The URL can be used to link to this page

Home My WebLink About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y Anne Prysunka at 10:00 am, Oct 19, 2022 'LJLWDOO\VLJQHGE\'DYLG +DDNLQVRQ '1FQ 'DYLG+DDNLQVRQ RX 8VHUV 'DWH 'DYLG+DDNLQVRQ MGR19OCT2022 DSR-10/19/22 RBDMS JSB 102822 BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϭϬͬϭϴͬϮϬϮϮ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DW&Ͳϴϲ >ĂƐƚŽŵƉůĞƚĞĚ͗ϵͬϯϬͬϮϬϮϮ Wd͗ϮϬϭͲϬϴϳ dс ϭϭ͕ϯϭϲ͛;DͿͬdсϳ͕Ϯϴϳ͛;dsͿ ϮϬ´ K<ůĞǀ͗͘ϰϮ͘ϵ͛ͬKƌŝŐ͘'>ůĞǀ͗͘ϭϬ͘ϵ͛ ŽǇŽŶϭϲZdƚŽddďŐƐƉŽŽůсϮϮ͘ϰϮ͛ ϳ͟ ´7$0 3RUW&ROODU# ¶ ϵͲϱͬϴ͟ Wdсϭϭ͕ϮϬϮ͛;DͿͬWdсϳ͕ϭϳϲ͛;dsͿ ´&DS6WULQJ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ W& ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϭ͘ϭͬ,ͲϰϬͬEͬ Eͬ ^ƵƌĨĂĐĞ ϭϭϮΖ Ϭ͘ϯϱϱ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬd ϴ͘ϴϯϱ ^ƵƌĨĂĐĞ ϲ͕ϱϭϴ͛ Ϭ͘Ϭϳϱϴ ϳΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϲͬ>ͲϴϬͬdͲD ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϭϭ͕Ϯϵϲ͛ Ϭ͘Ϭϯϴϯ dh/E'd/> ϰͲϭͬϮΗ dƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬ,ǇĚƌŝůϱϮϭ ϯ͘ϵϱϴ ^ƵƌĨĂĐĞ ϭϬ͕ϳϳϱ͛ Ϭ͘ϬϭϱϮ ϯͬϴ͟ ĂƉ^ƚƌŝŶŐ ^ƚĂŝŶůĞƐƐ^ƚĞĞů Eͬ ^ƵƌĨĂĐĞ ϭϬ͕ϳϳϱ͛ Eͬ :t>Zzd/> EŽ dŽƉ;DͿ /ƚĞŵ ϭ ϭϬ͕ϲϰϰ͛ ΘdƵďŝŶŐ^ƚŽƉtͬϰΗ'^&E Ϯ ϭϬ͕ϲϰϲ͛ ΘWĂĐŬKĨĨ/,ŝͲ&ůŽǁ ϯ ϭϬ͕ϲϱϰ͛ Θ^ƚŝŶŐĞƌϮϳͬϴΗhyDŽůǇWĂĐŬŝŶŐ ϰ ϭϬ͕ϲϱϱ͘ϴ͛ ŝƐĐŚĂƌŐĞ,ĞĂĚϯϴϬWƵŵƉϮϯͬϴΗϴZĚhyŽů ϱ ϭϬ͕ϲϱϲ WhDWηϯ͗ϯϴϬ^y͕ϭϭϲWϭϴ,ϲ&Z ϲ ϭϬ͕ϲϳϳ͛ WhDWηϮ͗ϯϴϬ^y͕ϭϭϲWϭϴ,ϲ&Z ;ŽůƚĞĚƚŽWƵŵƉηϭͿ ϳ ϭϬ͕ϲϵϳ͛ WhDWηϭ͗ϯϴϬ^y͕ϭϭϲWϭϴ,ϲ&Z ϴ ϭϬ͕ϳϭϴ͛ 'ĂƐ^ĞƉĞƌĂƚŽƌ͖ϯϴϬ'^sd,syD ϵ ϭϬ͕ϳϮϮ͛ WhDWzdd^W ϭϬ ϭϬ͕ϳϮϰ͛ yͬKϰ͘ϱ͟,ǇĚϱϮϭyϰ͘ϱ͟E^dW ϭϭ ϭϬ͕ϳϯϯ͛ ddĚƌŝůůĞĚƚƵďŝŶŐĐƌŽƐƐŽǀĞƌ ϭϮ ϭϬ͕ϳϰϰ͛ dĂŶĚĞŵƐĞĂůƐĞĐƚŝŽŶƐ;DŽĚĞů'^ϯͿ ϭϯ ϭϬ͕ϳϱϴ͛ DŽƚŽƌ͕yWͲϮϬϬ͕ϮϬϬ,W͕ϯϲϯϱǀŽůƚ͕ϯϰĂŵƉ ϭϰ ϭϬ͕ϳϳϮ͛ tĞůů>ŝĨƚ^ĞŶƐŽƌǁŝƚŚϲĨŝŶĞŶƚƌĂůŝǌĞƌʹ ŽƚƚŽŵΛϭϬ͕ϳϳϱ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ <ƵƉ͘ϯ ϭϭ͕Ϭϰϳ͛ ϭϭ͕Ϭϱϳ͛ ϳ͕ϬϮϲ͛ ϳ͕Ϭϯϲ͛ ϭϬ ϴͬϮϲͬϮϬϬϭ KƉĞŶ <ƵƉ͘Ϯ ϭϭ͕Ϭϲϰ͛ ϭϭ͕Ϭϳϰ͛ ϳ͕Ϭϰϯ͛ ϳ͕Ϭϱϯ͛ ϭϬ ϴͬϮϲͬϮϬϬϭ KƉĞŶ <ƵƉ͘ϭ ϭϭ͕Ϭϴϲ͛ ϭϭ͕Ϭϵϲ͛ ϳ͕Ϭϲϰ͛ ϳ͕Ϭϳϰ͛ ϭϬ ϴͬϮϲͬϮϬϬϭ KƉĞŶ <ƵƉ͘Ϯͬϭ ϭϭ͕Ϭϲϴ͛ ϭϭ͕ϭϬϴ͛ ϳ͕Ϭϰϲ͛ ϳ͕Ϭϴϱ͛ ϰϬ ϲͬϬϮͬϮϬϬϲ KƉĞŶ ZĞĨ>ŽŐ͗^t^:ĞǁĞůƌǇ>ŽŐͲϴͬϭϬͬϮϬϬϭ KWE,K>ͬDEdd/> ϮϬΗ ϮϲϬƐǆŽĨƌĐƚŝĐƐĞƚ/ŝŶϯϬ͟,ŽůĞ ϵͲϱͬϴ͟ ϭϬϬϬƐǆW&>ŝŶϭϮͲϭͬϰ͟ŚŽůĞƉůƵƐϮϮϱƐǆůĂƐƐ͞'͟ ϳΗ ϮϬϬƐǆůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟ŚŽůĞ͕ĞƐƚ͘dKсϵ͕ϰϴϱ͛ t>>/E>/Ed/KE d/> <KWΛϰϬϬ͛ DĂǆ,ŽůĞŶŐůĞсϲϲĚĞŐ͘Λϰ͕ϬϱϬ͛ DĂǆ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϭϱĚĞŐ͘ dZΘt>>, dƌĞĞ ϱD/tϰ͟ tĞůůŚĞĂĚ ϭϭ͟ϱD&D'ĞŶϱ͕ǁͬϰͲϭͬϮ͟&DdďŐ͘,ŶŐƌ͕͘ ϰͲϭͬϮ͟,ǇĚƌŝůϱϮϭdŽƉΘƚŵ͘,ĂŶŐĞƌƚŚƌĞĂĚĂŶĚ ϰ͟͞,͟WsƉƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϯϬϭϴͲϬϬ KƌŝŐ͘ƌŝůůŝŶŐďǇEĂďŽƌƐϮϳʹϴͬϬϲͬϮϬϬϭ KƌŝŐ͘ŽŵƉůĞƚŝŽŶďǇEĂďŽƌƐϰ^ʹϵͬϮϳͬϮϬϬϭ ZtKǁͬEĂďŽƌƐϯ^͕^WĐͬŽ͕&KĂŶĚĚĚWĞƌĨƐʹϲͬϬϰͬϮϬϬϲ ZtKǁͬEĂďŽƌƐϯ^͕^WĐͬŽ͕&KĂŶĚŝŶƐƚĂůůƐĐƌĞĞŶʹϮͬϬϲͬϮϬϬϳ ZtKǁͬEĂďŽƌƐϰ^͕^WĐͬŽʹϴͬϮϰͬϮϬϬϴ ZtWǁͬEĂďŽƌƐϯ^͕^WĐͬŽĂŶĚĂĚĚĐĂƉƚƵďĞʹϱͬϭϯͬϮϬϬϵ ZtKǁͬŽǇŽŶϭϲ͕^WĐͬŽĂŶĚƌƵŶĨƌĂĐƐƚƌŝŶŐʹϯͬϬϯͬϮϬϭϭ ZtKǁͬŽǇŽŶϭϲ͕ŝŶƐƚĂůůdd^WĂŶĚ&KʹϲͬϮϭͬϮϬϭϭ ZtKǁͬ/ͲZŝŐ͕ŝŶƐƚĂůůdd^WĂŶĚ&KʹϳͬϮϭͬϮϬϭϴ ZtKǁͬdhηϵ͕ŝŶƐƚĂůůdd^WĂŶĚ&KʹϲͬϮϯͬϮϬϮϮ ZtKǁͬdhηϵ͕ŝŶƐƚĂůůdd^WĂŶĚ&KʹϵͬϯϬͬϮϬϮϮ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW&Ͳϴϲ Žŝů ϱϬͲϬϮϵͲϮϯϬϭϴͲϬϬͲϬϬ ϮϬϭͲϬϴϳ ϵͬϮϳͬϮϬϮϮ ϵͬϯϬͬϮϬϮϮ ϵͬϮϯͬϮϬϮϮͲ&ƌŝĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϵͬϮϭͬϮϬϮϮͲtĞĚŶĞƐĚĂǇ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϵͬϮϮͬϮϬϮϮͲdŚƵƌƐĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ D/Zhdh͕WdƚŽϮϴϬƉƐŝůŽǁͬϰϮϱϬƉƐŝŚŝŐŚ͘DhΘZ/,ǁͬǀĞŶƚƵƌŝ,͘sĞŶƚƵƌŝŽŶƚŽƉŽĨƉƵŵƉĂƚϭϬϲϰϰΖ͕ĂƚƚĞŵƉƚƚŽƚƵƌŶŽŶ ƉƵŵƉͲŶŽŐŽ͘WK,͘DhΘZ/,ǁͬĨŝƐŚŝŶŐĂƐƐĞŵďůǇ͘ϰũĂƌůŝĐŬƐͲƉƵůůƚƵďŝŶŐƐƚŽƉ͘WK,͘ZĞĐŽǀĞƌƐůŝƉƐƚŽƉ͘Z/,ǁͬƐĂŵĞĨŝƐŚŝŶŐ ĂƐƐĞŵďůǇ͘ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϵͬϮϰͬϮϬϮϮͲ^ĂƚƵƌĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϵͬϮϳͬϮϬϮϮͲdƵĞƐĚĂǇ ϵͬϮϱͬϮϬϮϮͲ^ƵŶĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϵͬϮϲͬϮϬϮϮͲDŽŶĚĂǇ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW&Ͳϴϲ Žŝů ϱϬͲϬϮϵͲϮϯϬϭϴͲϬϬͲϬϬ ϮϬϭͲϬϴϳ ϵͬϮϳͬϮϬϮϮ ϵͬϯϬͬϮϬϮϮ ϵͬϯϬͬϮϬϮϮͲ&ƌŝĚĂǇ WKK,͘KdϯΗ'^^ƉĞĂƌ͘DhKdϰΗ'^^ƉĞĂƌ͘ĞƉůŽǇĞŶƚƌŝůŝĨƚƉƵŵƉηϯ͕ŝƐĐŚĂƌŐĞ,ĞĂĚ͕Θ,ĂŶŐĞƌZĞĐĞƉƚĂĐůĞ͘>ĂƚĐŚ ƵƉ,ϰΗ'^^ƉĞĂƌ͘Z/,͘>ĂƚĐŚƉƵŵƉηϯŝŶƚŽƉƵŵƉηϮΘηϭ͘dƵƌŶŽŶŵŽƚŽƌĂŶĚƚĞƐƚĞŶƚƌŝůŝĨƚƉƵŵƉƐͲŐŽŽĚ͘WKK,͕&Wd' ǁŝƚŚϰϬďďůƐŽĨĚŝĞƐĞů͘:ŽďŽŵƉůĞƚĞ͘t>>^,hdͲ/EKEZZ/s>͕WdWϯϬϬ>ϯϱϬϬ,͘^dϰͲϭͬϮΗW<ͲK&&Edh/E'^dKW KEdKWK&^WWhDWdϭϬ͕ϲϵϯΖ^>D͘t>>^,hdͲ/EKEWZdhZ͕EKd/&/WKW͘ ϵͬϮϴͬϮϬϮϮͲtĞĚŶĞƐĚĂǇ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ ŽŶƚŝŶƵĞƚŽZ/,ǁͬĨŝƐŚŝŶŐĂƐƐĞŵďůǇ͘ŝƌĐƵůĂƚĞǁĞůůƚŽϭй<>͘>ĂƚĐŚŝŶƚŽƉĂĐŬŽĨĨ͘:ĂƌϭϴƚŝŵĞƐΘWK,͕ƉƵŵƉĂĐƌŽƐƐƚŚĞƚŽƉ͘ ƌĞĂŬŽĨĨĨŝƐŚĐŚĞĐŬĨŽƌǁŚĞĞůŶŽƌĞĐŽǀĞƌǇĐŚĞĐŬƚŽŽůƐƐƚĂďďĂĐŬŽŶƚŽǁĞůůZ/,ƚŽůĂƚĐŚƉƵŵƉƐĞĐƚŝŽŶƐ͘Z/,ϰΗ'^^ƉĞĂƌ͘dĂŐ͘ ƚŽƉƉƵŵƉΛϭϬ͕ϲϴϲ͘ϵΖdDͬϭϬ͕ϲϵϰΖDĞĐŚ͘WƵůůWƵŵƉ͘WKK,͘>WƵŵƉͲƌĞĐŽǀĞƌϴŽͲƌŝŶŐƐŽŶƚŽƉŽĨƉƵŵƉ͘ůůϯƐĞĐƚŝŽŶƐŽĨ ƚŚĞƉƵŵƉΘĚŝĨĨƵƐĞƌĂƌĞůŽĐŬĞĚƵƉ͘&ůƵƐŚϰͲϭͬϮΗƚƵďŝŶŐ͘&WĐŽŝů͘WƵƚϭϬďďůƐŽĨĚŝĞƐĞů&WŝŶϰͲϭͬϮΗƚƵďŝŶŐ͘^ĞĐƵƌĞǁĞůů͘WůĂĐĞƵŶŝƚ ϵŽŶƐƚĂŶĚďǇ͘DŽǀĞĐƌĞǁƐŽǀĞƌƚŽDW&ͲϱϬ;ŽŝůϲͿ͘ ϵͬϮϵͬϮϬϮϮͲdŚƵƌƐĚĂǇ W:^DͬtĚƌŝůůĨŽƌĚĞƉůŽǇŝŶŐ^W͘WdŶŝŐŚƚĐĂƉƚŽϮϱϬͬϯϳϬϬƉƐ͘>ŽĂĚǁĞůůĂŶĚŵŽŶŝƚŽƌŽŶƚƌŝƉƚĂŶŬ͕ĚĞƉůŽǇ^WƐĞĐƚŝŽŶƐϭΘϮ͘ Z/,dĂŐŵŽƚŽƌϱ<ĚŽǁŶ͕WhƚŽŶĞƵƚƌĂů͘dĞƐƚŵŽƚŽƌͲŐŽŽĚ͘WƵŵƉŽĨĨĐĞŶƚƌŝůŝĨƚƉƵŵƉϭΘϮƐĞĐƚŝŽŶƐ͘dĞƐƚŵŽƚŽƌĂŐĂŝŶͲŐŽŽĚ͘ WƵŵƉϱ͘ϱďďůƐKŝů^ĂĨĞZƐƉŽƚƚŽƉƵŵƉƐ͘WKK, EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϭϬͬϭͬϮϬϮϮͲ^ĂƚƵƌĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϭϬͬϰͬϮϬϮϮͲdƵĞƐĚĂǇ ϭϬͬϮͬϮϬϮϮͲ^ƵŶĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϭϬͬϯͬϮϬϮϮͲDŽŶĚĂǇ 7\SHRI5HTXHVW $EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 5HSDLU:HOO 2SHUDWLRQVVKXWGRZQ 6XVSHQG 3HUIRUDWH 2WKHU6WLPXODWH 3XOO7XELQJ &KDQJH$SSURYHG3URJUDP 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 5HHQWHU6XVS:HOO $OWHU&DVLQJ 2WKHU77&(63&KDQJHRXW 2SHUDWRU1DPH &XUUHQW:HOO&ODVV 3HUPLWWR'ULOO1XPEHU ([SORUDWRU\ 'HYHORSPHQW $GGUHVV6WUDWLJUDSKLF 6HUYLFH $3,1XPEHU ,ISHUIRUDWLQJ:HOO1DPHDQG1XPEHU :KDW5HJXODWLRQRU&RQVHUYDWLRQ2UGHUJRYHUQVZHOOVSDFLQJLQWKLVSRRO" :LOOSODQQHGSHUIRUDWLRQVUHTXLUHDVSDFLQJH[FHSWLRQ" <HV 1R 3URSHUW\'HVLJQDWLRQ/HDVH1XPEHU )LHOG3RROV 7RWDO'HSWK0'IW 7RWDO'HSWK79'IW (IIHFWLYH'HSWK0' (IIHFWLYH'HSWK79' 0363SVL 3OXJV0' -XQN0' 1$ &DVLQJ &ROODSVH &RQGXFWRU 1$ 6XUIDFH SVL 3URGXFWLRQ SVL 3DFNHUVDQG66697\SH 3DFNHUVDQG66690'IWDQG79'IW $WWDFKPHQWV 3URSRVDO6XPPDU\ :HOOERUHVFKHPDWLF :HOO&ODVVDIWHUSURSRVHGZRUN 'HWDLOHG2SHUDWLRQV3URJUDP %236NHWFK ([SORUDWRU\ 6WUDWLJUDSKLF 'HYHORSPHQW 6HUYLFH (VWLPDWHG'DWHIRU :HOO6WDWXVDIWHUSURSRVHGZRUN &RPPHQFLQJ2SHUDWLRQV 2,/ :,1- :'63/6XVSHQGHG 9HUEDO$SSURYDO 'DWH *$6 :$* *6725 63/8* $2*&&5HSUHVHQWDWLYH*,1-2S6KXWGRZQ $EDQGRQHG &RQWDFW1DPH &RQWDFW(PDLO &RQWDFW3KRQH &RQGLWLRQVRIDSSURYDO1RWLI\$2*&&VRWKDWDUHSUHVHQWDWLYHPD\ZLWQHVV 6XQGU\1XPEHU 3OXJ,QWHJULW\ %237HVW 0HFKDQLFDO,QWHJULW\7HVW /RFDWLRQ&OHDUDQFH 2WKHU 3RVW,QLWLDO,QMHFWLRQ0,75HT G"<HV 1R 6SDFLQJ([FHSWLRQ5HTXLUHG"<HV 1R 6XEVHTXHQW)RUP5HTXLUHG $33529('%< $SSURYHGE\ &200,66,21(5 7+($2*&& 'DWH &RPP &RPP 6U3HW(QJ 6U3HW*HR 6U5HV(QJ 1$ ,KHUHE\FHUWLI\WKDWWKHIRUHJRLQJLVWUXHDQGWKHSURFHGXUHDSSURYHGKHUHLQZLOOQRWEHGHYLDWHGIURPZLWKRXWSULRUZULWWHQDSSURYDO $XWKRUL]HG1DPHDQG 'LJLWDO6LJQDWXUHZLWK'DWH $2*&&86(21/< 7D\ORU:HOOPDQ WZHOOPDQ#KLOFRUSFRP $XWKRUL]HG7LWOH2SHUDWLRQV0DQDJHU 7XELQJ*UDGH 7XELQJ0'IW3HUIRUDWLRQ'HSWK79'IW 7XELQJ6L]H 35(6(17:(//&21',7,216800$5< 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 $33/,&$7,21)25681'5<$33529$/6 $$& $'/$'/$'/ &HQWHUSRLQW'U6XLWH$QFKRUDJH$. +LOFRUS$ODVND//& 0,/1(3781,7) 0,/1(32,17.83$58.5,9(52,/ &2( /HQJWK 6L]H /+\GULO 79' %XUVW 0' 1$ SVL SVL 3HUIRUDWLRQ'HSWK0'IW 6HH6FKHPDWLF 6HH6FKHPDWLF 1$DQG1$ 1$DQG1$ U\ 6WDWX )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Samantha Carlisle at 10:06 am, Sep 06, 2022 'LJLWDOO\VLJQHGE\'DYLG +DDNLQVRQ '1FQ 'DYLG+DDNLQVRQ RX 8VHUV 'DWH 'DYLG+DDNLQVRQ '/%'65 ; 0*56(3 GWV Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.09.08 08:54:56 -08'00' RBDMS JSB 090822 ddͲ^WWƵŵƉ^ĞĐƚŝŽŶ^ǁĂƉ tĞůů͗DWh&Ͳϴϲ Wd͗ϮϬϭͲϬϴϳ W/͗ϱϬͲϬϮϵͲϮϯϬϭϴͲϬϬͲϬϬ tĞůůEĂŵĞ͗DWh&Ͳϴϲ W/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϯϬϭϴͲϬϬͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗WƌŽĚƵĐĞƌ΀^ŚƵƚŝŶ^W΁ WĂĚ͗&ͲWĂĚ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗^ĞƉƚĞŵďĞƌϮϬ͕ϮϬϮϮ ZŝŐ͗d ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍zĞƐ ĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ĂƌĐŝ,ŽƌŶĞƌ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϬϭͲϬϴϳ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗dĂǇůŽƌtĞůůŵĂŶ ;ϵϬϳͿϳϳϳͲϴϰϰϵ;KͿ ;ϵϬϳͿϵϰϳͲϵϱϯϯ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗dŽĚĚ^ŝĚŽƚŝ ;ϵϬϳͿϳϳϳͲϴϰϰϯ;KͿ ;ϵϬϳͿϲϯϮͲϰϭϭϯ;DͿ &EƵŵďĞƌ͗:ŽďdǇƉĞ͗ddͲ^WWƵŵƉ^ǁĂƉ ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗Ϯ͕ϯϳϵƉƐŝΛϲ͕ϳϲϬ͛dsϲ͘ϳϳWW'ͮdĂŬĞŶϬϵͬϬϭͬϮϬϮϮ DĂǆŝŵƵŵǆƉĞĐƚĞĚ,W͗Ϯ͕ϴϬϬƉƐŝΛϲ͕ϳϲϬ͛dsϴ͘ϬWW'ͮWƌŽũĞĐƚĞĚWhͿ DĂǆ͘ŶƚŝĐŝƉĂƚĞĚ^ƵƌĨĂĐĞWƌĞƐƐƵƌĞ͗Ϯ͕ϭϮϰƉƐŝ ;ĂƐĞĚŽŶϬ͘ϭƉƐŝͬĨƚ͘ŐĂƐŐƌĂĚŝĞŶƚͿ >ĂƐƚ^/t,W͗ϱϬϬƉƐŝ ;ϬϴͬϮϰͬϮϬϮͿ DŝŶ/͗ϯ͘ϵϱϴ͟/ΛϬ͛D dƵďŝŶŐ,ĂŶŐĞƌ DĂǆŶŐůĞ͗ϲϱ͘ϯΣΛϯ͕ϵϱϬ͛D DĂǆŽŐůĞŐ͗ϰ͘ϵΣͬϭϬϬĨƚΛϮ͕ϰϬϬ͛D ƌŝĞĨtĞůů^ƵŵŵĂƌǇ͗ DWh&ͲϴϲŝƐĂ<ƵƉĂƌƵŬƐĂŶĚƉƌŽĚƵĐĞƌ͘/ƚǁĂƐĚƌŝůůĞĚĂŶĚĐŽŵƉůĞƚĞĚŝŶϮϬϬϭǁŝƚŚĂĐŽŶǀĞŶƚŝŽŶĂů^W͘ DƵůƚŝƉůĞ^WĐŚĂŶŐĞŽƵƚƐǁĞƌĞĐŽŶĚƵĐƚĞĚďĞƚǁĞĞŶϮϬϬϲĂŶĚϮϬϭϭ͘/ŶϮϬϭϭƚŚĞǁĞůůĂdŚƌƵdƵďŝŶŐŽŶǀĞǇĞĚ ^W;ddͲ^WͿǁĂƐŝŶƐƚĂůůĞĚ͘dŚŝƐ^WŚĂƐĂƉĞƌŵĂŶĞŶƚůǇŝŶƐƚĂůůĞĚŵŽƚŽƌŽŶƚŚĞƚƵďŝŶŐƐƚƌŝŶŐďƵƚƚŚĞƉƵŵƉ ƐĞĐƚŝŽŶƐĐĂŶďĞƌĞƉůĂĐĞĚǁŝƚŚĐŽŝůƚƵďŝŶŐ͘dŚĞǁĞůůŚĂƐŚĂĚŵƵůƚŝƉůĞ^WƉƵŵƉƐĞĐƚŝŽŶĐŚĂŶŐĞŽƵƚƐƚŚƌŽƵŐŚŝƚƐ ůŝĨĞƚŝŵĞ͘dŚĞƉƵŵƉƐĞĐƚŝŽŶƐǁĞƌĞƌĞƉůĂĐĞĚŝŶƵŐƵƐƚϮϬϮϮĂŶĚǁĞƌĞƉĞƌĨŽƌŵŝŶŐǁĞůů͘ƉŽǁĞƌďƵŵƉƐŚƵƚŝŶ ƚŚĞ^WĂŶĚĂƚƚĞŵƉƚƐƚŽƌĞƐƚĂƌƚŚĂǀĞƌĞƐƵůƚĞĚŝŶǁŚĂƚĂƉƉĞĂƌƐƚŽďĞƐƚƵĐŬƉƵŵƉƐĞĐƚŝŽŶ;ƐͿ͘dŚĞŵŽƚŽƌŝƐ ďĂůĂŶĐĞĚ͘ KďũĞĐƚŝǀĞƐ͗ x ZŝŐƵƉĂŶĚƉƵůůƐůŝƉͲƐƚŽƉ͕ƉĂĐŬͲŽĨĨĂŶĚϯƐƚĂŐĞƉƵŵƉƐĞĐƚŝŽŶ;ď ŽůƚĞĚƚŽŐĞƚŚĞƌŶĞĐĞƐƐŝƚĂƚŝŶŐƐŝŶŐůĞƌƵŶ ĚĞƉůŽǇŵĞŶƚͿĨƌŽŵƚŚĞddͲ^W͘ x ĞƉůŽǇĂŶĚƐĞƚϯƐƚĂŐĞƉƵŵƉƐĞĐƚŝŽŶ͘ EŽƚĞƐZĞŐĂƌĚŝŶŐƚŚĞtĞůůΘĞƐŝŐŶ x ϳ͟ĐĂƐŝŶŐǁĂƐůĂƐƚƉƌĞƐƐƵƌĞƚĞƐƚĞĚĚŽǁŶƚŽϭϭ͕ϬϬϬ͛ŵĚƚŽϮ͕ϱϬϬƉƐŝĨŽƌϯϬŵŝŶƐŽŶϬϳͬϭϵͬϮϬϭϴ͘ WƌŽĐĞĚƵƌĞ͗ ŽŝůĞĚdƵďŝŶŐ EŽƚĞƐ͗ x ƵĞƚŽƚŚĞŶĞĐĞƐƐĂƌǇŽƉĞŶŚŽůĞĚĞƉůŽǇŵĞŶƚŽĨĂŶǆƚĞŶĚĞĚ,͕ϮϰͲŚŽƵƌĐƌĞǁĂŶĚt^^ĐŽǀĞƌĂŐĞŝƐ ƌĞƋƵŝƌĞĚ͘ x dŚĞǁĞůůǁŝůůďĞŬŝůůĞĚĂŶĚŵŽŶŝƚŽƌĞĚďĞĨŽƌĞƌĞĐŽǀĞƌǇŽĨƚŚĞddͲ^WƉƵŵƉƐĞĐƚŝŽŶƐ͘dŚŝƐǁŝůůďĞĚŽŶĞ ƉƌŝŽƌƚŽWKK,ĨƌŽŵƚŚĞƌĞĐŽǀĞƌǇŽĨƚŚĞƉĂĐŬŽĨĨ͘dŚŝƐǁŝůůƉƌŽǀŝĚĞŐƵŝĚĂŶĐĞĂƐƚŽǁŚĞƚŚĞƌƚŚĞǁĞůůǁŝůů ďĞŬŝůůĞĚďǇďƵůůŚĞĂĚŝŶŐŽƌĐŝƌĐƵůĂƚŝŶŐďŽƚƚŽŵƐƵƉƚŚƌŽƵŐŚŽƵƚƚ ŚĞũŽď͘/ĨƉƌĞƐƐƵƌĞŝƐƐĞĞŶŝŵŵĞĚŝĂƚĞůǇ ĂĨƚĞƌƉĞƌĨŽƌĂƚŝŶŐ͕ŝƚǁŝůůĞŝƚŚĞƌďĞŬŝůůĞĚďǇďƵůůŚĞĂĚŝŶŐǁŚŝůĞWKK,ŽƌĐŝƌĐƵůĂƚŝŶŐďŽƚƚŽŵƐƵƉƚŚƌŽƵŐŚ ƚŚĞƐĂŵĞƉŽƌƚƚŚĂƚŽƉĞŶĞĚƚŽƐŚĞĂƌƚŚĞĨŝƌŝŶŐŚĞĂĚ͘ʹ&ŽƌDWh&ͲϴϲƚŚĞǁĞůůǁŝůůďĞĐŝƌĐƵůĂƚĞĚ ďŽƚƚŽŵƐƵƉƚŽĂǀŽŝĚƉŽƐƐŝďŝůŝƚǇŽĨĐŚĂƌŐŝŶŐƚŚĞ<ƵƉĂƌƵŬ&ŽƌŵĂƚŝŽŶǁŚŝůĞďƵůůŚĞĂĚŝŶŐĂŶĞŶƚŝƌĞǁĞůů ǀŽůƵŵĞ͘ ϴ͘ϬWW'ͮ ddͲ^WWƵŵƉ^ĞĐƚŝŽŶ^ǁĂƉ tĞůů͗DWh&Ͳϴϲ Wd͗ϮϬϭͲϬϴϳ W/͗ϱϬͲϬϮϵͲϮϯϬϭϴͲϬϬͲϬϬ ϭ͘ D/ZhŽŝůĞĚdƵďŝŶŐhŶŝƚǁŝƚŚϮ͘Ϭ͟ĐŽŝůĞĚƚƵďŝŶŐĂŶĚƐƉŽƚĂŶĐŝ ůůĂƌǇĞƋƵŝƉŵĞŶƚ͘ Ϯ͘ WƌĞƐƐƵƌĞƚĞƐƚKWƚŽ ϯ͕ϱϬϬƉƐŝ,ŝϮϱϬ>Žǁ͕ϭϬŵŝŶĞĂĐŚƚĞƐƚ͘ Ă͘ ĂĐŚƐƵďƐĞƋƵĞŶƚƚĞƐƚŽĨƚŚĞůƵďƌŝĐĂƚŽƌǁŝůůďĞƚŽ ϯ͕ϱϬϬƉƐŝ,ŝϮϱϬ>ŽǁƚŽĐŽŶĨŝƌŵŶŽůĞĂŬƐ͘ ď͘ EŽK'ŶŽƚŝĨŝĐĂƚŝŽŶƌĞƋƵŝƌĞĚ͘ Đ͘ ZĞĐŽƌĚKWƚĞƐƚƌĞƐƵůƚƐŽŶϭϬͲϰϮϰĨŽƌŵ͘ Ě͘ /ĨǁŝƚŚŝŶƚŚĞƐƚĂŶĚĂƌĚϳͲĚĂǇƚĞƐƚKWƚĞƐƚƉĞƌŝŽĚ͕ĂĨƵůůďŽĚǇƚĞƐƚĂŶĚĨƵŶĐƚŝŽŶƚĞƐƚŽĨƚŚĞƌĂŵƐ ŝƐƐƵĨĨŝĐŝĞŶƚƚŽŵĞĞƚǁĞĞŬůǇKWƚĞƐƚƌĞƋƵŝƌĞŵĞŶƚ͘ ϯ͘ ĨƚĞƌDhD,ĂŶĚƉƵůůƚĞƐƚŝŶŐƚŚĞd͕ƚĂŐͲƵƉŽŶƚŚĞdƐƚƌŝƉ ƉĞƌƚŽĞŶƐƵƌĞ,ĐĂŶŶŽƚƉƵůůƚŚƌŽƵŐŚ ƚŚĞďƌĂƐƐƵƉŽŶWKK,ǁŝƚŚƚŚĞ,͘ ϰ͘ Dhϰ͟'^ĂŶĚZ/,ĂŶĚůĂƚĐŚƚŚĞƐůŝƉƐƚŽƉ͘:ĂƌĂƐŶĞĞĚĞĚƚŽĨƌĞĞĂŶĚWKK,͘ Ă͘ EŽƚĞƚŚĂƚ^>ĂŶĚƌĂŝĚĞĚ>ŝŶĞĂƚƚĞŵƉƚƐŚĂǀĞĨĂŝůĞĚƚŽƌĞĐŽǀĞƌ ͘ĂŝůĞƌƌƵŶƐŚĂǀĞďĞĞŶĐůĞĂŶ͘^ĞĞ t^Z͛ƐĚĂƚĞĚϴͬϭϰͲϴͬϭϱΘϴͬϮϮͲͬϮϰĨŽƌĂĚĚŝƚŝŽŶĂůĚĞƚĂŝůƐ͘ ϱ͘ Z/,ƚŽũƵƐƚĂďŽǀĞƚŚĞƉĂĐŬͲŽĨĨ͘ŝƌĐƵůĂƚĞƚŚĞǁĞůůŽǀĞƌƚŽƐŽƵƌĐĞǁĂƚĞƌ;ϴ͘ϯϯƉƉŐͿƚŽůŽĂĚĂŶĚŬŝůůƚŚĞ ƚƵďŝŶŐ͘ Ğ͘ ŽŶƚĂĐƚKƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌƚŽĐŽŶĨŝƌŵĐĂůĐƵůĂƚŝŽŶƐĨŽƌ<t&ƵƐŝŶŐƚŚĞ,ŐĂƵŐĞŝŶƚŚĞǁĞůů͘ ƵƌƌĞŶƚĞƐƚŝŵĂƚĞƐŝŶĚŝĐĂƚĞƚŚĞǁĞůůĐĂŶďĞŬŝůůĞĚǁŝƚŚƐŽƵƌĐĞǁĂƚĞƌ͘ Ĩ͘ tĞůůďŽƌĞǀŽůƵŵĞƚŽƚŽƉƉĞƌĨсϭϳϱďďůƐ Ő͘ ϰͲϭͬϮ͟dƵďŝŶŐʹϭϬ͕ϳϯϯ͛yϬ͘ϬϭϱϮсϭϲϯďďů Ś͘ ϳ͟>ŝŶĞƌ;ĐŽƵŶƚŝŶŐ^WŵŽƚŽƌƐĞĐƚŝŽŶǀŽůƵŵĞͿʹϯϭϰ͛y͘ϬϯϴϯďƉĨсϭϮďďů ϲ͘ ůĞĞĚŽĨĨĂůůt,WĂŶĚĐŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘ ϳ͘ Z/,ĂŶĚůĂƚĐŚƚŚĞƉĂĐŬͲŽĨĨ͘:ĂƌĨƌĞĞĂƐŶĞĞĚĞĚĂŶĚWKK,͘WŽƉŽĨĨĂŶĚ>ͬƉĂĐŬͲŽĨĨ͘ ϴ͘ ƚƐƵƌĨĂĐĞ͕ƉƌĞƉĂƌĞĨŽƌƌĞĐŽǀĞƌǇŽĨ^WdƌŝƉůĞWƵŵƉ^ĞĐƚŝŽŶ͘ ϵ͘ ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘ůĞĞĚĂŶǇƉƌĞƐƐƵƌĞŽĨĨƚŽƌĞƚƵƌŶƚĂŶŬ͘<ŝůůǁĞůůǁͬ<t&͕ϴ͘ϯϯƉƉŐƐŽƵƌĐĞǁĂƚĞƌ Žƌϴ͘ϱƉƉŐĂƐŶĞĞĚĞĚ͘DĂŝŶƚĂŝŶŚŽůĞĨŝůůƚĂŬŝŶŐƌĞƚƵƌŶƐƚŽƚĂŶŬƵŶƚŝůůƵď ƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶŝƐƌĞͲ ĞƐƚĂďůŝƐŚĞĚ͘&ůƵŝĚƐŵĂŶͲǁĂƚĐŚŵƵƐƚďĞƉĞƌĨŽƌŵĞĚǁŚŝůĞƌĞĐŽǀĞƌŝŶŐͬĚĞƉůŽǇŝŶŐ^WƉƵŵƉƐĞĐƚŝŽŶƚŽ ĞŶƐƵƌĞƚŚĞǁĞůůƌĞŵĂŝŶƐŬŝůůĞĚĂŶĚƚŚĞƌĞŝƐŶŽĞǆĐĞƐƐĨůŽǁ͘ ϭϬ͘ΎWĞƌĨŽƌŵĚƌŝůůďǇƉŝĐŬŝŶŐƵƉƐĂĨĞƚǇũŽŝŶƚǁŝƚŚd/tǀĂůǀĞĂŶĚƐƉĂĐĞŽƵƚďĞĨŽƌĞDh^WWƵŵƉƐĞĐƚŝŽŶ͘ ZĞǀŝĞǁǁĞůůĐŽŶƚƌŽůƐƚĞƉƐǁŝƚŚĐƌĞǁƉƌŝŽƌƚŽďƌĞĂŬŝŶŐůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂŶĚĐŽŵŵĞŶĐŝŶŐ ďƌĞĂŬĚŽǁŶͬŵĂŬĞƵƉŽĨϳϭ͛^WƉƵŵƉƐĞĐƚŝŽŶ͘KŶĐĞƚŚĞƐĂĨĞƚǇũŽŝŶƚĂŶĚd/tǀĂůǀĞŚĂǀĞďĞĞŶƐƉĂĐĞĚ ŽƵƚ͕ŬĞĞƉƚŚĞƐĂĨĞƚǇũŽŝŶƚͬd/tǀĂůǀĞƌĞĂĚŝůǇĂĐĐĞƐƐŝďůĞŶĞĂƌƚŚĞǁŽƌŬŝŶŐƉůĂƚĨŽƌŵĨŽƌƋƵŝĐŬĚĞƉůŽǇŵĞŶƚŝĨ ŶĞĐĞƐƐĂƌǇ͘ Ă͘ƚƚŚĞďĞŐŝŶŶŝŶŐŽĨĞĂĐŚũŽď͕ƚŚĞĐƌŽƐƐŽǀĞƌͬƐĂĨĞƚǇũŽŝŶƚŵƵƐƚďĞƉŚǇƐŝĐĂůůǇDhƚŽƚŚĞƚŽƉŽĨƚŚĞ ^WƉƵŵƉƐĞĐƚŝŽŶŽŶĞƚŝŵĞƚŽĐŽŶĨŝƌŵƚŚĞϰ͟'^ŝƐĐŽŵƉĂƚŝďůĞ͘ ϭϭ͘Z/,ĂŶĚůĂƚĐŚŝŶƚŽƉƵŵƉƐĞĐƚŝŽŶ͘:ĂƌĨƌĞĞĂŶĚƉƵůůƚŽƐƵƌĨĂĐĞ͘KŶĐĞĂƚƐƵƌĨĂĐĞ͕ĐŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘<ŝůů ǁĞůůĚŽǁŶďĂĐŬƐŝĚĞĂƐŶĞĞĚĞĚĂŶĚďůĞĞĚŽĨĨĂŶǇƌĞƐŝĚƵĂůƉƌĞƐƐƵƌĞ͘ Ă͘^ĞĞt^ZĚĂƚĞĚϬϲͬϮϬͬϮϬϮϮĨŽƌŚŽǁƉƌĞǀŝŽƵƐůŽǁĞƌƉƵŵƉƐĞĐƚŝŽŶǁĂƐƌĞĐŽǀĞƌĞĚŽƌĐŽŶƚĂĐƚK ĨŽƌĚŝƐĐƵƐƐŝŽŶŽŶŚŽǁƚŽĂĐŚŝĞǀĞůĂƌŐĞƌũĂƌůŝĐŬ͘ ϭϮ͘ƌĞĂŬůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂƚYd^ĂŶĚŚĂŶŐŽĨĨ^W͘ĞŐŝŶƌĞĐŽǀĞƌǇŽĨ^WWƵŵƉƐĞĐƚŝŽŶƉĞƌƐĐŚĞĚƵůĞ ďĞůŽǁ͘ŽŶƐƚĂŶƚůǇŵŽŶŝƚŽƌĨůƵŝĚƌĂƚĞƐƉƵŵƉĞĚŝŶĂŶĚĨůƵŝĚƌĞƚƵ ƌŶƐŽƵƚŽĨƚŚĞǁĞůů͘&ůƵŝĚƐŵĂŶͲǁĂƚĐŚ ŵƵƐƚďĞƉĞƌĨŽƌŵĞĚǁŚŝůĞĚĞƉůŽǇŝŶŐƉĞƌĨŐƵŶƐƚŽĞŶƐƵƌĞƚŚĞǁĞůůƌĞŵĂŝŶƐŬŝůůĞĚĂŶĚƚŚĞƌĞŝƐŶŽĞǆĐĞƐƐ ĨůŽǁ͘ ŽŶƚŝŶŐĞŶĐǇʹ/ĨƚŚĞƌĞŝƐĚĞďƌŝƐͬƌŽůůĞƌŝŶƚŚĞƚŽƉŽĨƚŚĞ^WƐŚĂĨƚƉƌĞǀĞŶƚŝŶŐƌŽƚĂƚŝŽŶ Ă͘ ŚĞĐŬƚŚĞƚŽƉŽĨƚŚĞ^WƐŚĂĨƚĨŽƌĚĞďƌŝƐ͘ƌŽůůĞƌĨƌŽŵƚŚĞ^>ƚŽŽůƐƚƌŝŶŐǁĂƐůŽƐƚŝŶŚŽůĞĂŶĚŶŽƚ ƌĞĐŽǀĞƌĞĚǁŚŝůĞƐĞƚƚŝŶŐƚŚĞƉĂĐŬŽĨĨĂŶĚĐŽƵůĚďĞůŽĚŐĞĚŝŶƚŽƚŚĞƚŽƉŽĨƚŚĞƐŚĂĨƚ͘/ĨƚŚŝƐŝƐƚŚĞ ĐĂƐĞĂŶĚŝƚĐĂŶďĞƌĞŵŽǀĞĚĂŶĚƚŚĞƐŚĂĨƚƌŽƚĂƚĞƐĨƌĞĞůǇ͕ĚŽŶŽƚƉƵůůƚŚĞddͲ^WWƵŵƉ^ĞĐƚŝŽŶƐ ĨƌŽŵƚŚĞǁĞůů͘ZĞͲĞŶŐĂŐĞĨŝƐŚǁŝƚŚ'^͕ƉƵůůƚŚĞĐͲƉůĂƚĞĂŶĚƌĞͲĐŽŶŶĞĐƚĂƚƚŚĞYd^͘WƌĞƐƐƵƌĞƚĞƐƚ Yd^͘ ddͲ^WWƵŵƉ^ĞĐƚŝŽŶ^ǁĂƉ tĞůů͗DWh&Ͳϴϲ Wd͗ϮϬϭͲϬϴϳ W/͗ϱϬͲϬϮϵͲϮϯϬϭϴͲϬϬͲϬϬ ď͘ Z/,ǁͬddͲ^WWƵŵƉƐĞĐƚŝŽŶƐĂŶĚůĂŶĚ͘WƵŵƉŽĨĨŽĨ'^ĂŶĚůĞĂǀĞŝŶƉůĂĐĞ͘ ϭϯ͘ /ŶƐƉĞĐƚĞĂĐŚƉƵŵƉƐĞĐƚŝŽŶƚŽĚĞƚĞƌŵŝŶĞŝĨϭ͕ϮŽƌϯƉƵŵƉƐĞĐƚŝŽŶƐĂƌĞďŽƵŶĚƵƉ͘ĂƐĞƉůĂŶŝƐƚŽƌĞͲƵƐĞ ĂƚůĞĂƐƚϭƉƵŵƉƐĞĐƚŝŽŶƚŽďĞĂďůĞƚŽĚĞƉůŽǇϯƉƵŵƉƐĞĐƚŝŽŶƐĂŐĂŝŶ͘ƵƌƌĞŶƚůǇƚŚĞƌĞĂƌĞϮƐƉĂƌĞƉƵŵƉ ƐĞĐƚŝŽŶƐĂǀĂŝůĂďůĞ͘ ϭϰ͘ DhŶĞǁddͲ^WdƌŝƉůĞWƵŵƉ^ĞĐƚŝŽŶƐĂƐƉĞƌƐĞĐƚŝŽŶƐŝŶƚŚĞĂ ƚƚĂĐŚŵĞŶƚƐǁŚŝůĞŵĂŝŶƚĂŝŶŝŶŐŚŽůĞĨŝůů͘ ϭϱ͘ Z/,ǁͬddͲ^WWƵŵƉƐĞĐƚŝŽŶƐĂŶĚůĂŶĚ͘WƵŵƉŽĨĨŽĨ'^ĂŶĚůĞĂǀĞŝŶƉůĂĐĞ͘ ď͘ EŽƚĞĂŶǇƚƵďŝŶŐƉƌĞƐƐƵƌĞĐŚĂŶŐĞŝŶt^Z͘ ϭϲ͘ ĨƚĞƌƐĞƚƚŝŶŐ͕Wh,ĂŶĚĞŶƐƵƌĞƚŚĂƚƚŚĞƉƵŵƉƐĞĐƚŝŽŶƐĂƌĞŝŶƉůĂĐĞĚŽǁŶŚŽůĞ͘ Ă͘ /ĨƉƵŵƉƐĂƌĞůĞĨƚŝŶŚŽůĞ͕WKK,ĂƐŶŽƌŵĂůĂŶĚĨƌĞĞǌĞƉƌŽƚĞĐƚǁĞůůŽŶǁĂǇKK,;ǁŝůůŶŽƚŶĞĞĚ ŽƉĞŶŚŽůĞŽƉĞƌĂƚŝŽŶƐƚŽďƌĞĂŬͲŽĨĨŽĨǁĞůůͿ͘ ď͘ /ĨĂŶǇŝŶĚŝĐĂƚŝŽŶƚŚĂƚƚŚĞ^WWƵŵƉ^ĞĐƚŝŽŶƐĂƌĞƐƚŝůůĂƚƚĂĐŚĞĚƚŽĐŽŝů͗ ŝ͘ ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚĂŶĚƌĞͲŬŝůůŝĨŶĞĐĞƐƐĂƌǇďĞĨŽƌĞƉƵůůŝŶŐƚŽƐƵƌĨĂĐĞ͘WƵŵƉƉŝƉĞ ĚŝƐƉůĂĐĞŵĞŶƚǁŚŝůĞWKK,͘ ŝŝ͘ ^ƚŽƉĂƚƐƵƌĨĂĐĞƚŽƌĞĐŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘<ŝůůǁĞůůŝĨŶĞĐĞƐƐĂƌǇ͘ZĞǀŝĞǁǁĞůůĐŽŶƚƌŽůƐƚĞƉƐ ĂŶĚ^ƚĂŶĚŝŶŐKƌĚĞƌƐǁŝƚŚĐƌĞǁƉƌŝŽƌƚŽďƌĞĂŬŝŶŐůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂŶĚĐŽŵŵĞŶĐŝŶŐ ďƌĞĂŬĚŽǁŶŽĨ^WWƵŵƉ^ĞĐƚŝŽŶ͘ ŝŝŝ͘ ŶƐƵƌĞƐĂĨĞƚǇũŽŝŶƚĂŶĚd/tǀĂůǀĞĂƐƐĞŵďůǇĂƌĞŽŶͲŚĂŶĚďĞĨŽƌĞďƌĞĂŬŝŶŐŽĨĨůƵďƌŝĐĂƚŽƌ ƚŽĐŚĞĐŬ^WWƵŵƉ^ĞĐƚŝŽŶ͘ ϭϳ͘ ZDKdh͘ ϭϴ͘ ZdWŽƌ&WǁĞůů͘ ^ůŝĐŬůŝŶĞ ϭ͘ Zh^>hŶŝƚĂŶĚƉƌĞƐƐƵƌĞƚĞƐƚWƚŽϮϱϬƉƐŝůŽǁͬϮ͕ϱϬϬƉƐŝŚŝŐŚ͘ Ϯ͘ Z/,ĂŶĚƐĞƚƉĂĐŬŽĨĨ͘ ϯ͘ Z/,ĂŶĚƐĞƚƚĞƐƚƚŽŽůŝŶƚŽƉĂĐŬŽĨĨĂŶĚƉƌĞƐƐƵƌĞƚĞƐƚƚƵďŝŶŐƚŽϭ͕ϬϬϬƉƐŝ͘WKK,ǁͬƚĞƐƚƚŽŽů͘ ϰ͘ Z/,ĂŶĚƐĞƚƚƵďŝŶŐƐƚŽƉ͘ ϱ͘ ZDK^>ƵŶŝƚ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƵƌƌĞŶƚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ ddͲ^WŝĂŐƌĂŵ ϰ͘ ŽŝůdƵďŝŶŐKW^ĐŚĞŵĂƚŝĐ ϱ͘ ^ƚĂŶĚŝŶŐKƌĚĞƌƐĨŽƌKƉĞŶ,ŽůĞtĞůůŽŶƚƌŽůĚƵƌŝŶŐWĞƌĨ'ƵŶĞƉůŽǇŵĞŶƚ ϲ͘ ƋƵŝƉŵĞŶƚ>ĂǇŽƵƚŝĂŐƌĂŵ 77&(637RWDO$VVHPEO\/HQJWKIW 77&(630D[LPXP$VVHPEO\'LDPHWHULQ &RLO7XELQJ5XQ 77&(637RWDO$VVHPEO\:HLJKWOE 'HSHQGLQJRQ%+3IUHH]HSURWHFWFRXOGXQGHUEDODQFHZHOO 083&( BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϳͬϭϵͬϮϬϮϮ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DW&Ͳϴϲ >ĂƐƚŽŵƉůĞƚĞĚ͗ϳͬϮϭͬϮϬϭϴ Wd͗ϮϬϭͲϬϴϳ dсϭϭ͕ϯϭϲ͛;DͿͬdсϳ͕Ϯϴϳ͛;dsͿ ϮϬ´ K<ůĞǀ͗͘ϰϮ͘ϵ͛ͬKƌŝŐ͘'>ůĞǀ͗͘ϭϬ͘ϵ͛ ŽǇŽŶϭϲZdƚŽddďŐƐƉŽŽůсϮϮ͘ϰϮ͛ ϳ͟ ´ 7$0 3RUW&ROODU# ¶ ϵͲϱͬϴ͟ Wdсϭϭ͕ϮϬϮ͛;DͿͬWdсϳ͕ϭϳϲ͛;dsͿ ´&DS 6WULQJ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ W& ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϭ͘ϭͬ,ͲϰϬͬEͬ Eͬ ^ƵƌĨĂĐĞ ϭϭϮΖ Ϭ͘ϯϱϱ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬd ϴ͘ϴϯϱ ^ƵƌĨĂĐĞ ϲ͕ϱϭϴ͛ Ϭ͘Ϭϳϱϴ ϳΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϲͬ>ͲϴϬͬdͲD ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϭϭ͕Ϯϵϲ͛ Ϭ͘Ϭϯϴϯ dh/E'd/> ϰͲϭͬϮΗ dƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬ,ǇĚƌŝůϱϮϭ ϯ͘ϵϱϴ ^ƵƌĨĂĐĞ ϭϬ͕ϳϳϱ͛ Ϭ͘ϬϭϱϮ ϯͬϴ͟ ĂƉ^ƚƌŝŶŐ ^ƚĂŝŶůĞƐƐ^ƚĞĞů Eͬ ^ƵƌĨĂĐĞ ϭϬ͕ϳϳϱ͛ Eͬ :t>Zzd/> EŽ dŽƉ;DͿ /ƚĞŵ ϭ ϭϬ͕ϲϰϰ͛ ΘdƵďŝŶŐ^ƚŽƉtͬϰΗ'^&E Ϯ ϭϬ͕ϲϰϲ͛ ΘWĂĐŬKĨĨ/,ŝͲ&ůŽǁ ϯ ϭϬ͕ϲϱϰ͛ Θ^ƚŝŶŐĞƌϮϳͬϴΗhyDŽůǇWĂĐŬŝŶŐ ϰ ϭϬ͕ϲϱϱ͘ϴ͛ ŝƐĐŚĂƌŐĞ,ĞĂĚϯϴϬWƵŵƉϮϯͬϴΗϴZĚhyŽů ϱ ϭϬ͕ϲϱϲ WhDWϯϴϬ^y͕ϭϭϲWϭϴ,ϲ&Z ϲ ϭϬ͕ϲϳϳ͛ WhDWϯϴϬ^y͕ϭϭϲWϭϴ,ϲ&Z ϳ ϭϬ͕ϲϵϳ͛ WhDWϯϴϬ^y͕ϭϭϲWϭϴ,ϲ&Z ϴ ϭϬ͕ϳϭϴ͛ 'ĂƐ^ĞƉĞƌĂƚŽƌ͖ϯϴϬ'^sd,syD ϵ ϭϬ͕ϳϮϮ͛ WhDWzdd^W ϭϬ ϭϬ͕ϳϮϰ͛ yͬKϰ͘ϱ͟,ǇĚϱϮϭyϰ͘ϱ͟E^dW ϭϭ ϭϬ͕ϳϯϯ͛ ddĚƌŝůůĞĚƚƵďŝŶŐĐƌŽƐƐŽǀĞƌ ϭϮ ϭϬ͕ϳϰϰ͛ dĂŶĚĞŵƐĞĂůƐĞĐƚŝŽŶƐ;DŽĚĞů'^ϯͿ ϭϯ ϭϬ͕ϳϱϴ͛ DŽƚŽƌ͕yWͲϮϬϬ͕ϮϬϬ,W͕ϯϲϯϱǀŽůƚ͕ϯϰĂŵƉ ϭϰ ϭϬ͕ϳϳϮ͛ tĞůů>ŝĨƚ^ĞŶƐŽƌǁŝƚŚϲĨŝŶĞŶƚƌĂůŝǌĞƌʹ ŽƚƚŽŵΛϭϬ͕ϳϳϱ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ <ƵƉ͘ϯ ϭϭ͕Ϭϰϳ͛ ϭϭ͕Ϭϱϳ͛ ϳ͕ϬϮϲ͛ ϳ͕Ϭϯϲ͛ ϭϬ ϴͬϮϲͬϮϬϬϭ KƉĞŶ <ƵƉ͘Ϯ ϭϭ͕Ϭϲϰ͛ ϭϭ͕Ϭϳϰ͛ ϳ͕Ϭϰϯ͛ ϳ͕Ϭϱϯ͛ ϭϬ ϴͬϮϲͬϮϬϬϭ KƉĞŶ <ƵƉ͘ϭ ϭϭ͕Ϭϴϲ͛ ϭϭ͕Ϭϵϲ͛ ϳ͕Ϭϲϰ͛ ϳ͕Ϭϳϰ͛ ϭϬ ϴͬϮϲͬϮϬϬϭ KƉĞŶ <ƵƉ͘Ϯͬϭ ϭϭ͕Ϭϲϴ͛ ϭϭ͕ϭϬϴ͛ ϳ͕Ϭϰϲ͛ ϳ͕Ϭϴϱ͛ ϰϬ ϲͬϬϮͬϮϬϬϲ KƉĞŶ ZĞĨ>ŽŐ͗^t^:ĞǁĞůƌǇ>ŽŐͲϴͬϭϬͬϮϬϬϭ KWE,K>ͬDEdd/> ϮϬΗ ϮϲϬƐǆŽĨƌĐƚŝĐƐĞƚ/ŝŶϯϬ͟,ŽůĞ ϵͲϱͬϴ͟ ϭϬϬϬƐǆW&>ŝŶϭϮͲϭͬϰ͟ŚŽůĞƉůƵƐϮϮϱƐǆůĂƐƐ͞'͟ ϳΗ ϮϬϬƐǆůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟ŚŽůĞ͕ĞƐƚ͘dKсϵ͕ϰϴϱ͛ t>>/E>/Ed/KE d/> <KWΛϰϬϬ͛ DĂǆ,ŽůĞŶŐůĞсϲϲĚĞŐ͘Λϰ͕ϬϱϬ͛ DĂǆ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϭϱĚĞŐ͘ dZΘt>>, dƌĞĞ ϱD/tϰ͟ tĞůůŚĞĂĚ ϭϭ͟ϱD&D'ĞŶϱ͕ǁͬϰͲϭͬϮ͟&DdďŐ͘,ŶŐƌ͕͘ ϰͲϭͬϮ͟,ǇĚƌŝůϱϮϭdŽƉΘƚŵ͘,ĂŶŐĞƌƚŚƌĞĂĚĂŶĚ ϰ͟͞,͟WsƉƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϯϬϭϴͲϬϬ KƌŝŐ͘ƌŝůůŝŶŐďǇEĂďŽƌƐϮϳʹϴͬϬϲͬϮϬϬϭ KƌŝŐ͘ŽŵƉůĞƚŝŽŶďǇEĂďŽƌƐϰ^ʹϵͬϮϳͬϮϬϬϭ ZtKǁͬEĂďŽƌƐϯ^͕^WĐͬŽ͕&KĂŶĚĚĚWĞƌĨƐʹϲͬϬϰͬϮϬϬϲ ZtKǁͬEĂďŽƌƐϯ^͕^WĐͬŽ͕&KĂŶĚŝŶƐƚĂůůƐĐƌĞĞŶʹϮͬϬϲͬϮϬϬϳ ZtKǁͬEĂďŽƌƐϰ^͕^WĐͬŽʹϴͬϮϰͬϮϬϬϴ ZtWǁͬEĂďŽƌƐϯ^͕^WĐͬŽĂŶĚĂĚĚĐĂƉƚƵďĞʹϱͬϭϯͬϮϬϬϵ ZtKǁͬŽǇŽŶϭϲ͕^WĐͬŽĂŶĚƌƵŶĨƌĂĐƐƚƌŝŶŐʹϯͬϬϯͬϮϬϭϭ ZtKǁͬŽǇŽŶϭϲ͕ŝŶƐƚĂůůdd^WĂŶĚ&KʹϲͬϮϭͬϮϬϭϭ ZtKǁͬ/ͲZŝŐ͕ŝŶƐƚĂůůdd^WĂŶĚ&KʹϳͬϮϭͬϮϬϭϴ ZtKǁͬdhηϵ͕ŝŶƐƚĂůůdd^WĂŶĚ&KʹϲͬϮϯͬϮϬϮϮ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϵͬϲͬϮϬϮϮ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DW&Ͳϴϲ >ĂƐƚŽŵƉůĞƚĞĚ͗ϳͬϮϭͬϮϬϭϴ Wd͗ϮϬϭͲϬϴϳ ? dсϭϭ͕ϯϭϲ͛;DͿͬdсϳ͕Ϯϴϳ͛;dsͿ ϮϬ´ K<ůĞǀ͗͘ϰϮ͘ϵ͛ͬKƌŝŐ͘'>ůĞǀ͗͘ϭϬ͘ϵ͛ ŽǇŽŶϭϲZdƚŽddďŐƐƉŽŽůсϮϮ͘ϰϮ͛ ϳ͟ ´ 7$0 3RUW&ROODU# ¶ ϵͲϱͬϴ͟ Wdсϭϭ͕ϮϬϮ͛;DͿͬWdсϳ͕ϭϳϲ͛;dsͿ ´&DS 6WULQJ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ W& ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϭ͘ϭͬ,ͲϰϬͬEͬ Eͬ ^ƵƌĨĂĐĞ ϭϭϮΖ Ϭ͘ϯϱϱ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬd ϴ͘ϴϯϱ ^ƵƌĨĂĐĞ ϲ͕ϱϭϴ͛ Ϭ͘Ϭϳϱϴ ϳΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϲͬ>ͲϴϬͬdͲD ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϭϭ͕Ϯϵϲ͛ Ϭ͘Ϭϯϴϯ dh/E'd/> ϰͲϭͬϮΗ dƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬ,ǇĚƌŝůϱϮϭ ϯ͘ϵϱϴ ^ƵƌĨĂĐĞ ϭϬ͕ϳϳϱ͛ Ϭ͘ϬϭϱϮ ϯͬϴ͟ ĂƉ^ƚƌŝŶŐ ^ƚĂŝŶůĞƐƐ^ƚĞĞů Eͬ ^ƵƌĨĂĐĞ ϭϬ͕ϳϳϱ͛ Eͬ :t>Zzd/> EŽ dŽƉ;DͿ /ƚĞŵ ϭ цϭϬ͕ϲϰϰ͛ ΘdƵďŝŶŐ^ƚŽƉtͬϰΗ'^&E Ϯ цϭϬ͕ϲϰϲ͛ ΘWĂĐŬKĨĨ/,ŝͲ&ůŽǁ ϯ цϭϬ͕ϲϱϰ͛ Θ^ƚŝŶŐĞƌϮϳͬϴΗhyDŽůǇWĂĐŬŝŶŐ ϰ цϭϬ͕ϲϱϱ͘ϴ͛ ŝƐĐŚĂƌŐĞ,ĞĂĚ͗ ϱ цϭϬ͕ϲϱϲ WhDWηϯ͗ ϲ цϭϬ͕ϲϳϳ͛ WhDWηϮ͗ ϳ цϭϬ͕ϲϵϳ͛ WhDWηϭ͗ ϴ цϭϬ͕ϳϭϴ͛ 'ĂƐ^ĞƉĂƌĂƚŽƌ͗ ϵ цϭϬ͕ϳϮϮ͛ WhDWzdd^W ϭϬ ϭϬ͕ϳϮϰ͛ yͬKϰ͘ϱ͟,ǇĚϱϮϭyϰ͘ϱ͟E^dW ϭϭ ϭϬ͕ϳϯϯ͛ ddĚƌŝůůĞĚƚƵďŝŶŐĐƌŽƐƐŽǀĞƌ ϭϮ ϭϬ͕ϳϰϰ͛ dĂŶĚĞŵƐĞĂůƐĞĐƚŝŽŶƐ;DŽĚĞů'^ϯͿ ϭϯ ϭϬ͕ϳϱϴ͛ DŽƚŽƌ͕yWͲϮϬϬ͕ϮϬϬ,W͕ϯϲϯϱǀŽůƚ͕ϯϰĂŵƉ ϭϰ ϭϬ͕ϳϳϮ͛ tĞůů>ŝĨƚ^ĞŶƐŽƌǁŝƚŚϲĨŝŶĞŶƚƌĂůŝǌĞƌʹ ŽƚƚŽŵΛϭϬ͕ϳϳϱ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ <ƵƉ͘ϯ ϭϭ͕Ϭϰϳ͛ ϭϭ͕Ϭϱϳ͛ ϳ͕ϬϮϲ͛ ϳ͕Ϭϯϲ͛ ϭϬ ϴͬϮϲͬϮϬϬϭ KƉĞŶ <ƵƉ͘Ϯ ϭϭ͕Ϭϲϰ͛ ϭϭ͕Ϭϳϰ͛ ϳ͕Ϭϰϯ͛ ϳ͕Ϭϱϯ͛ ϭϬ ϴͬϮϲͬϮϬϬϭ KƉĞŶ <ƵƉ͘ϭ ϭϭ͕Ϭϴϲ͛ ϭϭ͕Ϭϵϲ͛ ϳ͕Ϭϲϰ͛ ϳ͕Ϭϳϰ͛ ϭϬ ϴͬϮϲͬϮϬϬϭ KƉĞŶ <ƵƉ͘Ϯͬϭ ϭϭ͕Ϭϲϴ͛ ϭϭ͕ϭϬϴ͛ ϳ͕Ϭϰϲ͛ ϳ͕Ϭϴϱ͛ ϰϬ ϲͬϬϮͬϮϬϬϲ KƉĞŶ ZĞĨ>ŽŐ͗^t^:ĞǁĞůƌǇ>ŽŐͲϴͬϭϬͬϮϬϬϭ KWE,K>ͬDEdd/> ϮϬΗ ϮϲϬƐǆŽĨƌĐƚŝĐƐĞƚ/ŝŶϯϬ͟,ŽůĞ ϵͲϱͬϴ͟ ϭϬϬϬƐǆW&>ŝŶϭϮͲϭͬϰ͟ŚŽůĞƉůƵƐϮϮϱƐǆůĂƐƐ͞'͟ ϳΗ ϮϬϬƐǆůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟ŚŽůĞ͕ĞƐƚ͘dKсϵ͕ϰϴϱ͛ t>>/E>/Ed/KE d/> <KWΛϰϬϬ͛ DĂǆ,ŽůĞŶŐůĞсϲϲĚĞŐ͘Λϰ͕ϬϱϬ͛ DĂǆ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϭϱĚĞŐ͘ dZΘt>>, dƌĞĞ ϱD/tϰ͟ tĞůůŚĞĂĚ ϭϭ͟ϱD&D'ĞŶϱ͕ǁͬϰͲϭͬϮ͟&DdďŐ͘,ŶŐƌ͕͘ ϰͲϭͬϮ͟,ǇĚƌŝůϱϮϭdŽƉΘƚŵ͘,ĂŶŐĞƌƚŚƌĞĂĚĂŶĚ ϰ͟͞,͟WsƉƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϯϬϭϴͲϬϬ KƌŝŐ͘ƌŝůůŝŶŐďǇEĂďŽƌƐϮϳʹϴͬϬϲͬϮϬϬϭ KƌŝŐ͘ŽŵƉůĞƚŝŽŶďǇEĂďŽƌƐϰ^ʹϵͬϮϳͬϮϬϬϭ ZtKǁͬEĂďŽƌƐϯ^͕^WĐͬŽ͕&KĂŶĚĚĚWĞƌĨƐʹϲͬϬϰͬϮϬϬϲ ZtKǁͬEĂďŽƌƐϯ^͕^WĐͬŽ͕&KĂŶĚŝŶƐƚĂůůƐĐƌĞĞŶʹϮͬϬϲͬϮϬϬϳ ZtKǁͬEĂďŽƌƐϰ^͕^WĐͬŽʹϴͬϮϰͬϮϬϬϴ ZtWǁͬEĂďŽƌƐϯ^͕^WĐͬŽĂŶĚĂĚĚĐĂƉƚƵďĞʹϱͬϭϯͬϮϬϬϵ ZtKǁͬŽǇŽŶϭϲ͕^WĐͬŽĂŶĚƌƵŶĨƌĂĐƐƚƌŝŶŐʹϯͬϬϯͬϮϬϭϭ ZtKǁͬŽǇŽŶϭϲ͕ŝŶƐƚĂůůdd^WĂŶĚ&KʹϲͬϮϭͬϮϬϭϭ ZtKǁͬ/ͲZŝŐ͕ŝŶƐƚĂůůdd^WĂŶĚ&KʹϳͬϮϭͬϮϬϭϴ ZtKǁͬdhηϵ͕ŝŶƐƚĂůůdd^WĂŶĚ&KʹϲͬϮϯͬϮϬϮϮ ddͲ^WWƵŵƉ^ĞĐƚŝŽŶ^ǁĂƉ tĞůů͗DWh&Ͳϴϲ Wd͗ϮϬϭͲϬϴϳ W/͗ϱϬͲϬϮϵͲϮϯϬϭϴͲϬϬͲϬϬ ddͲ^WŝĂŐƌĂŵ ddͲ^WWƵŵƉ^ĞĐƚŝŽŶ^ǁĂƉ tĞůů͗DWh&Ͳϴϲ Wd͗ϮϬϭͲϬϴϳ W/͗ϱϬͲϬϮϵͲϮϯϬϭϴͲϬϬͲϬϬ ŽŝůĞĚdƵďŝŶŐKWƐ ^ƚĂŶĚŝŶŐKƌĚĞƌƐĨŽƌKƉĞŶ,ŽůĞtĞůůŽŶƚƌŽůĚƵƌŝŶŐWĞƌĨ'ƵŶĞƉůŽǇŵĞŶƚ ddͲ^WWƵŵƉ^ĞĐƚŝŽŶ^ǁĂƉ tĞůů͗DWh&Ͳϴϲ Wd͗ϮϬϭͲϬϴϳ W/͗ϱϬͲϬϮϵͲϮϯϬϭϴͲϬϬͲϬϬ ddͲ^WWƵŵƉ^ĞĐƚŝŽŶ^ǁĂƉ tĞůů͗DWh&Ͳϴϲ Wd͗ϮϬϭͲϬϴϳ W/͗ϱϬͲϬϮϵͲϮϯϬϭϴͲϬϬͲϬϬ ƋƵŝƉŵĞŶƚ>ĂǇŽƵƚŝĂŐƌĂŵ By Samantha Carlisle at 8:35 am, Jul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aylor Wellman for David Haakinson By Samantha Carlisle at 10:33 am, Mar 24, 2022 0LOQH 3RLQW )LHOG .XSDUXN 5LYHU 2LO 'LJLWDOO\VLJQHGE\7D\ORU :HOOPDQ '1FQ 7D\ORU:HOOPDQ RX 8VHUV 'DWH 7D\ORU:HOOPDQ '65 $'/$'/$'/6)' 0*5$356)' KRXUVHUYLFHFRLOFUHZZLOOEHXWLOL]HG GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.04.11 14:03:53 -08'00' RBDMS SJC 041222 ddͲ^WWƵŵƉ^ĞĐƚŝŽŶ^ǁĂƉ tĞůů͗DWh&Ͳϴϲ Wd͗ϮϬϭͲϬϴϳ W/͗ϱϬͲϬϮϵͲϮϯϬϭϴͲϬϬͲϬϬ tĞůůEĂŵĞ͗DWh&Ͳϴϲ W/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϯϬϭϴͲϬϬͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗WƌŽĚƵĐĞƌ΀^ŚƵƚŝŶ^W΁ WĂĚ͗&ͲWĂĚ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗Ɖƌŝůϱ͕ϮϬϮϮ ZŝŐ͗d ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍zĞƐ ĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ĂƌĐŝ,ŽƌŶĞƌ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϬϭͲϬϴϳ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗dĂǇůŽƌtĞůůŵĂŶ ;ϵϬϳͿϳϳϳͲϴϰϰϵ;KͿ ;ϵϬϳͿϵϰϳͲϵϱϯϯ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗ƌŝĂŶ'ůĂƐŚĞĞŶ ;ϵϬϳͿϱϲϰͲϱϮϳϳ;KͿ ;ϵϬϳͿϱϰϱͲϭϭϰϰ;DͿ &EƵŵďĞƌ͗:ŽďdǇƉĞ͗ddͲ^WWƵŵƉ^ǁĂƉ ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗Ϯ͕ϳϯϬƉƐŝΛϲ͕ϳϲϬ͛dsϳ͘ϴWW'ͮdĂŬĞŶϬϯͬϮϮͬϮϬϮϮ DĂǆŝŵƵŵǆƉĞĐƚĞĚ,W͗Ϯ͕ϴϬϬƉƐŝΛϲ͕ϳϲϬ͛dsϴ͘ϬWW'ͮWƌŽũĞĐƚĞĚWhͿ DĂǆ͘ŶƚŝĐŝƉĂƚĞĚ^ƵƌĨĂĐĞWƌĞƐƐƵƌĞ͗Ϯ͕ϭϮϰƉƐŝ ;ĂƐĞĚŽŶϬ͘ϭƉƐŝͬĨƚ͘ŐĂƐŐƌĂĚŝĞŶƚͿ >ĂƐƚ^/t,W͗ϴϲϬƉƐŝ ;ϬϯͬϮϮͬϮϬϮϮʹ/ƉƌĞƐƐƵƌĞ͕ƉĂĐŬĞƌůĞƐƐ^WͿ DŝŶ/͗ϯ͘ϵϱϴ͟/ΛϬ͛D dƵďŝŶŐ,ĂŶŐĞƌ DĂǆŶŐůĞ͗ϲϱ͘ϯΣΛϯ͕ϵϱϬ͛D DĂǆŽŐůĞŐ͗ϰ͘ϵΣͬϭϬϬĨƚΛϮ͕ϰϬϬ͛D ƌŝĞĨtĞůů^ƵŵŵĂƌǇ͗ DWh&ͲϴϲŝƐĂ<ƵƉĂƌƵŬƐĂŶĚƉƌŽĚƵĐĞƌ͘/ƚǁĂƐĚƌŝůůĞĚĂŶĚĐŽŵƉůĞƚĞĚŝŶϮϬϬϭǁŝƚŚĂĐŽŶǀĞŶƚŝŽŶĂů^W͘ DƵůƚŝƉůĞ^WĐŚĂŶŐĞŽƵƚƐǁĞƌĞĐŽŶĚƵĐƚĞĚďĞƚǁĞĞŶϮϬϬϲĂŶĚϮϬϭϭ͘/ŶϮϬϭϭƚŚĞǁĞůůĂdŚƌƵdƵďŝŶŐŽŶǀĞǇĞĚ ^W;ddͲ^WͿǁĂƐŝŶƐƚĂůůĞĚ͘dŚŝƐ^WŚĂƐĂƉĞƌŵĂŶĞŶƚůǇŝŶƐƚĂůůĞĚŵŽƚŽƌŽŶƚŚĞƚƵďŝŶŐƐƚƌŝŶŐďƵƚƚŚĞƉƵŵƉ ƐĞĐƚŝŽŶƐĐĂŶďĞƌĞƉůĂĐĞĚǁŝƚŚĐŽŝůƚƵďŝŶŐ͘dŚĞǁĞůůŚĂƐŚĂĚŵƵůƚŝƉůĞ^WƉƵŵƉƐĞĐƚŝŽŶĐŚĂŶŐĞŽƵƚƐƚŚƌŽƵŐŚŝƚƐ ůŝĨĞƚŝŵĞ͘ƵƌŝŶŐĂƌĞĐĞŶƚƉůĂŶƚƐŚƵƚĚŽǁŶƚŚĞƉƵŵƉƐĞĐƚŝŽŶƐďĞĐĂŵĞĚĂŵĂŐĞĚĂŶĚƚŚĞǁĞůůǁŝůůŶŽůŽŶŐĞƌ ƐƵƌĨĂĐĞĨůƵŝĚƐ͘ KďũĞĐƚŝǀĞƐ͗ x ZŝŐƵƉĂŶĚƉƵůůƉƵŵƉƐĞĐƚŝŽŶƐĨƌŽŵƚŚĞddͲ^W͘ x ĞƉůŽǇĂŶĚƐĞƚϯƐƚĂŐĞƉƵŵƉƐĞĐƚŝŽŶ;ďŽůƚĞĚƚŽŐĞƚŚĞƌŶĞĐĞƐƐŝƚĂƚŝŶŐƐŝŶŐůĞƌƵŶĚĞƉůŽǇŵĞŶƚͿ͘ EŽƚĞƐZĞŐĂƌĚŝŶŐƚŚĞtĞůůΘĞƐŝŐŶ x ϳ͟ĐĂƐŝŶŐǁĂƐůĂƐƚƉƌĞƐƐƵƌĞƚĞƐƚĞĚĚŽǁŶƚŽϭϭ͕ϬϬϬ͛ŵĚƚŽϮ͕ϱϬϬƉƐŝĨŽƌϯϬŵŝŶƐŽŶϬϳͬϭϵͬϮϬϭϴ͘ WƌŽĐĞĚƵƌĞ͗ ŽŝůĞĚdƵďŝŶŐ EŽƚĞƐ͗ x ƵĞƚŽƚŚĞŶĞĐĞƐƐĂƌǇŽƉĞŶŚŽůĞĚĞƉůŽǇŵĞŶƚŽĨǆƚĞŶĚĞĚWĞƌĨŽƌĂƚŝŶŐũŽďƐ͕ϮϰͲŚŽƵƌĐƌĞǁĂŶĚt^^ ĐŽǀĞƌĂŐĞŝƐƌĞƋƵŝƌĞĚ͘ x dŚĞǁĞůůǁŝůůďĞŬŝůůĞĚĂŶĚŵŽŶŝƚŽƌĞĚďĞĨŽƌĞŵĂŬŝŶŐƵƉƚŚĞŝŶŝƚŝĂůƉĞƌĨƐŐƵŶƐ͘dŚŝƐŝƐŐĞŶĞƌĂůůǇĚŽŶĞ ĚƵƌŝŶŐƚŚĞĚƌŝĨƚͬůŽŐŐŝŶŐƌƵŶ͘dŚŝƐǁŝůůƉƌŽǀŝĚĞŐƵŝĚĂŶĐĞĂƐƚŽ ǁŚĞƚŚĞƌƚŚĞǁĞůůǁŝůůďĞŬŝůůĞĚďǇ ďƵůůŚĞĂĚŝŶŐŽƌĐŝƌĐƵůĂƚŝŶŐďŽƚƚŽŵƐƵƉƚŚƌŽƵŐŚŽƵƚƚŚĞũŽď͘/ĨƉ ƌĞƐƐƵƌĞŝƐƐĞĞŶŝŵŵĞĚŝĂƚĞůǇĂĨƚĞƌ ƉĞƌĨŽƌĂƚŝŶŐ͕ŝƚǁŝůůĞŝƚŚĞƌďĞŬŝůůĞĚďǇďƵůůŚĞĂĚŝŶŐǁŚŝůĞWKK,ŽƌĐŝƌĐƵůĂƚŝŶŐďŽƚƚŽŵƐƵƉƚŚƌŽƵŐŚƚŚĞ ƐĂŵĞƉŽƌƚƚŚĂƚŽƉĞŶĞĚƚŽƐŚĞĂƌƚŚĞĨŝƌŝŶŐŚĞĂĚ͘ʹ&ŽƌDWh&ͲϴϲƚŚĞǁĞůůǁŝůůďĞĐŝƌĐƵůĂƚĞĚďŽƚƚŽŵƐ ƵƉƚŽĂǀŽŝĚƉŽƐƐŝďŝůŝƚǇŽĨĐŚĂƌŐŝŶŐƚŚĞ<ƵƉĂƌƵŬ&ŽƌŵĂƚŝŽŶǁŚŝůĞďƵůůŚĞĂĚŝŶŐĂŶĞŶƚŝƌĞǁĞůůǀŽůƵŵĞ͘ ϭ͘ D/ZhŽŝůĞĚdƵďŝŶŐhŶŝƚǁŝƚŚϮ͘Ϭ͟ĐŽŝůĞĚƚƵďŝŶŐĂŶĚƐƉŽƚĂŶĐŝ ůůĂƌǇĞƋƵŝƉŵĞŶƚ͘ Ϯ͘ WƌĞƐƐƵƌĞƚĞƐƚKWƚŽ ϯ͕ϱϬϬƉƐŝ,ŝϮϱϬ>Žǁ͕ϭϬŵŝŶĞĂĐŚƚĞƐƚ͘ (63HTXLSPHQW ddͲ^WWƵŵƉ^ĞĐƚŝŽŶ^ǁĂƉ tĞůů͗DWh&Ͳϴϲ Wd͗ϮϬϭͲϬϴϳ W/͗ϱϬͲϬϮϵͲϮϯϬϭϴͲϬϬͲϬϬ Ă͘ ĂĐŚƐƵďƐĞƋƵĞŶƚƚĞƐƚŽĨƚŚĞůƵďƌŝĐĂƚŽƌǁŝůůďĞƚŽ ϯ͕ϱϬϬƉƐŝ,ŝϮϱϬ>ŽǁƚŽĐŽŶĨŝƌŵŶŽůĞĂŬƐ͘ ď͘ EŽK'ŶŽƚŝĨŝĐĂƚŝŽŶƌĞƋƵŝƌĞĚ͘ Đ͘ ZĞĐŽƌĚKWƚĞƐƚƌĞƐƵůƚƐŽŶϭϬͲϰϮϰĨŽƌŵ͘ Ě͘ /ĨǁŝƚŚŝŶƚŚĞƐƚĂŶĚĂƌĚϳͲĚĂǇƚĞƐƚKWƚĞƐƚƉĞƌŝŽĚ͕ĂĨƵůůďŽĚǇƚĞƐƚĂŶĚĨƵŶĐƚŝŽŶƚĞƐƚŽĨƚŚĞƌĂŵƐ ŝƐƐƵĨĨŝĐŝĞŶƚƚŽŵĞĞƚǁĞĞŬůǇKWƚĞƐƚƌĞƋƵŝƌĞŵĞŶƚ͘ ϯ͘ ĨƚĞƌDhD,ĂŶĚƉƵůůƚĞƐƚŝŶŐƚŚĞd͕ƚĂŐͲƵƉŽŶƚŚĞdƐƚƌŝƉ ƉĞƌƚŽĞŶƐƵƌĞ,ĐĂŶŶŽƚƉƵůůƚŚƌŽƵŐŚ ƚŚĞďƌĂƐƐƵƉŽŶWKK,ǁŝƚŚŐƵŶƐ͘ ϰ͘ Dhϰ͟'^ĂŶĚZ/,ĂŶĚůĂƚĐŚƚŚĞƵƉƉĞƌƉƵŵƉƐĞĐƚŝŽŶ͘:ĂƌƉƵŵƉƐĞĐƚŝŽŶĨƌĞĞĂƐŶĞĞĚĞĚĂŶĚWKK,͘WŽƉ ŽĨĨĂŶĚ>ͬƉƵŵƉƐĞĐƚŝŽŶ͘ Ă͘ ŽŶƚŝŶŐĞŶĐǇŝĨƉƵŵƉƐĞĐƚŝŽŶƐĚŽŶŽƚƉƵůů͗ƉƵŵƉϭϬďďůƐŽĨϭϬͲϭϱй,ůĂĐŝĚĂŶĚůĞƚƐŽĂŬĨŽƌϭ ŚŽƵƌ͘ ϱ͘ Z/,ƚŽũƵƐƚĂďŽǀĞƚŚĞůŽǁĞƌƉƵŵƉƐĞĐƚŝŽŶ͘ŝƌĐƵůĂƚĞƚŚĞǁĞůůŽǀĞƌƚŽƐŽƵƌĐĞǁĂƚĞƌ;ϴ͘ϯϯƉƉŐͿƚŽůŽĂĚĂŶĚ ŬŝůůƚŚĞƚƵďŝŶŐ͘ Ğ͘ ŽŶƚĂĐƚKƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌƚŽĐŽŶĨŝƌŵĐĂůĐƵůĂƚŝŽŶƐĨŽƌ<t&Ƶ ƐŝŶŐƚŚĞ,ŐĂƵŐĞŝŶƚŚĞǁĞůů͘ ƵƌƌĞŶƚĞƐƚŝŵĂƚĞƐŝŶĚŝĐĂƚĞƚŚĞǁĞůůĐĂŶďĞŬŝůůĞĚǁŝƚŚƐŽƵƌĐĞǁĂƚĞƌ͘ Ĩ͘ tĞůůďŽƌĞǀŽůƵŵĞƚŽƚŽƉƉĞƌĨсϭϳϱďďůƐ Ő͘ ϰͲϭͬϮ͟dƵďŝŶŐʹϭϬ͕ϳϯϯ͛yϬ͘ϬϭϱϮсϭϲϯďďů Ś͘ ϳ͟>ŝŶĞƌ;ĐŽƵŶƚŝŶŐ^WŵŽƚŽƌƐĞĐƚŝŽŶǀŽůƵŵĞͿʹϯϭϰ͛y͘ϬϯϴϯďƉĨсϭϮďďů ϲ͘ ůĞĞĚŽĨĨĂůůt,WĂŶĚĐŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘ ϳ͘ Z/,ĂŶĚůĂƚĐŚƚŚĞůŽǁĞƌƉƵŵƉƐĞĐƚŝŽŶ͘:ĂƌƉƵŵƉƐĞĐƚŝŽŶĨƌĞĞĂƐŶĞĞĚĞĚĂŶĚWKK,͘WŽƉŽĨĨĂŶĚ>ͬƉƵŵƉ ƐĞĐƚŝŽŶ͘ ϴ͘ ŽŶƚŝŶŐĞŶĐǇ^ƚĞƉƐ͗ŽŶƚĂĐƚKĨŽƌĚŝƐĐƵƐƐŝŽŶŝĨĂůŝŐŶŵĞŶƚƚĞƐƚƚŽŽůŝƐŶĞĞĚĞĚďĂƐĞĚŽŶĐŽŶĚŝƚŝŽŶŽĨƉƵŵƉ ƐĞĐƚŝŽŶƐ͘ Ă͘ Zh^>ŽŶƚŽƉŽĨĐŽŝůĂŶĚƉƌĞƐƐƵƌĞƚĞƐƚWƚŽϮϱϬƉƐŝͬϮ͕ϱϬϬƉƐŝ͘ ď͘ Z/,ǁͬƚŚĞƌŽƚĂƚŝŽŶĂůƚŽŽůƚŽĐŽŶĨŝƌŵƚŚĞ^WŵŽƚŽƌƐŚĂĨƚŝƐƐƚŝůůŝŶƚĂĐƚĂŶĚĂůŝŐŶŵĞŶƚŝƐŐŽŽĚ͘ Đ͘ Z^>͘ ϵ͘ ƚƐƵƌĨĂĐĞ͕ƉƌĞƉĂƌĞĨŽƌĚĞƉůŽǇŵĞŶƚŽĨ^WWƵŵƉ^ĞĐƚŝŽŶ͘ ϭϬ͘ ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘ůĞĞĚĂŶǇƉƌĞƐƐƵƌĞŽĨĨƚŽƌĞƚƵƌŶƚĂŶŬ͘<ŝůůǁĞůůǁͬ<t&͕ϴ͘ϯϯƉƉŐƐŽƵƌĐĞǁĂƚĞƌ Žƌϴ͘ϱƉƉŐĂƐŶĞĞĚĞĚ͘DĂŝŶƚĂŝŶŚŽůĞĨŝůůƚĂŬŝŶŐƌĞƚƵƌŶƐƚŽƚĂŶŬƵŶƚŝůůƵď ƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶŝƐƌĞͲ ĞƐƚĂďůŝƐŚĞĚ͘&ůƵŝĚƐŵĂŶͲǁĂƚĐŚŵƵƐƚďĞƉĞƌĨŽƌŵĞĚǁŚŝůĞĚĞƉůŽǇŝŶŐ^WƉƵŵƉƐĞĐƚŝŽŶƚŽĞŶƐƵƌĞƚŚĞ ǁĞůůƌĞŵĂŝŶƐŬŝůůĞĚĂŶĚƚŚĞƌĞŝƐŶŽĞǆĐĞƐƐĨůŽǁ͘ ϭϭ͘ΎWĞƌĨŽƌŵĚƌŝůůďǇƉŝĐŬŝŶŐƵƉƐĂĨĞƚǇũŽŝŶƚǁŝƚŚd/tǀĂůǀĞĂŶĚƐƉĂĐĞŽƵƚďĞĨŽƌĞDh^WWƵŵƉƐĞĐƚŝŽŶ͘ ZĞǀŝĞǁǁĞůůĐŽŶƚƌŽůƐƚĞƉƐǁŝƚŚĐƌĞǁƉƌŝŽƌƚŽďƌĞĂŬŝŶŐůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂŶĚĐŽŵŵĞŶĐŝŶŐŵĂŬĞƵƉŽĨ ϳϭ͛^WƉƵŵƉƐĞĐƚŝŽŶ͘KŶĐĞƚŚĞƐĂĨĞƚǇũŽŝŶƚĂŶĚd/tǀĂůǀĞŚĂǀĞďĞĞŶƐƉĂĐĞĚŽƵƚ͕ŬĞĞƉƚŚĞƐĂĨĞƚǇ ũŽŝŶƚͬd/tǀĂůǀĞƌĞĂĚŝůǇĂĐĐĞƐƐŝďůĞŶĞĂƌƚŚĞǁŽƌŬŝŶŐƉůĂƚĨŽƌŵĨŽƌƋƵŝĐŬĚĞƉůŽǇŵĞŶƚŝĨŶĞĐĞƐƐĂƌǇ͘ Ă͘ƚƚŚĞďĞŐŝŶŶŝŶŐŽĨĞĂĐŚũŽď͕ƚŚĞĐƌŽƐƐŽǀĞƌͬƐĂĨĞƚǇũŽŝŶƚŵƵƐƚďĞƉŚǇƐŝĐĂůůǇDhƚŽƚŚĞƚŽƉŽĨƚŚĞ ^WƉƵŵƉƐĞĐƚŝŽŶŽŶĞƚŝŵĞƚŽĐŽŶĨŝƌŵƚŚĞϰ͟'^ŝƐĐŽŵƉĂƚŝďůĞ͘ ϭϮ͘ƌĞĂŬůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂƚYd^ĂŶĚďĞŐŝŶŵĂŬĞƵƉŽĨ^WWƵŵƉƐĞĐƚŝŽŶƉĞƌƐĐŚĞĚƵůĞďĞůŽǁ͘ ŽŶƐƚĂŶƚůǇŵŽŶŝƚŽƌĨůƵŝĚƌĂƚĞƐƉƵŵƉĞĚŝŶĂŶĚĨůƵŝĚƌĞƚƵƌŶƐŽƵƚŽĨƚŚĞǁĞůů͘&ůƵŝĚƐŵĂŶͲǁĂƚĐŚŵƵƐƚďĞ ƉĞƌĨŽƌŵĞĚǁŚŝůĞĚĞƉůŽǇŝŶŐƉĞƌĨŐƵŶƐƚŽĞŶƐƵƌĞƚŚĞǁĞůůƌĞŵĂŝŶƐŬŝůůĞĚĂŶĚƚŚĞƌĞŝƐŶŽĞǆĐĞƐƐĨůŽǁ͘ ϭϯ͘ Z/,ǁͬddͲ^WWƵŵƉƐĞĐƚŝŽŶƐĂŶĚůĂŶĚ͘WƵŵƉŽĨĨŽĨ'^ĂŶĚůĞ ĂǀĞŝŶƉůĂĐĞ͘ 77&(637RWDO$VVHPEO\/HQJWKIW 77&(630D[LPXP$VVHPEO\'LDPHWHULQ &RLO7XELQJ5XQ 77&(637RWDO$VVHPEO\:HLJKWOE (63VHFWLRQ $OOZRUNWREHOXEULFDWHG ddͲ^WWƵŵƉ^ĞĐƚŝŽŶ^ǁĂƉ tĞůů͗DWh&Ͳϴϲ Wd͗ϮϬϭͲϬϴϳ W/͗ϱϬͲϬϮϵͲϮϯϬϭϴͲϬϬͲϬϬ ď͘ EŽƚĞĂŶǇƚƵďŝŶŐƉƌĞƐƐƵƌĞĐŚĂŶŐĞŝŶt^Z͘ ϭϰ͘ ĨƚĞƌƐĞƚƚŝŶŐ͕Wh,ĂŶĚĞŶƐƵƌĞƚŚĂƚƚŚĞƉƵŵƉƐĞĐƚŝŽŶƐĂƌĞŝŶƉůĂĐĞĚŽǁŶŚŽůĞ͘ Ă͘ /ĨƉƵŵƉƐĂƌĞůĞĨƚŝŶŚŽůĞ͕WKK,ĂƐŶŽƌŵĂůĂŶĚĨƌĞĞǌĞƉƌŽƚĞĐƚǁĞůůŽŶǁĂǇKK,;ǁŝůůŶŽƚŶĞĞĚ ŽƉĞŶŚŽůĞŽƉĞƌĂƚŝŽŶƐƚŽďƌĞĂŬͲŽĨĨŽĨǁĞůůͿ͘ ď͘ /ĨĂŶǇŝŶĚŝĐĂƚŝŽŶƚŚĂƚƚŚĞ^WWƵŵƉ^ĞĐƚŝŽŶƐĂƌĞƐƚŝůůĂƚƚĂĐŚĞĚƚŽĐŽŝů͗ ŝ͘ ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚĂŶĚƌĞͲŬŝůůŝĨŶĞĐĞƐƐĂƌǇďĞĨŽƌĞƉƵůůŝŶŐƚŽƐƵƌĨĂĐĞ͘WƵŵƉƉŝƉĞ ĚŝƐƉůĂĐĞŵĞŶƚǁŚŝůĞWKK,͘ ŝŝ͘ ^ƚŽƉĂƚƐƵƌĨĂĐĞƚŽƌĞĐŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘<ŝůůǁĞůůŝĨŶĞĐ ĞƐƐĂƌǇ͘ZĞǀŝĞǁǁĞůůĐŽŶƚƌŽůƐƚĞƉƐ ĂŶĚ^ƚĂŶĚŝŶŐKƌĚĞƌƐǁŝƚŚĐƌĞǁƉƌŝŽƌƚŽďƌĞĂŬŝŶŐůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂŶĚĐŽŵŵĞŶĐŝŶŐ ďƌĞĂŬĚŽǁŶŽĨ^WWƵŵƉ^ĞĐƚŝŽŶ͘ ŝŝŝ͘ ŶƐƵƌĞƐĂĨĞƚǇũŽŝŶƚĂŶĚd/tǀĂůǀĞĂƐƐĞŵďůǇĂƌĞŽŶͲŚĂŶĚďĞĨŽƌĞďƌĞĂŬŝŶŐŽĨĨůƵďƌŝĐĂƚŽƌ ƚŽĐŚĞĐŬ^WWƵŵƉ^ĞĐƚŝŽŶ͘ ϭϱ͘ ZDKdh͘ ϭϲ͘ ZdWŽƌ&WǁĞůů͘ ^ůŝĐŬůŝŶĞ ϭ͘ Zh^>hŶŝƚĂŶĚƉƌĞƐƐƵƌĞƚĞƐƚWƚŽϮϱϬƉƐŝůŽǁͬϮ͕ϱϬϬƉƐŝŚŝŐŚ͘ Ϯ͘ Z/,ĂŶĚƐĞƚƉĂĐŬŽĨĨ͘ ϯ͘ Z/,ĂŶĚƐĞƚƚĞƐƚƚŽŽůŝŶƚŽƉĂĐŬŽĨĨĂŶĚƉƌĞƐƐƵƌĞƚĞƐƚƚƵďŝŶŐƚ Žϭ͕ϬϬϬƉƐŝ͘WKK,ǁͬƚĞƐƚƚŽŽů͘ ϰ͘ Z/,ĂŶĚƐĞƚƚƵďŝŶŐƐƚŽƉ͘ ϱ͘ ZDK^>ƵŶŝƚ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƵƌƌĞŶƚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ ddͲ^WŝĂŐƌĂŵ ϰ͘ ŽŝůdƵďŝŶŐKW^ĐŚĞŵĂƚŝĐ ϱ͘ ^ƚĂŶĚŝŶŐKƌĚĞƌƐĨŽƌKƉĞŶ,ŽůĞtĞůůŽŶƚƌŽůĚƵƌŝŶŐWĞƌĨ'ƵŶĞƉůŽǇŵĞŶƚ ϲ͘ ƋƵŝƉŵĞŶƚ>ĂǇŽƵƚŝĂŐƌĂŵ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϯͬϮϭͬϮϬϮϮ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DW&Ͳϴϲ >ĂƐƚŽŵƉůĞƚĞĚ͗ϳͬϮϭͬϮϬϭϴ Wd͗ϮϬϭͲϬϴϳ dсϭϭ͕ϯϭϲ͛;DͿͬdсϳ͕Ϯϴϳ͛;dsͿ ϮϬ´ K<ůĞǀ͗͘ϰϮ͘ϵ͛ͬKƌŝŐ͘'>ůĞǀ͗͘ϭϬ͘ϵ͛ ŽǇŽŶϭϲZdƚŽddďŐƐƉŽŽůсϮϮ͘ϰϮ͛ ϳ͟ ´7$0 3RUW&ROODU# ¶ ϵͲϱͬϴ ͟ Wdс ϭϭ͕ϮϬϮ͛ ;DͿͬWdсϳ͕ϭϳϲ͛;dsͿ ´&DS6WULQJ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ W& ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϭ͘ϭͬ,ͲϰϬͬEͬ Eͬ ^ƵƌĨĂĐĞ ϭϭϮΖ Ϭ͘ϯϱϱ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬd ϴ͘ϴϯϱ ^ƵƌĨĂĐĞ ϲ͕ϱϭϴ͛ Ϭ͘Ϭϳϱϴ ϳΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϲͬ>ͲϴϬͬdͲD ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϭϭ͕Ϯϵϲ͛ Ϭ͘Ϭϯϴϯ dh/E'd/> ϰͲϭͬϮΗ dƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬ,ǇĚƌŝůϱϮϭ ϯ͘ϵϱϴ ^ƵƌĨĂĐĞ ϭϬ͕ϳϳϱ͛ Ϭ͘ϬϭϱϮ ϯͬϴ͟ ĂƉ^ƚƌŝŶŐ ^ƚĂŝŶůĞƐƐ^ƚĞĞů Eͬ ^ƵƌĨĂĐĞ ϭϬ͕ϳϳϱ͛ Eͬ :t>Zzd/> EŽ dŽƉ;DͿ /ƚĞŵ ϭ ϭϬ͕ϲϲϱ͛ ΘdƵďŝŶŐ^ƚŽƉtͬϰΗ'^&E Ϯ ϭϬ͕ϲϲϳ͛ ΘWĂĐŬKĨĨ/,ŝͲ&ůŽǁ ϯ ϭϬ͕ϲϳϳ͛ ĞŶƚƌŝůŝĨƚdĂŶĚĞŵddͲ^WWƵŵƉƐ͗DŽĚĞů'^ϯ,>,ϲW &^ ϰ ϭϬ͕ϳϯϯ͛ ddĚƌŝůůĞĚƚƵďŝŶŐĐƌŽƐƐŽǀĞƌ ϱ ϭϬ͕ϳϰϰ͛ dĂŶĚĞŵƐĞĂůƐĞĐƚŝŽŶƐ;DŽĚĞů'^ϯͿ ϲ ϭϬ͕ϳϱϴ͛ DŽƚŽƌ͕yWͲϮϬϬ͕ϮϬϬ,W͕ϯϲϯϱǀŽůƚ͕ϯϰĂŵƉ ϳ ϭϬ͕ϳϳϭ͛ tĞůů>ŝĨƚ^ĞŶƐŽƌǁŝƚŚϲĨŝŶĞŶƚƌĂůŝǌĞƌʹ ŽƚƚŽŵΛϭϬ͕ϳϳϱ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ <ƵƉ͘ϯ ϭϭ͕Ϭϰϳ͛ ϭϭ͕Ϭϱϳ͛ ϳ͕ϬϮϲ͛ ϳ͕Ϭϯϲ͛ ϭϬ ϴͬϮϲͬϮϬϬϭ KƉĞŶ <ƵƉ͘Ϯ ϭϭ͕Ϭϲϰ͛ ϭϭ͕Ϭϳϰ͛ ϳ͕Ϭϰϯ͛ ϳ͕Ϭϱϯ͛ ϭϬ ϴͬϮϲͬϮϬϬϭ KƉĞŶ <ƵƉ͘ϭ ϭϭ͕Ϭϴϲ͛ ϭϭ͕Ϭϵϲ͛ ϳ͕Ϭϲϰ͛ ϳ͕Ϭϳϰ͛ ϭϬ ϴͬϮϲͬϮϬϬϭ KƉĞŶ <ƵƉ͘Ϯͬϭ ϭϭ͕Ϭϲϴ͛ ϭϭ͕ϭϬϴ͛ ϳ͕Ϭϰϲ͛ ϳ͕Ϭϴϱ͛ ϰϬ ϲͬϬϮͬϮϬϬϲ KƉĞŶ ZĞĨ>ŽŐ͗^t^:ĞǁĞůƌǇ>ŽŐͲϴͬϭϬͬϮϬϬϭ KWE,K>ͬDEdd/> ϮϬΗ ϮϲϬƐǆŽĨƌĐƚŝĐƐĞƚ/ŝŶϯϬ͟,ŽůĞ ϵͲϱͬϴ͟ ϭϬϬϬƐǆW&>ŝŶϭϮͲϭͬϰ͟ŚŽůĞƉůƵƐϮϮϱƐǆůĂƐƐ͞'͟ ϳΗ ϮϬϬƐǆůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟ŚŽůĞ͕ĞƐƚ͘dKсϵ͕ϰϴϱ͛ t>>/E>/Ed/KE d/> <KWΛϰϬϬ͛ DĂǆ,ŽůĞŶŐůĞсϲϲĚĞŐ͘Λϰ͕ϬϱϬ͛ DĂǆ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϭϱĚĞŐ͘ dZΘt>>, dƌĞĞ ϱD/tϰ͟ tĞůůŚĞĂĚ ϭϭ͟ϱD&D'ĞŶϱ͕ǁͬϰͲϭͬϮ͟&DdďŐ͘,ŶŐƌ͕͘ ϰͲϭͬϮ͟,ǇĚƌŝůϱϮϭdŽƉΘƚŵ͘,ĂŶŐĞƌƚŚƌĞĂĚĂŶĚ ϰ͟͞,͟WsƉƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϯϬϭϴͲϬϬ KƌŝŐ͘ƌŝůůŝŶŐďǇEĂďŽƌƐϮϳʹϴͬϬϲͬϮϬϬϭ KƌŝŐ͘ŽŵƉůĞƚŝŽŶďǇEĂďŽƌƐϰ^ʹϵͬϮϳͬϮϬϬϭ ZtKǁͬEĂďŽƌƐϯ^͕^WĐͬŽ͕&KĂŶĚĚĚWĞƌĨƐʹϲͬϬϰͬϮϬϬϲ ZtKǁͬEĂďŽƌƐϯ^͕^WĐͬŽ͕&KĂŶĚŝŶƐƚĂůůƐĐƌĞĞŶʹϮͬϬϲͬϮϬϬϳ ZtKǁͬEĂďŽƌƐϰ^͕^WĐͬŽʹϴͬϮϰͬϮϬϬϴ ZtWǁͬEĂďŽƌƐϯ^͕^WĐͬŽĂŶĚĂĚĚĐĂƉƚƵďĞʹϱͬϭϯͬϮϬϬϵ ZtKǁͬŽǇŽŶϭϲ͕^WĐͬŽĂŶĚƌƵŶĨƌĂĐƐƚƌŝŶŐʹϯͬϬϯͬϮϬϭϭ ZtKǁͬŽǇŽŶϭϲ͕ŝŶƐƚĂůůdd^WĂŶĚ&KʹϲͬϮϭͬϮϬϭϭ ZtKǁͬ/ͲZŝŐ͕ŝŶƐƚĂůůdd^WĂŶĚ&KʹϳͬϮϭͬϮϬϭϴ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϯͬϮϭͬϮϬϮϮ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DW&Ͳϴϲ >ĂƐƚŽŵƉůĞƚĞĚ͗ϳͬϮϭͬϮϬϭϴ Wd͗ϮϬϭͲϬϴϳ dсϭϭ͕ϯϭϲ͛;DͿͬdсϳ͕Ϯϴϳ͛;dsͿ ϮϬ´ K<ůĞǀ͗͘ϰϮ͘ϵ͛ͬKƌŝŐ͘'>ůĞǀ͗͘ϭϬ͘ϵ͛ ŽǇŽŶϭϲZdƚŽddďŐƐƉŽŽůсϮϮ͘ϰϮ͛ ϳ͟ ´7$0 3RUW&ROODU# ¶ ϵͲϱͬϴ ͟ Wdс ϭϭ͕ϮϬϮ͛ ;DͿͬWdсϳ͕ϭϳϲ͛;dsͿ ´&DS6WULQJ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ W& ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϭ͘ϭͬ,ͲϰϬͬEͬ Eͬ ^ƵƌĨĂĐĞ ϭϭϮΖ Ϭ͘ϯϱϱ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬd ϴ͘ϴϯϱ ^ƵƌĨĂĐĞ ϲ͕ϱϭϴ͛ Ϭ͘Ϭϳϱϴ ϳΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϲͬ>ͲϴϬͬdͲD ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϭϭ͕Ϯϵϲ͛ Ϭ͘Ϭϯϴϯ dh/E'd/> ϰͲϭͬϮΗ dƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬ,ǇĚƌŝůϱϮϭ ϯ͘ϵϱϴ ^ƵƌĨĂĐĞ цϭϬ͕ϴϬϭ͛ Ϭ͘ϬϭϱϮ ϯͬϴ͟ ĂƉ^ƚƌŝŶŐ ^ƚĂŝŶůĞƐƐ^ƚĞĞů Eͬ ^ƵƌĨĂĐĞ цϭϬ͕ϴϬϭ Eͬ :t>Zzd/> EŽ dŽƉ;DͿ /ƚĞŵ ϭ цϭϬ͕ϲϲϱ͛ ΘdƵďŝŶŐ^ƚŽƉtͬϰΗ'^&E Ϯ цϭϬ͕ϲϲϳ͛ ΘWĂĐŬKĨĨ/,ŝͲ&ůŽǁ ϯ цϭϬ͕ϲϳϳ͛ ĞŶƚƌŝůŝĨƚdƌŝƉůĞddͲ^WWƵŵƉƐ͗DŽĚĞů'^ϯ,>,ϲW&^ ϰ цϭϬ͕ϳϱϵ͛ ddĚƌŝůůĞĚƚƵďŝŶŐĐƌŽƐƐŽǀĞƌ ϱ цϭϬ͕ϳϳϬ͛ dĂŶĚĞŵƐĞĂůƐĞĐƚŝŽŶƐ;DŽĚĞů'^ϯͿ ϲ цϭϬ͕ϳϴϰ͛ DŽƚŽƌ͕yWͲϮϬϬ͕ϮϬϬ,W͕ϯϲϯϱǀŽůƚ͕ϯϰĂŵƉ ϳ цϭϬ͕ϳϵϳ͛ tĞůů>ŝĨƚ^ĞŶƐŽƌǁŝƚŚϲĨŝŶĞŶƚƌĂůŝǌĞƌʹŽƚƚŽŵΛцϭϬ͕ϴϬϭ͛ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ <ƵƉ͘ϯ ϭϭ͕Ϭϰϳ͛ ϭϭ͕Ϭϱϳ͛ ϳ͕ϬϮϲ͛ ϳ͕Ϭϯϲ͛ ϭϬ ϴͬϮϲͬϮϬϬϭ KƉĞŶ <ƵƉ͘Ϯ ϭϭ͕Ϭϲϰ͛ ϭϭ͕Ϭϳϰ͛ ϳ͕Ϭϰϯ͛ ϳ͕Ϭϱϯ͛ ϭϬ ϴͬϮϲͬϮϬϬϭ KƉĞŶ <ƵƉ͘ϭ ϭϭ͕Ϭϴϲ͛ ϭϭ͕Ϭϵϲ͛ ϳ͕Ϭϲϰ͛ ϳ͕Ϭϳϰ͛ ϭϬ ϴͬϮϲͬϮϬϬϭ KƉĞŶ <ƵƉ͘Ϯͬϭ ϭϭ͕Ϭϲϴ͛ ϭϭ͕ϭϬϴ͛ ϳ͕Ϭϰϲ͛ ϳ͕Ϭϴϱ͛ ϰϬ ϲͬϬϮͬϮϬϬϲ KƉĞŶ ZĞĨ>ŽŐ͗^t^:ĞǁĞůƌǇ>ŽŐͲϴͬϭϬͬϮϬϬϭ KWE,K>ͬDEdd/> ϮϬΗ ϮϲϬƐǆŽĨƌĐƚŝĐƐĞƚ/ŝŶϯϬ͟,ŽůĞ ϵͲϱͬϴ͟ ϭϬϬϬƐǆW&>ŝŶϭϮͲϭͬϰ͟ŚŽůĞƉůƵƐϮϮϱƐǆůĂƐƐ͞'͟ ϳΗ ϮϬϬƐǆůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟ŚŽůĞ͕ĞƐƚ͘dKсϵ͕ϰϴϱ͛ t>>/E>/Ed/KE d/> <KWΛϰϬϬ͛ DĂǆ,ŽůĞŶŐůĞсϲϲĚĞŐ͘Λϰ͕ϬϱϬ͛ DĂǆ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϭϱĚĞŐ͘ dZΘt>>, dƌĞĞ ϱD/tϰ͟ tĞůůŚĞĂĚ ϭϭ͟ϱD&D'ĞŶϱ͕ǁͬϰͲϭͬϮ͟&DdďŐ͘,ŶŐƌ͕͘ ϰͲϭͬϮ͟,ǇĚƌŝůϱϮϭdŽƉΘƚŵ͘,ĂŶŐĞƌƚŚƌĞĂĚĂŶĚ ϰ͟͞,͟WsƉƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϯϬϭϴͲϬϬ KƌŝŐ͘ƌŝůůŝŶŐďǇEĂďŽƌƐϮϳʹϴͬϬϲͬϮϬϬϭ KƌŝŐ͘ŽŵƉůĞƚŝŽŶďǇEĂďŽƌƐϰ^ʹϵͬϮϳͬϮϬϬϭ ZtKǁͬEĂďŽƌƐϯ^͕^WĐͬŽ͕&KĂŶĚĚĚWĞƌĨƐʹϲͬϬϰͬϮϬϬϲ ZtKǁͬEĂďŽƌƐϯ^͕^WĐͬŽ͕&KĂŶĚŝŶƐƚĂůůƐĐƌĞĞŶʹϮͬϬϲͬϮϬϬϳ ZtKǁͬEĂďŽƌƐϰ^͕^WĐͬŽʹϴͬϮϰͬϮϬϬϴ ZtWǁͬEĂďŽƌƐϯ^͕^WĐͬŽĂŶĚĂĚĚĐĂƉƚƵďĞʹϱͬϭϯͬϮϬϬϵ ZtKǁͬŽǇŽŶϭϲ͕^WĐͬŽĂŶĚƌƵŶĨƌĂĐƐƚƌŝŶŐʹϯͬϬϯͬϮϬϭϭ ZtKǁͬŽǇŽŶϭϲ͕ŝŶƐƚĂůůdd^WĂŶĚ&KʹϲͬϮϭͬϮϬϭϭ ZtKǁͬ/ͲZŝŐ͕ŝŶƐƚĂůůdd^WĂŶĚ&KʹϳͬϮϭͬϮϬϭϴ ddͲ^WWƵŵƉ^ĞĐƚŝŽŶ^ǁĂƉ tĞůů͗DWh&Ͳϴϲ Wd͗ϮϬϭͲϬϴϳ W/͗ϱϬͲϬϮϵͲϮϯϬϭϴͲϬϬͲϬϬ ddͲ^WŝĂŐƌĂŵ ddͲ^WWƵŵƉ^ĞĐƚŝŽŶ^ǁĂƉ tĞůů͗DWh&Ͳϴϲ Wd͗ϮϬϭͲϬϴϳ W/͗ϱϬͲϬϮϵͲϮϯϬϭϴͲϬϬͲϬϬ ŽŝůĞĚdƵďŝŶŐKWƐ ^ƚĂŶĚŝŶŐKƌĚĞƌƐĨŽƌKƉĞŶ,ŽůĞtĞůůŽŶƚƌŽůĚƵƌŝŶŐWĞƌĨ'ƵŶĞƉůŽǇŵĞŶƚ ddͲ^WWƵŵƉ^ĞĐƚŝŽŶ^ǁĂƉ tĞůů͗DWh&Ͳϴϲ Wd͗ϮϬϭͲϬϴϳ W/͗ϱϬͲϬϮϵͲϮϯϬϭϴͲϬϬͲϬϬ ddͲ^WWƵŵƉ^ĞĐƚŝŽŶ^ǁĂƉ tĞůů͗DWh&Ͳϴϲ Wd͗ϮϬϭͲϬϴϳ W/͗ϱϬͲϬϮϵͲϮϯϬϭϴͲϬϬͲϬϬ ƋƵŝƉŵĞŶƚ>ĂǇŽƵƚŝĂŐƌĂŵ Imag~, -'reject Well History' File Cover ~ :je XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. (~0 L-0(~ VVell.i,toryFilel.entifier Organizing I~o,,,~[] RESCAN [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: DIGITAL DATA ~' Diskettes, No. ~ [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERYL{~~/INDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~WINDY Scanning Preparation ~ x30= ~C~ BY: BEVERLY ROBIN VINCENT SHERYL(~WINDY OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Production Scanning Stage I PAGE COUNT FROM SCAN.ED F~LE: ............ ~a.__~._.~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: X' YES BY: Stage 2 IF NO IN STAGE '!, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES · (SCANNING IS COMI~LETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO NO RESCANNED BT: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /SI Quality Checked 12/10/02Rev3NOTScanned.wpd STATE OF ALASKA - E AL A6KA OIL AND GAS CONSERVATION COMMISSION- �1j t , REPORT OF SUNDRY WELL OPERATIONSJL 1.Operations Abandon Li Repair Well u Plug Perforations U Perforate U Other Li ,Md.jsigAiAtiotatment 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: BP Exploration(Alaska),Inc Development Exploratory ❑ ► 201-087-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 • 50-029-23018-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: 1 ADL0355018 a KUP MPF-86 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): MILNE POINT,KUPARUK RIVER OIL 11.Present Well Condition Summary: ,. Total Depth measured • 11317 feet Plugs measured None feet true vertical 7288.06 feet Junk measured None feet Effective Depth measured 11206 feet Packer measured None feet true vertical 7180.13 feet true vertical None feet Casing Length Si ze MD TVD Burst Collapse Structural None None None None None None Conductor 78 20"Conductor 34-112 34-112 0 0 Surface 6485 9-5/8"40#L-80 33-6518 33-4268.97 5750 3090 Intermediate None None None None None None Production 11264 7"26#L-80 32-11296 32-7267.63 7240 5410 Liner None None None None None None Perforation depth Measured depth See Attachment feet J U L 1 0 Z`14 True Vertical depth See Attachment feet WOO Tubing(size,grade,measured and true vertical depth) 2-7/8"6.5#L-80 31-10916 31-6899.73 Packers and SSSV(type,measured and true vertical depth) None None None Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): 11047'-11108' RBDMS MAY 1 8 2014 j Treatment descriptions including volumes used and final pressure: 44 Gallons FDP-S948A-09,44 Gallons FDP-S948B-09, 12 Gallons FDP-S948C-09,76 Gallons FDP-S929-09, 1.5 Gallons SURFACTANT 19N,3 Gallons HC-2 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 99 11 284 140 291 Subsequent to operation: 3 0 14 0 211 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratort Development❑✓ " Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil , 2 Gas ❑ WDSPL❑ GSTOR ❑ WINJ U WAG ❑ GINJ ❑ SUSP ❑ SPLU f] 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 Nita Summerhays Email Nita.Summerhays@bp.com Printed Name Nita Summer s Title Data Coordinator / Signatu - /.,��"/�trj/'ws......"� Phone 564-4035 Date 1/8/2014 VG -- 5"/z4 // Form 10-404 Revised 10/2012 ff -�/ Submit Original Only Daily Report of Well Operations ADL0355018 ACTIVITYDATE �O��ih��►_1:� 12/12/2013 -S-T-104 Fluid support *****Sand Consolidation Treatment"— T/I/O 350/500/20. PJSM. Spot in HES LMS (Liquid Metering System). Attach restraining devices to all energized fluid treating lines. Perform passing pressure test to 4850 psi. Test global kick out. Pass. Test PRV's. Pass. Perform injectivity using 3% kcl and foamed N2 per program. Freeze protect tubing with 60/40 McOH. Will perform matrix treatment in the AM 12/13. All pressure testing and pumping data will be turned in via electronic copy by Halliburton at completion of job. 12/12/2013 ***Job In Progress*** *****Sand Consolidation Treatment*****T/I/O 350/500/100. PJSM. Discuss slips/trips/fall, working with energized fluids. All energized fluid treating lines restrained. Test PRV's and global kick outs. Perform matrix Halliburton "Prop Stop Treatment" per procedure. Displace treatment to formation with 163 bbls Milne Point dead crude and 10 bbls 60/40 McOH. All pump data recorded by HES and turned into town engineer. Well to remain shut in for 72 hours (12/15 @ 10pm will be 72 hrs). Final pressures T/I/O 2590/2830/100 12/13/2013 *****Job Complete***** 12/13/2013 LRS tanker support FLUIDS PUMPED BBLS 163 MILNE POINT DEAD CRUDE 20 60/40 METH 10 3% KCL 100 FRESH WATER 293 TOTAL FLUIDS PUMPED GALS 44 FDP-S948A-09 44 FDP-S948B-09 12 FDP-S948C-09 76 FDP-S929-09 1.5 SURFACTANT 19N 3 HC-2 61 DIESEL 241.5 TOTAL a) N CO C'• ") CD 0) C'') CO CD CO C')) CD CD C') V Ll) Ln r r O 00 00 M N N 00 Ln CO O) N C'7 C'7 CO N- Ch V in Cu• N N C7 C7 V V Ln Ln CD CD CD ISO 00 O 0 0 0 0 0 0 0 0 0 0 0 O O C` C` N- C` C` C` C• N- C` N- C• N- N- FF- ❑ W (n WZ ❑ 11.1 a O 0 O O Y Y H 2 CD CO co C3) C) CD co co co CO CD co Lo 0 0 w W r = - O Cb Ln t CO N N Cb C- N- Ln < d (/) Q- CD CA 00 N CD 6) N 00 M CD N- CO W00 a) N N N Mcr in in co CD CO N • J W W J C) 00000000000 O O O O J J J ❑ J ; r- N N N N N N N N N N- N N N Z o 0 0 W a LL z p z 0 c i u~i v¢) N Lai) ro N LO m r Cb O Ln N- CD(b to CO O O N- 00 V 0 Ln Ln Ln (0 8 0 N- N- co Cb CJ) CJ) O) O 0 0 0 0 0 0 0 0 O s 2 U 0 U) v 0 ci u c0 00- +r a Ln a tr) U = OrN- 00oLnvoo = crLncoC) C) cor- J a V Ln Ln CO CO ti Cb CO CA ) ) O d o 0 0 0 0 0 0 0 0 0 0 0 0 0 i• a� O 2 t d -o .2 a. a, 0 U • LL LL_ U_ LL_ Lt_ Li_ LL Lt_ U_ LL LL_ Lt_ U_ LL m a a a d a a _ a a a a a d a `m < < < < < < < < < < < < < < a 0 t Ca a O N ? o oOOOOococococococo OD 0 Q 0 0 0 0 0 0 c:30 (00 (00 c 0 0 0 0 0 0 0 0 0 0 0 O O O J z W 0 N_ N N N N N N N N N N N N N a La N N W M O O CD CD O N N N N N N N N N WW W (Y N N N N N CO CD CD CD CD CD O CD CD ❑ U W W W W 8. 