar 3 protectolizers. Install hanger and penetrator,terminate cable and cap string, build connector meg and check ESP penetrator connection. Land hanger. Install BPV.Slip-n-cut line,clean cellar and BOPs. ND BOP. NU Tree.Test 250psi low/5,000psi high. Freeze protect with 15 bbl down tubing and 15 bbl annulus. 3/24/15-Tuesday RDMO release Rig. 1., OF To • 0\�� I�j:.4\ THE STATE Alaska Oil and Gas F��_-,e!, -,,,,,,, �_ _'�___4 ALASKA Conservation Commission 'it333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Op ALASIICPFax: 907.276.7542 SCANNED MAR 0 b 1" 3 www.aogcc.alaska.gov Chris Kanyer Operations Engineer Hilcorp Alaska, LLC i ' 3800 Centerpoint Drive, Suite 1400 ` Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR J-10 Sundry Number: 315-115 Dear Mr. Kanyer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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, 104e..444e. Cathy P oerster Chair, ommissioner n-a� DATED this 3 day of March, 2015 Encl. . RECEIVED STATE OF ALASKA FEB 2 7 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION J07-S 3l 3/) APPLICATION FOR SUNDRY APPROVALS AOGC 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well[ C./ft' Change Approved Program ❑ Suspend❑ Plug Perforations❑ , Perforate❑ Pull Tubing 0' Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other: ESP Changeout ❑, • 2.Operator Name: 4.Current WeN Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 194-110 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22500-00-00, 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.432C Will planned perforations require a spacing exception? Yes ❑ No ❑., J MILNE PT UNIT KR J-10 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025906 • Milne Point Field/Kuparuk River Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8,265 ' 7,401 • 8,045 ' 7,191 , 8,045(fill) N/A Casing Length Size MD ND Burst Collapse Structural Conductor 112' 13-3/8" 112' 112' 3,580psi 2,090psi Surface 2,664' 9-5/8" 2,664' 2,432' 5,750psi 3,090psi Intermediate Production 8,247' 7" 8,247' 7,384' 7,240psi 5,410psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic J See Attached Schematic 2-7/8" 6.5#/L-80/8rd EUE 7,617 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑� Exploratory ❑ Stratigraphic 111 Development E. Service ❑ 14.Estimated Date for X15.Well Status after proposed work: Commencing Operations: 3/18/2015 Oil Q , Gas 0 WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG 0 Abandoned 0 Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Email ckanyer@hilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signaturea . Phone 777-8377 Date 2/27/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3(5 - /I5 Plug Integrity ❑ BOP Test © Mechanical Integrity Test ❑ Location Clearance l❑ Other: 300c7 ,o L�� f ( AA `c e 0 p`�� J Spacing Exception Required? Yes ❑ No Er Subsequent Form Required: / 6- Li 04-1 APPROVED BY Approved by: /94CA•t(7-x--- COMMISSIONER THE COMMISSION Date:3-3-/S" m- J �1( /� / / Submit Forth an d Form 10-403 ed10/2012) A^ a t tliA 12 months from the date f approve. Attach qts in Duplicate /74 3-3-/ RBDMS<AtMAR C Z015 Well Prognosis Well: MPJ-10 !Mean)Alaska,LL Date:2/27/2015 Well Name: MPJ-10 API Number: 50-029-22500-00-00 Current Status: SI Producer Pad: J Pad Estimated Start Date: March 19, 2015 Rig: Nordic 3 Reg.Approval Req'd? March 18, 2015 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 194-110 First Call Engineer: Chris Kanyer (907) 777-8377 (0) (907) 250-0374 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: 1550619 Current Bottom Hole Pressure: —2,819 psi @ 7,000' TVD /{ ast BHP measured 2/26/2015) Maximum Expected BHP: —2,819 psi @ 7,000' TVD (No new perfs being added) Max. Allowable Surface Pressure: 0 psi (Based on actual reservoir conditions and water cut of 91% (0.430psi/ft)with an added safety factor of 1000' TVD of oil cap) Brief Well Summary: The Milne Point J-10 well was drilled as a Kuparuk development well that TD'd at a depth of 8,625' and ran a cemented 7" casing in October 1994. The well was initially completed with an ESP. This and subsequent ESPs failed and were replaced in 1998, 2000, 2004, 2006, 2010, and 2013. The recent pump failed in February 2015. The most recent casing test was performed on 5/4/2010. A retrievable bridge plug set at 7,543' and a test was performed prior to fixing a broken alignment pin on the tubing spool. This test was charted for 10min at 1,000psi with 10.3ppg brine in the well. This test would be equivalent to a test with 8.5ppg seawater to 1,500psi, and therefore a new casing test will not be performed during this workover. U k - 3.2-I Due to observed scale issues, a downhole chemical injection line will be run as part of the new completion. No subsidence issues are expected in this well. Notes Regarding Wellbore Condition Current well status is shut in oil producer. No subsidence issue suspected. RWO Obiective: Pull ESP& run 2-7/8" ESP completion with downhole chemical injection. Brief Procedure: 1. MIRU Nordic#3 Rig. 2. Circulate well with 8.5ppg seawater and monitor well. 3. ND tree, NU 13-3/8" BOPE with 11" spool adapter and test to 250psi low/3,000psi high, annular to 250psi low/2,500psi high. a. Notify AOGCC 24hrs in advance to witness test. 4. Unseat hanger and pull 2-7/8" ESP completion from 7,615'to surface and lay down same. Contingency: (Pending results of condition of pulled completion—sand/scale in pump) a. Option#1: RU Slickline. RIH and tag fill with gauge ring. POOH with same and RD slickline. b. Option#2: RIH with 7" cleanout BHA&attempt a cleanout wellbore to+/-8,050'. POOH with same. Well Prognosis Well: MPJ-10 Ililcorp Alaska.LL Date: 2/27/2015 1. MU and RIH with ESP with gas separator and 3/8" chemical injection line on 2-7/8" 8RD EUE L-80 tubing [to be replaced if necessary]. Set ESP at+/-7,615'. Land tubing hanger. 2. ND BOP, NU and tree. 3. RDMO workover rig and equipment. 4. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic Milne Point Unit Well: MPU 1-10 • SCHEMATIC Last Completed: 5/29/2013 Hilcorp Alaska.I.1 C PTD: 194-110 CASING DETAIL Orig.KB Elev.:31.1' Size Type Wt/Grade/Conn Drift ID Top Btm I _ I 13-3/8" Conductor 9-5/8" Surface 54.5/K-55/N/A N/A Surface 115' 40/L-80/Btrc. 8.679 Surface 2,664' 13-3/8' 7" Production 26/L-80/NSCC 6.151 Surface 8,247' I 1 TUBING DETAIL 2-7/8" Tubing 6.5/1-80/EUE 8rd 2.441 Surf 7,617' JEWELRY DETAIL No Depth Item 1 138' 2-7/8"x 1"KBMM GLM w/DSOV 2 7,365' 2-7/8"x 1"KBMM GLM w/Dummy 3 7,516' 2-7/8"XN-Nipple .'.250 No-go ID) 4 7,558' GPDIS Discharge Head 5 7,559' 137P17 SDX Pump 6 7,578' Gas Separator 7 7,582' Tandem Seal Section 8 7,596' Motor,210HP,2380 Volt,53 amp,ModeIMS1-250 9 7,613' WeIlLift Sensor w/ Centralizer/Bot.7,617' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.B Sands 7,744 7,766' 6,906' 6,927' 22 10/31/1994 Open 9-5/8" 4 lk, Kup.A3&A2 7,836' 7,910' 6,992' 7,062' 74 10/31/1999 Open Sands WELL INCLINATION DETAIL KOP @ 630' Max Hole Angle=39 deg.f/3,100' Max Hole Angle through perforations=20 deg. OPEN HOLE/CEMENT DETAIL 13-3/8" 250 sx of Arcticset I(Approx)in 24"Hole 9-5/8" 551 sx PF"E"in 12-1/4"Hole 2 TREE&WELLHEAD Tree 5M CIW 2-9/16" • 11"x 2-9/16"5M WKM w/TDF-CS-1 tbg Hanger,2- Short Joint Wellhead 7/8"EU 8rd T x B threads&2.5 CIW'H'BPV profile Marker Jt @ ' 7,519W.M_____i GENERAL WELL INFO C -1 4 API:50-029-22500-00-00 Coil Completion -10/31/1994 5 ESP Completion by Nabors 4ES—10/13/1998 ' ESP RWO by Nabors 4ES—11/10/2000 ' III: * 6 ESP RWO by Nabors 4ES—8/16/2004 �r 7 ESP RWO by Nabors 4ES—9/2/2006 FC ESP RWO by Nabors 4ES—5/8/2010 — ., i Doyon 16 RWO—5/29/2013 8 -KUP B Sands . J KUPA3&A2 Sands 7"1 I' TD=8,160'(MD)/TD=7,401'(TVD) PBTD=8,203'(MD)/PBTD=7,342'(TVD) Created By:TDF 2/27/2015 Milne Point Unit Well: MPU J-10 PROPOSED Last Completed: 5/29/2013 Hilcorp Alaska,LiA. PTD: 194-110 CASING DETAIL Orig.KB Elev.:31.1' Size Type Wt/Grade/Conn Drift ID Top Btm 13-3/8" Conductor 54.5/K-55/N/A N/A Surface 115' 9-5/8" Surface 40/L 80/Btrc. 8.679 Surface 2,664' 13-3/8" 7" Production 26/L-80/NSCC 6.151 Surface 8,247' 11 TUBING DETAIL 2-7/8" Tubing 6.5/L-80 EUE 8rd 2.441 Surf ±7,617' 3/8" Capstring Stainless Steel N/A Surf ±7,617' JEWELRY DETAIL No Depth Item 1 138' GLM 2 _7,365' GLM 3 ±7,516' 2-7/8"XN-Nipple(2.250 No-go ID) 4 ±7,558' GPDIS Discharge Head 5 ±7,559' Pump 6 ±7,578' Gas Separator 7 ±7,582' Tandem Seal Section 8 ±7,596' Motor • 9 ±7,613' WeilLift Sensor w/ Centra zer/Bot.±7,617' PERFORATION DETAIL ?" Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 9-5/8" • Kup.B Sands 7,744 7,766' 6,906' 6,927' 22 10/31/1994 Open Kup.A3&A2 7,836' 7,910' 6,992' 7,062' 74 10/31/1999 Open Sands WELL INCLINATION DETAIL KOP @ 630' Max Hole Angle=39 deg.f/3,100' Max Hole Angle through perforations=20 deg. OPEN HOLE/CEMENT DETAIL 13-3/8" 250 sx of Arcticset I(Approx)in 24"Hole 2 9-5/8" 551 sx PF"E"in 12-1/4"Hole 7" 330 sx Class"G"in 8-1/2"Hole TREE&WELLHEAD Short Joint Tree 5M CIW 2-9/16" Marker Jt @ r 3 '+ Wellhead 11"x 2-9/16"5M WKM w/TDF-CS-1 tbg Hanger,2 7,519NA1N �i 7/8"EU 8rd T x B threads&2.5 CIW'H'BPV profile 4 GENERAL WELL INFO API:50-029-22500-00-00 5 Coil Completion -10/31/1994 ESP Completion by Nabors 4ES—10/13/1998 6 ESP RWO by Nabors 4ES—11/10/2000 - 7 ESP RWO by Nabors 4ES—8/16/2004 ESP RWO by Nabors 4ES—9/2/2006 ESP RWO by Nabors 4ES—5/8/2010 $ Doyon 16 RWO—5/29/2013 l}KLP B Sands • ss l KUPA3&A2 Saids 7"a' I►' TD=8,160'(MD)/TD=7,401'(1VD) PBTD=8,203'(MD)/PBTD=7,342'(TVD) Created By:TDF 2/27/2015 MPU BOP Stack r � O i ii Hydril 13 5/8 5M 13 5/8 5M jeD 2 7/8"-5-1/2" variables INN NIP MIP MP) Spacer spool 135/85M C 13 5/8 5M _ , Blinds " I4s ! c Je i' TIP Spacer spool 13 5/8 5M ciaLatiMLIMILIMIJ 13 5/8" 5MX11" 5M DSA 11111 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. I~ L~ -i)"0 File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy~Vincent TO RE-SCAN Nathan Lowell Notes' Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si STATE OF ALASKA 4 ` A N. ,. r AISKA OIL AND GAS CONSERVATION COISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver ® Other El Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension Mill Packer, Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. • ❑ Exploratory ❑ Stratigraphic 194 - 110 • 3. Address: * ® Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 025906 MPJ - ` 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 8265' feet • Plugs:(measured) 8045' (Fill) feet true vertical 7401' feet Junk: (measured) None feet Effective depth: measured 8160' feet Packer: (measured) None feet true vertical 7191' feet Packer: (true vertical) None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13 -3/8" 32' - 112' 32' - 112' 3580 2090 Surface 2633' 9 -5/8" 31' - 2664' 31' - 2432' 5750 3090 Intermediate Production 8218' 7" 29' - 8247' 29' - 7384' 7240 5410 Liner Perforation Depth: Measured Depth: 7744' - 7910' feet True Vertical Depth: 6906' - 7062' feet Tubing (size, grade, measured and true vertical depth): 2 - 7/8 ", 6.5# L - 7617' 6787' Packers and SSSV (type, measured and true vertical depth): None None None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: SCANNED JUN 2 8 2 013 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 44 4 178 300 208 Subsequent to operation: 39 3 207 160 212 14. Attachments: ❑Copies of Logs and Surveys run 15. Well Class after work: ❑ Exploratory ❑ Stratigraphic IS Development ❑ Service ® Daily Report of Well Operations 16. Well Status after work: ' ® Oil ❑ Gas ❑ WDSPL ® 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: David Reem, 564 -5743 N/A Email: ReemDC @bp.com Printed e: Joe Lastufka Drilling Technologist Signatur iT$\ k..-� P hone: 564 - 4091 Date: (0/1$03 Form 10-404 Revised 10/2 JUN 2 6 20.\\§.L1 bmit Original � i /Z �- l RBDMS �` 1 4 . 0 • North America - ALASKA - BP re 1 d 12 . Operation Summary Report . ' Common Well Name: MPJ -10 i AFE No Event Type: WORKOVER (WO) Start Date: 5/22/2013 End Date: X4- 00XTH- E:DRILL (2,200,000.00 ) Project: Milne Point Site: M Pt J Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/29/1994 12:00:00AM Rig Release: 5/28/2013 Rig Contractor: DOYON DRILLING INC. 1 UWI: Active datum: Kelly Bushing / Rotary Table ©54.20usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 1 _ (usft) 5/22/2013 07:00 - 09:30 2.50 MOB P PRE PJSM, BRIDLE UP BLOCKS - R/D RIG FLOOR, PREP TO LAY DERRICK OVER - FINISH CLEANING PITS AND BLOW DOWN SURFACE EQUIPMENT 09:30 - 10:30 1.00 MOB 1 P PRE PJSM, LAY DERRICK OVER AND SECURE TO HEADACHE RACK - FUNCTION TEST MOVING SYSTEM, CHECK FOR LEAKS 10:30 - 12:00 1.50 MOB P PRE 1 W PJSM, MOVE OFF OF WELL MPG -16 1 - TEST EMERGENCY SHUT DOWN (ESD) I BEFORE MOVING RIG 1 I - WSL AND TOOLPUSHER PRESENT, PAD 1 OPERATOR NOTIFIED 12:00 - 14:00 2.00 MOB P PRE PJSM, MOVE RIG FROM MPG -PAD TO 1 MPJ -PAD - STAGE RIG ON EAST SIDE OF PAD FOR EASY ACCESS TO CELLAR 14:00 - 15:30 1.50 MOB P - PRE PJSM, RAISE DERRICK AND PIN INTO PLACE - R/U TUGGERS AND MANRIDER _ 1 - RAISE CATTLE CHUTE AND SECURE_ 1 15:30 - 21:00 5.50 MOB 1 P PRE PJSM, BRIDLE DOWN BLOCKS - R/U RIG FLOOR, BLEED OFF MANIFOLD AND STANDPIPE - INSTALL TOP DRIVE RAILS 1 '- RE- CONFIGURE STACK, FROM 3 I PREVENTER TO 4 PREVENTER BOP 21:00 - 21:30 0.50 MOB P PRE COMPLETE LAYING MATS AROUND MPJ -10 - STAGE WELL EQUIPMENT AROUND WELL, RAMS AND HOSES 1 1- PLACE WELL KILL MANIFOLD NEAR WELL IN 4 _ 1 CELLAR AREA 21:30 - 00:00 2.50 MOB P PRE ' PJSM, TO MOVE RIG OVER WELL MAKE FINAL CHECKS ON MOVING SYSTEM - JACK RIG UP AND MOVE FROM STAGING AREA TO MPJ-10 I - WSL AND TOOL PUSHER PRESENT, PAD OPERATOR NOTIFIED - SPOT RIG OVER WELL MPJ -10 AND SHIM I SUB BASE ' - LOWER CELLAR DOORS AND SHIM RIG SECURE STAIRS AND LANDINGS. ' READY PITS TO TAKE ON BRINE 5/23/2013 00:00 - 02:30 2.50 WHSUR P DECOMP PJSM, R/U WELL KILL MANIFOLD - RU HARD LINE TO FLOW BACK TANK - BLOW THRU LINE WITH AIR. 1- R/U KILL MANIFOLD IN CELLAR. R/U CIRCULATING LINES TO WELL HEAD AND TREE - TEST ALARM ON FLOW BACK TANK. L RIG ACCEPTED AT 00:00 HOURS Printed 6/10/2013 9:23:02AM • • North America - ALASKA - BP Page 2 of 12 Operation Summary Report Common Well Name: MPJ -10 AFE No Event Type: WORKOVER (WO) Start Date: 5/22/2013 End Date: X4- 00XTH- E:DRILL (2,200,000.00 ) Project: Milne Point Site: M Pt J Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/29/1994 12:00:00AM Rig Release: 5/28/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @54.20usft (above Mean Sea Level) Date From - To Hrs I Task I Code NPT NPT Depth Phase Description of Operations -- ( ) (usft) hr I '02:30 - 03:00 0.50 ! WHSUR P DECOMP HELD H2S EVACUATION DRILL. WSL, TOOLPUSHER, SCS, RIG CREW, GOOD RESPONSE TIME, PAD OPERATOR WAS NOTIFIED I - SIREN COULD BE HEARD BY ALL I 1 PERSONNEL I I I -AAR REVEALED EVERYONE KNEW THEIR I _ ROLES AND RESPONSIBILITIES 03:00 - 04:30 1.50 WHSUR P , DECOMP CONTINUE TO R/U FOR WELL KILL - LOAD 10.5 PPG 120 DEGREE BRINE INTO PITS - PRESSURE TEST WELL KILL MANIFOLD AND RELATED LINES PER DOYON SOP - 250 / 3500 PSI, 5 MIN, CHARTED, PASSED - R/U AND TEST SSV REMOTE ACTUATOR PANEL — IA = 720 PSI _ _ I - OA = 0 PSI t 04:30 - 06:00 i 1.50 WHSUR P DECOMP PJSM, WITH MPU DSM TO PULL BPV. - P/U DSM LUBRICATOR. RU TEST HOSES. - TEST LUBRICATOR TO 250 / 3500 PSI FOR 5 I CHARTED MIN. EACH. - PULL BPV WITH TESTED LUBRICATOR. I I - SITP = 710 PSI. SICP = 720 PSI I 1 I - L/D LUBRICATOR 06:00 06:30 WHSUR HSUR P DECOMP PJSM, WELL KILL OPERATIONS - COVER DDI WELL KILL SOP DISCUSSED ROLES OF EACH WORKERS I POSITION. I - DISCUSSED THE FLAT TIRE ON THE DIRTY !VAC TRUCK. Printed 6/10/2013 9:23:02AM • • North America - ALASKA - BP Page 8 of 42 Operation Summary Report Common Well Name: MPJ -10 AFE No Event Type: WORKOVER (WO) I Start Date: 5/22/2013 End Date: X4- 00XTH- E:DRILL (2,200,000.00 ) Project: Milne Point Site: M Pt J Pad Rig Name/No.: DOYON 16 Spud Date/Time: 8/29/1994 12:00:00AM Rig Release: 5/28/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @54.20usft (above Mean Sea Level) Date From - To Hrs Task Code I NPT NPT Depth Phase Description of Operations (hr) (usft) ---- - - - - -- -- - - -- - - - -- 06:30 - 09:30 3.00 WHSUR P DECOMP PJSM. WELL KILL WITH 10.5 PPG HEATED BRINE WSL / TOOL PUSHER VERIFY VALVE ALIGNMENT. - SITP = 500 PSI, SICP = 700, SIOA = 0 PSI - BLEED GAS FROM IA F/ 700 T/ 500 PSI IN 10 MIN. SITP = 500 PSI - FLUID RETURNS TO SURFACE. - CIRCULATE 44 BBLS KWF AT 3 BPM THRU CHOKE SKID TO FLOW BACK TANK - ICP = TBG / 950 PSI. IA/ 550 PSI. FCP = TBG / 150 PSI. IA / 200 PSI. - BULL HEAD ON THE FLY, 20 BBLS KWF DOWN THE TBG AT 3 BPM / 700 - 950 PSI. MONITOR WELL SHUT IN FOR 5 MINUTES. - SITP AFTER 5 MINUTE = '0' PSI. - SICP = HOLDING AT 800 PSI. PUMPED 310 BBLS HEATED KWF AT 3- 5 BPM DOWN THE TBG THRU CHOKE SKID TO FLOW BACK TANK. - GOOD RETURNS TO SURFACE DURING CIRCULATION. - ICP = 5 BPM / 1100 PSI. - BRINE RETURNS AFTER -250 BBLS PUMPED. - TOTAL OF 310 BBLS KWF PUMPED TILL i CLEAN RETURNS AT SURFACE, STOP PUMP. MONITOR FULL 30 MINUTES - TBG AND IA ON A VACUUM AFTER 10 MINUTES. WELL IS DEAD. - -10 BBLS KWF LOST TO FORMATION PLUS 20 BBLS BULL HEADED. -LOSS RATE AT 18 BPH. 09:30 11:00 1.50 WHSUR P DECOMP PJSM, R/D KILL MANIFOLD. - BLOW DOWN ALL SURFACE LINES - BREAK DOWN KILL LINES. - R/U SECONDARY KILL LINE. - STATIC LOSS RATE -18 BPH. I I - FEED THE WELL WITH 10.5 PPG BRINE. Printed 6/10/2013 9:23:02AM • • North America - ALASKA - BP p 4 x01 Operation Summary Report , Common Well Name: MPJ -10 I AFE No Event Type: WORKOVER (WO) Start Date: 5/22/2013 I End Date: !X4- 00XTH- E:DRILL (2,200,000.00 ) Project: Milne Point Site: M Pt J Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/29/1994 12:00:00AM I Rig Release: 5/28/2013 Rig Contractor: DOYON DRILLING INC. I 'I UVN: Active datum: Kelly Bushing / Rotary Table @54.20usft (above Mean Sea Level) Date 1 From - To Hrs Task Code � NPT I '1 NPT Depth Phase Description of Operations (hr) 1 - I (usft) 11:00 13:30 2.50 WHSUR P DECOMP FPJSM WITH WELL SUPPORT AND RIG CREW TO SET TWC - M/U LUBRICATOR & TEST 250 PSI LOW AND 1 3500 PSI FOR 5 MINS EACH , CHARTED - SET TWC - LAY DOWN LUBRICATOR PRESSURE TEST TWC - PERFORM ROLLING TEST BELOW TWC I , - PUMP DOWN IA @ 2 BPM AND 500 PSI FOR 10 MINS, CHARTED (21 BBLS KWF PUMPED) I I -1 BBL BACK. I - TEST TWC FROM ABOVE, 250 PSI LOW & I I ' 3500 PSI HIGH FOR 5 MINS EACH , CHARTED I 1 ! BP / WTLAND BP / RWO SUPERINTENDENT VISITED RIG AND CREWS - CLOSE OUT WELL WORK TRANSFER PERMIT ON MPG -16 13:30 - 14:30 1.00 WHSUR P I DECOMP PJSM, N/D TREE AND ADAPTER FLANGE - CIO TOP TREE CAP FLANGE TO 2 9/16" ID OTIS TYPE CONNECTION - FMC REP BLEED HANGER VOID - R/U SECONDARY KILL LINE TO IA - MAINTAIN CONTINUOUS HOLE FEED TO IA DURING N/D TREE AND N/U BOP LOSS RATE = 12 BPH OF 10.5 PPG BRINE I - 16:30 HRS 5/23/2013, JEFF TURKINGTON i THE AOGCC STATE INSPECTOR, WAIVED STATES WRIGHT OF WITNESS TO THE BOPE TEST. 14:30 - 18:00 I 3.50 BOPSUR P I DECOMP PJSM, N/U BOPE FOR BOP TEST 1 - R/U RISER, MOUSE HOLE, TURNBUCKLES AND ACCUMCULATOR LINES - R/U FLOOR VALVES, TEST JOINT AND TEST I EQUIPMENT 18:00 20:00 2.00 BOPSUR P DECOMP PJSM, INSTALL RAMS IN BOP - INSTALL BLIND SHEAR RAMS, AND 2 7/8" X 5" VARRIABLE RAMS - SERVICE MUD CROSS VALVES AND CHOKE ' MANIFOLD Printed 6/10/2013 9:23:02AM • • North America - .ALASKA - BP .Page 5 <A 12 Operation Summary Report Common Well Name: MPJ -10 AFE No Event Type: WORKOVER (WO) Start Date: 5/22/2013 End Date: X4- 00XTH- E:DRILL (2,200,000.00 ) Project: Milne Point Site: M Pt J Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/29/1994 12:00:00AM Rig Release: 5/28/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @54.20usft (above Mean Sea Level) Date From - To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 00:00 4.00 BOPSUR P DECOMP PJSM, TEST FOUR PREVENTER BOPE AND RELATED EQUIPMENT - BOP CONFIGURATION = ANNULAR, 2 7/8" X 5" VBR UPPER PIPE RAMS BLIND SHEAR RAMS, MUD CROSS, 2 7/8" X 5" VBR LOWER PIPE RAMS 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 MIN, CHARTED - TEST UPPER ANDLOWER 2 7/8" X 5" VARIABLE RAMS WITH 2 7/8" AND 4" TEST JOINTS, 250 PSI, 3500 PSI, 5 MIN, CHARTED - TEST BLIND RAMS, FLOOR VALVES, IBOP'S 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 - OA =0 PSI - LOSS RATE = 13 BPH - 24 HOUR FLUID LOSS = 143 BBLS, 10.5 PPG BRINE 5/24/2013 00:00 - 01:30 1.50 BOPSUR P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT • CHECKS - CONTINUE TEST FOUR PREVENTER BOPE AND RELATED EQUIPMENT - BOP CONFIGURATION = ANNULAR, 2 7/8" X 5" VBR UPPER PIPE RAMS BLIND SHEAR RAMS, MUD CROSS, 2 7/8" X 5" VBR LOWER PIPE RAMS I - 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 MIN, CHARTED - TEST UPPER ANDLOWER 2 7/8" X 5" VARIABLE RAMS WITH 2 7/8" AND 4" TEST JOINTS, 250 PSI, 3500 PSI, 5 MIN, CHARTED - TEST BLIND RAMS, FLOOR VALVES, IBOP'S AND CHOKE MANIFOLD TO 250 PSI, 3500 PSI, 1 5 MIN, CHARTED - TEST WITH FRESH WATER - PERFORM ACCUMULATOR DRAW DOWN TEST 1 FAIL PASS ON THE BLIND /SHEAR RAMS, CYCLED ONCE AND TESTED GOOD - JEFF TURKINGTON OF AOGCC WAIVED STATES RIGHT OF WITNESS TO THE BOP TEST 01:30 - 02:00 ! 0.50 BOPSUR P ! DECOMP R/D TEST BOP EQUIPMENT - UD TEST JOINT AND FLOOR VALVES DRAIN / VAC WATER OUT STACK I- MOBILIZE OFF -SET LUBRICATOR FOR WELL - - -- - -', , SUPPORT TO RIG FLOOR Printed 6/10/2013 9:23:02AM 6 • • North Amer l- ALASKA- BP 'Page 6of12 Operation Summary Report Common Well Name: MPJ -10 AFE No Event Type: WORKOVER (WO) I Start Date: 5/22/2013 End Date: X4- 00XTH- E:DRILL (2,200,000.00 ) Project: Milne Point Site: M Pt J Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/29/1994 12:00:00AM Rig Release: 5/28/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table I54.20usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 03:00 1.00 WHSUR P r DECOMP M/U DSW LUBRICATOR TO HANGER - PRESSURE TEST LUB TO 250 / 3500 PSI, 5 MIN, CHARTED, PASSED - VERIFY NO PRESSURE UNDER TWC '- PULL TWC, R/D DSM LUBRICATOR 03:00 - 04:30 1.50 PULL P DECOMP 1 PJSM, PULL HANGER TO RIG FLOOR AND CIRCULATE - M/U 2 7/8" EUE 8RD LANDING JOINT WITH TIW VALVE TO HANGER 1 - WSL VERIFY NO PRESSURE UNDER HANGER, WELL IS ON SLIGHT VAC - CAMERON REP BACK OUT LOCK DOWN SCREWS ' - PULL HANGER TO RIG FLOOR - HANGER BROKE OVER AT 105K, PULL PUWT = 97K, SOWT = 80K - REMOVE ESP CABLE AT PENETRATOR - CONTINUE POOH TO CLAMP AT BOTTOM OF FIRST FULL JT AND CUT ESP CABLE - RIH TO PLACE SLICK PIPE ACROSS STACK UD LANDING JOINT, REMOVE TIW FROM LANDING JT AND M/U TO HANGER M/U CEMENT HOSE TO TIW, CLOSE ;ANNULAR AND LINE UP O N GAS BUSTER 04:30 - 05:00 0.50 PULL P DECOMP 1 CIRCULATE 44 BBLS OF 10.5 PPG BRINE THRU GAS BUSTER - 3 BPM = 630 PSI, WITH FULL RETURNS - MONITOR WELL, WSL VERIFY NO PRESSURE UNDER ANNULAR 1 - OPEN ANNULAR AND MONITOR WELL, WELL ' IS ON LOSSES 1 1 -LOSS RATE = 18 BPH 05:00 - 06:00 1.00 PULL P DECOMP R/U ESP SHEAVE AND ESP CABLE TRUNK - R/U CENTRILIFT EQUIPMENT - POH 3 STANDS. F/ -7660' T/ -7375' MD. - CREW PULLED ESP CABLE OVER SHEAVE 1 IN DERRICK BY HAND. 06:00 - 11:30 5.50 PULL P DECOMP PULL 2 -3/8" ESP COMPLETION. - POH F/7375' T/ 68 FT. - STAND BACK 2 -7/8" EUE, 6.5# TBG IN DERRICK. - MAINTAIN CONTINUOUS HOLE FILL 1 - LOSS RATE W/ 10.5 PPG BRINE IS -7 BPH. 11:30 - 14:15 2.75 PULL P DECOMP PJSM, UD ESP ASSEMBLY. MONITOR WELL 10 MIN. SLIGHT LOSSES. CENTRILIFT REP DRAIN OIL FROM ASSEMBLY. - BREAK OUT AND UD PUMP AND MOTOR. 1- MOTOR SEALS BLOWN OUT. I- SOME SAND IN TOP SECTION, TWISTED AND BROKEN SHAFT IN GAS SEPARATOR, BEARING SHOT. - TBG IN GOOD SHAPE. - SLICK -LINE UNIT ARRIVE ON LOCATION. R/D ESP SHEAVE AND CABLE TRUNK F/ DERRICK. - 132) LASALLE CLAMPS RECOVERED - 3) FLAT GUARDS 5 PROTECTOLIZERS. Printed 6/10/2013 9:23:02AM • • North America - ALASKA - BP Page 7 of 12 , Operation Summary Report Common Well Name: MPJ -10 AFE No Event Type: WORKOVER (WO) I Start Date: 5/22/2013 End Date: X4- OOXTH- E:DRILL (2,200,000.00 ) Project: Milne Point l Site: M Pt J Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/29/1994 12:00:00AM Rig Release: 5/28/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @54.20usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase l Description of Operations (hr) (usft) 14:15 - 14:30 0.25 WHSUR P DECOMP M/U WEAR RING RUNNING TOOL. INSTALL 6.375" ID WEAR RING. L/D RUNNING TOOL. 14:30 - 15:00 0.50 PULL P DECOMP I CLEAN AND CLEAR RIG FLOOR - R/U AND MOVE FLOW BACK TANK. - SPOT SLICK -LINE UNIT. 15:00 - 16:30 1.50 EVAL P DECOMP PJSM, R/U SWS SLICK LINE UNIT. - INSTALL DUTCH RISER SYSTEM. - BRING WIRE LINE EQUIPMENT TO RIG FLOOR. HANG WIRE LINE SHEAVE IN DERRICK - HOLE IS STAYING FULL, LOSS RATE IS 8 BPH, NO "FULL PRESSURE CONTROL" REQUIRED - M/U WIRELINE RUNNING TOOLS AND CALIPER 16:30 - 18:30 2.00 EVAL P DECOMP RIH WITH PDS CALIPER MEMORY LOGGING TOOL RIH TO 1050' AND LOG UP TO SURFACE AT 50 FPM - VERIFY WITH WSL GOOD LOGGING DATA 18:30 - 19:00 0.50 EVAL T P DECOMP R/D SWS WIRELINE EQUIPMENT - R/D DUTCH RISER AND REPLACE WITH STANDARD RISER - CIO 0-RING RUBBERS ON DUTCH RISER LDS, SPCC PREVENTATIVE 19:00 - 21:00 2.00 FISH P DECOMP I PJSM, FOR M/U OF BAKER PACKER MILLING BHAAND RIH 1X1 - ENSURE HANDS ARE USING A ROTARY PEG AND PROPER LIFTING TECHNIQUES WHILE HANDLING BHA M/U FISHING BHA #1 = PACKER MILL, 3 -BOOT BASKETS, BUMPER SUB, OIL JAR - M/U 4 3/4" COLLARS / HWDP 21:00 - 00:00 3.00 FISH P DECOMP RIH WITH 4" 15.7# HT38 DRILL PIPE 1X1 FROM PIPE SHED - RIH FROM BHA= 320' TO 2691' MD - OA =0 PSI - LOSS RATE = 8 BPH - 24 HOUR FLUID LOSS = 234 BBLS, 10.5 PPG BRINE 5/25/2013 00:00 - 04:30 4.50 FISH P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS CONTINUE P/U 4" 15.7# HT38 DRILL PIPE 1X1 I FROM PIPE SHED - RIH FROM 2691' TO 7619' MD PUWT = 175K, SOWT = 120K, ROWT = 142K, 40 RPM = 6K FREE TQ SPR'S, 30 SPM = 100 PSI, 40 SPM = 260 PSI 04:30 - 09:00 4.50 FISH P DECOMP BEGIN MILLING 7" PACKER AT 7630' MD - TAG TOP OF PACKER AT 7630' MD - 75 RPM = 7K TQ, 5 BPM = 630 PSI. - PACKER CUT FREE AND DROPPED 1.5 FT. Printed 6/10/2013 9:23:02AM • • North America - ALASKA - BP Page l3 of 12 , Operation Summary Report Common Well Name: MPJ -10 AFE No Event Type: WORKOVER (WO) Start Date: 5/22/2013 I End Date: X4- 00XTH- E:DRILL (2,200,000.00 ) Project: Milne Point Site: M Pt J Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/29/1994 12:00:00AM Rig Release: 5/28/2013 Rig Contractor: DOYON DRILLING INC_ UWI: Active datum: Kelly Bushing / Rotary Table @54.20usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) ' (usft) 09:00 - 10:30 1.50 FISH P DECOMP PJSM, CBU THROUGH GAS BUSTER. - P/U TO FIRST TOOL JT AND CLOSE ANNULAR. - 20 BBL HIGH VIS SWEEP WAS 200 STROKES FROM BEING CIRCULATED TO SURFACE. - CBU THROUGH GAS BUSTER. - TRACE OF OIL AT BU. - GOOD SHOW OF METAL SHAVINGS AND 1 LCM TYPE MATERIAL AT SHAKERS. PUMPS ! 1 OFF. - MONITOR WELL. BLED BACK 5 BBLS. 69 I BBLS PUMPED AWAY INCLUDING 20 BBL SWEEP. ' - OPEN ANNULAR. WSL / DRILLER / TOOLPUSHER CONFIRMED WELL ON VACUUM. 10:30 11:30 1.00 FISH P DECOMP 1 PJSM, PU 4 "DP FROM PIPE SHED. CONTINUE TO MILL / PUSH PACKER TO - 8022' MD. - PU 4" DP 1X1 FROM PIPE SHED. - MILL ON PACKER, 2 MINUTES @ 70 - 100 RPM. PUMPING AT 5 BPM @ 650 PSI. - FLOW CHECK WELL F /10 MIN. SLIGHT LOSS RATE. 11:30 - 12:00 0.50 FISH P DECOMP MONITOR WELL - FLOW CHECK WELL F /10 MIN. SLIGHT LOSS RATE. - FLUSH AND BLOW DOWN CHOKE MANIFOLD DRAIN GAS BUSTER. I- SET 15 K DOWN ON PACKER, VERIFY DEPTH - PUWT = 180K, SOWT = 125K OFF BOTTOM (INC. 40K TOP DRIVE WT) - MAINTAIN CONTINUOUS HOLE FILL AT -8 _ BPH LOSS RATE W/ 10.5 PPG BRINE. 12:00 - 12:30 0.50 FISH P DECOMP 1RIG SERVIVE - SERVICE DRAWORKS. - SERVICE TOP DRIVE. 12:30 - 15:30 3.00 FISH P DECOMP POH WITH BAKER PACKER MILL ASSEMBLY. - POH F/ 8022' MD. - MAINTAIN CONTINUOUS HOLE FILLAT -8 BPH LOSS RATE W/ 10.5 PPG BRINE. 15:30 - 16:00 0.50 FISH N RREP DECOMP TROUBLESHOOT AND REPAIR DRAW WORKS COOLING SYSTEM - SEE REMARKS IR #4430896 16:00 - 18:00 -- -- �- — -- - -- - - - 2.00 FISH P DECOMP UD FISHING BHA #1 = PACKER MILL STAND BACK COLLARS H L/D PACKER MILL, AND BOOT BASKETS CLEAN OUT BOOT BASKETS = 5 GAL BUCKET OF METAL SHAVINGS AND PIECES 18:00 - 19:00 1.00 FISH P DECOMP DISCUSS BHA OPTIONS WITH TOWN ENGINEER - WILL RE- CONFIGURE SPEAR ASSY AND RUN OPTIONAL 3.557" NOMINAL CATCH GRAPPLE CLEAN / CLEAR RIG FLOOR Printed 6/10/2013 9:23:02AM • • North America - ALASKA - BP ' Page 90112 Operation Summary Report Common Well Name: MPJ -10 AFE No Event Type: WORKOVER (WO) � Start Date: 5/22/2013 1 End Date: X4- 00XTH- E:DRILL (2,200,000.00 ) I Project: Milne Point ' Site: M Pt J Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/29/1994 12:00:00AM 1Rig Release: 5/28/2013 Rig Contractor: DOYON DRILLING INC. 1 UWI: Active datum: Kelly Bushing / Rotary Table @54.20usft (above Mean Sea Level) Date From - To 1 Hrs Task Code 11 NPT T NPT Depth Phase Description of Operations (hr) (usft) I 19:00 - 21:00 I 2.00 FISH P ! DECOMP PJSM, M/U FISHING BHA #2 = SPEAR ASSY, BUMPER SUB, OIL JAR, COLLARS, INTENSIFIER JAR - MOBILIZE SMALL 2' TONGS TO RIG FLOOR, R/U WITH LOAD CELL TO READ LOW MAKE -UP TORQUES ' 1- BREAK OUT SPEAR AND ADD EXTENSION 1 j AND 3.557" NOM. GRAPPLE - TORQUE UP SPEAR AND M/U TO BUMPER ' 1 SUB 1- RIH WITH COLLARS, M/U INTENSIFIER JAR 1 21:00 - 00:00 3.00 FISH P DECOMP 1— RIH WITH FISHING BHA #2 - FROM BHA = 320' TO 7998' MD 1 - OA =0 PSI I - LOSS RATE = 4 BPH, HOLE IS STAYING FULL - 24 HOUR FLUID LOSS = 155 BBLS, 10.5 PPG BRINE 5/26/2013 00:00 - 01:00 1.00 FISH P DECOMP PJSM, PERFORM SPCC AND EQUIPMENT ICHECKS - SPR'S, 30 SPM = 190 PSI, 40 SPM = 340 PSI - PUWT = 180K, SOWT = 125K, 3 BPM = 360 1 PSI ' - TAG TOP OF FISH WITH SPEAR AT 8022' MD 1- OBSERVE GRAPPLE DRAG DOWN TO 1 NO-GO, -3.5 FEET SWALLOW, 10K DOWN WT, TURN PUMP OFF ' I- PICK UP 8' AND OBSERVE INITIAL 15K IOVERPULL - SET DOWN AGAIN WITH 20K DOWN WT - PICK UP 15', SEE 5K ADDITIONAL PUWT - SET DOWN AGAIN WITH 15K AND TAG 2.5' HIGHER 1- PICK UP 30' WITH 5K STEADY DRAG 1- MONITOR WELL 10 MINUTES, WELL IS ON LOSSES 01:00 - 04:00 3.00 FISH P DECOMP POOH WITH FISH AND STAND BACK DRILL PIPE F/ 8022' T/ BHA = 320' MONITOR DISPLACEMENT CLOSELY FLOW CHECK BEFORE PULLING COLLARS THRU STACK . 04:00 - 05:30 1.50 FISH P DECOMP 1 PJSM, L/D FISHING BHA #2 = SPEAR RUN - L/D REMNANTS OF PACKER AND 26' OF ' SCREENS 1 - L/D BAKER JARS AND BUMPER SUB 1 1 1 - CLEAR RIG FLOOR OF ALL BAKER TOOLS - CLEAN RIG FLOOR, PREP TO RIH WITH 1 MULE SHOE 05:30 - 08:00 2.50 CASING 1 P ' DECOMP PJSM, M/U 3-1/2" MULE SHOE TO COLLARS 1 - RIH ON 4" DP FROM DERRICK TO 7961' MD. - 1 08:00 - 08:30 0.50 CASING P DECOMP PJSM, SLIP / CUT DRLG LINE. - SLIP AND CUT 50' OF 1.25" DRLILLING LINE. 08:30 - 09:00 0.50 CASING 1 P I DECOMP IRIH WITH 3 -1/2" MULE SHOE 1 - SINGLE IN HOLE TO TAG FILL - TAG FILL AT 8045' MD I — _ - P/U TO 8025' MD. NO DRAG. Printed 6/10/2013 9:23:02AM • • North America - ALASKA - BP Pagel(' of 12 ' Operation Summary Report Common Well Name: MPJ -10 AFE No Event Type: WORKOVER (WO) Start Date: 5/22/2013 End Date: 'X4- OOXTH- E:DRILL (2,200,000.00 ) Project: Milne Point Site: M Pt J Pad ' Rig Name /No.: DOYON 16 Spud Date/Time: 8/29/1994 12:00:00AM Rig Release: 5/28/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @54.20usft (above Mean Sea Level) Date 'I, From - To Hrs Task I Code I NPT ' NPT Depth , Phase ! Description of Operations (hr) (usft) 09:00 - 10:00 1.00 CASING P DECOMP CBU AT 8025' MD ' I - CIRCULATE 20 BBL HI -VISC SWEEP. I - 6 BPM / 740 PSI. I - NO SAND NOTED. MONITOR WELL, SLIGHT LOSS RATE. 10:00 - 18:00 8.00 CASING P DECOMP I I PJSM, POH L/D DP. '- POH F/8025' T/ 360' MD W/ MULE SHOE. - L/D 4" DP 1X1 TO PIPE SHED. ! - L/D 4 3/4" DRILL COLLARS AND HWDP - CONTINUOUS HOLE FILL. 18:00 - 18:30 0.50 CASING P DECOMP ' C/O ELEVATORS TO 2 7/8" TUBING 'ELEVATORS I M/U RUNNING TOOL AND PULL WEAR BUSHING - CLEAR AND CLEAN RIG FLOOR 18:30 - 19:00 1 0.50 RUNCOM P RUNCMP RE -DRESS HANGER FOR COMPLETION RUN I - MAKE HANGER DUMMY RUN, VERIFY "J" I INTO POSITION BY WSL, TOUR PUSHER AND I CAMERON REP ! - WELLHEAD ALIGNMENT PIN MEASUREMENT = 5/8" EXPOSED 19:00 - 21:00 2.00 RUNCOM P RUNCMP . PREP RIG FLOOR TO RUN 2 7/8" ESP I [ COMPLETION I ' I - MOB POWER TONGS TO RIG FLOOR AND I R/U - HANG ESP SHEAVE IN DERRICK AND I ISECURE - MOBILIZE CANNON CLAMPS TO RIG FLOOR - SPOT AND R/U CENTRILIFT SPOOLING UNIT, LOAD ESP CABLE REEL 21:00 - 00:00 3.00 RUNCOM I P I RUNCMP PJSM FOR M/U AND RUN 2 7/8" 6.5# EUE ESP ' COMPLETION - M/U ESP MOTOR AND PUMP ASSEMBLY PER ! ' CENTRILIFT REP - M/U ESP CABLE POT HEAD TO MOTOR ASSY CHECK CONDUCTIVITY, GOOD - OA =0 PSI - LOSS RATE = 4 BPI-I, HOLE IS STAYING FULL - 24 HOUR FLUID LOSS = 86 BBLS, 10.5 PPG BRINE 5/27/2013 i 00:00 - 06:30 6.50 I RUNCOM P RUNCMP I PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - RIH WITH 2 7/8" 6.5# EUE 8 RD TUBING ESP COMPLETION, FROM DERRICK. ' - RUN FROM ESP ASSEMBLY TO 7600' MD. TUBING TORQUE = 2300 FT /LBS '- INSTALL CANNON CLAMPS ON EVERY COLLAR ON THE FIRST 9 JOINTS, THEN ' EVERY OTHER COLLAR THEREAFTER I I I 1- CHECK CONDUCTIVITY EVERY 2000' - PUMP 5 BBLS TO FLUSH THRU PUMP AT .50 ' BPM, EVERY 2000', NOT TO EXCEED 3000 PSI - MAINTAIN CONTINUOUS HOLE FILL, >1 BPH - - -- LOSS RATE W/ 10.5 PPG BRINE 1 I- -1- 06:30 - 07:00 0.50 I RUNCOM ! P RUNCMP ' PJSM, PU TBG HANGER. '- PU LANDING JOINT WITH FOSV. I - PU 11" X 2 7/8" WKM TBG HANGER AND ORIENT PER CAMERON REP. Printed 6/10/2013 9:23:02AM • • North America - ALASKA - BP gage 11 of 12 . Operation Summary Report Common Well Name: MPJ -10 ! AFE No Event Type: WORKOVER (WO) I Start Date: 5/22/2013 End Date: IX4- 00XTH- E:DRILL (2,200,000.00 ) Project: Milne Point I Site: M Pt J Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/29/1994 12:00:00AM Rig Release: 5/28/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @54.20usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) (usft) ! 07:00 - 08:00 1.00 RUNCOM 1 P RUNCMP 1 PJSM, TERMINATING ESP CABLE. I - INSTALL PENETRATOR IN HANGER ! 1 - TERMINATE ESP CABLE TO PENETRATOR ' ! - CANNON CLAMPS = 207 - PROTECTOLIZERS = 5 - FLAT GUARDS = 2 08:00 - 09:00 1.00 RUNCOM P RUNCMP PJSM, LANDING 11" WKM TBG HANGER. 1 CAMERON REP, WSL, CENTRALIFT REP IN ATTENDANCE. - LAND HANGER PER CAMERON REP ' PU WT = 97K, SOW = 77K. INCLUDING 40K 1 , ! TOP DRIVE WT. I BTM OF MOTOR SET AT 7616' MD. '- RUN IN LOCK DOWN SCREWS PER CAMERON REP. ' LD LANDING JOINT. 09:00 - 10:00 1.00 RUNCOM ' P ! RUNCMP 'PJSM, SET / TEST TWC. - CAMERON REP INSTALL 2 -1/2" TYPE 'H' I TWC. - PERFORM ROLLING PRESSURE TEST FROM BELOW TWC / HANGER. 1.5 BPM ROLLING 700 PSI F/ 10 CHARTED I I MIN. PASSED. - 25 BBLS PUMPED ' - TEST FROM ABOVE TWC, 250 / 3500 PSI, 5 MIN, CHARTED. PASSED. - MAINTAIN CONTINUOUS HOLE FILLAT -1 ! BPH W/ 10.5# KWF. 10:30 0.50 BOPSUR P 10:00 RUNCMP PJSM, CLEAN OUT BOPE. 1- PU 1 JT. 4" DP. MAKE UP STACK WASHER, I SCREW INTO TOP DRIVE - WASH OUT BOPE STACK - L/D STACK WASHER 10:30 - 12:00 1.50 BOPSUR P RUNCMP PJSM, WELL SUPPORT TO SPOT TREE IN 1 CELLAR. I !- RECEIVE MILNE PT RIG OPS APPROVAL FOR 1 LIFT I - USED WELL SUPPORT LOADER AND I OPERATOR WITH STINGER TO SPOT TREE IN I CELLAR. i - LIFT TREE OVER BLOCKED AND BLED FLOW I 'LINE TO ACCESS CELLAR AREA. - BP SUPERINTENDENT, WSL, TOOL PUSHER, I I RIG CREW, DSM IN ATTENDANCE. - PJSM, CHANGE OUT SAVER SUB ON TOP DRIVE. ' 12:00 - 13:30 I 1.50 BOPSUR P 1 OTHCMP PJSM FOR N/D BOP STACK AND N/U TREE - REMOVE RISER, TURNBUCKLES, CHOKE I I AND KILL LINES - R/D ACCUMULATOR LINES, PULL MOUSE 'HOLE T - STAND BOP BACK ON PEDESTAL 13:30 - 17:00 W 3.50 HSUR P OTHCMP N/U 11" X 2 9/16" 5000# TUBING HEAD ADAPTER - CAMERON REP CLEAN AND INSPECT 1 I 1 BEFORE INSTALLATION I . - TEST ADAPTER VOID, 250 / 5000 PSI, 30 MIN, ! , I CHARTED, GOOD TEST - WSL WITNESSED Printed 6/10/2013 9:23:02AM • • North America - ALASKA - BP P•1‘;012-0112 Operation Summary Report Common Well Name: MPJ -10 AFE No Event Type: WORKOVER (WO) Start Date: 5/22/2013 End Date: X4- 00XTH- E:DRILL (2,200,000.00 ) Project: Milne Point Site: M Pt J Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/29/1994 12:00:00AM Rig Release: 5/28/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @54.20usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) f I 17:00 - 19:00 • 2.00 WHSUR P ' OTHCMP N/U 2 9/16" 5000# CAMERON PRODUCTION i 1 1 TREE 1- TEST TREE, 250 / 5000 PSI, 5 MIN, CHARTED, GOOD TEST 19:00 - 21:30 2.50 WHSUR P OTHCMP PJSM, R/U AND TEST DSM LUBRICATOR - TEST 250 / 3500 PSI, 5 MIN, CHARTED - PULL TWC - RETEST LUBRICATOR; INSTALL 2 -1/2" TYPE 'H' BPV - R/D DSM LUBRICATOR_ 21:30 - 22:00 0.50 WHSUR P OTHCMP PERFORM ROLLING TEST ON BPV FROM BELOW - PUMP 1.5 BPM = 500 PSI, 10 MIN CHARTED, ' 20 BBLS PUMPED, .5 BBLS RETURNED i - WELL IS STATIC 22:00 - 22:30 ' 0.50 WHSUR ' P OTHCMP R/D AND BLOW DOWN ALL TEST AND I CIRCULATING LINES i - SECURE CELLAR AREA AND TREE 22:30 - 00:00 1.50 RIGD P I OTHCMP CLEAN AND OFF LOAD PITS - BRIDLE UP BLOCKS AND PREP RIG FLOOR FOR DERRICK OVER ' j- 24 HOUR FLUID LOSS = 98 BBLS, 10.5 PPG BRINE • - RELEASE RIG AT 24:00 HOURS FROM MPJ -10 FOR MOVE TO MPE -11 5/27/2013 Printed 6/10/2013 9:23:02AM • 0 Tree: 2 9/16" - 5M CIW M PJ -1 O Orig. KB Elev. = 65.75 (N 22E) Wellhead: 11" x 2 9/16" 5M WKM Orig. GL Elev. = 34.60" w/ TDF -CS -1 tbg hgr, 2 7/8" EU 8rd RT To Tbg. Spool = 30.45' (N 4E) T x B threads & 2.5 CIW 'H' BPV profile 13 3/8" 54.5 # /ppf, K -55 115' Camco 2 7/8" x 1" sidepocket KBMM GLM 138' 9 5/8 ", 40 # /ft, L -80 Btrc. 2,664' I , KOP @ 630' Max. hole angle = 39 deg. f/ 3,100' Hole angle thru' perfs = 20 deg 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg (drift ID = 2.347 ", cap. = 0.00592 bpf) 7" 26 ppf, L -80, NSCC production casing (drift ID = 6.151", cap. = 0.0383 bpf) Camco 2 7/8" x 1" 7" X 2 7/8" annular cap. = .02758 bpf) sidepocket KBMM GLM 7,365' 1 2 -7/8" XN- Nipple 7,516' (2.250" no -go id) Centrilift ESP SXD 7,558' 137 -P17 Gas Separator / GRSFTXAR 7,576' Stimulation Summary Centrilift tandem seal section 7,582' GSB3DBUT /LT SB /SB PFSA Mig n „ _r . ,,, . . Centrilift MSP1 7,596' 7" short joint marker at 7,519' wlm. 210 HP motor, 2380 v. / 53 Amp MR Perforation Summary Welllift w/ 6 fin centralizer 7,615' Ref log: 10/03/94 GR /CCL Welllift TVD 6,785' Size SPF Interval (TVD) 3 -3/8 6 7,744'- 7,766' 6,906' - 6,927' 3 -3/8 6 7,836'- 7,910' 6,992'- 7,062' Plug Back TD 5/26/2013 8,045' 7" Landing collar 8,161' 7" float collar (PBTD) 8,203' 7" float shoe 8,247' DATE REV. BY COMMENTS MILNE POINT UNIT 10/31/94 jjm Coil Completion 10/13/98 MDO ESP completion 4ES WELL J -10 11/10/00 Lee MDO Hulme ESP RWO 4ES API NO: 50- 029 -22500 9/2/06 Lee Hulme ESP RWO 4ES 5/8/10 REH ESP RWO - Nabors 4ES 5/29/13 B.Bixby Doyon 16 RWO / Remove 7" Packer BP EXPLORATION (AK) STATE OF ALASKA c ALAS~IL AND GAS CONSERVATION COMMI N R~~EIVED REPORT OF SUNDRY WELL OPERA~NS 1. operations Performed: AleSke 0!I & ~iBS Gans. Commissio: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Susp nd d W I ~ ~ A era e nc ^ 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: Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 194-110 3. Address: ^ Service ^ Stratigraphic ~. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22500-00-00 7. Property Designation: ~ 8. Well Name and Number: ~ ADL 025906 MPJ-10 9. Field /Pool(s): ~ Milne Point Unit / Kuparuk River Sands 10. Present well condition summary Total depth: measured 8265' feet true vertical 7401' feet Plugs (measured) None Effective depth: measured 8160' feet Junk (measured) None true vertical 7301' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13-3/8" 112' 112' 3580 2090 Surface 2633' 9-5/8" 2664' 2432' 5750 3090 Intermediate Production 8218' 7" 8247' 7384' 7240 5410 Liner Perforation Depth: Measured Depth: 7744' - 7910' True Vertical Depth: 6906' - 7062' Tubing (size, grade, measured and true vertical depth): 2-718", 6.5# L-80 7610' 6781' ' ' ' ' - 6829 - 7662 6805 2-7/8", 6.5# L-80 7636 Packers and SSSV (type, measured and true vertical depth): 7" x 4" Baker'F-1' Permanent Packer 7636' 6805' 11. Stimulation or cement squeeze summary: Intervals treated (measured): ~. it ~~ ~it~ ~fr ~~ ~r~~$ ~~.. Treatment description including volumes used and final pressure: Y,~ , _ ~ , '~ L. 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 Subsequent to operation: 94 75 735 280 221 13. Attachments: ^ Copies of Logs and Surveys run • Well Class after work: ^ Exploratory ®Development ^ Service ort of Well O erations ® Dail Re y p p ® Well Schematic Diagram ~• 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 'rf C.O. Exempt: Contact Mehrdad Nadem, 564-5941 NIA Printed Name Terrie Hubble Title Drilling Technologist Prepared By NamelNumber. O Signature Phone 564-4628 Date v' Terrie Hubble, 564-4628 Form 10-404 Revised 07!2009 ~ Submit Original Only RE3DMS JUN d 8 20~ ~ ~ (-~-/d ~~~ • • North America -ALASKA - BP Page 1 of t Operation Summary Report Common Well Name: MPJ-10 DIMS AFE No Event Type: MOBILIZATION (MOB) Start Date: 4/28/2010 End Date: 4/30/2010 X4-OOQ9F-E (100,000.00 ) Project: Milne Point Site: M Pt J Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 8/29/1994 12:0O:OOAM Rig Release: 5/8/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @54.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations _ (hr) __ ; (ft) _ _ _ 4/30/2010 06:00 - 12:00 6.00 MOB P PRE RD RIG, PREPARE TO MOVE FROM MPE-08 TO MPJ-10 -0730-hrs SCOPE DOWN TOP OF DERRICK I -0900-hrs LOWER DERRICK ~ i -0920-hrs RU CAMP, RIG, SHOP TO TRUCK AND ~ ( PREP TO MOVE OFF LOCATION. ~ -1100-hrs MOVE RIG OFF WELL. PAD OPERATOR PRESENT TO WITNESS. ~ ' =STAGE TRUCKS AT EDGE OF PAD _ _ __ 12:00 - 15:30 3.50 MOB P ~ _ PRE ~ MOVE RIG FROM MPE PAD TO MPJ PAD - ~ 15:30 - 20:30 5.00 MOB P PRE MOVE RIG ON PAD. SPOT CAMP, SUB OVER ~ WELL, PIPE SHED,'PITS. _ __ __ 20:30 - 00:00 _ 3.50 ___ MOB P _ __ PRE RAISE DERRICK. CHANGE OUT SAND LINE. _ SCOPE UP'DERRICK _____ 5/1/2010 00:00 - 01:00 1.00 MOB P PRE CONTINUE FILLING PITS. Printed 5127/2010 9:22:27AM • North America -ALASKA - BP Page 1 of 11 Operation Summary Report Common Well Name: MPJ-10 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 4/29/2010 ~ End Date: 5/8/2010 X4-0009E-E (300,000.00 ) Project: Milne Point Site: M Pt J Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 8/29/1994 12:0O:OOAM Rig Release: 5/8/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @54.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 5/t/2010 01:00 - 02:00 1.00 KILLW P DECOMP PU LUBRICATOR AND PT TO WITH DIESEL TO 500 PSI. PULL BPV 1100 PSI ON TUBING. 02:00 - 02:30 0.50 KILLW P DECOMP CONTINUE TO FILL PITS 02:30 - 03:00 0.50 KILLW P DECOMP EVACUATION DRILL INCLUDED 4CH2MHILL OPERATORS. LESSONS LEARNED CAPTURED. - -NEED TO HAVE VISITOR POST THEIR HARMONY -CH2MHILL PRESENTED LEASON LEARNED TO I THEIR SAFETY MEETING I I _ -PEAK DRIVERS REMINDED TO SIGN OUT _ ~ 03:00 - 04:00 1.00 KILLW P DECOMP ' _ CONTINUE TO FILL PITS. - 1 04:00 - 06:30 ---- 2.50 KILLW P DECOMP WELL KILL. CIRCULATE 9.8 PPG BRINE 446BBL I TO DISPLACE TUBING: BULL HEAD 18 BBL TO FORMATION. CIRCULATE THROUGH CHOKE THROUGH TUBING 246 BBL, UNTIL RETURNS i ; WERE CLEAN. ~ -CIRCULATE AT 3-BPM WITH 1470 PSI PUMP - __ __ ~ 0 i KIL W -- N FLUD __ DECOMP PRESSURE. ~ 06:30 - 10:0 3.50 L SHUT IN AND MONITOR WELL. PRESSURE ~ i EQUALIZED AT TBG- 80-PSI, CSG - 80-PSI. -TAKE SAMPLE, 9.7-PPG WITH ODOR OF DIESEL. i I ALLOW TO U-TUBE ANY DIESEL THAT MAY BE ~ ( AT TOP OF TUBING AND FROM FREEZE I PROTECT. -0708-hrs PRESSURE DROPPED TO 50-PSI ON i i BOTH TUBING AND CSG. I ~ ' ! -REVERSE CIRCULATE 10-BBL TO PUSH OUT j ANY DIESEL AT THE TOP OF TUBING. I I i -CIRCULATE 176-BBLS DOWN THE TUBING AT ~ I . j , ~ 2.5-BPM @ 440-PSI PUMP PRESSURE. -LOST I. i ( 9-BPH WHILE CIRCULATING. -0900-hrs SHUT IN AND CHECK FOR FLOW. ~ ~ FLOW WAS CONSTANT AT 2.5-BBL IN 5-MIN. SHUT IN AND MONITORED. i -1000-hrs SITP 20-PSI, SICP 20-PSI. CALL RWO ENGINEER AND SUPERINTENDENT AND DISCUSS ~ OPTION TO WEIGHT UP SYSTEM TO 10.1-PPG j WHICH ALLOWS FOR 75-PSI OVERBALANCE 10:00 - 16:30 6.50 KILLW P DECOMP WAIT ON SODIUM BROMIDE PRODUCT TO ARRIVE ON LOCATION _ 16:30 - 00:00 7.50 KILLW I P I __ DECOMP PJSM WITH MUD ENGINEER, RIG CREW, WSL ON I PLAN FOR MIXING PRODUCT AND KILLING WELL. -1700-hrs BEGIN WEIGHTING PITS UP TO 10.1 TO ~ ~ ___ BEGIN CIRCULATING. 5/2/2010 00:00 - 02:30 2.50 ! KILLW P I DECOMP I ULATE WELL TO 10.1 PPG NABR 5000 CIRC STROKES 3BPM @ 620 PSI. CRUDE IN RETURNS FOR FIRST 450 STROKES. 10.1 PPG IN AND OUT AT 5000 STROKES. TUBING PRESSURE 0 PSI CASING PRESSURE 0 PSI. FLOW CHECK WELL. NO FLOW. STATIC LOSS RATE 6 BPH. Printed 5/27/2010 9:23:24AM • North America -ALASKA - BP Page ~ ~~r ~ ~ Operation Summary R eport Common Well Name: MPJ-10 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 4/29/2010 End Date: 5/8/2010 X4-0009E-E (300,000.00 ) Project: Milne Point Site: M Pt J Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 8/29/1994 12:0O:OOAM Rig Release: 5/8/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @54.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (ft) I _ 1 i 02:30 - 04:00 1.50 WHSUR P DECOMP BLOW DOWN LINES. SET TWC AND TEST 3500 PSI ABOVE FOR 10 MINUTES AND ROLLING 500 PSI TEST BELOW TWC @ 1 BPM. _ __ __ _ ____ 04:00 - 06:00 2.00 BOPSUR P _ DECOMP ND TREE 06:00 - 09:30 3.50 BOPSUR P DECOMP NU BOP, RU BOP PRESSURE TESTING I EQUIPMENT. j -MAINTAIN HOLE FILL THROUGH IA WITH 7-BPH ~ LOSS RATE. __________ 09:30 - 10:00 0.50 BOPSUR P __ DECOMP PJSM ON PRESURE TEST BOP. -AOGCC INSPECTOR JOHN CRISP PRESENT FOR BOP'TEST. _ _______ 10:00 - 10:30 0.50 BOPSUR P _ DECOMP FUNCTION TEST BOP EQUIPMENT, AND MARK TEST JOINT. Printed 5/27/2010 9:23:24AM r 1 North America -ALASKA - BP Page 3 of 11 Operation Summary Report Common Well Name: MPJ-10 DIMS ' AFE No Event Type: WORKOVER (WO) Start Date: 4/29/2010 End Date: 5/8/2010 X4-0009E-E (300,000.00 ) ~ -- -- - Project: Milne Point Site: M Pt J Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 8/29/1994 12:0O:OOAM Rig Release: 5/8/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @54.2ft (above Mean Sea Level) Date From - To ~ Hrs Task Code NPT NPT Depth Phase Description of Operations ~ (hr) (ft) ___ ~ _ ___ ;3p - 21:00 10.50 BOPSUR P DECOMP ' BEGIN TESTING BOP STACK. i -1120-hrs AFTER SEVERAL ATTEMPTS TO i ~ PERFORM FIRST TEST ON BOP STACK, THROUGH PROCESS OF ELIMINATION DETERMINED THAT TWC WAS NOT HOLDING ~ PRESSURE. DECIDED TO CHANGE OUT TWC. -1130-hrs RU DUTCH SYSTEM FOR DSM TO PULL TWC. -1315-hrs RU AND TEST LUBRICATOR TO 500-PSI WITH DIESEL. GOOD TEST. -PULL TWC AND INSTALL NEW TWC. TOOK THE OLD TWC APART AND NOTICED SAND DEBRIS IN THE SEALING''ELEMENT: i ~ -1439-hrs RD LUBRICATOR AND DUTCH RISER. ~ ~ -1500-hrs. TEST GAS DETECTION SENSORS ON I ~ THE RIG. -1515-hrs CONTINUE WITH BOP TEST. AFTER ' ( RE-PRESSURING THE TEST SEVERAL TIMES ~ WITH THE PRESSURE STEADILY DROPPING LESS; CHANGED OUT THE SENSOR CAP ON THE ~ TEST CHART LINE. PRESSURED UP AND ABLE TO GET THE FIRST BOP TEST TO PASS. --MAINTAIN HOLE FILL WITH 7-BPH LOSS RATE. -1657-hrs UNABLE TO GET A GOOD TEST ON THE SECOND TEST. NARROWED THE AREAS ~ THAT WE WERE TESTING AGAINST TO I i ELIMINATE LEAKS. NO SIGNS OF LEAKS ON ~ FLANGES OR FROM A PIPE RAMS. OPENED THE IA AND NOTICED FLUID SEEPING DOWN THE SIDE ~ ~ OF THE PENETRATOR, THROUGH THE SEALS AGAINST THE HANGER. AFTER DISCUSSION WITH RWO SUPERINTENDENT DECIDED TO TEST ANNULAR AND ENSURE NO LEAKS (SHEAR RAMS AND PIPE RAMS HAVE ALREADY BEEN TESTED WITH ~ ~ i NO SIGNS OF LEAKS), PLAN FORWARD IS PULL _ ~ HANGER, CUT ESP LINE, REPLACE PENETRATOR j SEALS AND TO CAP THE TOP OF PENETRATOR, RE-LAND HANGER, AND CONTINUE WITH BOP ~ TEST. -AOGCC REP JOHN CRISP APPROVED THE I PROCEDURE AS WELL AS RWO WTL LOWELL CRANE. ALSO APPROVED ALTERNATE PLAN IF TWC FAILS TO RETEST TO REPLACE HANGER PRIOR TO TESTING BOP. Printed 5127/2010 9:23:24AM r North America -ALASKA - BP Page 4 of 11 Operation Summary Report Common Well Name: MPJ-10 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 4/29/2010 i End D ate: 5/8/2010 X4-0009E-E (300,000.00 ) Project: Milne Point Site: M Pt J Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 8/29/1994 12:0O:OOAM Rig Release: 5/8/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @54.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ 21:00 - 00:00 _ 3.00 BOPSUR P DECOMP CLOSE HYDRIL AND TEST 250 PSI LOW AND 3500 PSI HI. GOOD TEST I. E. NO VISABLE LEAKS.. I ~ PU LANDING JOINT AND ATTEMPT TO TEST TWC I BY PRESSUREING DOWN LANDING JOINT. TEST FAILED ATTEMPTED SECOND RETEST NO G0. I DISCUSSED TWC FAILURE WITH FIELD . i SUPERINTENDENT J WILLINGHAM DECIDED TO ' i PULL HANGER AND HANG TUBING STRING . FROM TIW VALVE AND TEST PLUG ASSEMBLY. -AOGCC REP JOHN CRISP GAVE VERBAL APPROVAL OF PLAN AND CONTIGENT PLAN AS HE LEFT LOCATION AND WANTED A CALL i AFTER FIRST BOP TEST PASSED. i MAINTAIN CONTINUOUS HOLE FILL WITH 3 BPH LOSS RATE. 5/3/2010 00:00 - 04:00 ~ 4.00 BOPSUR P I DECOMP pU DUTCH SYSTEM. PJSM FOR PULLING TWC. ~ RU LUBRICATOR AND TEST TO 500 PSI. PULL - TWC. TWC HAD SOME GRIT AND SAND IN IT. PULL DUTCH SYSTEM. PU LANDING JOINT. BOLDS. PULL HANGER TO FLOOR WITH 73K. LD ~ LANDING JOINT AND TUBING HANGER & 10'PUP JOINT. INSPECTED HANGER BPV PROFILE. ~ PROFILE IN GOOD SHAPE. THE HANGER IS, REUSABLE PER CIW. PULL PENETRATOR FROM TUBING HANGER AND INSPECT. SLIGHT FLAT i SPOT ON 'O'RING. CUT ESP CABLE AT FIRST CABLE CLAMP.PU TEST PLUG, TIW, XO TO 2-7/8 i EUE 8 RD TUBING STRING. LAND TEST PLUG, ~ TIW (CLOSED) XO AND ESP COMPLETION. ~ MAINTAIN CONTINUOUS HOLE FILL 3 BPH LOSS. - 04:00 - 09:00 -- 5.00 ~ -- BOPSUR P - DECOMP TEST BOPE TO 250-psi LO, 3,500-psi HI WITH 2-7/8"TEST JOINTS. TEST ANNULAR PREVENTER TO 250-psi LO/3500-psi HI WITH i ~ 2-7/8"TEST JOINT. GOOD TEST._ 04:15 HRS NOTIFIED PAGED AOGCC AND NOTIFIED THEM THAT BOP TESTING HAD ~ RESUMED. 04:20 HRS AOGCC'S JOHN CRISP RETURNED CALL AND WAIVED WITNESSING THE BOP TEST. CONTINUE TESTING BOP. MAINTAIN HOLE FILL WITH 3-BPH LOSS RATE 09:00 - 09:30 0.50 BOPSUR _ P _ DECOMP RD BOP TEST EQUIPMENT. 09:30 - 10:00 ~ 0.50 BOPSUR P DECOMP EVAC DRILL WITH CREW. ----- -------- 10:00 - 11:00 -- i 1.00 BOPSUR - P DECOMP PJSM, RU LANDING JOINT, PULL TEST PLUG TO 1 I j THE RIG FLOOR. BREAK OUT TEST PLUG AND j TEST JOINT. LD TEST JOINT. Printed 5/27/2010 9:23:24AM ~~ North America -ALASKA - BP Page 5 of 11 Operation Summary Report ___ _ _ - __ Common Well Name: MPJ-10 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 4/29/2010 End Date: 5/8/2010 X4-0009E-E (300,000.00 ) Project: Milne Point Site: M Pt J Pad Rig Name/No.: NABORS 4ES Spud Date(Time: 8/29/1994 12:0O:OOAM Rig Release: 5/8/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @54.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) I (ft) 11:00 - 19:30 8.50 BOPSUR N HMAN _ DECOMP DROP OBJECT ON RIG. DROP 3-1/2" TEST JOINT DOWN SKATE. SHUT DOWN RIG FOR INVESTIGATION. -1200-hrs RU TO CIRCULATE WELL. 10.1-PPG GOING IN AND 10+-PPG COMING OUT. NOTICE DISCREPANCY ON TOTCO AND PIT START ~ ( SHOWING A GAIN. STOP CIRCULATING TO FLOW CHECK. WELL ON A VAC WITH 2.5-3 BPH LOSS RATE. CONTINUE CIRCULATING. PUMP . 137-BBL NOTICEANOTHER GAIN. STOP TO CHECK-FLOW AND WELL ON A VAC WITH SAME LOSS RATE. OILS MIXED IN WITH RETURNS -1330-hrs STOP CIRCULATING TO BATCH PITS BACK TO A 10.1-PPG. WEIGHT. WHILE WEIGHTING UP, ANOTHER STRAP WAS TAKEN AND PITS SHOWED A LOSS THAT WOULD HAVE ~ BEEN 3-BPH SINCE BEFORE CIRCULATION BEGAN:. MAINTAIN HOLE FILL WHILE BATCHING PITS. ~ -1400-hrs CONTINUE CIRCULATING AT 3-BPM ~ WITH 560-PSI PUMP PRESSURE. --ADW HSE REP, ALLEN GRAFF AND NABORS ~ HSE REP, PAUL HOLLEY ARRIVED ON ~ LOCATION TO PERFORM INVESTIGATION OF i INCIDENT. REVIEW PIPE SHED AND RIG FLOOR AREA, PERFORM INTERVIEWS WITH RIG CREW ~ MEMBERS INVOLVED. -1630-hrs PJSM WITH RIG CREW, HSE REPS, WSL, TOOL PUSHER ON HAZARDS ~ i ASSOCIATED WITH REIN ACTING THE j SCENARIO. ATTEMPT TO REIN ACT SCENARIO. j ( -1900-hrs HSE REPS CONCLUDE INVESTIGATION i I ON LOCATION. Printed 5/27/2010 9:23:24AM North America -ALASKA - BP Page 6 of ~ 1 Operation Summary Report __ _ -_ __ Common Well Name: MPJ-10 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 4/29/2010 End Date: 5/8/2010 X4-0009E-E (300,000.00 ) Project: Milne Point Site: M Pt J Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 8/29/1994 12:0O:OOAM Rig Release: 5/8/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @54.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth ( Phase Description of Operations (hr) (ft) __ __ 19:30 23:00 3.50 BOPSUR _ N RREP DECOMP -1830-hrs PER CONVERSATION WITH JIM WILLINGHAM, DECIDED THAT PIPE SKATE WOULD NOT BE USED IN OPERATION UNTIL THE SKATE EXTENSION WAS FASTENED IN A ~ POSITION THAT WOULD NOT ALLOW IT TO j MOVE AROUND POSSIBLY CONTRIBUTING TO ( THE DROPPED OBJECT. --RIG CREWS CONTINUED TO RU IN PREPARATION TO PULL ESP ASSEMBLY. -2100-hrs WELDER ARRIVED ON LOCATION ~ MADE PLANS WITH TOOLPUSHER TO WELD PLATES THAT WOULD MAKE IT SO THAT SKATE WOULD NOT MOVE. -2230-hrs AFTER ASSESSING THE WORK NEEDED TO COMPLETE THE TASK, CALLED DAVE REEM TO OBTAIN PERMISSION TO i PROCEED WITH WELL OPERATION UNTIL IN A SAFE POINT WHEN THE WELL HAS A PLUG IN THE HOLE. THE FEW PICKS NECESSARY FROM ~ ~ THE PIPE SHED WILL BE 100% TIED OFF AND ~ ( ASSISTED IN RAISING AND LOWERING WITH THE TUGGER, TOUR PUSHER WILL ALSO WITNESS ALL PICKS. --THE WELDING WORK TO THE SKATE EXTENSION WILL BE DONE WHEN THE RBP AND STORM PACKER ARE SET AND THE OPEN WELL WILL BE COMPLETELY ISOLATED WHILE WE ARE PERFORMING WELLHEAD WORK. 23:00 - 00:00 _ _ 1.00 ~ PULL P DECOMP PERFORM WEEKLY SAFETY MEETING 514/2010 00:00 - 00:30 0.50 PULL P DECOMP PJSM FOR POH WITH ESP COMPLETION 00:30 - 01:30 1.00 ~ PULL P ~ DECOMP PU TWO JOINT RIH AND TAG PACKER WITH 5K ~ DOWN. @ 7634. PU AND RU TO PULL ESP j _ CABLE TO SPOOLER. 01:30 - 09:30 8.00 __ PULL P ____ DECOMP pOH WITH EXISTING 2-7/8" ESP COMPLETION STANDING BACK TUBING IN THE DERRICK. ~ VISUALLY INSPECTING ALL JOINTS. MAINTIAN CONTINUOUS HOLE FILL. LOSS RATE - 3 BPH ___ 09:30 - 14:30 5.00 ~ __ PULL P DECOMP AT SURFACE WITH ESP ASSY. -BREAK AND LAY DOWN ESP COMPONENTS ' __ _WITH CENTRILIFT REPS. 14:30 - 16:30 _ 2.00 _ PULL P __ DECOMP CLEAN AND CLEAR RIG FLOOR. i -LD AND REMOVE ESP PARTS ~ -RAISING MW IN PITS FROM 10.1 PPG TO 10.3 _ PPG . 16:30 - 23:00 ~ 6.50 BOPSUR P RUNCMP PU RIH W/HES RBP TO 7,543' ON 242 JNTS OF 2-7/8" TUBING. ~ -SET RBP PER HES REP. -TESTED TO 1000 PSI FOR 10 CHARTED MIN -POH AND RACK BACK ONE STAND. -CONTINUE TO RAISE MW IN PITS TO 10.3 PPG. Printed 5/27/2010 9:23:24AM r~ North America -ALASKA - BP Page 7 of 11 Operation Summary Report __ _ _ Common Well Name: MPJ-10_DIMS (AFE No Event Type: WORKOVER (WO) Start Date: 4/29/2010 End Date: 5/8/2010 X4-OOQ9F-E (300,000.00 ) I Project: Milne Point Site: M Pt J Pad Rig Name/No.: NABORS 4ES Spud DatelTime: 8/29/1994 12:0O:OOAM Rig Release: 5/8/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @54.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) __ _ _ ____ _ __ 23:00 - 00:00 1.00 BOPSUR P _ RUNCMP pU/MU HES RTTS. -RIH 8 SET RTTS 32' IN , - 8' BELOW THE WELL H EA_D. 5/5/2010 00:00 - 01:00 1.00 i BOPSUR P ___ RUNCMP pU 7" HES STORM PACKER AND RIH. ~ -SET STORM PACKER 32' IN, -8' BELOW WELLHEAD. ~ ' ~~ i -TESTED STORM PACKER TO 1000 PSI FOR 10 CHARTED MINUTES -GOOD TEST. 01:00 - 02:00 1.00 BOPSUR P RUNCMP ND 13-5/8" 5K BOP STACK AND BLOW DOWN LINES. -BARRIERS IN PLACE ARE: RBP SET @ 7,543' ANO'A STORM PKR SET 32' IN, - 8' BELOW THE ~ WELL HEAD __ ____ _ 02:00 - 02:30 _ __ 0.50 BOPSUR P _ RUNCMP REPLACE BROKEN ALIGNMENT PIN ON TUBING ____ ~ __ _ __ _ SPOOL _ ~ 04:30 02:30 2.00 BOPSUR P T RUNCMP I NU 13-5/8" SK BOP STACK. __ _ _ .-- 04:30 - 06:00 I 1.50 BOPSUR ~ P i RUNCMP PRESSURE TEST THE BREAK ON THE BOP ~ ~ STACK: i ' ~ -250/3500 PSI FOR FIVE CHARTED MINUTES - ~ GOOD TEST. ~ -TEST WITNESSED BY NAD TOOL PUSHER & BP WSL 06:00 - 07:00 1.00 BOPSUR P RUNCMP CREW CHANGE AND RIG SERVICE. -PERFORM ENVIROMENTAL WALK AROUNDS. -SERVICE RIG, GREASE CROWN, BLOCKS AND DRAW WORKS. -CHECK AND SET PVT ALARMS. -PERFORM DAILY DERRICK INSPECTION. _ _ __ ____ 07:00 10:30 _ 3.50 BOPSUR N RREP i __ 8.0 RUNCMP NABORS WELDER FIXED THE AMOUNT OF SLOP IN THE UPPER SKATE EXTENSION. THIS I REQUIRED RE-SPOTTING THE PIPE SHED TO THE __ RIG. _ 10:30 - 12:00 1.50 __ BOPSUR P RUNCMP RU TBG HANGLING EQUIPMENT -DRAIN STACK -PULL AND LD TEST PLUG ___ _ __ 12:00 - 13:30 i ~- 1.50 BOPSUR P ~ _ RUNCMP _ _ RIH 8 ENGAGE 7" STORM PACKER -ENGAGE W/21 RH TURNS _ I~I - --- _ -PULL PKR W/ 45K , LD SAME -.- 13:30 - 16:30 ' 3.00 BOPSUR P t ~ RUNCMP SWAP FLUIDS IN WELL BORE. i -SWAPPED OUT 10.1 PPG WITH 10.3 PPG MW -PUMPED 2-5 BPM @ 240 TO 1490 PSI -TOTAL 4800 STROKES PUMPED OR - 282 BBLS - -- __ __ ____ _ _ 16:30 - 18:00 1.50 _ _ BOPSUR P RUNCMP CLEAN 8 CLEAR RIG FLOOR -RAISE THE REMAINDER OF THE FLUIDS IN THE PITS TO A 10.3 PPG 18:00 - 19:00 i 1.00 BOPSUR P __ RUNCMP PTSM -RIG INSPECTIONS AND ENVIRONMENTAL CHECKS __ 19:00 - 00:00 ~ 5.00 BOPSUR P _ RUNCMP SLIP 8 CUT 84' OF DRILL LINE -INSTALLED AND CALIBRATED NEW WEIGHT INDICATOR SENSOR Printed 5/27/2010 9:23:24AM r~ ~~ North America -ALASKA - BP Page 8 of 11 Operation Summary Report Common Well Name: MPJ-10 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 4/29/2010 End Date: 5/8/2010 X4-0009E-E (300,000.00 ) Project: Milne Point Site: M Pt J Pad Rig Name/No.: NABORS 4ES Spud DatefTime: 8/29/1994 12:0O:OOAM Rig Release: 5/8/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @54.2ft (above Mean Sea Level) Date ~ From - To Hrs Task Code ~ NPT NPT Depth Phase ~ Description of Operations ~ (hr) (ft) -- 5/6/2010 _ __ _____ 00:00 01:30 _ 1.50 BOPSUR _ P RUNCMP i RIH TO PULL 7" HES RBP ~ MU TO RBP PULLD 10K, WAITED FOR ( ELEMENTS TO RELAX i -MONITORED WELL, WELL LOST FLUID _ _ i IMMEDIATLY, -46PH. _ 01:30 - 04:30 , 3.00 BOPSUR ~ P RUNCMP ~ TOH 15 STANDS F/ 7,543' -DURING A CONNECTION SAW THAT WE WERE ~ j GETTING FLUID COMING UP THE TUBING. STOPPED STABBED THE TIW VALVE AND DID A FLOW CHECK. WELL WAS NOT FLOWING. PUMPED A TUBING VOL CHECKING THE MW IN AND OUT. MW WAS OUTAF BALANCE, WITH A 10.3 IN AND A 10.48 HEAVY OUT. WITH SOME CRUDE SPOTTING OUT. PUMPED A FULL CIRCULATION CHECKING MUD WT IN AND OUT TILL WE GOT SOLID 10.3 IN AND 10.3 OUT. WHEN WE GOT A FULL CIRCULATION AROUND I AND EVEN MUD WT. THE DECISION WAS MADE ~ TO GO BACK TO BOTTOM WITH 15 STANDS FROM THE DERRICK AND PUMP A FULL i CIRCULATION. --- --- 04:30 - 05:00 0.50 -- BOPSUR - P RUNCMP TIH 15 STANDS TO CIRCULATE. -DISPLACEMENT ON THE TRIP WAS RIGHT ON @ - 3 BBLS. HOLE IS STATIC, NOT LOSING ANY FLUID 05:00 - 18:00 I ~-- 13.00 KILLW P RUNCMP CIRCULATING WELL @ 3 BPM W/ 580 PSI I -BRINGING BRINE WT UP F/ 10.3 PPG TO 10.6 PPG ~ -MI MUD ENGINEER ON LOCATION TO OVER SEE WEIGHT UP. -WITH 10.6 (H) IN AND OUT -AVG CIRC LOSS RATE : 3 BPH ~ -AVG STATIC LOSS RATE : 2 BPH ___ 18:00 - 19:00 1.00 __ KILLW P i ___ _ _ RUNCMP PTSM -RIG INSPECTIONS AND ENVIRONMENTAL CHECKS 19:00 - 00:00 ~ 5.00 KILLW P _ RUNCMP CIRCULATING WELL @ 3 BPM W/ 580 PSI i -BRINGING BRINE WT UP F/ 10.3 PPG TO 10.6 PPG -MI MUD ENGINEER ON LOCATION TO OVER SEE WEIGHT UP. I -WITH 10.6 (H) IN AND OUT ~ -AVG CIRC LOSS RATE : 3 BPH ( -AVG STATIC LOSS RATE : 2 BPH _ _ 5/7/2010 00:00 - 06:00 6.00 ~ KILLW P i RUNCMP MONITORING & CIRCULATING WELL @ 3 BPM W/ ~ 580 PSI -MW 10.6+ IN AND OUT i ~ -LOSS RATES DROPPED -AVG CIRC LOSS RATE : 2 BPH ~ -AVG STATIC LOSS RATE : 1 BPH Printed 5/27/2010 9:23:24AM r~ North America -ALASKA - BP Page 9 of 11 Operation Summary Report ---___ Common Well Name: MPJ-10 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 4/29/2010 ~ End Date: 5/8/2010 X4-0009E-E (300,000.00 ) Project: Milne Point Site: M Pt J Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 8/29/1994 12:0O:OOAM Rig Release: 5/8/2010 Rig Contractor: NABORS ALASKA DRILLING INC. ~ UWL Active Datum: ORIG KELLY BUSHING @54.2ft (above Mean Sea Level) Date From - To ~ Hrs Task Code NPT NPT Depth Phase Description of Operations ~ (hr) (ft) 06:00 - 13:00 _ 7.00 RUNCOM P RUNCMP pOH STANDING BACK 2-7/8" TUBING IN DERRICK. i -PULLED BLOWFLY TO AVOID SWABBING WITH THE 7" RBP. -STOPED EVERY 10 STANDS WHILE POH TO FLOW CHECK WELL. BEFORE CONTINUING TO POH VERIFIED DISPLACEMENTS AND ZERO FLOW. ~ -VERIFIED WELL WAS STATIC BEFORE PULLING I ~ ! (RBP THROUGH STACK. j I -TOTAL LOSS FOR TRIP WAS 2 BBLS 13:00 - 13:30 ' 0.50 RUNCOM ' P RUNCMP LD HES 7" RBP AND RUNNING TOOL. 13:30 - 14:00 0.50 RUNCOM P I RUNCMP MU TUBING HANGER TO LANDING JT. -PERFORMED A"DUMMY" RUN WITH THE TUBING ~ HANGER TO MARK LANDING JT. AND VERIFY POSITION OF ALIGNMENT PIN IN TUBING SPOOL. AS PER CAMERON REP __ __ 14:00 - 15:00 1.00 RUNCMM P RUNCMP _ RU TO RUN 2-7/8" ESP COMPLETION. I -CLEAN RIG FLOOR. I -RU TUBING HANDLING EQUIPMENT. -RUN ESP CABLE THROUGH SHEAVE AND TIE OFF ON RIG FLOOR. 