0730-300-30-3 o J J D D a O a J 0 0 W W m W W (n Cn a CC m m CD CD CO CD CD CD CD CO CD CD CO CD CD (O t 111111 � � LLLL � � � � � LL � LL LULL Cn a a a a CL CL CL L L L L cL cL cL u) 0 J U N 2 LL X2222222222 CCC m LUi_ LL FAo) a Tree: 41/16", 5M MPF-86 Oriy. KB Elev. = 42.9' (N27E) Wellhead:11" Gen 5 FMC Orig. GL Elev. = 10.9' w/11 x 4.5" TC-B-EC Tbg Hgr. RT to Tbg. Spool = 32.0' (N27E) w/4"CIW'H'BPV profile 41 112' 9-5/8"TAM Port Collar 1010' 0 9-5/8", 40#/ft., L-80 BTRC 6,517' A L 4 1/2" 12.6 ppf, L-80 IBT-M (drift ID=3.833",cap=0.0152 bpf) 3/8"x.049 wall capillary tube .00313 gal/ft displacement 7" 26#/ft., L-80 BTC-M Production Casing (drift ID = 6.151", cap. = 0.0383 bpf) _ (cap.w/4.5"tbg inside = 0.0186 bpf) AIM D&D Tbg Stop 10733' Capillary tube 3/8" OD x.049 wall D&D Packoff Assy Top 10735' (capacity= 3.131 gallons/ 1000') Centrilift TTC-ESP Top 10743` KOP @ 400` ' Max. Hole Angle = 64° Max. Hole Angle Thru Perfs. = 15° Ei,. TTC Drilled Tbg Crossover 10743' i1 IR 1 ant Tandem Seal Sections Nor°i Model GSB3 DB UT/LT HL H6 PFS 10753' Stimulation Summary: 152.8K#of 16/20 Carbolite and 48.3k#of 12/18 behind pipe Motor,55 HP,1259 volt, 10766' St P 26 amp,Model KMHA Perforation Summary: Igi ) PumpMate w/4 fin Centralizer 10786' Ref. Log SWS jewelry log 8/10/01 s PumpMate ='TVD Size SPF Interval (TVD) 3-3/8" 6 11047-11057' 7026'-7036' 3-3/8" 6 11064'-11074' 7043'-7053' 3-3/8" 6 11086'-11096' 7064'-7074' 4-1/2" 5 11068'-11108' 7046-7085' — — Note:11068'-11108 interval was shot with = x Power Jet Omega 5 SPF TCP's = — PBTD 06-02-06 during the RWO = (PBTD) 11,206' 7" Float Collar 11,212' Doyon 16 ECO to 11170'-3/3/11 7" Float Shoe 11,296' illi IA Tested to 1000 psi 2-4-07 DATE REV. BY , COMMENTS MILNE POINT UNIT 08/25/01 M.Linder Initial perforations 6/4/06 L Hulme ESP Completion Nabors 3S WELL MPF-86 (KUP) 2/6/07 M.Ross FCO&Screens Added&ESP Completion Nabors 3S 8/24/08 REH ESP RWO BY Nabors 4ES API No. 50-029-23018 5/13/09 L Hulme ESP RWO-Add Cap Tube-Nabors 3S 3/3/11 L Hulme Pull ESP&run Frac string-Doyon 16 6/21/11 B.Bixby ESP RWO Thru Tbg.ESP-Doyon 16 BP EXPLORATION (AK) • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Mr. Tom Maunder �J Alaska Oil and Gas Conservation Commission \ ()A V 333 West 7 Avenue C ' '� Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPF -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10404) MPF -Pad 10/29/2011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls 8 gal MPF -01 1950450 50029225520000 10.2 WA 10.2 N/A 122.4 8/7/2011 MPF-02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF-05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 1.2 N/A 15.3 812/2011 MPF-09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 8/2/2011 MPF -13 1950270 50029225490000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/62011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 8/2/2011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/1/2011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/9/2011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF -33 2010620 50029226890000 23 Need top job MPF-34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF -37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 MPF-41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF-42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF -45 1950580 50029225560000 8 WA 8 N/A 78.2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A N/A MPF-49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF-61 1951170 50029225820000 62 Need top lob MPF -62 1951610 50029226090000 2.0 NN 2.0 N/A 13.6 9/1/2011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/31/2011 MPF-69 1951250 50029225860000 0.8 N/A 0.8 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -77 1951360 50029225940000 0.2 N/A 0.2 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 N/A 5.1 7/312011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 N/A 6.8 8/3/2011 MPF-80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/32011 MPF-81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF -82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF -83 2000930 50029229630000 1.2 WA 12 N/A 13.6 8/32011 MPF -84B 2001760 50029229310200 1.2 N/A 1.2 N/A 10.2 8/32011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 - -41•• MPF -86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/12/2011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/13/2011 MPF -88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/3/2011 MPF -89 2050900 50029232680000 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/13/2011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/132011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 WA 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/132011 MPF -95 1981790 50029229180000 0.5 NIA 0.5 N/A 3.4 8/132011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/12011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/112011 STATE OF ALASKA ALASKA- AND GAS CONSERVATION COMMIS t REPORT OF SUNDRY WELL OPERA NS 1. Operations Performed: ❑ Abandon IN Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension Frac and Run ESP Completion 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory — 201 - 087 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 — 50 - 029 - 23018 - 00 - 00 7. Property Designation: 8. Well Name and Number: ADL 355018 ' MPF 9. Field / Pool(s): Milne Point Unit / Kuparuk River Sands 10. Present well condition summary Total depth: measured 11316 feet Plugs (measured) None feet true vertical 7287 feet Junk (measured) None feet Effective depth: measured 11206 feet Packer. (measured) None feet true vertical 7180 feet Packer: (true vertical) None feet Casing Length Size MD TVD Burst Collapse . Structural Conductor 78' 20" 112' 112' 1490 470 Surface 6485' 9-5/8" 6518' 4269' 5750 3090 Intermediate Production 11263' 7" 33' - 11296' 33' - 7268' 7240 5410 Liner Perforation Depth: Measured Depth: 11047' - 11108' y .' A 0 1 (3 2b1 ) True Vertical Depth: 7026' - 7085' Tubing (size, grade, measured and true vertical depth): 4-1/2", 12.6# L - 10790' 6778' Packers and SSSV (type, measured and true vertical depth): P 1�V None �' " tit i1 1 I1.' 11. Stimulation or cement squeeze summary: Intervals treated (measured): Alaska Gil & o$ Com Ger +xr+ +ssion Treatment description including volumes used and final pressure: `tnchaf'dg Doyon 16 Pull 2 -7/8" ESP Completion. Pull retrievable packer and attached screens. Run 4-1/2" work/frac completion string. RDMO. Frac'd pumping 185,729# of 16/20 Carbolite behind pipe, leaving 3,488# in wellbore. Clean out to 11189. Cut (work string) tubing at 10885'. RU Doyon 16, pull work string. Run ESP Completion. 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 141 9 253 Not Available Not Available Subsequent to operation: 137 12 290 -0- 196 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: ❑ Exploratory » ® Development ❑ Service ❑ Stratigraphic IN Daily Report of Well Operations ® Well Schematic Diagram 15. Well Status after work: ❑ GINJ w Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Wilmer Hoffman, 564 -4592 N/A Printed Name Terrie Hubble Title Drilling Engineer /Sign ature Prepared By Name/Number Signature Q / Phone 564 -4628 Date V'' Ii i Terrie Hubble, 564 -4628 Form 10-404 Revised 10/2010RB c J UL G 7 1t �/� 8 p /( Submit Original Only VV ��77 �l 7 ,,,,,) d • Tree; 4 1/16 ", 5M MPF-86 Orig. KB v. = 42.9' (N27E) Wellhead: 11" Gen 5 FMC • Orig. GLiv. = 10.9' w/11 x 4.5" TC -B -EC Tbg Hgr. RT to Tbg. Spool = 32.0' (N27E) w/ 4" CIW 'H' BPV profile 112' 1 9 -5/8" TAM Port Collar 1010' 0 9 -5/8 ", 40 # /ft., L -80 BTRC 6,517' a ■ 4 1/2" 12.6 ppf, L -80 IBT -M (drift ID = 3.833 ", cap = 0.0152 bpf) 3/8" capillary tube 7" 26 # /ft., L -80 BTC -M Production Casing (drift ID = 6.151 ", cap. = 0.0383 bpf) g (cap. w/ 4.5" tbg inside = 0.0186 bpf) D &D Tbg Stop 1 10733` Capillary tube 3/8" OD x .049 wall D &D Packoff Assy Top I 10735' I (capacity = 3.131 gallons / 1000') 1 i Centrilift TTC -ESP Top 10743' KOP @ 400' Max. Hole Angle = 64° Max. Hole Angle Thru Perfs. = 15° j Tbg TTC Drilled Tb Crossover 1 10743` 1 � I mo; F y Tandem Seal Sections � �' Model GSB3 DB UT /LT HL H6 PFS 10753'1 Stimulation Summary; 152.8K# of 16/20 Carbolite and MB Et 48.3k# of 12/18 behind pipe Motor, 55 HP, 1259 volt, I 10766'1 26 amp, Model KMHA Perforation Summary; ' IIF 1 PumpMate w/ 4 fin Centralizer 1 10786` : ' Ref. Log SWS jewelry log 8/10/01 PumpMate = ' TVD Size SPF Interval (TVD) �3 -3/8" 6 11047`- 11057' 7026-7036' 0 .,' 3 -3/8" 6 11064' - 11074' 7043' -7053' H 3 -3/8" 6 11086` 11096' 7064` -7074' f' 4 -1/2" 5 11068`- 11108' 7046` -7085' Note: 11068' - 11108 interval was shot with Power Jet Omega 5 SPF TCP's (PBTD) 11,206' 06 -02 -06 during the RWO 7" Float Collar _ 11,212' Doyon 16 FCO to 11170' - 3/3/11 7" Float Shoe 11,2961 IA Tested to 1000 psi 2 -4 -07 1 DATE FEV. BY COMMENTS MILNE POINT UNIT 08/25/01 M.Linder Initial perforations 6/4/06 L Hulme ESP Completion Nabors 3S WELL MPF-86 (KUP) 2/6/07 M. Ross FCO & Screens Added & ESP Completion Nabors 3S 8/24/08 REH ESP RWO BY Nabors 4ES API No. 50-029 -23018 5/13/09 L Hulme ESP RWO - Add Cap Tube - Nabors 3S 3/3/11 L Hulme Pull ESP & run Frac string - Doyon 16 6/21/11 B. Bixby ESP RWO Thru Tbg. ESP - Doyon 16 BP EXPLORATION (AK) 1 . . MPF -86, Well History (Pre Rig Workover) Date Summary 12/12/2010 T /I /0= 850/900/0 Pre Rig Freeze protect Tbg & Flowline. Pump 15 bbls 90 °F diesel down Tbg. Pump 2 bbls 60/40 meth followed by 3 bbls diesel and 2 bbls 60/40 meth down flowline. Hang F/P tag. FWHP= 400/1000/0. 12/15/2010 WELL S/I ON ARRIVAL. DRIFT W/ 2.11" CENT, 6' x 1 -1/2" stem, 2.04" CENT, 1 -1/2" S. BAILER TO ESP @ 10,847' MD. (no restrictions) RAN 24 ARM PDS CALIPER, FROM XN @ 10,795' MD TO SURFACE. PULLED ST# 1 BK -DGLV FROM 10,611' MD. PULLED ST# 2 DPSOV -BK FROM 169' MD. SET ST #2 BK -DGLV @ 169' MD. IN HOLE W/ SBHPS. 12/16/2010 RAN SBHPS PER PROGRAM. WELL LEFT S/I OPER NOTIFIED. 12/20/2010 T /I /O =SSV /920/50, Temp =SI. PPPOT-T (PASS), PPPOT -IC (PASS). Pre RWO. PPPOT -T: Stung into test port (0+ psi), bled to 0 psi. Functioned LDS (ET style), all moved freely (1 "), torqued to 350 lb /ft. Pressured void to 5000 psi for 30 min test, lost 200 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to Opsi. PPPOT -IC: Stung into test void (0+ psi), bled to 0 psi. Functioned LDS (ET style), all moved freely (.75 "), torqued to 400 lb /ft. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 0 psi in 30 min (PASS). Bled void to 0 psi. 1/9/2011 The Well Support Techs rigged up and removed the wellhouse, flowline and foundation in prep for the RWO. 2/2/2011 WELL S/I ON ARRIVAL. RAN 2.05" CENT, S. ABSORBER DUAL SPARTEK GAUGES AS PER PROGRAM. MADE 15 MIN GRADIENT STOP @ 10,326' SLM / 10,347' MD. MADE 3 HR BHP STOP @ 10,823' SLM / 10,847' MD. ASSIST WELL SUPPORT W/ BPV. BPV SET. TURN LEFT S /I, TURN OVER TO DSO. JOB COMPLETED. See Doyon 16 Summary: 02/16/11 - 03/05/11 i st.0 U 4/26/2011 WELL S/I ON ARRIVAL. SET 4 -1/2" WHIDDON (3.8" od, 78" lih) ON BALL & ROD @ 10962' MD. 4/27/2011 PULLED 1" BK -DGLV FROM ST #1 @ 10,819' MD. SET 1" BK -SPMG IN ST #1 © 10,819' MD. LRS MIT IA TO 4000 PSI (passed). PULLED CATCHER FROM 10,962' MD (empty). RAN 3.70" BELL GUIDE, 2" JU (steel), PULLED B &R FROM 10,962' MD. PULLED RHC PLUG BODY FROM 10,962' MD. DRIFT W/ 3.17" CENT, 2' x 1 -7/8" stem, S. BAILER. TAG BTM @ 11,101' SLM (11,120' MD 12' of rathole below pert at 11108' MD). RECOVERED 1 CUP OF SCHMOO/ FRAC SAND. WELL S/I ON DEPARTURE. JOB COMPLETE. 4/27/2011 T /I /0= 300/260/ 0 "Pre Frac" MIT -IA (PASSED) to 4000 psi. _ Pumped 1 bbl diesel down Tbg to pressure up to 1000 psi. Pump 4.1 bbls diesel down IA to reach test pressure. 1st 15 Min. IA lost 20 psi 2nd 15 Min. IA lost zero psi for a total loss of 20 psi in 30 Min. Bleed IA down to 400 psi w/ all diesel pumped returned, Hang tags. Notified Operator FWHP= 900/400/0. 4/30/2011 Hold backside pressure during frac. Pressured IA to 3500 psi with 2.4 bbls DSL, pumped additional 0.9 bbls to maintain 3500 psi during data frac. Pumped 2.6 bbls diesel down IA to maintain 3500 psi during frac. Bled IA to 500 psi. 4/30/2011 Rig up frac equipment and tree saver. Pump break down /step down test, Scour Stage, Data Frac. Pump Frac at 25 bpm using 40# x -link gel w. 8 gpt of L065 (Scale Inhibitor) for a total of 210 gals. Pump 275 bbl pad then pump 100 bbls of 1 ppa stage leading in with 16/20 ceramic proppant. Ramp 1 to 4 ppa with c-` 16/20 in 250 bbls, continue ramp from 4 ppa to 10 ppa in 450 bbls. Hold 10 ppa flat stage for 200 bbls with treating pressure of - 4515 - 6455 psi. Flush vols of 59 bbls XL Gel, 59 bbls of non -XL Gel, 30 bbls � �� diesel placing freeze protect at -1972'. Total of 16/20 C -Lite proppant behind pipe 185,729# Left 3,488# 1 � - in wellbore. Job Complete. 5/3/2011 RIH with 2.25" JSN, tag sand @ 10836 ctmd. Begin clean out, clean to 11189 ctmd and chase out of hole @ 60 %. Bull head diesel 167 bbls freeze protect. RDMO. Job Complete. 5/8/2011 T /I /0= 600/580/60 Freeze Protect, Pump 5 bbls 60/40 followed by 40 bbls diesel down tubing. Page 1 of 2 • MPF -86, Well History (Pre Rig Workover) Date Summary 5/9/2011 T /I /O = 600/580/60. Freeze protect. Pumped 17 bbls diesel down Tbg. FWHP= 750/500/60. 5/11/2011 WELL S/I ON ARRIVAL. DRIFT 3.65" CENT, 2' x 1 -7/8" STEM, 4 -1/2" T.E.L., 1 -1/2" S. BAILER. LOC TT @ 10,968' SLM (10,989' MD, 21' ft CORRECTION). TAG TD @ 11,094' SLM (11,115' MD) 7' FT OF RAT HOLE. RAN 3.65" CENT, S. ABSORBER, DUAL SPARTEK GAUGES. MADE 30 MIN GRADIENT STOP @ 10,585' SLM (10,606' MD). MADE 3 HR BHP STOP @ 11,085' SLM (11,106' MD). CURRENTLY SETTING 3.813" XXN PLUG W/ 2' FILL EXT (3.80" od, 51" oal) IN XN NIPPLE 10963' MD. 5/12/2011 SET 3.813" XXN PLUG W/ 2' FILL EXT (3.80" od, 8 1/8" ea. ports, 51" lih) IN XN NIPPLE 10963' MD. MIT TUBING TO 2000 PSI, PASSED ON SECOND ATTEMPT. LOST 0 PSI ON 1ST AND 2ND 15 MIN. SET 4 -1/2" WHIDDON (3.80" od, 78" lih) ON XXN PLUG @ 10,9633' MD. PULLED 1" BK -SPMG FROM ST #1 © 10,819' MD. MADE 15 MIN GRAD STOP @ 10,319' MD. BLEED TBG DOWN TO 450 PSI. SET 1" BK -DGLV IN ST #1 @ 10,819' MD. PRESSURE TBG TO 1000 psi, MONITOR 10 MIN (passed). PULL 4 -1/2" WHIDDEN FROM XXN PLUG © 10,963' MD (empty). WELL LEFT S/I ON DEP. JOB COMPLETE. 5/20/2011 WELL SHUT IN ON ARRIVAL. INITIAL T /I /O= 100/50/0 RIG UP AND RIH WITH MH22 /ERS /2X EQF43 /CCU2X SHOCK MANDRELS (2GEMCOS) /3.65" JET CUTTER FISHING NECK= 1.38" OAL =24' OAW= 180# AT 3970', 3972', 3974', 3981', 5343', 6050', 6320' TOOL SET DOWN AT 6320' UNABLE TO GET TOOL DOWN, POOH AND CHANGE TOOL CONFIGURATION. RIH WITH MH22 /ERS /EQF43 (GEMCO) /EQF46 /CCU2X SHOCK MANDRELS (GEMCO) / 3,65" JET CUTTER FISHING NECK= 1.38" OAL =24', OAW= 220 #. DISCREPANCY FOUND IN 3- MAY -11 TUBING TALLY. CONFIRMED WITH PE AND INSTRUCTED TO POOH AND RETURN TOMORROW FOR CUT. 5/21/2011 CUT TUBING AT 10885' WITH SLB 3.65" POWER JET CUTTER. PRESSURED UP ON TUBING FOR 10 MINUTES AND THERE WAS NO CHANGE IN TUBING OR IA PRESSURE. FINAL T /I /O = 0/0/0 PSI. WELL LEFT SHUT IN UPON DEPARTURE. JOB COMPLETE. 5/22/2011 The Well Support Techs rigged up and set a BPV. 400 psi on tubing. NOTE: BPV was left in for upcoming RWO. 5/23/2011 T /I /0= 270/0/60 temp =si CMIT Tx IA 500 psi Rigged up to tree cap and pumped 7.6 bbls diesel down tubing, unable to reach test pressures, out of fluid. Rig down and road unit to reload. Back on location, MIRU to tree cap. Unable to get pressure test. Call for grease truck to service valves. 5/24/2011 CMIT Tx IA to 500 psi FAIL. Will return for a retest. Valves on tree serviced. Resumed pumping down tbg. Pumped 1.3 bbls diesel to reach 500 psi test pressure on IA thru BPV in Tbg. 9 bbls total pumped Starting pressures was 900/500/40, 1st 15 minute pressures were 0/490/40, and 2nd 15 minutes were 0/470/40. IA lost 30 psi total. Left Pressures on well and Rigged down. FWP's = 900/470/40 5/29/2011 T /I /O= BPV /0/0 Temp =Sl PPPOT-T (PASS) PPPOT -IC (PASS) (Pre RWO) PPPOT -T : RU 2 HP BT onto THA 50 psi bled to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bled void to 0 psi, RD test equipment, re- installed Alemite caps. Cycle and torque LDS "ET style" all were in good working and visual condition. PPPOT -IC : RU 2 HP BT onto IC test void 0+ psi bled to 0 psi, flush void until clean returns achieved. Pressured to 3500 psi for 30 minute test, 3500/ 15 minutes, 3500/ 30 minutes. Bled void to 0 psi, RD test equipment, re- installed Alemite caps.Cycle and torque LDS "ET style" all were in good working and visual condition. 6/3/2011 T /I /O= 0/0/0. Temp= S /I. CMIT -TxIA to 500psi. 6/4/2011 CMIT -TxIA PASSED to 500psi. Pressured up TxIA w/ 4 bbls ambient diesel. CMIT lost 40/20 psi in 1st 15 mins and 0/0 psi in 2nd 15 mins w/ a total loss of 40/20 psi over 30 min test. Bled WHP down. Bled back 1.2 bbls. FWHP's= 0/0/0. Well left shut in. Pad Op notified. See Doyon 16 Summary: 06/13/11 - 06/21/11 Page 2 of 2 O • . . . „ .North Ametlaa ', ALASKA -, BFi : - , . - , „ i . Page 1 :Of 1;1 Operation Summary Report — " .. . Common Well Name: MPF-86 1AFE No Event Type: WORKOVER (WO) Start Date: 2/16/2011 I End Date: 3/5/2011 X4-00RVK-E (1,540,000.00 ) I , Project: Milne Point , Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. p,1( 6...5? I. UWI: 500292301800 Active Datum: MPF-86 @42.90ft (above Mean Sea Level) Date : From - To Hrs Task Code I NPT NPT Depth I Phase I Description of Operations I (hr) , (ft) I 2/16/2011 15:00 - 00:00 9.00 MOB P , ] PRE MOB RIG OFF OF H-15. -UD DERRICK. I , -BACK OFF WELL AND SPOT ON PAD. : I -REMOVE BOPE. — 2/17/2011 00:00 - 12:00 12.00 MOB I P , PRE MOB RIG FROM H-PAD AT 0230 HRS. 12:00 - 00:00 i 12.00 MOB P PRE I CONTINUE RIG MOVE TO MPU F-86 -STOP AT TEXACO PAD AND INSTALL FRONT BOOSTERS. 1 , 2/18/2011 00:00 - 06:30 6.50 MOB P PRE MOVE RIG FROM TEXACO PAD TO MPU F 1 , PAD. Ir. 06:30 - 12:00 , 5.50 MOB P 1 PRE STAGE RIG ON F PAD. I 1 i -REMOVE BOOSTER WHEELS AND INSTALL I I BOPE STACK ON PEDESTAL I , I 1 -24-HR NOTICE OF BOPE TEST GIVEN TO AOGCC AT 0952-HRS ON 2/18/11. I , -RAISE DERRICK. 12:00 - 00:00 12.00 MOB P . PRE ! SREAD HERCULITE, SET MATS . -PJSM, SPOT RIG OVER WELL -BRIDDLE DOWN -RU RIG FLOOR : • -CONTINUE TO SPOT EQUIPMENT ON LOCATION 1 : L -MINOR RIG MAINTENENCE, CLEANING 2/19/2011 00:00 - 11:00 1 11.00 1 1 MOB P PRE RIG UP OVER F-86 1 I -TIE IN TIGER TANK HARDLINE AND TEST. I 1 : I -R/U CIRCULATION LINES IN CELLAR. I t , I -SPOT AUXILIARY EQUIPMENT. 11:00 - 13:00 2.00 MOB P 1 PRE HOLD ATP WITH MPU ASSET LEADERSHIP AT MPU BASE CAMP. I , -DISCUSS MPU SPECIFIC POLICIES AND : i 1 PROCEDURES. REVIEW F-PAD , I , ENVIRONMENTAL PRESENTATION. ' -HOLD LEADERSHIP AAR AND DEVELOP RIG ACTION ITEMS ASSOCIATED WITH MPU SPECIFIC OPERATIONS. 13:00 - 15:00 2.00 : MOB P PRE BRING ON 120-DEGREE 9.7-PPG BRINE. -CENTRILIFT REPORT BOTTOM HOLE PRESSURE IS READING 3456-PSI. -RIG WELDER INSTALL CAMERA BRACKET. 15:00 - 16:00 1.00 MOB P ; PRE HOLD PRE-WELL MEETING WITH RIG CREW AND MI MUD ENGINEER. -DISCUSS ALL UPCOMING WELL I OPERATIONS. -HIGHLIGHT DIFFERENCES WORKING AT MILNE PT AND WITH THE JOB TASKS AT HAND. -DISCUSS WELL CONTROL ISSUES AND , , CONSIDERATIONS. 16:00 - 18:00 2.00 MOB P PRE RIG UP CIRCULATING EQUIPMENT TO TREE. -BLEED 750-PSI OFF OF TREE TO BLEED TRAILER. -CENTRILIFT SPOOLER DELIVERED TO LOCATION. -RIG UP BLEED LINE FROM OA TO BLEED I , . I , TRAILER. 18:00 - 18:30 ; 0.50 MOB , P ! PRE !ACCEPT RIG AT 1800-HRS. I : -PU DSM LUBRICATOR AND MU TO TREE. Printed 7/5/2011 9:18:14AM - 01th ftilTl2fIC ALA BP Page 2 of 12 peration Summary Report Common Well Name: MPF -86 AFE No Event Type: WORKOVER (WO) Start Date: 2/16/2011 End Date: 3/5/2011 jX4- 00RVK -E (1,540,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 ; Spud Date/Time: I Rig Release: Rig Contractor: DOYON DRILLING INC. UWI. 500292301800 Active Datum: MPF -86 ©42.90ft (above Mean Sea Level) Date From - To Hrs Task Code NPT ' NPT Depth Phase I Description of Operations T18:30 - 19:30 1 1 1.00 T MOB P 1 PRE PRESSURE TEST LUBRICATOR -LOW PT 300 PSI 5 MIN W/ DIESEL, GOOD TEST -HIGH PT 3500 PSI 5 MIN W/ DIESEL, GOOD TEST 19:30 - 20:30 1.00 MOB P PRE I PULL BACK PRESSURE VALVE -800 PSI TUBING PRESSURE -1000 IA PRESSURE 20:30 - 21:30 1.00 KILLW P I DECOMP . PJSM FOR WELL KILL !