15:00 - 17:00 2.00 RUNCOM P ____ _ RUNCMP RU FLOOR TO SERVICE ESP PUMP ASSEMBLY -PU ESP PUMP ASSEMBLY ( -INSPECT & SERVICE ESP PUMP ASSEMBLY _ _ _ 17:00 - 21:30 4.50 __ RUNCOM __ P RUNCMP RIH WITH 2-7/8" ESP COMPLETION ON STANDS FROM THE DERRICK ! -FLUSH PUMPS W/ 5BBLS AT EVERY CONDUCTIVITY TEST (-2,000') 21:30 - 22:00 0.50 RUNCMM P _ RUNCMP pTSM -CREW CHANGE OUT, DAILY CHECKS AND ENVIRO WALK AROUNDS 22:00 - 23:30 1.50 RUNCOM _ P __ RUNCMP RIH WITH 2-7/8" ESP COMPLETION ON STANDS FROM THE DERRICK I -RIH TO 7,606' ON 239 JNT I -137-LASALLE CLAMPS , 5-PROTECTOLIZERS , I 3-ARMSTERGUARDS i 23:30 - 00:00 0.50 RUNCOM P RUNCMP pU MU HANGER AND PENETRATOR ~ -MU LJ TO HANGER -MU FIELD CONNECTION & TEST- GOOD TEST 5/8/2010 ' 00:00 - 01:30 1.50 RUNCOM P i RUNCMP PU MU HANGER AND PENETRATOR -MU LJ TO HANGER -MAKE FIELD CONNECTION SPLICE WITH i I CENTRILIFT REP & TEST, GOOD TEST ~ -CLEAN AND CLEAR RIG FLOOR - -- i 01:30 - 02:00 ~ 0.50 _--_ RUNCOM ~ r-.-___ P ___.- RUNCMP LAND HANGER , PU WT 55K , SO WT 40K ' -CAMERON RILDS -TESTED SEALS ON THE WKM TO MAKE SURE HANGER WAS PROPERLY SEATED. -LD LANDING JNT IN PIPE SHED Printed 5127/2010 9:23:24AM North America -ALASKA - BP Page 10 of 11 Operation Summary Report _ _ --- _- Common Well Name: MPJ-10 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 4/29/2010 End Date: 5/8/2010 X4-OOQ9F-E (300,000.00 ) Project: Milne Point Site: M Pt J Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 8/29/1994 12:0O:OOAM Rig Release: 5/8/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @54.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations __ (hr) (ft) ~ 02:00 - 03:00 ! 1.00 _ WHSUR _ P I RUNCMP i CAMERON SET TWC -TEST FROM ABOVE TO 1,000 PSI FOR 10 i CHARTED MIN. POSITIVE TEST -TESTED FROM BELOW, HELD 550 PSI FOR 15 ~ MIN ,TEST CHARTED _ 03:00 - 04:30 ~ __ I 1.50 _ _ WHSUR ~ P RUNCMP NA 13-5/8" BOP 04:30 - 05:00 0.50 WHSUR P ' RUNCMP NU 2-9/16" WKM TREE AND ADAPTER FLANGE 05:00 - 06:00 1.00 WHSUR N HMAN RUNCMP BEFORE NU TREE THE CAMERON WELL HEAD REP REALIZED THAT THE WRONG PENETRATOR ( HAD BEEN INSTALLED. -CENTRILIFT WAS CALLED BACK OUT TO ~ INVESTIGATE: ~ I -THE MODEL NUMBER OF THE PENETRATOR INSTALLED MATCHED WHAT WAS INDICATED ON CENTRILIfT'S RUNNING SHEET. -THERE ARE 2DIFFERENT TYPES OF PENETRATORS THAT CAN BE USED WHEN RUNNING A WKM WELLHEAD AND CAMERON TREE. THE MODEL NUMBERS ON THOSE TWO PENETRATORS DIFFERS ONLY BY THE LAST DIGIT. WHEN THE COMPLETION WAS RUN IN 2006 THE WRONG MODEL NUMBER WAS I ENTERED INTO THE PAPERWORK. i -THE MAIN PHYSICAL DIFFERENCE BETWEEN THE TWO PENETRATORS IS THE LOCATION OF i THE O-RING SEALS ON THE PROFILE AND THE ~ OVERALL LENGTH OF THE PENETRATOR ITSELF. I -NEITHER THE CENTRILIFT REP OR THE ~ CAMERON REP NOTICED THAT THE PENETRATOR INSTALLED WAS DIFFERENT i THAN THE ONE THAT WAS REMOVED SEVERAL _ _____ _ ~ I DAYS PRIOR. 06:00 - 06:30 ______ 0.50 __ WHSUR N ~ HMAN ~ RUNCMP CREW CHANGE PERFORM PRE-TOUR CHECKS AND SERVICE RIG. ~ PERFORM ENVIRONMENTAL WALK AROUND. _ ~ ~ ~ -INSPECT ALL EQUIPMENT. 06:30 - 08:00 1.50 WHSUR I N HMAN _ ______ _ _ RUNCMP ~ __ NU 13-5/8" BOP STACK. 08:00 - 08:30 0.50 WHSUR - ----- N HMAN RUNCMP -- PRESSURE TEST BOP BREAKS. - 250 PSI LOW AND 3500 PSI HIGH FOR 5 I CHARTED MINUTES. -GOOD TEST. 08:30 - 10:00 1.50 WHSUR N HMAN _ RUNCMP WAIT FOR MPU WELL SUPPORT TO PULL TWC. -MPU WELL SUPPORT HAD JUST RIGGED UPON ~ MPE-11 WHEN CALLED WITH A 40 MIN HEADS U P. -THE 7" X 4" OTIS XO THAT IS USED FOR THE DUTCH SYSTEM TO THE MPU LUBRICATOR WAS I ON MPL PAD WITH THE SCHLUMBERGER COIL _ ___~ __ ~ _~ _ UNIT. HAD TO WAIT FOR THAT TO BE LOCATED AND PICKED UP. Printed 5/27/2010 9:23:24AM i ~~ North America -ALASKA - BP Page 11 of 11 Operation Summary Report Common Well Name: MPJ-10 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 4/29/2010 End Date: 5/8/2010 X4-0009E-E (300,000.00 ) Project: Milne Point Site: M Pt J Pad Rig Name/No.: NABORS 4ES Spud DatelTime: 8/29/1994 12:0O:OOAM Rig Release: 5/8/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @54.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 10:30 _ _ 0.50 WHSUR N HMAN __ RUNCMP RU MPU LUBRICATOR AND TEST WITH DIESEL TO 500 PSI. PULL TWC AND RD MPU ~ LUBRICATOR. _ ___ _ 10:30 - 11:30 _ 1.00 __ _ __ WHSUR ___ N HMAN ___ RUNCMP pU LANDING JOINT AND MU TO HANGER : ~ BOLDS IN HANGER. ~ -PULL HANGER TO THE FLOOR WITH 57K LBS ' UP WEIGHT. __ ____ 11:30 - 12:00 i 0.50 _ __ WHSUR _ N HMAN __ ___ ; _ RUNCMP .UNPLUG ESP PENETRATOR LEAD FROM PENETRATOR AND REMOVE THE INCORRECT PENETRATOR FROM THE TUBING HANGER. ~ RE-INSTALL THE CORRECT PENETRATOR IN THE HANGER AND RECONNECT ESP LEAD. VERIFY THAT HANGER SEALS ARE IN GOOD CONDITION. ___ i 12:00 - 12:30 0.50 WHSUR N HMAN RUNCMP i _ RIH AND RE-LAND TUBING HANGER. ' -PU = 57K, S0 = 35K. 12 30 - 13:00 0.50 WHSUR N HMAN RUNCMP -RtLDS. CAMERON INSTALLED TWC IN TUBING HANGER ~ PROFILE WITH A T-BAR. -TEST TWC FROM BELOW TO 500 PSI FOR 10 CHARTED MINUTES -GOOD TEST. -TEST TWC FROM ABOVE TO 1000 PSI FOR 10 CHARTED MINUTES -GOOD TEST. 13:00 - 14:30 I 1.50 WHSUR N HMAN RUNCMP ND 13-5/8" BOP STACK AND STAND BACK. 14:30 - 16:30 2.00 WHSUR P RUNCMP NU 2-9/16" WKM TREE AND ADAPTER FLANGE. } -CENTRILIFT PERFORMED FINAL CHECKS. _ __ _ 16:30 - 17:00 0.50 - WHSUR P RUNCMP TEST TREE AND ADAPTER FLANGE WITH DIESEL ~ 17:00 - 18:00 I _ ' 1.00 WHSUR ; P RUNCMP TO 5000 PSI FOR 30 MINUTES. PU MPU WELL SUPPORT LUBRICATOR AND j ~ MAKE UP TO TREE. -FILL WITH DIESEL AND TEST TO 500 PSI FOR 5 MINUTES -GOOD TEST. -PULL TWC AND INSTALL BPV. -TEST BPV TO 500 PSI FOR 5 MINUTES -GOOD TEST. i -CHANGE OUT FLANGE ON IA ~ **RIG RELEASE @ 18:00 HRS** Printed 5/27/2010 9:23:24AM Tree: 2 9/16" - 5M CIW Wellhead: 11" x 2 9/16" 5M WKM w/ TDF-CS-1 tbg hgr, 2 7/8" EU 8rd T x B threads & 2.5 CIW `H' BPV profile 13 3/8' 54.5 #/ppf, K-55 115' '' NOtt': Alignment pin for hanger is bent or sheared off. Consideration due next RWO as for need to replace. 9 5/8", 40#/ft, L-80 Btrc. 2,664' 2 7/8" 6.5 ppf, L-80, 8rd EUE tbg (drift ID = 2.347", cap. = 0.00592 bpf) M PJ -10 Orig. KB Elev. = 65.75 (N 22E) Orig. GL Elev. = 34.60" RT To Tbg. Spool = 30.45' (N 4E) Camco 2 7/8" x 1" sidepocket KBMM GLM 135' KOP @ 630' Max. hole angle = 39 deg. f/ 3,100' Hole angle thru' perfs = 20 deg 7" 26 ppf, L-80, NSCC production casing (drift ID = 6.151", cap. = 0.0383 bpf) 7" X 2 7/8" annular cap. _ .02758 bpf) Camco 2 7/8" x 1" sidepocket KBMM GLM 7394' Stimulation Summary 7" short joint marker at 7,519' wlm. Perforation Summary Ref log: 10/03/94 GR/CCL Size SPF Interval (TVD) 3-3/8 6 7,744'-7,76 ' 6,906'-6,927' 3-3/8 6 7,836'-7,91 ' 6,992'-7,062' 2-7/8" XN-Nipple 7535' (2.250" no-go id) Centrilift ESP SXD TC ' 119-P23 Tungsten Stg. 7548 Tungsten Gas Master 7566' Centrilift tandem seal section 7571' GSB3DBUT/LT SBlSB PFSA Centrilift KMH-A series, 7584' 190 HP motor, 2415 v. / 48 Amp PumpMate w/ 6 fin centralizer 7603' PumpMate TVD 6774' 7"x4" Baker F-1 perm. pkr. 7 636' 22' Baker weld 20 ga screen 7 658' 3.5" SWN nipple (2.75" no-go) 7 661' w/ pxn plug installed wleg 7 662' 7" Landing collar 8 161' 7" float collar (PBTD) 8,203' 7" float shoe 8,247' DATE REV. BY COMMENTS 10/31/94 jjm Coil Completion 10/13/98 MDO ESP completion 9/2/06 Lee Hulme ESP RWO 4ES 5/8/10 REH ESP RWO -Nabors 4ES MILNE POINT UNIT WELL J-10 API NO: 50-029-22500 BP EXPLORATION (AK) ~. ~~ SFr z ~ za~~ STATE OF ALASKA ALA A OIL AND GAS CONSERVATION COM SJ~rslka~ Otl + 's'~sj~si~pn REPORT OF SUNDRY WELL OPERATIONS ~~'~ .. 1. Operations Abandon ~ Repair Well ~' Plug Perforations ~ Stimulated Other ~ SEAL-TITS Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory ~~ 194-1100 ' 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-22500-00-00 7. KB Elevation (ft): 9. Well Name and Number: 65 KB MPJ-10 8. Property Designation: 10. Field/Pool(s): ADLO-025906 - MILNE POINT Field/ KUPARUK RIVER OIL Pool 11. Present Well Condition Summary: Total Depth measured 8265 ' feet Plugs (measured) None true vertical 7401.21. feet (measured) None J unk qq ~~,gq {~ d,:~r~ .. Effective Depth measured 8160 feet ` true vertical 7300.65 feet Casing, Length Size MD TVD Burst Collapse Conductor 80' 13-3l8" 54.4# K-55 Surface - 112' Surface - 112' 3580 2090 Surface 2633' 9-5/8" 40# L-80 Surface - 2664' Surface - 2432' 5750 3090 Production 8218' 7" 26# L-80 Surface - 8247' Surface - 7348' 7240 5410 Perforation depth: Measured depth: 7744 - 7766 7836 - 7860 7860 - 7886 7886 - 7910 _ True Vertical depth: 6906.22 - 6926.86 6992.65 - 7015.25 7015.25 - 7039.76 7039.76 - 7062.43 _ Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 Surface - 7609' 2-7/8" 6.5# L-80 7636' - 7662' Packers and SSSV (type and measured depth) 7"X4" BAKER F-1 PERM PACKER 7636' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 190 33 929 382 Subsequent to operation: 187 38 1109 324 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas WAG ~' GINJ WINJ ~ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer 'r Signature ~,,,• Phone 564-4944 Date 12/12/2007 7 Form 10-404 Revi ed 04/2006 ~ IJ Submit Original Only ~~,,. ~11-1~ ~ ~ 2007 • • MPJ-10 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVtTYDATE `SUMMARY 10/26/2007 T/I/0=S-1/650/120. (Bradenhead leak). Pressure up on OA to 500 psi. ;Bradenhead started leaking. Bleed OA pressure down to 0 psi. FWHP=S- '; (/650/0. 11 /15/2007 T/IA/OA= SSV/980/0 Temp=S1 Assist Seal-Tite International (Gel-Seal 'Treatment ) RU Triplex onto OA valve, PT outer annuls to 200 psi verify leak path. RU Seal-tite sealant pumps through triplex PT to 500 psi for 30 minutes pressure dropped to 350 psi. Pressured to 700 psi for 30 minutes pressure drop to 500 ...psi, re pressurized to 700 psi pressure dropped to 620 psi very quick, unsure of '.pressure drop where leak path is no apparent raise of pressure on IA. RD test equipment left pressure on well will continue on 11/ 16 "` Continue on 11/ 16 ** _. ~~__w 11!15/2007 T/110 =SSV/970/130. Assist wJ Seaf-Tite (mitigate startinghead leak). IAP ~~ increased 320 psi, OAP increased 10 psi since 10/26/07. OA FL @ surface. Bled OAP from 130 psi to 0 psi in 10 mins (bled back 10 gal fluid). Pumped seal-Tite into OA to 750 psi, See Cameron WSR for pressure info. FWHP's = SSV/970/500. __,_. 11/17/2007 T/IA/OA= 0/900/450 Temp=S1 (warm) Assist Seal-tite International (Gel-Seal treatment ) RU Seal-Tite pump onto OA outlet valve, pressured OA to 1100 psi w/ Gel- Seal. SI OA valve, will bleed in morning, with pressure reading. *`'' Continue Job on 11/18/07 '""' _~_ ___~_ . „_._ ...,, _a ~_ __ ' 11/17/2007 T/I/O =SSV/970/400. Assist Seal-Tite (SH leak). FWHP's =SSV/970/1000. _._ __.. __, _ __ __ .,. ~...._ .~~ .,..~,..__._ ..~... e . ___ 11/18/2007 T/I/0= SSV/970/1000. Temp= SI. Assist Sealtite (SH leak). Bled OAP to slop trailer from 1000 psi to 320 psi in 5 minutes hour. No change in pressures. Final WHP's= SSV/970/320. OA FL C«~ surface. . Monitored for 1 11/18/2007 T/IA/OA= 0/900/1000 Temp=S1 (warm) Assist Seal-Tite (Gel-Seal Treatment) RU to OA valve 1000 psi bleed to 320 psi, OA annuls did not lose pressure in 24 hours, no visual leak from previous leak path on starting. head threads. 11/26/2007T/I/0=300/350/960.~BIeed OA. Bled OA from 960 psi to 100 psi in 3 minutes. ;:Final WHP'S = 300/350/100 12/9/2007'ASRC Unit 1 flow and test MPJ-10 "Job Complete* MPJ-14 possible surface casing leak Page l of 1 • Regg, James B (DOA From: MPU, Wells Ops Coord [MPUWeIIsOpsCoord@BP.com] ~„ ~ `~;`~ f (C7 Sent: Saturday, October 13, 2007 9:11 AM ,~'~ ~ To: NSU, ADW Well Integrity Engineer; MPU, Well Operations Supervisor; MPU, Wells Ops Coord; Regg, James B (DOA) Cc: MPU, Field Lead Tech ~(~~ _ y' O Subject: MPJ-10 possible surface casing leak J 1 Andrea, When conducting an SVS test on MPJ-10 (10/12/07) I noticed residual diesel in drip tray below Braden head. I looked in the weflfile and there was no indication of any problem. I had an MITOA conducted to verify good integrity. During MITOA did /~ incremental step test to 2000 psi. Pressures held until we approached 2000 psi. OA pressure immediately fell off to 1500 psi. Bled pressure off and retested again. Pressures held until approaching 2000 psi then OA pressure fell off to 1100 psi. continued pumping to establish leak rate. I was informed of the MITOA results this morning and we then shut in the well. We would like the DHD crew to come out and do an MITOA with N2 to determine if we have an open shoe or a leak in the surface casing. NOTE: there was no indication of fluid to surface when conducting MITOA. Please call with questions or concerns. Thank you, Rob Handy MPU Well Operations Coordinator ~~~~ NL''~~ Q $ ~QQ~ (907) 670-3387 "~~ (907) 670-3390 Fax MPUWe1lsOpsCoord@bp.com 10/I 6/2007 ,). . " .,.~ . STATE OF ALASKA . ALA OIL AND GAS CONSERVATION COM ION OCT 042006 REPORT OF SUNDRY WELL OPERA TION~laska Oil & Gas Cons. Commission RECEIVED . 1. Operations Performed: " o Abandon ~ Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver ~ Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development o Exploratory 194-110 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22500-00-00 7. KB Elevation (ft): KBE = 65' 9. Well Name and Number: MPJ-10 8. Property Designation: 10. Field 1 Pool(s): ADL 025906 Milne Point Unit 1 Kuparuk River Sands 11. Present well condition summary Total depth: measured 8265 feet true vertical 7401 feet Plugs (measured) NIA Effective depth: measured 8160 feet Junk (measured) NIA true vertical 7301 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13-3/8" 112' 112' 3580 2090 Surface 2633' 9-5/8" 2664' 2432' 5750 3090 Intermediate Production 8218' 7" 8247' 7384' 7240 5410 Liner ;'C !\~t~~\~;':µ 'j''-?ü-;¡,..'. ..~'''C Perforation Depth MD (ft): 7744' - 7910' Perforation Depth TVD (ft): 6906' - 7062' 2-7/8",6.5# L-80 7609' Tubing Size (size, grade, and measured depth): ')-7/8" n 5# _.~- 1-80 7A~A' _ 7AA?' . Packers and SSSV (type and measured depth): 7" x 4" Baker 'F-1' Permanent Packer 7636' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS 8Ft 0 CT a 4 2006 13. Representative Daily AveraQe Production or Injection Data Oil-Bbl Gas-Met Water-Bbl CasinQ Pressure Tubina Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 241 25 522 350 324 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: ~ Daily Report of Well Operations o Exploratory ~ Development o Service 16. Well Status after proposed work: ~ Well Schematic Diagram ~Oil o Gas o WAG OGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact Bryan McLellan, 564-5516 Printed Name Sondra Stewman Title Technical Assistant -1 ~ Prepared By Name/Number: "nature ~:?\ (PI :/.~-1.-)" Phone 564-4750 Dattl) -Ü)'D(PSondra Stewman, 564-4750 . . Form 10-404 Reviséd 04/2lj R \ G \ l~ A L SubmIt Onglnal Only ! ... , ~ .1< Tree: 2 9/16" - 5M CIW Wellhead: 11" x 2 9/16" 5M WKM wI TDF-CS-1 tbg hgr, 2 7/8" EU 8rd T x B threads & 2.5 CIW 'H' BPV profile 13 318' 54.5 #/ppf, K-55 I 115' 95/8", 40#/ft, L-80 Btrc. I 2,664' I 2 718" 6.5 ppf, L-80, 8 rd EUE tbg (drift ID = 2.347", cap. = 0.00592 bpf) 7" 26 ppf, L-80, NSCC production casing (drift ID = 6.151", cap. = 0.0383 bpf) 7" X 2 7/8" annular cap. = ..02758 bpf) Stimulation Summary 7" short joint marker at 7,519' wlm. Peñoration Summary Ref loa: 10/03/94 GRlCCL Size SPF Interval (TVD) 3-3/8 6 7,744'-7,76 '6,906'-6,927' 3-31E 6 7,836'-7,91 ' 6,992'-7,062' MPJ-10 DATE REV. BY COMMENTS 10/31/94 jjm Coil Completion 10/13/9B MOO ESP com retion 4ES 11/10100 MDO ESP RWO 4 - ES 8/16104 Lee Hulm ESP RWO 4ES 9/2106 Lee Hulme ESP RWO 4ES Orig. lev. = 65.75 (N 22E) Orig. GL Elev. = 34.60" RT To Tbg. Spool = 30.45' (N 4E) Cameo 27/8" x 1" sidepocket KBMM GLM 135' I KOP @ 630' Max. hole angle = 39 deg. fl 3,100' Hole angle thru' perfs = 20 deg Cameo 27/8" x 1" sidepoeket KBMM GLM 17394' I 2-7/8" XN-Nipple I 7534' (2.250" no-go id) Centrilift GC 1700 ESP, I 7547' GPMTAR 1:1, 151 stage Tandem Gas Separator I 7565' GRSTX AR H6 (513 Series) Intake TVD I 6739' Centrilift tandem seal section 7570' GSB3DBUTIL TH6PFSAFLAS/HSN Centrilift KMH 562 series, 7584' 171 HP motor,.2390 v. I 44 Amp PumpMate wi 6 fin centralizer 7603' PumpMate TVD 6774' 7"x4" Baker F-1 perm. pkr. 22' Baker weld 20 ga screen 3.5" SWN nipple (2.75" no·go) wI pxn plug installed wleg 7636' 7658' 7661' 7662' 7" Landing collar 7" float collar (PBTD) 7" float shoe 8,161' 8,203' 8,247' MILNE POINT UNIT WELL J-10 API NO: 50-029-22500 BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-10 MPJ-10 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 8/30/2006 Rig Release: 9/3/2006 Rig Number: Spud Date: 8/29/1994 End: 9/3/2006 8/31/2006 06:00 - 12:30 6.50 MOB P PRE Rig down Sub Base and other modules. Move from MPC-14 to MPJ-10 Well Slot. 12:30 - 16:00 3.50 RIGU P PRE Spot Rig Components on MPJ Pad. Spot Rig over well slot MPJ-10. Raise and scope Derrick. Accepted Rig @ 16:00 hrs on 8/31/2006. 16:00 - 19:30 3.50 RIGU P DECOMP Begin taking hot 2% KCL into Pits. Rig up to Tree and prepare to circulate well clean. Pressure test lines to 3,500 psi and connect lines to Tiger Tank. Inital wellhead pressures: Tbg = 1050 psi and IA = 1000 psi. 19:30 - 20:30 1.00 KILL P DECOMP RU Lubricator with Well Support representative and pull BPV. Tbg pressure 950 psi and IA = 1050 psi. 20:30 - 21 :00 0.50 KILL P DECOMP RD Lubricator. Bleed gas off of well in preparation for well kill. After bleeding all the gas off the well into the Tiger Tank, the pressures were: Tbg = 480 psi, IA = 530 psi. 21 :00 - 23:00 2.00 KILL P DECOMP Begin pumping down the tubing taking returns up the IA and into the Tiger Tank. Break circulation at 1.5 bpm I 850 psi maintaing 650 psi on the IA. After stabilization, increase rate to 2.5 bpm 11100 psi maintaining 650 psi on the IA. Increase rate final time to 3 bpm 11150 psi with 750 psi on the IA. Pump a total of 60 bbls and shut in returns to bullhead. Bullhead 45 bbls (tubing volume) into the formation at 3 bpm 11700 psi. Open up the choke and begin circulating again at 3 bprn 11100 psi and 1150 on the IA. Maintain 1100 psi on the tubing as circulating the 2% KCL up the IA. Pumped a total of 355 bbls and shut down to monitor well (clean returns seen on surface). Pressures are: Tbg = 570 psi, IA = 570 psi. 23:00 - 00:00 1.00 KILL P DECOMP Monitor pressures on the well post·circulation. At midnight, the pressures are: Tbg = 510 psi, IA = 500 psi. 9/1/2006 00:00 - 05:30 5.50 KILL P DECOMP Continue monitoring well pressures. At 00:30 Tbg = 500 psi, fA = 490 psi. Calculate kill weight needed for next circulation. 500 psi (SITP) + 75 psi (safety factor) = 575 psi. Therefore, KMW = 575 psi 17000' (TV D) I .052 + 8.5 (2% KCL MW) = 10.1 ppg. Order out 575 bbls of 10.1 NaBr Brine. Truck may be delayed due to rig moves. RU Elephant Trunk Hose. Continue to monitor well. At 01 :00 hrs the pressures were: Tbg = 490 psi, IA = 490 psi. At 02:00 hrs, Tbg = 480 psi, IA = 480 psi. At 03:00 hrs, Tbg = 480 psi, IA = 470 psi. At 04:00 hrs, Tbg = 470 psi, IA = 470 psi. At 05:00 hrs, Tbg = 470 psi, IA = 460 psi. 05:30 - 07:00 1.50 KILL P DECOMP First load of 10.1 ppg on location. Begin fluid swap out of Pits to 10.1 ppg brine from 2% KCL. Continue to wait on next vac truck to commence well kill operations. 07:00 - 09:30 2.50 KILL P DECOMP Swap Well over to 10.1 Ib/gal Brine at 3 bpm/560 psi until returns were clean. Total Brine pumped = 330 bbls. 09:30 - 10:00 0.50 KILL P DECOMP Monitor Well dead. 10:00 - 11 :30 1.50 WHSUR P DECOMP Set TWC with Serviceman. Test TWC from below at 2 bpm 250 - 600 psi (bullhead into formation) x 10 minutes. Test TWC from top at 1,500 psi x 10 minutes. Record on Chart. 11 :30 - 13:30 2.00 WHSUR P DECOMP Nipple-down WKM Tree and Adaptor flange. Inspect hanger threads. 13:30 - 16:30 3.00 BOPSU P DECOMP Nipple-up Double Stub Adaptor, Test Spool, and BOP Stack. 16:30 - 20:30 4.00 BOPSU P DECOMP Rig-up test equipment. Test BOPE per BP/AOGCC requirements at 250/3500 psi. BOP Test witnessed by J. Crisp...AOGCC Rep. Bleed down and RD Test Equipment. Printed: 9/5/2006 11 :08:55 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-10 MPJ-10 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 8/30/2006 Rig Release: 9/3/2006 Rig Number: Spud Date: 8/29/1994 End: 9/3/2006 9/1/2006 20:30 - 21 :00 0.50 WHSUR P DECOMP RU Lubricator and pull TWC with Well Support representatives. 21 :00 - 22:00 1.00 PULL P DECOMP PJSM with Cameron and CentrUift representatives. BOLDS. MU Landing Joint and screw into Tubing Hanger (2 7/8" EUE 8rd Threads). Pull Hanger to the Rig Floor with an UW = 70K. Hanger came free at 70K. Fill hole with 10 bbls of 10.1 ppg brine. Cut ESP Cable and pull over Sheave. Break off Tubing Hanger and re-dress by Cameron reps. Lay down Landing Joint. 22:00 - 00:00 2.00 PULL P DECOMP Begin POH with existing 2 7/8" ESP Completion standing back Tubing in the Derrick. Visually inspect all joints as coming out of the hole. No visual indications of scale on Tubing. Maintain continuous hole fill. 91212006 00:00 - 03:00 3.00 PULL P DECOMP Continue POH with existing 2 7/8" ESP Completion. No indications of scale on any of the joints of Tubing. All joints of Tubing looked to be in good condition to be re-run. 03:00 - 06:00 3.00 PULL P DECOMP On surface with ESP Assembly. Break down ESP components with Centrilift reps. Cut ESP Cable and pull over Sheave to Spooling Unit. Put ESP components into boxes. RD Elephant Trunk Hose. Clear and clean Rig Floor. 06:00 - 06:30 0.50 P DECOMP Lub Rig. Inspect Derrick. Check PVT Alarms. 06:30 - 09:30 3.00 RUNCMP Pick-up and seNice new ESP Assembly. Pull ESP Cable over sheave. Attach to Motor. Test cable. 09:30 - 12:30 3.00 RUNCMP Trip in with ESP Assembly and 2 7/8" Tubing from Derrick. Stop to make armor splice. 12:30 - 13:30 RUNCMP Make armor splice. Cable ok. 13:30 - 16:00 RUNCMP Finish TIH with ESP Assembly and 2 718" Tubing. Ran a total of 239 Joints of 2718",6.5# L-80 EUE 8rd Tubing. Ran 132 LaSalle Clamps, 5 Protectolizers and 3 Flat Guards. 16:00 - 17:00 RUNCMP Make-up Tubing Hanger. MU Landing Joint. Cut and pull ESP cable over Sheave and install Penetrator. 17:00 - 18:00 1.00 RUNCMP Make field connection splice with CentrUift reps. Clear and clean Rig Floor. 18:00 - 19:00 1.00 RUNCMP Land Tubing Hanger and RILDS with Cameron representative. PU Wt = 70K , 8/0 Wt = 48K. Lay down Landing Joint in Pipe Shed. 19:00 - 20:00 1.00 WHSUR P RUNCMP Test lower set of seals on Hanger with Cameron rep. Set TWC with Cameron rep. Test from above to 1,000 psi for 10 minutes - charted. Attempt to test from below by pumping a total of 15 bbls down the backside at a rate of 3 bpm /700 psi - charted. 20:00 - 22:00 2.00 BOPSU P RUNCMP PJSM. NO BOPE. 22:00 - 00:00 2.00 WHSUR P RUNCMP NU 2 9/16" WKM Tree and Adapter Flange. 9/3/2006 00:00 - 01 :00 1.00 WHSUR P RUNCMP Make final checks on ESP. The phase to phase readings on all three phases were 3 ohms. The phase to ground readings on all three phases were 0 ohms. Got a 701 meg reading from the motor. Pressure at intake = 3470 psi. Motor Temp = 167.3 and Intake Temp = 165.2. Pressure test the Hanger void seal and Adapter to 5,000 psi for 30 minutes with Cameron representative - good. Pressure test Tree to 5,000 psi - good. 01 :00 - 03:00 2.00 WHSUR P RUNCMP RU Lubricator and pull TWC with Well Support Techs. Set BPV. Attempt to test BPV by pumping down the annulus at a rate of 2.5 bpm 11000 psi. Secure cellar and RDMO. Rig released at 03:00 hrs 9/3/2006. Printed: 9/512006 11 :08:55 AM ~ STATE OF ALASKA ""' ALASKA ,AL AND GAS CONSERVATION COlvilv1ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. A dress: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): II Repair Well 0 Plug Perforations II Pull Tubing 0 Perforate New Pool 0 Operation Shutdown 0 Perforate Change Out ESP 0 Stimulate II Other 0 Waiver 0 Time Extension 0 Re-Enter Suspended Well 4. Current Well Class: II Development 0 Exploratory 0 Stratigraphic 0 Service 99519-6612 KBE = 65' 194-110 6. API Number: 50-029-22500-00-00 9. Well Name and Number: MPJ-10 8. Property Designation: ADL 025906 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands 11. Present well condition summary Total depth: measured 8265 feet true vertical 7401 feet Plugs (measured) NIA Effective depth: measured 8160 feet Junk (measured) NIA true vertical 7301 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13-3/8" 112' 112' 3580 2090 Surface 2633' 9-5/8" 2664' 2432' 5750 3090 Intermediate Production 8218' 7" 8247' 7384' 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 7744' - 7910' 6906' - 7062' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 2-7/8",6.5# 2-7/8",6.5# 7" x 4" Baker 'F-1' Permanent Packer L-80 L-80 7591' 7636' - 7662' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and ~IßfL SEP 1 £1 ECE\\l~ SEP 1 3 2004 f' mm\SS\ot\ 01 & Gas Cons. ,,0 ?n~!as~a' ~nc\\ofaQe Oil-Bbl Re resentative Dail as-Met Tubin Pressure 13. Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run II Daily Report of Well Operations II Well Schematic Diagram 15. Well Class after proposed work: 0 Exploratory II Development 0 Service 16. Well Status after proposed work: II Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL Sundry Number or N/A if C.O. Exempt: Printed Name Sandra Stewman Title Technical Assistant CY N I Prepared By Name/Numbe~ Date O-\-lCTV'1 Sandra Stewman, 564-4750 Submit Original Only Tree: 29/16" - 5M FMC Wellhead: 7-1/16" 5M FMC wI 27/8" WKM Tubing Hanger, wI 3" Acme LH Thrds ,2.5" CIW H BPV profile 13 3/g' 54.5 #/ppf, K-55 I 115' 9 5/8", 40#/ft, L-80 Btrc. 1 2,664' 1 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg (drift 10 = 2.347", cap. = 0.00592 bpf) 7" 26 ppf, L-80, NSCC production casing (drift 10 = 6.151 ", cap. = 0.0383 bpf) 7" X 2 7/8" annular cap. = .02758 bpf) Stimulation Summary 7" short joint marker at 7,519' wlm. Perforation Summary Ref loa: 10103/94 GRlCCL Size SPF Interval (TVD) 3-3/8 6 7,744'-7,766' 6,906'-6,927' 3-3/8 6 7,836'-7,910' 6,992'-7,062' ~ MPJ-10 DATE REV. BY COMMENTS 10/31/94 jjm Coil Completion 10/13/98 MOO ESP completion 4ES 11/10/00 MOO ESP RWO 4 - ES 8/16/04 Lee Hulme ESP RWO 4ES ""' Orig. KB Elev. = 65.75 (N 22E) Orig. GL Elev. = 34.60" RT To Tbg. Spool = 30.45' (N 4E) Camco 2 7/8" x 1" sidepocket KBMM GLM I 135' I KOP @ 630' Max. hole angle = 39 deg. f/ 3,100' Hole angle thru' perfs = 20 deg Camco 2 7/8" x 1" side pocket KBMM GLM 17394' I I I 17565' Intake TVD I 6739' Centrilift tandem SFeasl Ssection I GSB3DBUT/LTH6PFSA LA IH N 2-7/8" XN-Nipple (2.250" no-go id) Centrilift GC 1700 ESP, GPMTAR 1:1, 151 stage Tandem Gas Separator GRSTX AR H6 (513 Series) Centrilift KMH 562 series, 171 HP motor, 2390 v. /44 Amp 7505' I 7547' I I I 7571' I 17584' 1 PumpMate wI 6 fin centralizer 1 7600' I PumpMate TVD I 6772' I 7"x4" Baker F-1 perm. pkr. 22' Baker weld 20 ga screen 3.5" SWN nipple ( 2.75" no-go) wI pxn plug installed wleg 7" Landing collar 7" float collar (PBTO) 7" float shoe 7.636' 7.658' 7.661' 7.662' I 8,161' I 8,203' I 8,247' MILNE POINT UNIT WELL J-1 0 API NO: 50..029-22500 BP EXPLORATION (AK) r" ""' 'i' BP EXPLORATION Page 1 of 1 Operations Summary Report legal Well Name: MPJ-10 Common Well Name: MPJ-10 Spud Date: 8/29/1994 Event Name: WORKOVER Start: 8/16/2004 End: Contractor Name: NABORS ALASKA DRilLING I Rig Release: 8/17/2004 Rig Name: NABORS 4ES Rig Number: I I Date From - To Hours Task Code NPT Phase I Description of Operations -- -- -- ----- -----._-------- -------.--- 8/16/2004 06:00 - 07:00 1.00 MOB P PRE Finish moving Rig and Equipment from MPF-Pad to MPJ-10. 07:00 - 09:00 2.00 RIGU P PRE Spot Sub Base, Pits, and Pipe Shed. Raise and scope Derrict. Spot Camp. 09:00 - 11 :30 2-50 RIGU P PRE Accept rig at 09:00 hrs. Take on 120 deg Sea Water in Pits. Spot Tiger Tank and lay Line. Hook up Lines to Production Tree. Pressure Test Lines at 3,500 psi. Pick-up Lubricator and pull BPV. Lay down Same. 11 :30 - 12:00 0.50 RIGU P PRE PJSM with All. Notify CTU of planned Well Kill Operations. 12:00 - 14:30 2.50 KILL P DECOMP Open Well. Tp = 350 psi. CSG = 680 psi. Bleed Gas. Circulate down Tbg with 1120 Deg Sea Water at 4 bpm/500. Pump Tbg Vol plus 20 bbls...close in Choke and Bullhead 20 bbl Csg Vol. Crack Choke and circulate out remaining Gas/Oil/Produced Water. Returns clean. Monitor. Well dead. 14:30 - 15:00 0.50 WHSUR P DECOMP Install TWC. Test. 15:00 - 16:00 1.00 WHSUR P DECOMP Nipple down Production Tree. 16:00 - 17:00 1.00 BOPSUF P DECOMP Nipple up BOPE. 17:00 - 20:00 3.00 BOPSUF P DECOMP Test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. Test witnessing waived by Jeff Jones wI AOGCC. 20:00 - 20:30 0.50 PULL P DECOMP P/U lubricator & pull TWC. UD lubricator. 20:30 - 21 :00 0.50 PULL P DECOMP M/U landing it. BOLDS. Pull hanger to floor wI 73K. Inspect & UD hanger & landing jt. 21:00 - 21:30 0.50 PULL DECOMP Pull ESP cable over sheave & connect to reel in spooler unit. 21 :30 - 00:00 2.50 PULL P DECOMP POOH w/2 7/8" ESP completion & stand back in derrick. 8/17/2004 00:00 - 00:30 0.50 PULL P DECOMP Finish POOH wI ESP completion. UD bottom 3 its. Check ESP cable & pump thru pump every 2000'. 00:30 - 02:00 1.50 PULL P DECOMP UD pump & motor. 02:00 - 03:00 1.00 PULL P DECOMP Clear & clean rig floor. Prep to P/U new ESP. 03:00 - 04:30 1.50 RUNCŒ P RUNCMP M/U pump & motor. Service & test same. 04:30 - 10:00 5.50 RUNCŒ P RUNCMP P/U 4 new jts. & RIH wI ESP completion. 10:00 - 10:30 0.50 RUNCŒ p RUNCMP P/U landing jt & M/U into hanger. Install penetrator. 10:30 - 13:00 2.50 RUNCŒ P RUNCMP Make field connection. Plug in & test same. 13:00 - 14:00 1.00 RUNCŒ p RUNCMP Land completion. P/U wt = 65K, S/O wt = 40K. RILDS. UD landing jt. Set TWC. Blow down lines. 14:00 - 15:00 1.00 BOPSUF P RUNCMP N/D BOPE. 15:00 - 16:30 1.50 WHSUR P RUNCMP N/U tree. Test void & tree to 5000psi, Ok. 16:30 - 18:00 1.50 WHSUR P RUNCMP Make final check on ESP cable. P/U lubricator & pull TWC. Install BPV. UD lubricator. Secure tree & cellar. RELEASE RIG @ 1800hrs. Printed: 8/23/2004 9:25:12 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Acidize ESP Pump Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 65 feet 3. Address Explorato~__ 7. Unit or Property name P. O. BoX 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Milne Point Unit 4. Location of well at surface 8. Well number 2759' FNL, 3318' FEL, Sec. 28, T13N, R10E, UM (asp's 552000, 6014918) MPJ-10 At top of productive interval 9. Permit number / approval number 970' FNL, 818' FEL, Sec. 28, T13N, R10E, UM (asp's 554483, 6016724) 194-110~ At effective depth 10. APl number 912' FNL, 728' FEL, Sec. 28, T13N, R10E, UM (asp's 554572, 6016783) 50-029-22500-00 At total depth 11. Field / Pool 898' FNL, 303' FEL, Sec. 28, T13N, R10E, UM (asp's 554997, 6016800) Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 8265 feet Plugs (measured) true vertical 7401 feet Effective depth: measured 8160 feet Junk (measured) true vertical 7301 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 80' 13-3/8" 250 sx Arcticset I (Approx 112' 112' Surface 2633' 9-5/8" 551 sx PF 'E', 250 sx 2664' 2432' Production 8218' 7" 330 sx Class 'G' 8247' 7384' Perforation depth: measured Open Perfs 7744'-7766', 7836'- 7910' ~ , . true vertical Open Perfs 6906' - 6927', 6992' - 7062' ~l~(a0il& OaS 0~$. Col~r~l!Ssior~ Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 7537'; 2-7/8". 6.5#, L-80 from 7636' to 7662'. ESP pump from 7537' to 7591'. Packers & SSSV (type & measured depth) 7" x 4" Baker 'F-I' permanent packer @ 7636'. Camco 2-7/8" x 1" sidepocket KBMM GLM @ 126'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 12/03/2001 431 205 480 352 Subsequent to operation 12/13/2001 433 209 577 341 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~w~.~J~ Title: Technical Assistant Date January 29, 2002 De Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE MPJ-10 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 12/07/2001 PUMPING: FREEZE PROTECT DUE TO FIELD SHUT DOWN. 12/08/2001 SLICKLINE: TAGGED ESP PUMP. 12/08/2001 ESP MAINTENACE: ESP ACID WASH 01/16/2002 PUMPING: SCALE INHIBITION EVENT SUMMARY 1 2/07/01 ESP PUMP LOCKED UP. FREEZE PROTECTED TUBING WITH 15 BBLS METHANOL AT 1.5 BPM/700 PSI. 1 2/O8/O 1 TAGGED ESP PUMP SHAFT. ATTEMPTED START WHILE BEATING ON SHAFT WITH BLIND BOX. NO LUCK. WILL PERFORM ESP ACID JOB AND ATTEMPT RESTART. 12/08/2001 ESP WOULD NOT START AFTER FIELD S/D. PUMPED 10 BBLS 7.5% ACID, 900 PSI DROP WHEN ACID HIT THE EXP. LET SOAK FOR 15 MINUTES AND STARTED ESP AT MINIMUM HZ, NO PROBLEM. RAN FOR 10 MINUTES IN RVS, FWD, RVS AND FWD TO A TANK, FLOWED BACK 190 BBLS UNTIL PH REACHED 6 AND PUT BACK INTO THE PRODUCTION HEADER. 01/16/2002 NO PROBLEMS ENCOUNTER DURING INHIBITION TREATMENT. USED 9 BBLS OF EC6085A DURING JOB. LEFT WELL SHUT-IN FOR 6 HOURS. ALL WATER WAS FILTERED TO 3 MICRONS. FLUIDS PUMPED BBLS 6O METHANOL 332 SOURCE WATER 137 CRUDE 10 7.5% DAD ACID 9 EC6085A ACID 548 TOTAL Page I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU' Julie Heusser, ;:~,~;-;\?- Commissioner - ,.~ Tom Maunder, ~..~Q-~ "~.. P. !. Supervisor ~h.~.,-~L\ FROM' Chuck Scheve; SUBJECT: Petroleum Inspector DATE: April 22, 2001 Safety Valve Tests Milne Point Unit J& I Pads Sunday April 22, 200!' I traveled to BPXs MPU J & I Pads and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 17 wells and 34 components with no failures. Lee Hulme performed the testing today; he demonstrated good test procedures and was a pleasure to work v~th. I also inspected the well houses on these pads during the SVS testing. All the welihouses were very clean and the equipment appeared to be in excellent condition. Summary: i witnessed SVS testing at BPXs MPU J & I Pads. MPU J Pad, 11 wells 22 components 0 failures MPU I Pad ~6wells 12 components 0 failures 23 wellhouse inspections Attachment: SVS MPU J Pad 4-22-01 CS SVS MPU I Pad 4-22-01 CS X Unclassified Confidential (Unclassified if doc. removed ) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Lee Hulme AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Milne Point / MPU / I Pad Separator psi: LPS 140 HPS 4/22/01 i i i i i i i i ii i i i i i ii i i i i -: - r I . _1 i[ IIL [ ii i i i i Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE I'.o 9oo'90o .................. 1-02 1900910 14b ' '1 O0 95 P P .......... OIL 1-03 1900920 " i40 100 95 P P .... OIL 1.04 1900930 "'146 loo ' 95 P~ P OIL 1-06 ' 197195b" 140 " ' 100 ' 95 P" 'P ' 6i[ 1-07 19515i'b.... 140 10~)' 95' V 'P OIL 1'08 1971920 '~40 100 95 P P Wells: 6 Components: 12 Failures: 0 Failure Rate: 0.00% E]9o var Remarks: RJF 1/16/01 Page 1 of 1 SVS MPU I Pad 4-22-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Lee Hulme AOGCC Rep: Chuck Scheve Submitted By: "Cl~ek Scheve Date: Field/Unit/Pad: Milne Point / MPU / J Pad Separator psi: LPS 140 HPS 4/22/01 i i i i i i i i i i [ ii ii i i i Well Pemit Separ Set ~ ~ Test TeSt T~t Date _Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE . J-01A 1991110 ' 140 " 100 95 "P" P OIL , J-03 1900970 140 100 95 e P OIL J-04 ' 1900980 ' "140 100 95 .... e ....... OiL J-05 1910950 140 100 95 ' P P .... OiL ~-06 ' 1940950 ' 140 100 125 "P p ....... OIL , ~ , ~, ,,,,, l, ,,, , . , ., .., , . J-07 1910970 140 100 95 P P OIL ., , , .~ ,. , , J-08A 1991170 140 100 95 P P OIL J-09A 1991140 140' ' ' 100 110 p "' e 'l ........ OIL , . , . , ., J-10 ,,1941,100 140~ ,, ~0q ,, 95 P p ,; .......... OIL J-11 1941140 j, 2 ,,, ...... 8 .... 972200 .............. J-19A 1951700 ' ........ J-2o" 972 So " ' J-21 1972000 140 100 .... 95 p '' p ' ~IL .., , ~, . ,, J-22 1981240 140 100 95 P P OIL , , .... , .., . . . . J-23 2001200 , . .,. ,. . .. ... . , , ,,. Wells: 11 Components: 22 Failures: 0 Failure Rate: 0.00% Remarks: RJF 1/16/01 Page 1 ofl SVS MPU J Pad 4-22-01 CS STATE OF ALASKA ~- ALASKA .c AND GAS CONSERVATION COMIV,._$1ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 65' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2520' NSL, 1961' EWL, SEC. 28, T13N, R10E, UM MPJ-10 At top of productive interval 9. Permit Number / Approval No. 194-110 4309' NSL, 4461' EWL, SEC. 28, T13N, R10E, UM 10. APl Number At effective depth 50-029-22500-00 4366' NSL, 4550' EWL, SEC. 28, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 4383' NSL, 4575' EWL, SEC. 28, T13N, R10E, UM Sands 12. Present well condition summary Total depth: measured 8265 feet Plugs (measured) true vertical 7401 feet Effective depth: measured 8160 feet Junk (measured) true vertical 7301 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 13-3/8" 250 sx Arcticset I (Approx.) 112' 112' Surface 2633' 9-5/8" 551 sx PF 'E', 250 sx 2664' 2432' Intermediate Production 8218' 7" 330 sx Class 'G' 8247' 7384' Liner Perforation depth: measured 7744' - 7766', 7836' - 7910' true vertical 6906' - 6927', 6993' - 7062' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 TO 7591'; 2-7/8", 6.5#, L-80 from 7636' to 7662' Packers and SSSV (type and measured depth) 7" x 4" Baker 'F-I' permanent packer at 7636' 13. Stimulation or cement squeeze summary r-~ Intervals treated (measured) BEC Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. Commission 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble Title Technical Assistant Date i ~' - Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 QRir IKIAI Submit In Duplicat"e~ ~ i OP rati summary Report Legal Well Name: MPJ-10 Common Well Name: MPJ-10 Spud Date: 8/29/1994 Event Name: REPAIR Start: 11/7/2000 End: Contractor Name: NABORS Rig Release: 11/10/2000 Group: RIG Rig Name: NABORS 4ES Rig Number: ~::~: :: i : Description of Operations 11/7/2000 23:00 - 23:59 0.98 RIGD POST :Rig down & prepare to move to MPJ-10 11/8/2000 00:00 - 08:00 8.00 CONS POST move in & rig up & level & spot rig & safe out equipment. 