- DISCUSSED PUMP SCHEDULE, WIND :DIRECTION FOR GAS VENTING, ROLES & l 1 RESPONSIBILITIES 21:30 - 23:00 1.50 KILLW P DECOMP RIG UP TO IA AND TREE CAP FOR WELL KILL -PT SURFACE LINES UPSTREAM OF CHOKE -LOW PT TO 300 PSI FOR 5 MIN, GOOD TEST I -HIGH PT TO 3500 PSI FOR 5 MIN, GOOD TEST 23:00 - 00:00 1 1.00 KILLW P DECOMP :OPEN UP WELL TO CHOKE MANIFOLD -650 TUBING PRESSURE -1010 IA PRESSURE -PUMP RATES AND PRESSURES 750 PSI TUBING PRESSURE © 2 BPM 1010 PSI TUBING PRESSURE @ 3 BPM 1330 PSI TUBING PRESSURE @ 4 BPM -GAS RETURNS TO TIGER TANK -FLUID RETURNS STARTING AT 23:20 -SHUT DOWN PUMP AND SHUT IN CHOKE ; FOR BULLHEAD I I - BULLHEAD 30 BBLS DOWN TUBING, 4 BPM @ I 1 1950 PSI TUBING PRESSURE -SHUT DOWN PUMP AND OPEN CHOKE TO CIRCULATE SURFACE TO SURFACE 2/20/2011 : 00:00 01:30 1.50 KILLW P DECOMP CONTINUE TO CIRCULATE WELL AT 4 BPM 1 MAINTAINING 1100 PSI TUBING PRESSURE ✓ -CASING PRESSURE DROPPING WHILE 9.7 : BRINE COMES UP BACKSIDE 1 -400 BBLS PUMPED FOR SURFACE TO SURFACE -9.7 BRINE RETURNS 01:30 - 02:00 0.50 KILLW P DECOMP SHUT DOWN PUMP, SHUT IN CHOKE AND MONITOR WELL FOR 30 MIN - INITIAL PRESSURES: 50 PSI IAP, 40 PSI TUBING PRESSURE -FINAL PRESSURES AFTER 30 MINUTE MONITOR: 10 PSI IAP, 0 PSI TUBING PRESSURE 02:00 - 03:30 1.50 KILLW P L DECOMP OPEN CHOKE AND BRING ON PUMP TO 5 BPM AT 1970 PSI FOR SECOND WELL CIRCULATION THROUGH GAS BUSTER BACK TO PITS -6.5 BBLS TO CATCH RETURNS -LOSS RATE WHILE PUMPING 42 BBUHR 03:30 - 04:00 0.50 KILLW P DECOMP SHUT DOWN PUMP AND MONITOR WELL -WELL STATIC WHILE MONITORING -NO STATIC LOSS ES 04:00 - 06:00 2.00 WHSUR P DECOMP PU LUBRICATOR -TEST LOW PRESSURE TO 300 PSI ; -TEST HIGH PRESSURE TO 3500 PSI SET TWC Printed 7/5/2011 9:18:14AM arth America - ALASKA -, BP ` Page 3 of 12 O peratic Summary.' ." Report Common Well Name: MPF -86 AFE No Event Type: WORKOVER (WO) I Start Date: 2/16/2011 End Date: 3/5/2011 X4- 00RVK -E (1,540,000.00 ) Project: Milne Point I Site: M Pt F Pad I Rig Name /No.: DOYON 16 I Spud Date/Time: ! Rig Release: Rig Contractor: DOYON DRILLING INC. IUWI: 500292301800 Active Datum: MPF -86 @42.90ft (above Mean Sea Level) Date From - To Hrs Task Code NPT I NPT Depth 1 Phase Description of Operations hr t (ft) TEST TWC. 06:00 - 08:30 2.50 WHSUR P DECOMP -TEST FROM BELOW FOR 5- MINUTES WITH ' PUMP ROLLING. PUMP AT 2 -BPM WITH 550 PSI. -TEST TWC FROM ABOVE TO 250 -PSI FOR 5- MINUTES AND THEN 3500 -PSI FOR j ' I10- MINUTES. -CHART ALL TESTS. + -ALL TESTS GOOD. 08:30 - 10:00 1.50 WHSUR P I DECOMP IATTEMPT TO PUMP THROUGH 3/8" SS CAPILLARY TUBE USING RIG TEST PUMP. CAPILLARY TUBE WAS INSTALLED ON THE EXTERIOR OF THE 2 -7/8" TUBING TO ENABLE SCALE INHIBITOR TO BE INJECTED INTO THE ' WELL THE RIG UP INCLUDED DUAL CHECK I VALVES. THE LINE WAS NEVER PUMPED 1 I INTO WITH SUCCESS. AN MSDS FOR THE ' j I ' SCALE INHIBITOR THAT WOULD HAVE BEEN PUMPED WAS REVIEWED AND AVAILABLE I TO ALL WHO WORKED AROUND THE LINE. -THE LINE IMMEDIATELY PRESSURED UP TO L 4000-PSI. -HOLD AND CHART TO ASSESS IF CHECK VALVES OPENED. DREW A STRAIGHT LINE 'INDICATING LINE WAS NOT ABLE TO BE ! PUMPED THROUGH I -BLOW DOWN AND RIG DOWN ALL !CIRCULATING LINES. _ -SPOT ESP CABLE SPOOLING UNIT. 10:00 - 11:00 ! 1.00 ' WHSUR P I DECOMP ND PRODUCTION TREE AND ADAPTER FLANGE. -MPU SINGLE BARRIER DISPENSATION IN ! PLACE. 1 - MAINTAIN CONTINUOUS HOLE FILL WITH I 5-BPH LOSS RATE -SINGLE MECHANICAL BARRIER IS TWC IN I TUBING HANGER. 11:00 15:00 4.00 WHSUR P DECOMP I INSPECT TUBING HANGER. ' -TEST FIT CROSSOVERS FOR LANDING JOINT AND OPSO LOPSO. - PENETRATOR HEIGHT INTERFERES WITH PROPER MU OF 2 -7/8" 8RD. -TAKE PHOTOGRAPHS AND FORWARD TO RWO OPERATIONS TEAM. DISCUSS OPTIONS WITH RWO SUPERINTENDENT. ' DECIDE TO USE MECHANICAL LUBRICATOR ' WITH HAZARD ASSESSMENT. - CHANGE HOLE FILL TO ALLOW GRAVITY FEED. LOSS RATE = 13 -BPH. 15:00 21:00 6.00 BOPSUR P DECOMP INI.1 BOP STACK AND ASSOCIATED EQUIPMENT. 21:00 - 22:00 1.00 BOPSUR 1 P DECOMP RIG UP FOR BOP TEST - LOSSES 14 BPH 22:00 - 00:00 2.00 BOPSUR N RREP DECOMP REMOVE 2 -7/8" X 5" VARIABLE PIPE RAMS FOR INSPECTION 2/21/2011 00:00 - 01:00 1.00 1 BOPSUR N RREP I DECOMP REMOVE 2 -7/8" X 5" VBR FOR INSPECTION I AND REPAIR - REPAIR VBR AT SHOP BY REPLACING ! ,PACKER ! -MAINTAIN CONTINUOUS HOLE FILL AT 14 BBUHRLOSSES Printed 7/5/2011 9:18:14AM firth America - ALASKA $KA - BP Page 4 of 12 Operation Summary Report Common Well Name: MPF -86 1 AFE No Event Type: WORKOVER (WO) Start Date: 2/16/2011 1 End Date: 3/5/2011 X4- 00RVK -E (1,540,000.00 ) Project: Milne Point 1 Site: M Pt F Pad 1 Rig Name /No.: DOYON 16 1 Spud Date/Time: !Rig Release: Rig Contractor: DOYON DRILLING INC. i UWI: 500292301800 Active Datum: MPF -86 @42.90ft (above Mean Sea Level) Date 1 From - To Hrs 1 Task 1 Code NPT I NPT Depth Phase Description of Operations — ( ) hr 1 1 1 (ft) 01:00 - 02:00 1.00 1 BOPSUR P 1 DECOMP TEST 2 -7/8" AND 4" TIW VALVES, DART 1 1 1 VALVES, UPPER AND LOWER IBOP I 1 -ALL TESTS TO THE FOLLOWING CRITERIA: 1 250 PSI LOW, 3500 PSI HIGH CHARTED FOR 5 MIN - AOGCC, JOHN CRISP, WAIVED STATE'S I RIGHT TO WITNESS 1 -ALL TESTS WITNESSED BY DOYON TOOLPUSHER OR BP WSL - CONTINUE WORK ON 2 -7/8" X 5" VBR 02:00 - 05:30 1 , 3.50 BOPSUR N RREP , DECOMP ',- FINISH REPAIR OF VBR AT SHOP BY ' REPLACIN G PACKER 1- INSTALL IN RAM BODY 1- MAINTAIN CONTINUOUS HOLE FILL AT 14 `BBL/HR LOSSES _ 05:30 - 08:00 2.50 1 BOPSUR I P 1 DECOMP !TEST BOPE 1 - 2 -7/8" X 5" VBR USING 2 -7/8" TEST JT TO 250 j LOW AND 3500 PSI HIGH EACH FOR 5 MIN, 1 I GOOD TEST. - ATTEMPT TO TEST ANNULAR USING 2 -7/8" 1 I TEST JT - TEST FAILED. 1 08:00 - 17:00 9.00 BOPSUR N RREP DECOMP DRAIN BOP STACK AND PREPARE TO REMOVE ANNULAR ELEMENT. -PULL RISER AND REMOVE DUTCH RISER FLANGE. -MU POTATO MASHER AND REMOVE 1 1 ANNULAR CAP. 1- REMOVE AND REPLACE ANNULAR ' ELEMENT. -REINSTALLANNULAR CAP. 1 FUNCTION TEST ANNULAR. GOOD TEST. - REINSTALL DUTCH RISER FLANGE AND , , RISER. -PHASE 2 WEATHER DECLARED AT MPU AT 1600 -HRS 1 -LOSS RATE = 10 -BPH. 17:00 - 00:00 7.00 BOPSUR 1 i P DECOMP I CONTINUE INITIAL BOPE TEST. -PJSM - FILL BOP AND TEST CHOKE MANIFOLD VALVE bbe -TEST 4 -1/2" TEST JOINT IN 2 -7/8" X 5" VBR . -k ' -TEST ANNULAR PREVENTER WITH 2 -7/8" TEST JOINT -ALL TESTS TO THE FOLLOWING CRITERIA: WI %I 250 PSI LOW, 3500 PSI HIGH CHARTED FOR 5 MIN -LOSS RATE = 11 BPH - AOGCC, JOHN CRISP, WAIVED STATE'S RIGHT TO WITNESS ' -ALL TESTS WITNESSED BY DOYON TOOLPUSHER OR BP WSL 2/22/2011 00:00 - 00:30 ! 0.50 BOPSUR P DECOMP BOP TEST CONTINUED - ACCUMULATOR TEST, GOOD TEST - LOSSES = 12 BPH 00:30 - 01:00 0.50 BOPSUR P DECOMP RIG EVACUATION DRILL -WELL SECURED, IGNITION SOURCES ISOLATED, -ALL PERSONNEL ON LOCATION SIGNED IN ' AND PRESENT FOR MUSTER Printed 7/5/2011 9:18:14AM orth America - ALASKA - BP Page 5 of 12 Aeration Summary Report Common Well Name: MPF -86 - __. AFE No —J Event Type: WORKOVER (WO) I Start Date: 2/16/2011 End Date: 3/5/2011 jX4- 00RVK -E (1,540,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. ' UWI: 500292301800 Active Datum: MPF -86 ©42.90ft (above Mean Sea Level) Date From - To I Hrs Task I Code NPT I NPT Depth Phase I Description of Operations 02:30 1.50 P (ft) 01:00 DECOMP RIG DOWN ROPE TESTING EQUIPMENT (hr) ft - ' BOPSUR -PU AND PRESSURE TEST DUTCH RISER AND LUBRICATOR I I I 250 PSI LOW, 5 MIN, GOOD TEST 3500 PSI HIGH, 5 MIN, GOOD TEST 02:30 - 04:00 1.50 BOPSUR I P DECOMP PULL TWC -LAY DOWN LUBRICATOR AND DUTCH RISER -FILL TUBING, 11 BBLS TO FILL - LOSSES DOWN TUBING 2 BPH 04:00 07:00 3.00 WHSUR 1 P ! DECOMP 1 RIG IIP TO Pill 1 TUBING HANGER, 1 1-PJSM -BACK OUT LOCK DOWN SCREWS -PULL TUBING HANGER. PICK UP WEIGHT 110K LBS. BREAK OVER WEIGHT 105K -LAY DOWN TUBING HANGER — RU TO CIRCULATE. 07:00 - 10:30 3.50 PULL P j DECOMP , CI IRCULATE 2X BOTTOMS UP @ 5 BPM / 1900 ' PSI. - CIRCULATE 1 BOTTOMS UP @ 2.5 BPM / 500 I PSI. - CIRCULATE ACROSS THE TOP OF THE HOLE i WHILE R/U ESP PULLING EQUIPMENT. ' 10:30 - 13:00 2.50 PULL P DECOMP r PJSM. POH. -UD 2 -7/8" L -80, 6.5 #, ESP COMPLETION ASSY ' TO 10752' MD.. 1 13:00 - 13:30 0.50 PULL P ' DECOMP SERVICE RIG. 13:30 - 19:00 5.50 PULL P ' DECOMP CONTINUE TO PULL & UD ESP COMPLETION ASSY TO 7520' MD. 119:00 20:00 PULL DECOMP L P I E G - CHANGE ESP CABLE REELS (10 (101 T). I JTS OUT). 1.00 120:00 - 22:30 2.50 PULL P I DECOMP CONTINUE TO POH. UD 2 -7/8" TBG TO 5728' MD. T 22:30 23:00 0.50 PULL P I DECOMP AAR ON TRIP OUT OF THE HOLE. WORK ON PROCEDURES. 23:00 - 00 :00 I 1.00 PULL P ' DECOMP CONTINUE TO MAINTAIN HOLE FILL W/ I CENTRIFUGAL PUMP. -POH. UD 2 -7/8" TBG TO 5440' MD. CONTINUE 2/23/2011 00:00 - 07:30 7.50 PULL P DECOMP TO PULL & UD 2 -7/8" ESP ' COMPLETION. -LD 342 JTS OF 2 -7/8" TUBING, 2 GLMS, AND , ALL CLAMPS. 07:30 - 08:30 1.00 PULL P DECOMP PJSM / MAKE PROCEDURE FOR BREAK OUT AND UD OF ESP ASSEMBLY. 08:30 10:00 1.50 PULL P DECOMP BO & UD ESP ASSEMBLY . 10:00 - 10:30 0.50 PULL P DECOMP AAR FOR LAY DOWN OF ESP AND UD OF TBG. 10:30 - 14:00 3.50 PULL P DECOMP R/D FROM PULLING COMPLETION STRING. -R/D AND OFF LOAD SWS SPOOLER. -RID ESP SHEAVE, AND CLEAR RIG FLOOR. 