08:00 - 10:30 2.50 KILL COMP rig up to tree all lines & HCR valve & test same to 3000 psi. & rig lubricator & pull bpv. 10:30 - 21:00 10.50 KILL COMP Hold well kill PJSM. Tbg. Psi. 1200 Psi. Csg. 1300 Psi. & Circ. well bore influx out with 9.9 Ppg. brine & monitor same wel cont. to flow. Shut in well & get pressures Tbg. 80 annulus 120 . cont. to circ. & clean fluid & wait on Sodium brine & wt. up to 10.2 & kill well. & monitor same tbg. O-ann. 0 21:00 - 21:30 0.50 WHSUR COMP set twc& test same to 1000 psi. 21:30 - 23:00 1.50 WHSUR COMP nipple down tree. 23:00 - 23:59 0.98 BOPSUF COMP nipple up bop 11/9/2000 00:00 - 01:00 1.00 BOPSUF COMP nipple up bop. (Test Waived by John Crisp with AOGC) 01:00 - 04:00 3.00 BOPSUF COMP test bop's to 250-1ow & 3500 high. 04:00 - 05:30 1.50 BOPSUF COMP Rig lubricator & pull twc 05:30 - 07:00 1.50 PULL DECOMP mu landing jt and pull hanger to the floor. Pick up weight 65 K Test ESP and tie on to electrical cable spool 07:00 - 12:30 5.50 PULL DECOMP Pulled out of the hole with 2 7/8" completion string 12:30 - 14:30 2.00 PULL DECOMP Broke out and laid down ESP. Held pre job safety meeting with Co rep, crews, and Toolpusher on handling corrosion Inhibitorsump joints. Broke out and laid down same 14:30 - 15:00 0.50 PULL DECOMP clean rig floor, fill hole with 9 bbls and monitor well 15:00 - 15:30 0.50 WHSUR DECOMP Set 7" BPV in false bowl and test 250 psi 15:30 - 17:30 2.00 WHSUR DECOMP Nipple down BOP. Removed coiled completion spool and installed false bowl puller. 17:30 - 20:00 2.50 WHSUR DECOMP Install adapter spool and NU BOPE 20:00 - 20:30 0.50 WHSUR DECOMP Body test BOP to 250 psi/3000 psi. 20:30 - 21:00 0.50 PULL DECOMP pull false bowl Id same 21:00 - 23:30 2.50 RUNCOI~I COMP pick up and make up ESP pump assembly check cable, install fiat guards to pump assembly 23:30 - 00:00 0.50 RUNCOI~ COMP RIH with ESP and 2 7/8" tbg 11/10/2000 00:00 - 04:00 4.00 RUNCOI~ COMP cont. tih to 7590' circ. at 5800' 10-bbl. 04:00 - 07:00 3.00 RUNCOI~ COMP mu hanger & make esp connector at splice & land hanger. & set & test twc. 07:00 - 09:30 2.50 RUNCOr COMP nipple down bop 09:30 - 12:00 2.50 RUNCO~ COMP change out adapter fig on tree & install new one & tree & mu and test same to 5000 psi. & pull twc & set bpv & secure tree area. RECEIVED Alaska Oil & Gas Cons. Co~nission Anchorage Prin[ed: 11/28/2000 8:53:50 AM ON OR BEFORE W c:bORiX_~II, M.I>OC ,¢ ..... STATE OF ALASKA --- ALASKA O,_ AND GAS CONSERVATION COMIv,,SSION REPORT OF SUNDRY WELL OPERATIONS I. Operations performed: []Operation Shutdown []Stimulate [] Pull Tubing 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2520' NSL, 1961' EWL, SEC. 28, T13N, R10E, UM At top of productive interval 4310' NSL, 823' WEL, SEC. 28, T13N, R10E, UM At effective depth 4277' NSL, 873' WEL, SEC. 28, T13N, R10E, UM At total depth 4384' NSL, 709' WEL, SEC. 28, T13N, R10E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 2633' Intermediate Production 8218' Liner Perforation depth' measured true vertical [] Plugging [] Perforate ';" _.-...-;~:?~ ~. :..: []Alter Casing [] Repair Well [] Other Change Out ESP 6. Datum Elevation (DF or KB) KBE = 65' 5. Type of well' [] Development [] Exploratory [] Stratigraphic []Service 7. Unit or Property Name Milne Point Unit 8. Well Number MPJ-10 9. Permit Number / Approval No. 94-110 10. APl Number 50-029-22500 11. Field and Pool Milne Point Unit / Kuparuk River Sands 8265 feet Plugs (measured) 7401 feet i i 7636 feet Junk (measured) ii-~ i ' ' ~ ' i ;'~. 6805 feet .~ i\ ~ '...? ~ [",~ / ~,L.~ Size Cemented MD TVD 13-3/8" 250 sx Arcticset I (Approx.) 112' 112' 9-5/8" 551 sx PF 'E', 250 sx 2664' 2432' 7" 330 sx Class 'G' 8247' 7384' 7744'-7766', 7836'-7910' 6906'-6927', 6993'-7062' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE tubing to 7489'; 2-7/8" tubing with wire wrapped screen filled with scale inhibitor pellets from 7491' - 7560' Packers and SSSV (type and measured depth) 7" x 4" Baker F-1 permanent packer at 7636' Casing Pressure Tubing Pressure 13. Stimulation or cement squeeze summary Intervals treated (measured) Service Terrie Hubble, 564-4628 Submit In Duplicate-"~-~ Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl 15. Attachments I16. Status of well classifications as: [] Copies of Logs and Surveys run I [] Oil [] Gas [] Suspended [] Daily Report of Well Operations 17. I hereby certify that the f.~eregoing is, t, rue a. nd. ~rrect to the best of my knowledge Signed Terrie Hubble If~/~-- Title Technical Assistant III Prepared By Name/Number: Form 10-404 Rev. 06/15/88 Progress Report Facility M Pt J Pad Well MPJ-10 Page 1 Rig Nabors 4ES Date 10 February 99 Date/Time 07 Oct 98 08 Oct 98 09 Oct 98 10 Oct 98 11 Oct 98 12 Oct 98 13 Oct 98 22:00-06:00 10:30-13:00 13:00-17:30 17:30-19:30 19:30-00:30 00:30-01:00 01:00-05:00 05:00-06:00 06:00-09:00 09:00-11:00 11:00-12:00 12:00-13:30 13:30-17:00 17:00-19:30 19:30-20:00 20:00-21:30 21:30-01:00 01:00-02:00 02:00-06:00 06:00-07:00 07:00-23:30 23:30-00:30 00:30-01:30 01:30-02:30 02:30-03:00 03:00-04:00 04:00-06:00 06:00-06:30 06:30-12:00 12:00-13:30 13:30-20:00 20:00-21:30 21:30-23:00 23:00-01:00 01:00-02:00 02:00-03:30 03:30-05:30 05:30-06:00 06:00-06:15 06:15-06:30 06:30-09:00 09:00-13:00 13:00-15:00 15:00-18:00 18:00-18:15 18:15-19:30 19:30-20:00 20:00-23:00 23:00-23:15 23:15-23:30 23:30-03:30 03:30-04:30 04:30-05:00 05:00-06:00 Duration 8hr 2-1/2 hr 4-1/2 hr 2hr 5hr 1/2 hr 4hr lhr 3hr 2hr lhr 1-1/2 hr 3-1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr 3-1/2 hr lhr 4hr lhr 16-1/2 hr lhr lhr lhr 1/2 hr lhr 2hr 1/2 hr 5-1/2 hr 1-1/2 hr 6-1/2 hr 1-1/2 hr 1-1/2 hr 2hr lhr 1-1/2 hr 2hr 1/2 hr 1/4 hr 1/4 hr 2-1/2 hr 4hr 2hr 3hr 1/4 hr 1-1/4 hr 1/2hr 3hr 1/4 hr 1/4 hr 4hr lhr 1/2 hr lhr Activity Rig moved 100.00 % Bleed down well Circulated closed in well at 6589.0 ft Removed Xmas tree Installed BOP stack Tested Blind / Shear ram Serviced Blind / Shear ram Tested BOP stack Tested BOP stack Circulated at 7500.0 ft Pulled Tubing on retrieval string to 7500.0 ft Removed BOP stack Serviced Wellhead connector Rigged up BOP stack Tested BOP stack Removed Hanger plug Circulated at 7450.0 ft Held safety meeting Laid down 1850.0 ft of Tubing Held safety meeting Laid down 7473.0 ft of Tubing Rigged down sub-surface equipment - Debris barrier Rigged up Drillstring handling equipment Worked on BOP - Variable ram Tested Variable ram Made up BHA no. 1 R.I.H. to 2000.0 ft Held safety meeting Singled in drill pipe to 7632.0 ft Reverse circulated at 7632.0 ft Laid down 7632.0 ft of 3-1/2in OD drill pipe Worked on BOP - Variable ram Conducted slickline operations on Slickline equipment - Retrival run Rigged up Tubing handling equipment Functioned Slotted joint Installed ESP Ran Tubing to 2343.0 ft (2-7/8in OD) Pulled Tubing in stands to 1500.0 ft Held safety meeting Serviced Drillfloor / Derrick Pulled Tubing in stands to 0.0 ft Serviced Electrical submersible pumps Ran Tubing in stands to 2337.0 ft Ran Tubing to 5610.0 ft (2-7/8in OD) Held safety meeting Ran Tubing to 7540.0 ft (2-7/8in OD) Installed Tubing hanger Serviced Electric cable Ran Tubing on landing string to 7560.0 ft Installed Hanger plug Repaired Blind / Shear ram Removed BOP stack Installed Xmas tree Tested Xmas tree Progress Report Facility M Pt J Pad Well MPJ- 10 Rig Nabors 4ES Page 2 Date 10 February 99 Date/Time 06:00-06:30 06:30-07:00 07:00-07:30 07:30-08:30 Duration 1/2 hr 1/2 hr 1/2 hr lhr Activity Tested Xmas tree (cont...) Retrieved Hanger plug Installed Hanger plug Freeze protect well - 19.000 bbl of Diesel i.--':' E R H I T D A"F A T D A T A_.F' L U E; 96 .... i'i0 i 'i 0 i i 0 i10 {:i 299 63i2 ::3 U RV E Y ('.: ,'.3 L CCL. C: D N / D C CDN/DC C D R / D C (-: D R/D C (30 I'11 j) ,:: O J'4 F' lO/ 'i 5/' 9~.~ '1 i / 0 :;/ · 1 i ,/ i f!; / !:il h. '1 i ,.' 'i 8/9 ~".~ '1 i I i 8/.::, ~'~ ~. 'l 'J / {.'.1 ,/-t I' ~.)LI I 0 / I :-1'~ / !;', ~ i 'J/0tl./9~. [) i /' 'J () /' 9 5 (..:~ 'j ./' 'j (}/' 9 5 i 0/' i "2.,,' 9 i O/ J 2/' 9L~. ,,% i'"e Ar'::. we i'l ','e i'i '¥ s C O H ki El N T S 500 W. International Airport Road Anchorage, Alaska 99518-1199 (907) 562-7669 January 9,1995 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the LWD DEPTH CORRECTED CDR & CDN TVD for well MPJ-10, Job # 94384 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 3 Bluelines 1 Film S_tat e_of Ata~k~: :~:-- - - --~-Al~ka Oil & Gas Conservation Comm. /"~"~ Attn' Larry Grant .3001 Porcupine Drive -~-~"-~Anchorage, Alaska 99501 --~_ ---~ - _ . I Blueline '-~", 1 RFold~.d Sepia OXY USA, Inc Attn: Erma Galindo P.O. Box 50250 Midland, Texas 79710 1 Blueline 1 RFolded Sepia Sent Certified Mail P 905 127 757 PLEASE BP EXPLORATION (ALASKA) INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 Schlumberger Courier: Date Delivered: Received By: PERMIT DATA Ge~-~gical Materials Inventor~'~"~ T DATA_PLUS Date' 11/28/94 RUN DATE_RECVD 94-110 6312 94-110 6299 94-110 SURVEY 94-110 DWOP 94-110 407 94-110 GR/CL 94-110 CL T 2607-8272 OH/CDR/CDN 1-2 T 7300-8158 CH/GR/CCL 1 R 0.00-8043.86 ANADRILL~ R 08/29-0z37~9 ~ R COMP DATE: 10/31/94 L 7300-8158 1 L 2930-3066 1 94-110 CDR/DC L 2670-8200 COMP 94-110 CDN/DC L 4700-8200 COMP 94-110 CCL L 7460-7710 1 94-110 CCL L 7430-8130 1 94-110 1 L 7400-7850 1 Are dry ditch samples required~~y~ no And received? Was ttne well cored? ~~. Analysis & description received? Are well tests requ~d?~/~ Received? yes no Well is in compliance Initial COMMENTS 11/03/94 10/15/94 11/16/94 11/16/94 11/16/94 10/12/94 10/12/94 11/03/94 11/03/94 11/04/94 10/13/94 11/04/94 yes no yes no STATE OF ALASKA ' ~''~ ~ ~-'~' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration (Alaska) inc. 94-110 3. Address 8. APl Number P. O. Box 196612, Anchora~le, Alaska 99519-6612 50- 029-22500 4. Location of well at surface ~---~-~1 9. Unit or Lease Name 2520' NSL, 1961' EWL, SEC. 28, T13N, RIOE i; ~;::;".i.;...i T.i '?,,~,-'! ~ V~-';~:I~D ' Milne Point Unit At Top Producing Interval ;~ i"/,,ii ! i ~ 10. Well Number ~' NSL, 709' WEL, SEC. 2& T13N, RIOE''~ .... ' .... :.~.A "'- Milne Point - Kuparuk River 5. Elevation in f~t (indi~te KB, DF, etc.) ~. Le~e Design~ion and ~rial No. KBE = 65' I ADL 25906 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Su~. or Aband. ~15. Water D~th, if offshore ~16. No. of Completions 8/29/94 9/3/94 10/31/94~ N/A feet MSL~ One 17. Total Depth (MD+TVD) 18. PI~ ~ck D~th (MD+~D) 19. Directional Survey 20. Depth where SSSV set ~1. Thickness of Permafrosl 8265' MD/7401' ~D 8160' MD~301' ~D ~ B ~ D LLC ~ 7~2' feet MD~ 1800' (Approx.) 22. Type Electric or Other Logs Run GR/CDN/CDR 23. CASI~, LINER AND C~EN~ R~D SE~I~ DE~ MD CASING SIZE ~. PER ~. G~DE TOP ~OU ~LE Sl~ C~~ ~O~ AMOU~ P~LED 13-3/8"' 54.5~ K-55 32' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40~ L-80 31' 2664' 12-1/4" 551 sx PF 'E"~50 sx 7" 26~ L-80 29' 824 7' 8-1/2" ~0 sx Class "G" 24. Pedorations open to Pr~uction (MD+TVD of Top and Bottom and 25. ~BI~ R~ORD interv~, size and number) SIZE DEP~ S~ (MD) PACKER SET (MD) Gun Diameter 3-3/8" 6 spf 2- 7/8~ HS- 70CM 754 7' 7636' MD ~D 7744~ 7766' 6906~6927' w/ ESP 7836~7910' 6993~7062' 26. ACID, F~C~RE, CEME~ ~UE~ ~C. DEP~ I~ERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRO~ TEST Date First Production lMeth~ of Operation (Flowing, g~ lift, etc.) 11/4/94 I ESP Date of Test Hours Tested PR~T~ FOR OIL-BBL GA~MCF WATER-BBL C~ESI~ IGAS-OIL RATIO I ~ST ~R~D Flow Tubing Casing Pre~um 3ALCU~TED OIL-BBL GAS-MCF ~ATER-BBL OIL GRAVITY-APl (corr) Press. 2~HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fra~ures, apparent dips, and presence of oil, g~ or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Kuparuk C Sand 7654' 6757' Top A Sand 7821' 6914' Base A Sand 7949' 7035' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ./ ~ '~-~ ~.~J~"L Title DrillinaEn~ineerSu~ervisor Date / / /6 ~? 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 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. ~ ~ C ~ 1~! ~ !) .. Item 28: If no cores taken, indicate "none". Form 10-407 1,~,5~{~ 0[~ ~' ~S ~0[~;. (";0~[~55~0~ MP J-lO 08/29/94 625' MOVE RIG FROM J-08 TO J-10. NU 20" DIVERTER AND MIX SPUD MUD. STRAP AND PU BHA #1. ACCEPTED RIG @1800 HR'S ON 08/28/94. SPUD AND DRILL F/110-625'. 08/30/94 2,680' DRILL F/625-1464'. SHORT TRIP TO JARS. REAM 1180-1464'. NO PROBLEMS. DRILL F/1464-2680'. CIRC BOTI'OMS UP. SHORT TRIP TO JARS. NO PROBLEMS. CIRC BO'I-rOMS UP. DROP EMS AND POH. POH AND LD BHA. CLEAR RIG FLOOR AND RU TO RUN 9 5/8" CASING. RUNNING 9 5/8" CASING. 08/31/94 2,680' FINISH RUNNING 9 5/8" CASING. SHOE @2664'. MU CEMENT HEAD AND WASH DOWN 12' TO BOTTOM. CIRC AND COND MUD. RU HOWCO. TEST LINES. DROP BOTTOM PLUG. MIX AND PUMP 551 SXS @ 12 PPG. TAIL WITH 250 SXS "C" @ 15.6 PPG. DROP TOP PLUG AND PUMP 10 BBL'S WATER. DISPLACE WITH 185 BBL'S MUD WITH RIG PUMPS. BUMP PLUG. FLOATS HELD. LD CEMENT HEAD AND LANDING JT. ND DIVERTER. RU AND PUMP 200 SXS "C" TOP JOB. RD HOWCO AND CLEAR RIG FLOOR OF CASING EQUIP AND LONG BAILS. MU SPEED AND TORQUE TO 11000' LB's. NU 13 5/8" BOPE. TEST BOPE. SPEED HEAD APPEARED CROSS THREADED AFTER PUTTING ON STACK. PULLED TEST PLUG. CLOSED BLIND RAMS AND PRESSURED UP CASING. INSTALL LONG WEAR RING. PU BHA #2. SURFACE TEST MWD/LWD AND MOTOR. CUT AND SLIP DRILLING LINE. SERVICE TOP DRIVE. RIH TO FC @2578'. RE-TEST CASING. DRILL FLOAT EQUIPMENT AND CEMENT. 09/01/94 4,879' DRILL FLOAT EQUIPMENT AND 10' NEW FORMATION TO 2690'. RUN LOT WITH 8.9 PPG. DID NOT BREAK DOWN FORMATION. DRILL 8 1/2" HOLE FROM 2690-4026'. CIRC AND PUMP HI-VIS SWEEP. SHORT TRIP TO CASING SHOE. NO PROBLEMS. DRILL 8 1/2" HOLE FROM 4026-4879'. SHORT TRIP 10 STANDS. NO PROBLEMS. PUMP HI-VIS SWEEP AROUND. DROP EMS AND PUMP PILL. POH. RETRIEVE EMS, DOWN LOAD SOURCE AND LD MOTOR. MU BHA #3. TURBINE, MWD/LWD, ORIENT AND TEST SAME. RIH W/BHA #3. 09/02/94 6,832' SERVICE TOP DRIVE. FINISH RIH TO 4825'. MAD PASS TIE-IN WITH LWD/MWD FROM 4825-4879'. DRILL 8 1/2" HOLE F/4879-6832'. CIRC BOTTOMS UP. SHORT TRIP 30 STANDS. NO PROBLEMS. 09/03/94 8,022' FINISH SHORT TRIP. REAM through TIGHT SPOT @6780'. DRILLING 8 1/2" HOLE F/6832-8022'. CONTROL DRILL THROUGH SANDS. 09/04/94 8,265' DRILLING 8 1/2" HOLE F/8022-8265'. FINISH CIRC HI-VIS SWEEP AROUND. SHORT TRIP 20 STANDS. NO PROBLEMS. CIRC BOTTOMS UP AND SPOT 100 BBL THREATEN PILL ON BOTTOM. POH. LD 58 JTS DP. REPAIR SKATE. CONTINUE TO POH TO BHA. LD BHA AND DOWNLOAD SOURCE. CHANGE TOP RAMS TO 7", PULL WEAR RING AND TEST SEALS. RU TO RUN 7" CASING. RUNNING 7" 26# L-80 NSCC CASING. 09/05/94 8,265' FINISH RUNNING 7" CASING. MU LANDING JT AND CEMENT HEAD. HAD TO WASH LAST JT DOWN. TRYING TO PACK OFF. CIRC AND COND MUD AFTER LANDING HANGER. DID NOT RECIPROCATE CASING. RU HOWCO. TEST LINES. DISPLACE WITH RIG PUMP AND BUMP PLUG. FLOATS HELD. LOAD PLUGS AND OPEN ES CEMENTER. CIRC BOq-TOMS UP. PUMP 20 BBL'S WATER, 70 BBL'S SPACER FOLLOWED BY 110 SXS "G"/ DISPLACE W/RIG PUMP. BUMP PLUG. FLOATS HELD. CHANGE TOP RAMS TO 3 1/2" AND TEST. SET WEAR RING. CHANGE TOP DRIVE OVER TO 3 1/2"/ PU CLEAN OUT BHA, 3 1/2" DP AND RIH. DRILL OUT ES CEMENTER @4832'. CONTINUE PU 3 1/2" DP AND RIH. 09/06/94 8,265' FINISH PU 3 1/2" DP. TAG LANDING COLLAR @ 8161'. TEST CASING, OK. CIRC BOTTOMS UP. R/U AND REVERSE CIRC PUMP 30 BBL'S HI-VIS SWEEP, 50 BBL DIRT MAGNET, 30 BBL'S HI-VIS SWEEP. CIRC AND FILTER SOURCE WATER. POH. LD 3 1/2" DP. DISPLACED TOP 2000' OF 7" CASING WITH DIESEL. PULL WEAR RING AND INSTALL FALSE BOWL AND BPV. CHANGE RAMS AND TOP DRIVE TO 5". ND BOPE. NU AND TEST TREE. FREEZE PROTECT J-10 ANNULUS WITH 60 BBL'S DIESEL. RELEASE RIG @0300 HR'S ON 09/06/94. TO: PHILLIPS FROM: MELVAN/HINKEL WELL:MPJ-10 MAIN CATAGORY: DRLG SUB CATAGORY: FILL CLEANOUT LOCATION' ANCHORAGE DATE' 10-17-94 OPERATION' POST FRAC CARBOLITE CLEANOUT Status (psi) (psi) (psi) (psi) (psi) F) II I NA I o I NA I NA I AMa TIMEI OPERATION I 10/17 0700 MIRU NOWCAM 4905. SPOT UNIT, REV MANIFOLD, TANKS, ETC. RU TO REV. CIRC. PU FN & NZL. 10.30 NEW COIL. PUMP 1.25" BALL. PUMP 44 BBL MEOH. 1130 STOP @ 44 BBL- BALL NOT IN NZL-STOPPED IN CT SOMEWHERE. PREP TO PUMP PIG. 1330 PUMP FOAM PIG. SAW 200 PSI INC @ 6.2 BBL PUMPED THEN BALL POPPED FORWARD-TIGHT SPOT. 14.27 PRESS TEST BOPS. PIPES, SHEARS, BODY. 15.35 RETRIEVE MEOH. 16.38 RIH FINALLY. RETURNS. 17.48 550 1.3 100 CONT. DWN. SPIKES UP TO 11 PPG RETURNS. 19.00 1000 1.3 0 1150 200 PULL UP TO CHECK PIPE. OK. CONT IN HOLE. SAND MORE CONCENTRATED. 20.30 1500 1500 310 CONTINUE WASHING SAND. 22.55 2700 1600 500 CONTINUE WASHING SAND. 9.2 LB/GAL RETURNS. 10/18/94 00.03 3225 586 9.3 LBS/GAL RETURNS. 01.47 4000 722 04:00 5000 WEIGHT CHECK, 7000 LBS. 06.09 5810 1.0 1500 1060 9.6 LBS/GAL 06.32 5900 1.2 1800 1080 9.5 LBS/GAL PUH 06.35 5700 PARK NZL. LET COIL CLEAN UP. RETUN TANK ALMOST FULL. 06.59 1121 SD PUMP TO SWITCH LINE TO SECOND TANK. 07.24 5900 1.3 0 1600 1121 BACK TO REVERSING. 10.59 6580 1.27 1675 1405 STILL FULL RETURNS. 12.45 6900 A LI'I-rLE GAP IN THIS AREA. 14.44 7268 1.31 1250 1690 START TO LOOSE RETURNS- +/- 20% STOP TO CLEAN UP COIL. INC RATE TO 1.5 BPM. 15.21 " 700 1750 ADD CHOKE IN RETURNS LINE. START ADDING FRIC. REDUCER. 15.32 " 1.3 " CONTINUE REVERSING- LOOKS LIKE A GAP. 16.54 7465 " 1300 1860 GE'I-rING BACK INTO CARBOLITE. 18.05 7633 1.32 1550 HIT A ~H,~I~ ~I~6~T ~I~IEN WENT THROUGH SENT VIA MAC MAIL PAGE -1- 18.53 7755 1450 2018 SLCK WATER COMING AROUND NZL. 19.03 7786 1400 2031 RETURNS 1.0/9.4 LB/GAL. 19.19 7815 2051 HARD SPOT. 19.21 7820 2055 FELL THRU. 19.30 7836 1300 2067 AT TOP PERFS. RETURNS 1.0 BPM .9.0 LBS/GAL. 20.00 7819 1200 2110 THRU PERFORATIONS. CONTINUE INTO SUMP. 20.32 8000 2150 8.9 LB/GAL. 20.45 8140 2170 END SUMP CLEAN OUT. 20.55 7800 PUH. WEIGHT CHECK OFF BTM 15,000 LBS. 21.00 7810 2195 SHORT TRIP BACK TO BTM. 21.42 8140 2251 BACK TO BTM. PUH. 21.52 7675 2263 SWITCH TO JET. 22.15 1.25 650 2295 JETTO BTM ~25 FT/MIN. 22.18 PUH 22.22 7300 0 500 FINAL REVERSE BACK TO BTM. 23:00 8140 2337 PARK ON BTM. 23.05 2346 START POOH. 23.24 5700 2368 SWITCH TO METHANOL 10/19/94 00.36 Surf 600 2452 Out of hole. Close swab. 00.40 2483 Finish freeze protect coil. 01.00 Start to rig down. 02:45 Finish ri~ down. Move off location. Final Well DATE WHP lAP 0AP GLP FLT Status (psi) (psi) (psi) (psi) (o F) II 1°/19/94 I 6oo I .A I 0 I SUMMARY Run in hole with 3.4" nozzle. Found several ice plugs from 125 ft to 500 ft. Found top of carb-o-lite at approx 1000 ft. Reverse out sand down to 8140 ft CTD. Pulled nozzle up hole to 7675 ft. Jetted back to bottom. Pulled nozzle back up hole to 7300 ft. Made a final reverse trip back to bottom. (Started Iooseing returns on final reverse-out). Started to pull out of hole. Freeze protected well to 2000 ft with methanol and diesel. Finished out of hole. Close in well. Freeze protect coil. Rig down. FLUIDS PUMPED B BLS. DESCRIPTION 2368 SEAWATER, FILTERED TO 3 MICRONS 105 Methanol 10 Diesel SENT VIA MAC MAIL PAGE -2- TO: PHILLIPS FROM: HINKEL/MELVAN WELL: MPJ-10 MAIN CATAGORY: DRILLING SUB CATAGORY: COMPLETION PREP LOCATION: ANCHORAGE DATE: 10/22/94 OPERATION: RUN LLC VALVE II Initial Well I SIWHP I lAP I 0AP I GLP I FLP I FLT Status (psi) (psi) (psi) (psi) (psi) (o F) I!, 48s I NA I o I NA I NA I NA T I M E I OPERATION 21:00 MIRU Nowcam 4905 (C'IV 33 bbls/. Rig up flanged lubicator below BOP stack. 10/23/94 00:30 Coil hanging up in BOP Unable to get thru. Nipple down top section of lubicator. 01:00 Thru BOP. Nipple up lubicator again. 01:33 Install coil connector and pull test to 15,000 lbs. Good test. 01:40 Make up tool string. 02:00 Pressure test tools to 1500 psi. Good test. 02:15 Make up centralizer sub. (Had to dig hole in cellar to get tool under lubicatorI. 03.15 Pick up Camco LLC valve, seal ass},, and latch. 04:00 Press test lubicator. Leak, no test. Replace "O" ring. 04:20 Re-test lubicator to 2500 psi. Good test. 04:20 Open swab. "Read}, to go, finall}'! iw.. i BPM I CTP VOL'I REMARKS 04.30 Surf 0 500 500 Start RIH with LLC valve. 05.23 5000 Weight check 12,000 lbs. 05.48 7500 600 580 Up weight 16,500 lbs. Down weight 6200 lbs. 05.54 7642 Tag packer. Set down. Pick up twice. 05.58 Latched in. Cock jars at 27,000 lbs. 06.04 Fourth jar lick tool sheared. 06.08 7500 Pull up hole and park. 06.10 0 0 Open well to tank. Pressure fell to "zip". 06.12 Monitor wellhead returns-few drips. (Meoh in coil expanding) 0800 " ShLrt well in- No pressure buildup. Valve holding. 08.55 7590 1.5 2310 0 0 Begin brine circulation. 09.50 " 70 Start up hole slowl}'. 12.23 1000 310/0 Switch to MEOH to Frz prot coil. 12.55 0 At surface. RD/Secure well. 16.00 Leave Location. Final Well DATE WHP lAP 0AP GLP FLT Status (psi) (psi) (psi) (psi) (° F) 10/23/94 0 NA 50 NA NA SENT VIA MAC MAIL SUMMARY Run in hole with Camco liquid level control valve and tool string. Find packer at 7642 ft CTD. Latch LLC valve into packer. Unload jars with 10,000 lbs over normal "up wieght". Tool sheared on fourth jar lick. Bleed wellhead pressure to "0" and monitor. Returns fell off to nothing. Shut well in and monitored buildup pressure- no buildup. LLCV holding. Swapped well over to 10.1 ppg brine (310 bbl pumped). Frz protected wellhead and top 100 ft with MEOH and strung a little Meoh, 3 bbl, from 100 to 900 ft. FLUIDS PUMPED B L S. DESCRIPTION 0 SEAWATER, FILTERED TO 3 MICRONS 310 10.1 ppg brine. 38 MEOH 348 TOTAL BOTTOM-HOLE ASSEMBLY #1 Tool String Descriptions I O.D. I I.D. I Length I Comments Baker Fishing Neck 3 1/8" 1" .92" Check Valves 3.1/8" 1" 1.55" Jars 3 1/8" 1 1/4" 8.85" Hydraulic Disconnect 3 3/8" 13/16" 1.52" 7/8" Ball 2 7/8" flow couplings (4 ea w/centralizers). 5.75" 2.35" 15.01" 3.5" LLC-2 (Liquid Level Control Valve 5.71" 6.46" with runnin~l tool). Baker seal assy and latch 4.00" 3.00" 2.09" Total Tools 36'.40" SENT VIA MAC MAIL PAGE -2- ROSSBERG · om: Melvan / Dunham Location: ANCHORAGE Date: 10/27/94 Well: MP J-10 Operation: 2 7/8" COILED TUBING ESP COMPLETION I Main Category: DRLG- AFE330063 ! Sub CategorT: COMPLETION ! Well Status: Shut In I WHP (psi): 0 ! lAP Ipsi): o I GLP (psi) NA I OAR (psi): o I WHT (°F/ amb i TIME I ' "' .... OPER.~,TION .... 10/27 (BOP and DSR unit spotted during the night.)Rig up Nowcam 4907. Set 7 1/16" BOP and CT Window Section. Set 09.00 "deadmen" and string gu), wires. Spot unit, tank, cjenerator house. Run lines 1o BOP. 17.30 Test BOPE. Test Pipe Rams, Blind/Shear Rams, Blind Rams to 400 psi and 4000 psi. Test Hydril to 1~00 psi. spot ESP reel house and pump shack. Load pump cable spool. 20.00 Prep pump. Check pump oil. Load spool onto 4907. [REEL NO. 2142]~ Prep to stab pipe. .. Prep ESP equipment while finishing rig up. 23.26 Pick up P-gauge/mtr. intake. Fill motor and perform all motor Q/A on floor. PU pump section & bolt on same. Pre~ to stab 10/28 02.00 RU sheave and PU cable. Attach cable and band flat to pump with guards. Cut cross bar off reel. Connect new spool to old stub. Fill motor seals. 05.00 PU GLM assembl)' with pump head a~d check valve. PU injector head. Run dwn old coil and cut same. 06.00 Chain connector kinked over and jammed in lower part of inj head. 09.30 Chain link connector freed. Busted during freeing attempts. Pick up inj hd and secure to window. Run pipe down a few feet then it started binding up. Check out head with man lift. Work coil. No metal in chains. Looks like ice is affecting gripping of the pipe, causing early contact and scarring the pipe. De-ice chains with MECH. Run pipe dwn and cut out bad pipe. Pipe now running free. · 14.22 Flush coil w/70 bbl MECH. Returns Clean. Having trouble w/manlift as usual. Problem cleared up. Used 55' of flat cable and splice over to round cable. Used 9 protective trays over flat cable. 15.22 Stab coil tubing connector. Pull test to 40k. ( tried several stageS to calibrate electronic Icad cell/ 16.54 Pressure test Coil and Completion string to 2000 psi. , 18.05 Connect reel valve to bop's to take MEOH returns from coil. RU ladder. 18.15 Begin running in hole. At 350 ft of pipe in, injector started damaging pipe again. Snow still blowing. Still mo. re ice on reel. 19.00 Inspect inj hd and reel. No iron debris visible in inj head. Presume ice problem on chains and outside wrap on reel. 20.00 Wrap inj head in tarp and begin heating. Wrap reel and heat also to remove small pieces of hard ice. Tolerances too close on clam shell gripper s)'stem to accomodate it. Decide to cut out 390 ft of coil and start over. 23.30 Pull pump back to surface. Remove 15 bands Cut and drain coil. ,10/29 , 0100 Cut 413 ft of pipe. 0400 Restab connector. Pull test 20K. P-test 2K. Zero coil at floor. 05.30 Begin Running in hole again. Recover little ding in cable armor. Continue in. 07.00 Chk cable @ 20,00 fi. Continue running in hole 08.53 Chk cbl @ 3000 ft. Strg wt 25K 10.00 Chk chi ~ 400O ft Strg wt 22K 11.05 Chk chi ~ 5000 ft. 27K string wt. 11.40 Stop @ 5521, injector head gouged the coil again-no ice this time! Gouge not as bad as before- drift appears OK. Inspect head and coil damage. Damage will be at +/- 1900 ft. Order 10ft splice in case we decide to cut it out. Found another gouge. Analyze problem. Gouges match loose inserts. IQuite a few of the inj inserts appear to be loose. Found two more bolts sheared. Insert bolts are worn on several others, allowing inserts to rotate in carrier. This could be causing the pipe to get caught by the grippers at the top of the head just before the), close. Order more insert bolts and splice from deadhorse. When starting to replace bolts in inserts, special tool broke which had to be repaired. Re-all,In lower goose neck rollers- Possible cause of insert bolt breakage. 22.00 Begin replacing bolts in inserts. Not enough on slope to change all. 10/30 01.00 Drill and cut coil. Install splice, pull & P-T 05.10 Start running in a~lain. 05.30 Shut down again. Hydraulics problem. Discover hyd oil leak in power skid. Repair same. Found snap-rite on injector head return hose failed, not allowing r.eturn flow- head hydraulicall), locked. Replace same. Injector now working. 11.20 Continue in hole. 13.30 Stop Tag up @ 7489 CTD ! (only 7386 of coil in the hole per counter depth) TOP LLC 7631. Counter must have been slipping. Check everything out. Discuss tag and compute maximum set down on pump- l~k,.~ ,,i.U. ~ .~ ~8~..~ Check cable- 15.00 Decide to change out pup below hanger while discussing possibly running pump before~-'J'~,r{ttin~. ' 17.01 At hanger point. Prep to cut coil tubing. Prepare next location for CTU move while wait o,n, final..~de, cisio? ~i- ,. 18.15 Decide not to run pump before landing. .... '" · · ,' 19.00 Tbg hanger w/shorter pup arrives. Pick up tbg hanger and running tool. RU Hot oil and P~ Perform splice. .~1 Jl.00 Land Hanger. P-test han~ler seals to 2000 psi. Holding. Back out landing jr. Set 2-way check. 06.00 Rig down complete and equipment moved to J-11. Begin wellhead nipple up. Remove 7-1/16" valve. Nipple uptbg hanger bonnet and P/T. Nipple up tree. Open SSV w/FMC han. d pump. Rig up triplex and P/T tree. Close SSV. Leave 2 way check in tbg hanger. Completion completed. 15.30 ND 7-1/16" valve w/roustabout crew & FMC. NU bonnet & PT. NU Tree. 21.00 PT tree (Waited for pump to finish another job/ OPERATIONS SUMMARY Ran Centrilift type GC-1200 Series 513 pump w/tandem seals and Model KME, Series 562, 100 h.p. motor section, and CentriLift Check Valve. Ran Camco type KBMG Gas Lift Mandrel w/l" pocket, and DCK gas lift valve with DCK latch in place. Mandrel run 20 ft above Check Valve. Ran 7419 ft 2 7/8" 5.46# HS-70 Coil Tubing (2.495" I.D.) Hung string off in FMC 7 1/16" X 2 7/8" Tubing Hanger. Bottom of pump assembly at 7548 RKB. Ran 9 flat cable guards including 51 flat guard bands. Ran 369 preformed bands to fasten cable to coiled tubing. Lost 1 band into hole during operations. Inner annulus and tubing filled with 10.1 ppg brine. Pumped 2 bbl MEOH down 7" csg to frz protect. KBMG mandrel run w/DCK valve and BK5 latch set for 3500 psi tbg to casing shear. Due to injector head problems damaging pipe, a 2-7/8 by 10 ft pup splice had to be inserted @ 1910 ft BKB. Tree nippled up with 2 way check in hanger. 2.5" H BPV profile. 2 7/8" FMC tubing hanger with 2 7/8" ACME left hand threads on top and 8 rd threads on bottom. BOTTOM HOLE ASSEMBLY II i MAX O.D. I.D. LENGTH ITEM (InchesI (Inches// (FeetI P- Gauge 4.50 NA 1.98 Motor 5.62 NA 11.02 Seal Section 5.13 NA 12.62 Pump and Discharge head. 5.13 NA ,20.25 2 7/8" 6.5# L-80 EUE 8 RD. Tubing Pup 3.67 2.441 2.21 Centdlift CheCk Valve 3.7 NA 0.41 Pup 2 7/8" 6.5~ L-80 8 Rd. Tubing 3.67 2.441 10.21 XO Pup 2 7/8" 6.5# L-80 8 Rd. Tubing 3.67 2.441 9.80 GLM 4.7 2.441 6.5 XO Pup 2 7/8" 6.54¢ L-80 8 Rd. Tubing 3.67 2.441 3.72 Coiled ~ Conn, 4.25 " 1.9 2-7/8" Coiled tbg. 2.875 2.495 5542 , Splice (w/two coiled tubing connectors) 4.25 2.441 14.51 2-7/8" Coiled tbg. 2.875 2.495 1877 Coiled Tbg Conn. 4.25 2,495 1.9 Pup 2 7/8" 6.,54¢ L-80 8 Rd. Tubing 3.67 2.441 4.29 Hanger (to lock dwn screws/ 6.95 2.441 0.68 RKB to hanger lock dwn screws 27.00 Total Length 7548 LOCATION C- MAG)~'?IC D~LINATI[~4 28,95 WEU, t, ILI~-(EF: WELt. H~I:: L:CATION: LAT(R,'-S) 0~ ~iMbTH TF.OM M:~AR¥ TABLE TG ?A~ IS TI~ IN POINT_(TIF':', : INCLINATION 0,® AZl~_rn4 O,~ LAI ITUDE (N/-?: 0, ~j D~'~II.$',E -.'. ~. -" - W ) 0,~:, DBr'(E,'-W) O, .~?.' N RECEiVEr) ;" 0"i '! F, 'i?) 3 ~'- .~ ,,, ,'~.' ~.~s Crm~. commission TARG~ ~,-qTIDN AZII'UIH ~TITU3£ ~,19 0,14 0.50 0,28 ~ oo 0,S6 5,57 1.~ 0,12 282~% r;l~t~,f~.:¢ ~I8?t~[1~1T at h7.IMLrrd DL3 ft ft de.3 t,Y)t t -0,1~ 0,57, 341,11 0,21 -0,13 -0,21 I 54£,57 637,37 728,72 821.14 '13,32 8-9,5 ~2 '~1 ,S ,"28,53 %,4 8~.57 9'"2,2 9!1,96 1.--91 6,78 ~.,,45 1,91 -0, r~' 1 ,?I ..357...' ,43 ,7; ,".-~ 0 .... 1 4,3! 2.24 14,15 4.31 ~'~' 4,~ 7 8 % 4,16 ~,97 8,58 3,i5 9,i4 15.3 6,30 33,~ 151, o~.7.~ 8,14 17,~ £7,'<': 2,3'-.' ~4,72 ~.62 41,~ 24,72 15:~. ~.20 32,19 2.74 1006.3¢ ¢5:,1 I~33,58 ?2.4 1093,% 94,7 1184,71 96.8 1276.21 o.. ,o:~ 11.6i ~,I6 37.6':.' ~,~ 4.~, 4c, 34.04 3,5,, . 4~ ' ~ u .. . ~ we 55.~ 14,52 ~,~ 5~,~8 ~.,~ ~.,2~, ~,5'? .:,,,' Y 1Cx3,16 ~),72 3i,~ 1~,16 7t,~; I~.~ '5,~3 3,35 1477,56. 157,'0.42 166'7,53 17EQ.lO 94,4 1446,38 92,9 1528,54 97,1 1612,81 ~.6 1690,94 168,01 Z7,04 27,91 1.E4.,01 2¢%!4 2~,51 26,52 206,1~ 247.~: 31,12 ~,67 247,40 256.~ ~:.75 36,43 ~1,85 ~,S1 37,78 33!,85 ~u-, 1.7-' 110,52 20!,10 1~.96 ~.45 5~,23 3,76 184,~ ~2,03 32,64 3,26 217,.s7 ~6.87 1~1 2045,69 2142,90 2234,74 232g,Z7 1849,76 93.7 ,,-. tgi', 97.2 20O7,72 5'1,8 7a ~r, . . ~,,? 34,~; ~,16 374,49 417,9I ~,14 ~,74 417,91 4E,2,6~ 34.I6 34,'.~' 462,~ 505,18 34,71 35,14 505.18 547,82 34,77 38,58 547,82 248 '" '~ "" .o~ 449,50 o ..... o 2,1E 278,4~ 50£.15 3S,67 0,36 30~',60 556,71 33,7'~ 0,15 ST~.,44 .%g,,_q3 ~.'?0 0,61 o, 1,40 ~1,85 34,14 2,0~' 2419,03 ~21,52 ~%'.26 2713,23 2~8,92 D,8 ~4,40 102.5 2317.~ 77,7 114,0 2471 95.7 '~z..548.82 ~9,47 35,E,5 ~,,~ 549,47 6-%,93 36,10 39,62 636.93 672,51 36,Z 2.3,86 672,51 725-. ~ .... 36,~) 38,12 725,35 769,47 36,66 40,12 769,47 t03,27 714,22 34.30 440,~, ~4 511,.35' 8$7,50 35,1[' 547,28 944.25 35.42 25'03,94 2996,41 305.,'0,64. 3!84,61 3279,71 '~,0 2624,g~ 92,5 2697.45 94.2 2770.78 94,0 2M3.97 _95.1 2919.45 812.6~- 37,56 42,05 854,38 38,56 43,79 g96,69 3~,2~ 44.59 982.5~, ~..51 ~,~ 982.% 5,?,4.77 1~)1,3I 35,75 6~,76 1051.7,25 36.13 EJ.5,1! 1116.43 36.57 705,79 I174,f~ 744,22 12'52,59 37.14 1.54 1,12 2,21 3373,17 .3562,15 3750,a3 93.5 2%5,58 95_,.7 ~74.60 93,3 3151 96,8 323._.1,50 91,9 3307,C 10~,21 34,45 ~,17 1025,21 1C69,72 34.~ ~,71 1069,79 1113,68 34.50 33,03 1113,._'.% 1159,12 34.21 34,37 1159,1~ 1201,~ 33.83 34,98 '12~1.40 777,~ 12~,78 37,,16 4,I7 808,19 1~0.69 37,0? 0,8~' 837,15 1o~,23 '~ 0,51 ~.7,45 1447,76 896.69 14~.14 I~A~IRZD Ihri~VhL V~;TICAL D£PTH ft ft ft 3846,16 ~,S 3940,75 94,6 3468,33 403,57 94,.8 3550,74 4t30,71 95,,1 4,',o.o7 9"5.7 .a, l~'.~', TAF:G~T ~ATIC~4 AZIMUTH LATI TL~$ ft deo deg. ft 1243,8,1 32.34 ~,85 1243,~1 1319,~ 28 1~1,71 27,~ 47,01 I~1,71 1379,~ ~,~ 53,71 1379,20 D~'~ql.~:E: DI~F'L~CEMI~T at AZIPILKrI~ ft ft d.r-.g 926,~.4 t55i,lb 36,69 1600,o., F_'N6,, 70 956,4E. ' ""- 986,33 t647,17 36,78 1017,47 1671,85 36 ,?7 t050.~ 17._%,73 37 dea/ 100. ft t+ 3,44 4320,52 4416,14 4511,51 46Q$,66 4700,31 94,1 3,Aj~,,71 :,5,6 ~90:.A4 95,4 3976,31 94,2 406'.5.63 94,6 4145,.55 t402,26 25,80 57,96 1402,26 i422.73 %~. ,,v'"" &3,55 1422,73 143'.~',~ 25,~ 70,59 14~,06 1450.01 26,42 78,68 1450,01 14~,19 26,57 61,73 1457,1:,' ,.,~ 1772,71 ~7,72 1 1121,10 1611.36 3a,24 2,61 1159,67 1MB,17 3B,af 3,26 1!~%63 1881,~ ~,60 1241,23 1914,17 40,42 1 4792.il 4918,44 5011,~ 5201,01 91,8 4~7,65 126,3 4341,07 95.2 4510,22 94,5 4594.~3 146.2,69 26,5& 82,87 I462,69 1470,34 25,~ 61,C~ 1470,3m. 1476,61 ~,92 -SO,&$ 1476,61 148~,% 26,17 80,07 1~C:,53 14%,92 26~46 79,61 1490,92 1281.93 194~.94 4t ,~ 0.54 1376,~ 7.=1y,03 43,00 0,34 141~.: 16 2~2.33 43,71 0,45 1~'-7.~40 2.0~.31 44,~ 0,37 52~,I? 5395,81 5491.I? 5585,93 94,2 4679.13 1~6 47~,79 ~.4 4853,42 94,7 4~7,15 94,7 1498,26 26,.77 80,~ 1496,26 1505,~ 27,21 81,21 1_~:Y5,58 1512,55 27,71 80,55 1512,55 1520,11 28,08 79,81 lSD,11 1528,64 23..% 76,19 1528.~ 1500.55 2120,76 45,05 0,4E 1546,02 2158,03 45.76 0.59 1589,45 2194.12 46.42 1633,12 ~YJl,ll 47,05 0,54 1673,73 22./-4,74 47,5? 4?2 5772,43 5868,21 5970.11 6063,I9 6157.55 91.8 51e~,OB %,8 5193,37 101.9 52~,~09 93.1 537O,63 94,4 5456,19 1537,70 24,22 75.79 1537.70 1547,11 24.4I 76,5? 1547,11 1557,08. 24.61 76,13 1557,06 1566.6I 24,64 75.53 1566,61 1576,62 ~,O~ 75,32 1576,6£ 6~9.14 6351.02 6444,85 65~,47 101,6 5548,16 91.9 5631,t8 ~:.8 5715,79 ~4.6 500.1 96,0 5887 1586,94 ~,23 77,0I 1586,94 1595,89 25,52 76,70 1595,89 16C~,24 25,72 76,64 1./'05,24 1614,70 25,66 76,72 1614,7Q 1625,04 ~,10 74,t4 1625,04 1907.56 2481.37 50,24 0,73 1945.90 ~16.63 ~.~ 0,34 1985.~. ~3.14 51.0~ 0.22 20~,29 ~'~,18 51,44 0,07 2065,I3 2627,84 51,8~ 1,2~ 6729.67 .~03,20 6902,99 6%'7,&~ 7092.43 94,2 5973,10 73.5 60~,70 ';o ~ 6130,3'¢ 94.~ 6216,~ 94,5 &303,13 1&95,82 ~,09 74,56 1835,82 1644,11 25,06. 74,57 1644,11 1655.62 24.24 73,3~3 16~,62 1667,24 24,21 7I.98 I~,7,24 l&79,4& 24.28 71.34 l&79.4& 2103.59 "' ~664.,77 52.13 0,19 2133,62 26~a,& 52.~ 0,04 ~17a,62 27.~,34 52.70 2210,7A. ~,c ~ ~ 98 0.57 · . ~10¢,7C' .~£ ~ 2247.63 28,05.79 53.~ 0.~9 7167,69 7264,53 7377,5,8 7470,64 7567,I3 95.,.3 6~0,26 96,8 6479,24 93,0 656.4,98 93,1 6651d2 96,5 6740,8? 16~Z,11 23,4I 70,28 1~92,11 1704,62 ~,12 71.55 1704,62 1717,36 ~.61 67,12 1717,36 1731.59 21,85 65.16 1731,59 I746,68 21,19 64.33 1746,.A8 2284.00 2M2,51 53.47 1.02 £320,14 2679.03 53.70 0.60 2~3,96 ~?13.83 53.89 1,93 2'J~6,i5 ~%,24 ~,OS 1.15 241&,16 2983,02 54,16 0.~ MEAS~.D I~S&JC~L VER?ICAL ?AR¢.~ STA?ION AZIMLrfH LA?i?UI).~. ft ft ft ft ~eo deo ~t ft it ~,o~ ~7,5 ~1,?0 17~,~ ~,82 61,52 l~c.~.~ 244';.27 ~;/,~ ~a,~ 6918,v8 1778,58 ~,,24 59,66 ,~,,.,_~ 2477,0~'~ 304'~,~ ~,33 7854.,14 98.5 7011,61 I796,03 lS'.~ 57,72 i796,03 7947.51 ~.4 70~.~ 1612,~ 18,62 56,45 ','"" ~' ~3,86 94.3 7187,57 1828,41 17,~ ~.(~ 1828.41 ~..54 3143.~' 54,4S 1,46 8137,7.5 ?S.? 7279..~ 1843.44 16,73 SS,~. 1843.44 ~79.5.S 3170:57 ~.45 8265,~) t~.2 7~1,21 l&~.C,7 16.70 ~.70 i8~,07 ~?.81 ~07,15 5~.46 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE Date: RE: ANCHORAGE AK, 99501. Dear Sir/Madam, >~~~_l i~ Reference: MBpP NORTH ~OPE find the data a~'sc~'~bed below: Enclosed, please Pr~nts/~lm~: ~ COL PER~ ~I~hL BL Run ~ CCL PhCKER FINhB BL Run ~ CCB PER~ R~ SEPI~ Run [ COL P~KER R~ SEPIh Run 26 October 1994 Transmittal of Data ECC #: 6281.02 Sent by: U.S. MAIL Data: MISC return ts- Atl~ ~ireiine S=~vic~=~_~_~_~_~ 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Or /~to (907) 563-7803 500 W. International Airport Road Anchorage, Alaska 99518-1199 (907) 562-7669 TO: November 3, 1994 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the LWD DEPTH CORRECTED CDR & CDN for well MPJ-10, Job # 94311 was sent to: BP Exploration (Alaska) Inc. 1 OH LIS Tape Petrotechnical Data Center, MB3-3 ~. 1 Depth Shift Monitor Pict 900 E. Benson Blvd. ~'~ 3 Bluelines Anchorage, Alaska 99519-6612 '''C(¢'~,, 1 Film ~'k~j~ Returning CDR, ODN, CDR & CDN - TVD *~ ~~~~~ Oa~- ~ Field Film State of Alaska ~~ 1 OH LIS . ~~ ~lt~2.k~ ~atio,1 comm. *g~ I '~ n~ 1 OH LIS Tape ~ m~ ~ OXY USA, lnc Attn: E,ma Galindo 1 Blueline ~~ X P.O. Box 50250 1 RFolded Sepia Midland, Texas 79710 Sent Certified Mail P 676 541 362 PLEA DGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP EXPLORATION (ALASKA) INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-I 199 Schlumberger Coulier: Date Delivered: Received By: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 14 October 1994 Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ECC No. / t~ F-05 (14-36-12-13)&~ 1 CN/GR LDWG TAPE+LIST Run # 1 2577.03 /, -17 (14-23-11-13) ,~ 1 PDK/GR LDWO TAPE+LST Run ~ 1 6036.04 ' C-33 (17-11-14)~ . GR/CCL LDWG TAPE+LST Run ~ 1 6123 01 10, · Please sign and re~ Atlas Wire/e S er~ ~ ~ ~ ~ ~ 0 ~ s~ ~e~ ~ . ~ Anchorage, ~ 99~8 / ] ' ' AttOrney D. P~son : Date 0Or . LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 10 October 1994 Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 'PFC/GR/PERF FINAL BL PFC/GR/PERF RF SEPIA CCL/PERF FINAL BL CCL/PERF RF SEPIA Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 6282.00 6283.00 P1 ~as ~i~=linc ~c~vic~_ 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson ~J ..... 199,~ _as.? Oil & ~a~ cons LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 5 October 1994 RE: Transmittal of Data ECC #: 6281.00 Sent by: U.S. MAIL Data: LDWG Dear Sir/Madam, Reference: MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 GR/CCL FINAL BL Run # 1 1 CCL/PLUG FINAL BL Run # 1 1 GR/CCL FINL.RF SEPIA Run # 1 1 CCL/PLUG RF SEPIA Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received b~ ./ _/~-~A~ 2 /// ~~-~.~_~ Date: WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE; (907) 279-1433 TELECOPY: (907) 276-7542 August 24, 1994 Adrian Clark Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPJ-10 BP Exploration (Alaska), Inc. Permit No. 94-110 Sur. Loc. 2520'NSL, 1961'WEL, Sec. 28, T13N, R10E, UM Btmnhole Loc. 4219'NSL, 677'WEL, Sec. 28, T13N, R10E, UM Dear Mr. Clark: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional .permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) ~ust be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman~ ~ BY ORDER OF T~E COM~ISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~) prinled on recycled paper STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrill Bllb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepenl'-11 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 65' feet Milne Point - Kuparuk River 3. Address 6. Property Designation P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL 25906 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 2S.02S) 2520' NSL, 1961' WEL, SEC. 28, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 4199' NSL, 800' WEL, SEC. 28, T13N, RIOE MPJ-IO 2S100302630-277 At total depth 9. Approximate spud date Amount 4219' NSL, 677' WEL, SEC. 28, T13N, RIOE 8/25/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property 15. Proposed depth (Ma a,d t line prop L 315848-1061' feet No close approach feet 2560 8182' MD/7312' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth ~00 feet Maximum hole angle36.3,~ o Maximum surface 2850 psig At total depth (TVD) 8182'/3550 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD MD TVD (include stage data) 24" 13-3/8" 54.5# K-55 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 36# K-55 BTRC 2721' 31' 31' 2752' 2501' 551 sxPF"E"/250sx"C"/250"C" 8-1/2" 7" 26# L-80 BTRC 8152' 30' 30' 8182' 7312' 320 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface RECEIVED Intermediate Production Liner AU0. 'l 9 1994 Perforation depth: measured true vertical Aiaska Oil & Gas Cons. Commission 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch u urmlnfl program[] Drilling fluid prog. q)~am [] Time vs d.e~th plot [] Refraction analysis [] Seabed reportl-I 20 AAC 25.050 requirements[] 21.1Signed. h e re b y ~/V~a?/t.t~ ~Y~" -~/(~*~'~/~--- f o, reg o)~g ., !' is true and Cc°rreCtommissi;n s ' ' y 't° T I t I euthe Deri~r~lbest OfEng/neersmY knowledgeuporv/sor. Date// Permit Number IAPI number IApp~val date .-, ISee cover letter I.o-o*-- ¢- I~' ~ ~'~ for other requirements Conditions of approval Samples required [] Yes [] No Mud log require' 'd []Yes ,~ No Hydrogen sulfide measures [] Yes J~ No Directional survey required ,1~ Yes [] No Required working pressure for DOPE []2M; 1-13M; 1~5M; [-110M; I-I15M; by order of Other:Approved by ,qm~irl0riginalw Signedl,~ ~. ot,,.,BY Commissioner ~ne com m~ssion Date ('~9 Form 10-401 Rev. Submit in triplicitte [' Welf Name: [ MPJ-IO Well Plan Summary Type of Well (producer or ir~jector): ] Kuparuk Producer Surface Location: Target Location: Bottom Hole Location' [AFE Number: ] 330063 2520' NSL 1961' WEL Sec 28 T13N R10E UM., AK. 4199' NSL 0800' WEL Sec 28 T13N R10E UM., AK. [ I~Stim~ted Start Date: [ 8/25/94 I MD: I 8 82' I ['Well Design (conventional, slimhole, etc.): ,4219' NSL 0677' WEL Sec 28 T13N R10E UM., AK. I [Rig: ]Nabors 22-E [ Operating days to complete: I TVD: !ll 17312' bkb I [KBE: [ Milne Point Ultra Slimhole 7LS 165' Formation 'Markers: Formation Tops - MD TVD (bkb)' ! base permafro, st 1901' 1815' MA 4203' 3705' Ugr~u Sands NA 4479' 3950' ' Top of SChrader Bluff (West Sak) San'ds' OA 4657' 4110'" Seabee Shale 4830' 4265' Base of the Schrader Bluff (west Sak) sands HRZ 7408' 658'5' High Resistivity Streak Top Kup 7611' 6775' K. uparuk.Cap Rock Top C Sand 7728' 6885' ,,, Target 7818' 6970' Total Depth 8182' 7312' Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 13 3/8" 54.5# K-55 Weld 80 32/32 112/112 '12 i/4" 9 5/8" 36# K'-55 btrc 2721 31/31 2752/2501 ~8 1/2" 7" 26# L-80 btrc 8152 30/30 8182/7312 Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7100 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3550 psi is 2850 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface Intermediate Final [Cased Hole Logs: None None Dir MWD across the Schrader Bluff/Mad Pass w/RFT when RIH w/LWD. LWD GR/Resisfivity/Neutron/Density, Possible RFT across Kuparuk. GR/CCL will be run by production. CBL run only if necessary. A gamma ray log will be obtained from surface to TD. Mud Logging is not required. Mud Program: Special design considerations [ None- LSND freshwater mud Surface Mud Properties: ! Density Marsh Yield 10 sec i0 min pH Fluid (PPG) Viscosity Point geI gel Loss 8.6 50 15 8 10 9 8 tO tO tO tO tO tO tO , 9.6 90 35 15 30 10 15 Intermediate Mud Properties: N/A I Density Marsh Yield 10 sec i0 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: ] Density Marsh Yield 10 sec 10 min 'pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 tO tO tO tO tO tO tO ,, 10.2 50 15 10 20 9.5 4-6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. R [ ~' [ IV [ D Directional: I KOP' 1500 Maximum Hole Angle: Close Approach Well: 36.34 degrees (No Shut Ins) u'~t a C~as Cu,,~. 1,0mmissi0n Disposal: Cuttings Handling- CC2A Fluid Handling' All drilling and completion fluids can be annular injected. Otherwise, Haul to CC2A. Annular InjectiOn: The MPJ-10 annulus is permitted for drilling & completion fluid injection. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL PREV VOL PERMITTED PERMITTED INJECTED VOL i(BBLS) i(BBLS) Milne Point MPJ-10 ~0 35,000 5/3/94 thru Milne Point MPJ-08 0 35,000 5/3/94 thru M'ilne Point MPJ-06 0 35,000 5~3/94 thru FREEZE PROTECTION: Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are kept open by ensuring that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practice is used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to v~ ,~ MPJ-IO Proposed Summary of Operations . 2. 3. 4. 5. . o . 10. 11. 12. 13. 14. 15. Drill and Set 13-3/8" Conductor. Weld a starting head on conductor. Prepare location for rig move. MIRU Nabors 22E ddlling dg. NU and test 20" Diverter system. Build Spud Mud. Drill a 12-1/4" surface hole and run and cement 9-5/8" casing. Run only Dir MWD (No LWD required). ND 20" Diverter, NU and Test 13-5/8" BOPE. RIH w/Insert bit on Low Speed/High Torque Motor, and Directional MWD. Test 9-5/8" casing to 3000 psig, Drill out float equipment and 10 feet of new formation, Pedorm a LOT. Drill ahead to the base of the Schrader Bluff (West Sack) into the Seabee Shale and POOH. LD the Insert Bit and Motor. Send Scrader Bluff Log Data to town ASAP. MU a R417G PDC bit on a turbine, with Directional/Gamma Ray, Resistivity/Neutron/Density (Triple Combo) MWD/LWD tools to the Dir/GR/Res. RIH. Drill 8.5" hole to TD, POOH, and Run and Cement 7" casing. This hole section will be logged LWD with Triple Combo (GR/Res/Neu/Dens). RIH while PU 3-1/2" drill pipe with 7" 26# bit and scraper. Drill out ES Cementer, RIH to PBTD, displaCe the drilling mud out of the hole with source water, while performing a casing wash, filter source water to 2 micron absolute. POOH L/D 3-1/2" drill pipe. Freeze protect the well. ND BOPE, NU and Test the Frac Tree. Set BPV in 7" x 11" tubing hanger. RDMO Nabors 22E drilling rig to drill MPJ-11. Well will be completed with Coil Tubing deployed ESP. MPJ-10 WELL 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 50 deg F at 2500' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: 551 Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 2.0% caci2 WEIGHT: 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk APPROX #SACKS: 250 FLUID LOSS: 100-150 cc THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER:0 ~EGE~V EO TOP JOB CEMENT TYPE: Permafrost C ADDITIVES: Retarder Gas Cons. Anchof~ ,~ WEIGHT: 15.6 ppg YIELD: 0.96 cu ft/sk. MIX WATER: 3.7 gal/sk APPROX NO SACKS: 250 CENTRALIZER PLACEMENT: 1. I Bowspring centralizer per joint of 9-5/8" casing on bottom 10 joints of casing (10 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Pedorm lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover 500' md above the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to sudace with 100% excess. 4. 80'md 9-5/8", 40# capacity for float joints. 5. Top Job Cement Volume is 250 sacks. MPJ-10 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON STAGE ! CEMENT ,.lOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: 140° F BHST 170 deg F at 7040' TVDSS. SPACER: 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu f'dsk APPROX Cf SACKS: 210 FLUID LOSS: < 50cc/30 rain @ 140° F MIX WATER: 5.0 gal/sk THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FREE WATER: 0cc @ 45 degree angle. STAGE !! CEMENT JOB ACROSS THE SCHARADER BLUFF SANDS: CIRC. TEMP: 60°F BHST 80 deg F at 7040' TVDSS. SPACER: 75 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton. specifications weighted to 1.0 ppg above current mud weight. LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX CfSACKS: NONE THICKENING TIME: Greater than 4 hrs at 50° F. REcEIVE. E) TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad 344, 2.0% CaCI2 WEIGHT: 15.Sppg YIELD: 1.15 cu ft/sk AUG. ] 9 i:~las~a i:)i~ & Gas 6OHS. Commission MIX WATER: 5.0 gal/sk APPROX Cf SACKS: 1 1 0 THICKENING TIME: 4 hours @ 50 FLUID LOSS: 100-150 cc FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4"Straight Blade Rigid Centralizers-- two per joint on the bottom 19 joints of 7" Casing (38total). This will cover 300' above the C Sand. 2. 7"x 8-1/4"Straight Blade Rigid Centralizers-- one per joint from 4700' - 4100' to cover the Schrader Bluffs Sands (15Total). 3. Run one 7"x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 4. Total 7"x 8-1/4"Straight Blade Rigid Centralizers needed is 54. OTHER CONSIDERATIONS: Pedorm lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is n.ot necessary. CEMENT VOLUME: 1. Stage 1 cement volume is calculated to cover 1000' md above the LK1 with 30% excess, 2. Stage 2 cement volume is caicualted to cover from the OG base to the to 500' above the NA Top with 30% excess. PRUBHOE BAY DRZ_LZNG GROUP ~PJ-~0 (P10) VERTICAL SECTION VIEW Section at: 8~.04 TVD Scale.' ~ ~nch = ~000 feet Bep Sca]e· ~ ~nch = ~000 feet ) ~ ~ .J Marker Ident,ficat,on A) KB MD BKB SECTN INCLNo 0 0 0.00 .... ..... ~ ..... Fl END OF 2/~00 CURVE 4721 4167 1434 26.~9 BA~E PF lB15 G} START 2/100 DROP 7~09 63~0 2487 26. ~9 )__ ~ I H) END OF 2/100 DROP 74~8 6594 2609 20.00 ~ I} --- TARGET --- 78~8 6970 2745 20.00 t--- ~ - RECEIVED -~-~ .....~ .....~~~ _._, ...... . ........... ,. :T~ZcZs[~ Z ~OC Z ] ...... .~r¢~_¢ ~ _ ~: :ZZZZZZZZZZ: ZZZZ: d 0 500 ~000 ~500 2000 2500 3000 3500 4000 asoo 5000 5500 6000 6500 Section Departure (Anadrill (c)g3 NPJlOP~O B~.52 5:29 PN l] PRUDHOE BAY DRT Narker Identif ~cat~on NB N/S E/H _LING GROUP NPJ-~O (P~O) PLAN VIE~ CLOSURE .....: 3~38 feet at Azimuth 57.2~ DEOL]NATZON.: 30.000 E SCALE .......: ~ ~nch = 500 feet DRA~N .......: 08/~8/94 AnadrJ ]] Schlumberger i ~'~"~ [ [ , ,,,,.o~, :l~i & Gas 6ohs, co~mlsslo~ ~C 250 0 250 500 750 ~000 i250 ~500 ~750 2000 2250 2500 2750 3000 3250 <- NEST ' EAST -> ~ , , (Anadri]] [c)g3 NPJ~OPiO BI.52 5:29 PN l) WELL PERMIT CHECKLIST INIT CLASS O~,/ /~ 2/ WELL NAME GEOL AREA UNIT# PROGRAM: exp D dev ~ redrll [] serv [] ADMINISTRATION APPR D TE 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. 'Well located in a defined pool ............ N 5. Well located proper distance from drlg unit boundary. · N 6. Well located proper distance from other wells ..... N ' 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval.. N 13. Can permit be approved before 15-day wait ....... N ENGINEERING 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg. . N 17. CMT vol adequate to tie-in long string to surf csg . . · Y 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~3 N 21. If a re-drill, has a 10-403 for abndnmnt been approved..Y N.~ 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ,~"'"~:~:)D psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... 29. Is presence of ~2S gas probable ............. Y GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... 32. Seismic analysis 9f shallow gas zones .......... y N 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports . . . ~/. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: · Comments/Instructions: HOW/jo - A:~ORMSAcheklist rev 0.3/94 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 finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ********************************* 'hlumberqor A~asks Cor~p~t~,rJ~ Center 31,-DC'T-~994. 14,:00 ~bluwberqer A!a~ka Compt~tin,~ Center 3~-OCT-! 994 14:00 :1. c !, J. [:,r~ed ctlrv~$; T ,5 R !P D E P T [~ ';';XT; .... b!,~1 .~ CU~,VF FO'~ ~iiT~TS: ~RCii C!;RVE 3HIF'T # p~.n .:a...1.! bit runs merqed, SToP DEPTH 2665,0 46 ~i!6, .0. .......... F (.:~ t,! ] V A T, If. ~"i 'l' 79g~,f: 7~72,5 7~17.q 778).C 7647.5 75~a,n CDP CDN ....... ~072,5 8n72,~ dn(,)6.~ dOO6.C 79~!,0 7q61.0 7023.0 7q23.() 7nSg.0 7~8a.0 'lgSl.n 7961.¢ 77~7.~ 77~7.~ 7747.n 7747.~ 7647.n 7647.0 7624,0 '759o,~ 759f).~ U ~,*SH IFT~F,' DEPmH .......... S Tsoe '!~eri~:ic,~t.t on 'hlumber!:~.r Alaska Computino Center 31.-OCT-!. 9c~4 14:00 756~,. 5 7566.5 7~25.~ '751J .5 7511.5 750g..0 7506.0 745~.0 745g.0 739~.0 7392.~ 7364.o 7364'0 "734n. :: 7340.5 7307.0 7307.0 :! 2662,0 ? 4745,0 ~'!E;RGK B~SE ':.:,:::"""o 8..?.. 0 4.0 (:~aVc; a~':t:':., bi.,:[,, CgR A~D CD:',~ CURV~:,S C~RIED. ,FH~ CASED HObK CR :,:~,~ OvER '~'riE IXTE~VAL FRO~ ~158 TO 7304 FT, i'~O A. t:~!..,C~C~< SHIFT [:~P +3,5 ~15 APPLIED F"PO~ 7304 TO 2665 FT. PAGE: ~hlumberger i~],aska Con'.putinq Center '''' ........... F' q' ' ........... 00 00 ''''''''''''''''''''''''', 0 i ......... 4' '' ~ ;'''''''''' ~''~'000000 00 0 1 !, 1 4 68 0000000000 G 1 1 1 4, 68 0000000000 0 1 I ~. 4 68 0000000000 0 1 ~, 1 4 68 0000000000 0 1, !: 1, 4 68 0000000000 0 1 1 1 4 68 0000000000 O ! ~ i 4 68 0000000000 0 1 I 1 4 68 0000000000 O 1 1 I 4 68 0000000000 0 1 1 1. 4 68 O00OO00000 0 1, 1 1, 4 68 0000000000 0 1 1 ! 4 68 0000000000 0 1 1, 1 4 68 0000000000 0 1 1 1 4 68 O0000OO000 0 I I I 4, 68 0000000000 0 1, 1 1. 4 6B 0000000000 -999.250 -999,250 61.430 -999.250 -999.250 -9~9.250 -999.250 -999.250 **** b FTLF' DI~TV ~'"~X RVC STZ~ L~,8~ vILE : v D ! T ,0 O 1 : VLTC ; O0 ~ Co 1 .' 04tl. o/31 : 1 : : 'hlUr~'t~"er'ge~' A],a$~a Camput. i,F~;a refit, er 31-r'cT-!ga4 1,4:;00 PA~E: Curves and lo:.4 !:~ar.~er data for each bit. run ir,~. se~'iarate. R U I>~ ~'~ U 4 'ia E r,.:..; TF~.]T S'TPI~G (TOt~ ~[.', Cr~.~' Cf]t".P. [!UAL RI~i;SIS'.ITVTTY DEPTH 03-5EP-94 l..,O C, Lt S 20 FAST 2.5 8265.0 2607.0 8204.0 25.~ 39.3 2661.0 I0,20 files. .hlumberger A.]a,,qKa Co,',putin~ Center 3!..-OCT-1994 1~:00 23000 155.0 2. 870 2.500 0.000 66.0 66.0 0.0 DS?O!~F' .9....65 50(.) 000 PORT TO BIT 52,52 ~"T 3~ FT, GR '.["0 P. IT 59 77 F"T ~ R V A [,,: 2680 T 0 4:877 F .... . ~ ..,, 68.82 ~'T, CR ']2:0 ~1.:~ 79,24 FT BiT !38,~{ FT, [:;~hS..LTg ~.'0 BIT 1.31.,1.6 FT ,SEPW 3,!99~ ~FDI,, T0 DFPTH OP 8265 PACE~ 3~ CT 1, 94 1, a: ,..n., .- 9 ~0 1 fi 6 6 $ Fi:~t UN' · g~VICF~ iT.E NLt r,~ P '" .........................~.,,,, ' ,oo '5;'";o o ........ o ;"' ..... ~ "'""~, ........ ~ s;'" .... oooo';';o .... ooo ¢,~1 O~¢N 00 000 00 0 2 1 1. 4 68 0000000000 ~'; ! ~'35.! ~',.~ ~' 0 a 000 U 0 0 2 1 1 4 68 O 000000000 ~; 1. [.~.~ N i;4 M (,) o o 0 f) O 0 O 2 ~. I 4 68 0 O 00000000 WI F/?tb' 00 00(') ()0 0 2 1 1 4 68 0000000000 a ! G Z~, P !'. 0 o 000 00 0 2 ~.. 1 4 68 0000000000 ~',' I 00 000 00 0 2 ~ 1 a 613 0000000000 -999.250 -9q9.250 'blUmberc~er ,A].,ask'a COmpL~t,~,no Center 3 !,-0CT-~,994 ~or esch T':i' 5 IZ~.: bit run Jn semarate STOP D~:PTH ~264,5 8264.5 03-8EP-94 LOGO$ 20.4 FAST 2,5 8 2 6 5.0 2607, 0 !6.7 RG5022 ;~D8052 8.500 2661 .n I 0, ~55.~ 2..~70 2 · 50u 0. files. 66.0 0.0 :,$ Ta~e Ver.,,tf!,cAtfon t, istino .hlu~berger a ask, a Co,',put g~ Center 3 ! ,-DCT-- ~1. 9C14 14;00 ?.65 8.500 1 · 0 0 () DF~T F"T O0 {~V. 0. (.) I 6 ., OOnO00 R~?Jp t,~;~ G/C~ OO 0()~ O~ 0 3 ] ! 4 68 Tape Vertf~c~t.l,,on Listi~c~ 'hlumberqer A.!.as~'a Co~putln~ Center ..q 1-OC?'- 1994 I4:00 P~GE! 10 ** }..;~,![; (.:,r- r"ATA -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 ~*** FTb~' T'.,x/t 1. !', E P, **** SFRVI. Ck : FI..~ T C VER~I~,. : 00! COl O ~ '.1;~ : q--'.~/10 / 31 ,~i~X RfC ~,rgt] : ].02,1 F'IL~' TYPE, : LO L~S* FiI,E :~ ~a~e Ver,!,(ica~,on !,~istt, nc :hlt)~z~berqer ,~.l, aSKa Cor~plltl, n~ Center 31-UC?-1994 14;00 11 MPJ - 10 MILNE POINT ~aska .Oil & Gas Cons. Cemmi~_ [o~- -/~chorage - Run 1: 03 - October - 1994 GR/CCL Cased Hole 58 M ICR01:ILHEG, .=RN ATLAS Atlas Wireline Services · ~'ape Subfile 2 is'type~: LIS TAPE HEADER , MILNE POINT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MPJ - 10 500292250000 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 05-OCT-94 6281.00 J. DAHL D. ROBERTSON 28 13N 10E 2520 1961 65.75 34.60 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) lST STRING 2ND STRING 13.375 110.0 3RD STRING 9.625 2664.0 PRODUCTION STRING 7.000 8247.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: ATLAS WIRELINE SERVICES EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ GR/CCL Cased Hole. REMARKS: 61.00 40.00 26.00 *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** PASS 1 WAS NOT DEPTH SHIFTED SINCE PASS 1 IS THE DEPTH REFERENCE FOR THIS WELL. LOG TIED TO MAGNETIC MARKS, REFERENCED 28.65' RKB - BF. KB ELEVATION CALCULATED WITH 34.6' PAD ELEVATION + 2.5' TO BF & 28.65' BF TO KB. FILE HEADER FILE NUMBER: EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 7304.0 8158.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 1 (MAIN PASS). NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPJ- 10 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 2 TENS GR 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 21 990 60 6 4 4 10 579 41 1 * DATA RECORD (TYPE# 0) Total Data Records: 21 1014 BYTES * Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = 8165.000000 7293.000000 0.500000 Tape File D6pth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5236 datums Tape Subfile: 2 114 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS · FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 7941.0 8158.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: BASELINE DEPTH GRCH 8056.5 8056.5 8072.0 8071.5 8078.5 8078.5 8137.0 8137.5 $ REMARKS: -- EQUIVALENT UNSHIFTED DEPTH -- PASS 2 (REPEAT PASS). CN WN FN COUN STAT / ? ?MATCH1. OUT : BP EXPLORATION (ALASKA) : MPJ- 10 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 2 TENS GR 68 1 LB 4 4 66 264 36 0 4 4 10 579 41 1 * DATA RECORD (TYPE# 0) Total Data Records: 1014 BYTES * Tape File start Depth = 8165.000000 Tape File End Depth = 7933.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1396 datums Tape Subfile: 3 41 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 7304.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 8162.0 03-OCT-94 FSYS REV. J001 VER. 1.1 1110 03-OCT-94 8161.0 8159.0 7300.0 8158.0 1800.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR SBAR SINKER BAR CCL CASING COLLAR LOC. GR GAMMA RAY $ TOOL NUMBER 2324XA 1311XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .000 8247.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SEAWATER/DIESEL .00 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): .0 BASE NORMALIZING WINDOW (FT): .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 1 (MAIN PASS). $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPJ- 10 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 5 TTEN GR 68 1 GAP I 4 1 4 1 F/MN 4 1 LB 4 1 LB 4 4 21 990 60 6 4 26 165 19 6 4 76 115 41 1 4 10 579 41 1 4 10 579 41 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 84 Tape File Start Depth = 8165.000000 Tape File End Depth = 7293.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 26171 datums Tape Subfile: 4 158 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 7940.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 8162.0 03-OCT-94 FSYS REV. J001 VER. 1.1 1059 03-OCT-94 8161.0 8159.0 7300.0 8158.0 1800.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR SBAR SINKER BAR CCL CASING COLLAR LOC. GR GAMMA RAY $ TOOL NUMBER 2324XA 1311XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .O00 8247.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SEAWATER/DIESEL .00 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): .0 BASE NORMALIZING WINDOW (FT): .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 0 TOOL STANDOFF (IN): .0 REMARKS. · PASS 2 (REPEAT PASS). $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPJ - 10 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 5 TTEN GR 68 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 1 LB 4 4 21 990 60 6 4 26 165 19 6 4 76 115 41 1 4 10 579 41 1 4 10 579 41 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 23 Tape File Start Depth = 8165.000000 Tape File End Depth = 7933.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6971 datums Tape Subfile: 5 97 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 is type: LIS 94/10/ 5 01 **** REEL TRAILER **** 94/10/ 5 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 5 OCT 94 2:04p Elapsed execution time = 4.34 seconds. SYSTEM RETURN CODE = 0