14:00 - 15:00 1.00 PULL P DECOMP AAR FOR R/D OF ESP PULLING EQUIPMENT. PJSM FOR P/U OF PACKER RETRIEVAL BHA 18:00 3.00 PULL P DECOMP AND RIH. I 15:00 - P/U HES PACKER RETRIEVAL TOOL, BUMPER SUB, 9 DC'S, AND PUMP OUT SUB. -RIH ON 2 -JTS OF DP 18:00 - 00:00 6.00 PULL N WAIT 302.00 DECOMP i DECLARE PHASE 3 WEATHER AT MPU. - CIRCULATE ACROSS THE TOP OF THE WELL WITH 9.7 -PPG BRINE. LOSS RATE = 6 -BPH. Printed 7/5/2011 9:18:14AM orth America - ALASKA BP Page 6 of 12 Aeration Summary Report Common Well Name: MPF -86 _ I AFE No Event Type: WORKOVER (WO) Start Date: 2/16/2011 End Date: 3/5/2011 X4- 00RVK -E (1,540,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292301800 Active Datum: MPF -86 @42.90ft (above Mean Sea Level) Date 1 From - To Hrs Task ! Code I NPT i NPT Depth [ Phase I Description of Operations (hr) I (ft) 2/24/2011 100:00 - 00:00 1 24.00 PULL I N WAIT 302.00 ' DECOMP I CONTINUE TO WAIT ON WEATHER. MPU IN 1 1 I I PHASE 2, LEVEL 3 DUE TO ROAD I CONDITIONS. I - PACKER RETRIEVAL BHA IN THE WELL TO ' 1 302'. -BHA CONSISTS OF RETRIEVAL TOOL, BUMPER SUB, 9(EA) 4 -3/4" DCS, PUMP OUT 1 I SUB, XO AND 2 -JTS OF 4" DP. ' -LOSS RATE CIRCULATING ACROSS THE TOP ' OF THE WELL = 6 -BPH WITH 9.7 -PPG BRINE -2(EA) 290 -BBL LOADS OF 9.7 -PPG BRINE ON i LOCATION AS CONTINGENCY. - PERFORM CREW C HANGE WITH HEAVY EQUIPMENT ESCORT AS APPROVED BY MPU I I I OPS. - CH2MHILL PERFORM CREW CHANGE FOR VAC TRUCK DRIVERS AT NOON AND AGAIN AT TOUR CHANGE (2330 -HRS). -FUEL AND WATER DELIVERED TO RIG i i MIDDAY. -SHUT DOWN SIGN IN SHACK GENERATOR AS IT WILL BE UNMONITORED FOR AN . EXTENDED PERIOD OF TIME. I , .- PERFORM GENERAL HOUSE KEEPING. . COMPLETE MP2 WORK ORDERS. I - DISCUSS FOUL WEATHER SAFETY CONCERNS - DOOR SAFETY, USING THE BUDDY SYSTEM OUTDOORS, RADIO 1 I COMMUNICATION - WITH BOTH CREWS IN ' 1 it PRE -TOUR SAFETY MTGS. - - - - — - -- -- - -- - - - -- - - 2/25/2011 00:00 - 00:00 24.00 PULL N WAIT 302.00 1 DECOMP I WAIT ON WEATHER. -PHASE 3 WEATHER DECLARED AT MPU AT I 0300 -HRS. -RIG CENSUS - 10 DOYON DRILLING I 1 EMPLOYEES, 2 CH2MHILL TRUCK DRIVERS. -CAMP CENSUS - 23 PERSONNEL (ASRC, BP, CH2MHILL SPOC, DDI, DUS) -MPU BASE CAMP - 1 BP WSL, 1 HES PACKER REP. -RIG CAMP AND RIG HAVE AMPLE SUPPLY OF FUEL AND WATER FOR -2 -DAYS. -WELL STATUS - RETRIEVAL BHA REMAINS IN WELL WITH 4" DP ACROSS BOP STACK. LOSS RATE CIRCULATING ACROSS THE TOP OF THE WELL REMAINS AT 6 -BPH WITH 9.7 -PPG BRINE. - DISCUSS FOUL WEATHER SAFETY HAZARDS - BUDDY SYSTEM, RADIO COMMUNICATION, DOOR SAFETY & USING THE BUDDY SYSTEM WHEN OUTSIDE- WITH 1 CREW AT RIG & SUPPORT CREW AT PRE -TOUR MTG. Printed 7/5/2011 9:18:14AM Orth`America - ALASKA BP ` Page 7 of 12 Operation' Summary Re port Common Well Name: MPF -86 _._ __ AFE No Event Type: WORKOVER (WO) Start Date: 2/16/2011 End Date: 3/5/2011 X4- 00RVK -E (1,540,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 j Spud Date/Time: 1 Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292301800 Active Datum: MPF -86 @42.90ft (above Mean Sea Level) Date From - To j Hrs 1 Task Code I NPT NPT Depth Phase 1 Description of Operations (hr) II (ft) 2/26/2011 ' 00:00 - 11:00 11.00 PULL N WAIT I 302.00 DECOMP WAIT ON WEATHER. j - TRAVEL APPROVED BY IMT ONLY. -RIG CENSUS - 10 DDI RIG CREW, 2 1 CH2MHILL TRUCK DRIVERS. -CAMP CENSUS - 23 BP, CH2, DDI, DUS EMPLOYEES -MPU BASE CAMP CENSUS - 1 BP WSL, 1 HES -PKR REP. ' -CAMP REMAINS ON WATER RESTRICTION ' TO CONSERVE WATER. i -CH2MHILL TRUCK DRIVERS SHUT DOWN TRUCKS AND TRAVEL TO MILNE PT BASE 1 CAMP WITH PAD OPERATOR AT 0900 -HRS. -LOSS RATE OF 9.7 -PPG BRINE CIRCULATING (ACROSS THE TOP OF. THE WELL REMAINS AT ' 6-BPH. 11:00 12:00 1.00 PULL N WAIT 1 302.00 DECOMP ' PERFORM CREW CHANGE. ' -MIKE WIEHL'S CREW GOES TO RIG WITH , MPU HEAVY EQUIPMENT ESCORT. ' -SEAN TOWER'S CREW RETURNS FROM RIG I WITH MPU HEAVY EQUIPMENT ESCORT. 12:00 - 00:00 12.00 PULL N 302.00 WAIT - 0 DECOMP CONTINUE TO WAIT ON WEATHER -MPU IN PHASE 2 LEVEL 3 WITH MPU RD CLOSED AND SPINE RD IMPASSABLE AT W -PAD. -CIRCULATE ACROSS THE TOP OF THE WELL T _ WITH 6 -BPH LOSSES. 2/27/2011 00:00 16:30 16.50 PULL P DECOMP PJSM. DISCUSS FOCUS AND BEING OUT OF THE NORMAL. - SINGLE IN WITH THE PACKER RETRIEVAL BHA TO 10908' MD. -PUW= 200K, SOW= 150K. . -NOTE: CH2MHILL TRUCK DRIVERS, LEAD, LOADER & MECHANICS: -ON LOCATION GETTING VAC TRUCKS I RUNNING. -LOSS RATE WHILE RIH = 6 -BPH. 1 -SNOW REMOVAL OPERATIONS ONGOING: -CLEAR AROUND CH2MHILL VAC TRUCKS & ' ' RIG. 16:30 17:30 1.00 PULL P DECOMP ' HOLD PJSM WITH RIG CREW. -SLIP & CUT 56' OF 1 -1/4" DRILLING LINE. ' '- PERFORM DERRICK AND TOP DRIVE ' INSPECTION. 17:30 - 20:00 ' 2.50 PULL P ' ' DECOMP C /O: GAS SPRINGS ON TD GRABBERS, LINK ' TILT PINS. '- COMPLETE DERRICK INSPECTION. 20:00 20:30 0.50 PULL P DECOMP BREAK CIRCULATION 4 BPM / 490 PSI. 5 BPM / 690 PSI. ' ' - OBTAIN SPR, MP1= 2 BPM / 150 PSI. 3 BPM / 240 PSI. I Printed 7/5/2011 9:18:14AM arth America - ALASKA - BP Page 8 of 12 Aeration Summary Report Common Well Name: MPF -86 —___— _-_._ - -- - �_ - II AFE No Event Type: WORKOVER (WO) ' Start Date: 2/16/2011 End Date: 3/5/2011 X4- 00RVK -E (1,540,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: , Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292301800 Active Datum: MPF -86 @42.90ft (above Mean Sea Level) Date From - To Hrs Task Code '', NPT NPT Depth 1 Phase Description of Operations 20:30 22:30 2 0 PULL P eft) DECOMP 1 TAG TOP OF PKR @ 10990' MD. PUW= 205K, SOW= 115K. -LATCH PKR W/ 10K DOWN WT. CONFIRM LATCH W/ 225 UP WT. -P /U, SECOND SHEAR @ 300K UP WT. NOTED FLUID DROP IN STACK. -POSITION TOOL JT. CLOSE BAG, BULLHEAD 40 BBLS OF 9.7 PPG NACL. I I -PUMP RATE: 5 BPM; ICP= 1940 PSI, FCP= I 2300 PSI. BLED PRESSURE TO ZERO. - MONITOR WELL, WELL FLOWING, SHUT IN WELL @ CHOKE. - PRESSURE NOTED @ SITP 120 PSI & SICP 140 PSI. ' -BLEED BACK 9 BBLS„ SHUT IN, ZERO PSI NOTED. OPEN WELL MONITOR WELL - STATIC. 22:30 - 00:00 1 1.50 PULL P , : DECOMP I BREAK OUT TD. DROP DART. -PUMP DART DOWN HOLE 5 BPM / 1700 PSI. -SHEAR OPEN POS @ 3100 PSI. ' -SHUT BACK IN. CIRCULATE HOLE VOLUME THROUGH CHOKE. ' -4 BPM / 430 PSI. 2/28/2011 00:00 - 02:00 2.00 PULL P DECOMP , CIRCULATE THROUGH CHOKE, 4 BPM / 420 PSI. - MONITOR WELL - SLIGHT LOSSES. ' -BLOW DOWN CHOKE & TD. 02:00 - 09:00 7.00 PULL PU 1 P DECOMP POH W/ PKR ASSY ON 4" DP. -OBSERVE WELL WHILE STANDING BACK DP. -PULL 5 STDS. MONITOR WELL - LOSS RATE 3 BPH. -CONTINUE TO POH TO 3255 MD. 09:00 - 10:00 1.00 PULL P I 'CIRCULATE 1.5 -TIMES BOTTOMS UP: - 4 BPM / 140 -PSI. 16 -BPH LOSSES WHILE CIRCULATING. - MONITOR WELL - LOSING SLOWLY. -BLOW DOWN TOP DRIVE. 10:00 - 13:30 3.50 PULL P 1 DECOMP CONTINUE TO POH FROM 3255 TO 302'. -LOSS RATE = 3 -BPH. -FLOW CHECK WELL ON LAST STAND OF DRILL PIPE. -FLUID LEVEL SLOWLY DROPPING. 13:30 - 14:30 1.00 PULL P DECOMP POH & STAND BACK 3 -STDS OF DRILL COLLARS. -L/D PACKER RETRIEVAL BHA. -14:05 HRS - GAVE AOGCC 3 -HR NOTICE FOR BOPE TEST. -CHUCK SCHEVE WILL WITNESS TEST. 14:30 - 17:00 2.50 PULL P DECOMP L/D RETRIEVAL TOOL WITH PACKER ENGAGED. - PACKER MISSING THE BOTTOM SEALING RUBBER (1 ELEMENT OF 3) -PUNCH CONNECTIONS ABOVE AND BELOW ALL CONNECTIONS BELOW PACKER. -L/D 1 -JT OF 4-1/2" TBG, 3-DURAGRIP SCREENS W/ BULL PLUG. -LOSS RATE = 10 -BPH. 17:00 17:30 0.50 PULL P DECOMP R/D HANDLING EQUIPMENT FOR L/D PACKER & SCREENS. -CLEAR & CLEAN RIG FLOOR. Printed 7/5/2011 9:18:14AM orth America - ALASKA BP Page 9 of 12 Operation Summery Report Common Well Name: MPF -86 AFE No Event Type: WORKOVER (WO) Start Date: 2/16/2011 1 End Date: 3/5/2011 X4- 00RVK -E (1,540,000.00 ) Project: Milne Point I Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292301800 Active Datum: MPF -86 @42.90ft (above Mean Sea Level) Date From - To Hrs Task Code ' NPT I NPT Depth Phase Description of Operations (hr) I-- (ft) 17:30 - 18:00 0.50 BOPSUR P I DECOMP ; PULL WEAR RING & SET TEST PLUG. ! -R/U TO PERFORM WEEKLY BOPE TEST. 18:00 23:00 5.00 BOPSUR P DECOMP 1 PERFORM WEEKLY BOPE TEST. -TEST 2 -7/8" X 5" VBRS USING 4" AND 4 -1/2" P)C) TEST JTS. : y ' -TEST ANNULAR USING 4" TEST JT. -TEST TO 250 -PSI LOW AND 3500 -PSI HIGH 'PRESSURE. -HOLD AND CHART EACH TEST FOR ),I1 1\ I ' 5- MINUTES. -ALL TESTS WITNESSED BY DDI TOOLPUSHER AND BP WSL. - AOGCC REP CHUCK SCHEVE WITNESSED TEST. 23:00 - 00:00 III 1.00 BOPSUR P DECOMP [RID BOP TEST EQUIPMENT. BLOW DOWN CHOKE & TEST LINES. i -PULL TEST PLUG. CLEAR & CLEAN RIG FLOOR. - INSTALL WEAR RING - 7.25" ID. 3/1/2011 00:00 - 02:30 2.50 CLEAN P DECOMP ,P /U & M/U 7" CSG SCRAPER BHA: 1 -JUNK MILL, STRING MILL, 4 X BOOT BASKETS, BIT SUB, STRING MAGNET, BUMPER SUB, OIL JAR, 5 X DC'S, DOUBLE PIN SUB, 7" CSG SCRAPER, -BIT SUB, POS, 4 X DC'S, XO SUB. 02:30 - 06:30 4.00 i CLEAN P DECOMP i RIH W/ 7" CSG SCRAPER BHA ON 4" DP. I 1 -© 5117 MD, CIRCULATE 1 DP VOLUME. __ - - -- -CONTINUE TO RIH TO 10,948' 06:30 08:00 1.50 1 CLEAN ' P DECOMP KELLY UP AT 10,948' AND OBTAIN PARAMETERS. -PUW = 210K, SOW = 112K. I 1 -20 -SPM = 70 -PSI, 30 -SPM = 270 -PSI. -WASH DOWN AT 4 -BPM / 600 -PSI. ' -WASH FROM 10,948' TO 11,170' MD. -DID NOT TAG ANY OBSTRUCTION OR FILL. -WORK SCRAPER FROM 10957' TO 10864' SEVERAL TIMES. 08:00 - 10:00 2.00 CLEAN P DECOMP PUMP 20 -BBL HI VIS SWEEP AND CHASE AT 6 -BPM / 1020 -PSI. - RECIPROCATE PIPE SLOWLY WHILE CIRCULATING. -LOSS RATE WHILE CIRCULATING = 24 -BPH. - NOTED: FRAC SAND & STICKY PARAFFIN 1 DURING CIRCULATION. - BOTTOMS UP AND SWEEP BROUGHT MORE SAND. -MPU WELL OPS SUPERVISOR, OPTIMIZATION ENGINEER AND PE CAME AND PRESENTED SPOT AWARD TO ALL RIG CREW MEMBERS WHO ASSISTED IN ' KEEPING THE WATER INJECTION SYSTEM RUNNING FOR THE F -PAD EXPANSION WELLS DURING PHASE 3 CONDITIONS. -SHUT DOWN PUMPS AFTER HI VIS SWEEP OUT OF HOLE AND HAD SMALL AMOUNT OF ' FLOW Printed 7/5/2011 9:18:14AM orth America - ALASKA - BP : : Page 10 of 12 . . . . . • . . ' - Operation Summary Report Common Well Name: MPF-86 AFE No Event Type: WORKOVER (WO) I Start Date: 2/16/2011 I End Date: 3/5/2011 I X4-00RVK-E (1,540,000.00 ) I I Project: Milne Point i Site: M Pt F Pad Rig Name/No.: DOYON 16 Spud Date/Time: I Rig Release: Rig Contractor: DOYON DRILLING INC. I UWI: 500292301800 Active Datum: MPF-86 @42.90ft (above Mean Sea Level) Date From - To Hrs I Task I Code ' NPT NPT Depth Phase I Description of Operations (hr) I 1 I (ft) I 1 0:00 - 12:30 2.50 I CLEAN I P I I DECOMP -PUMP OUT OF HOLE TO GET ABOVE PERFS. I I I STAND BACK 3 STANDS. -CBU @4 BPM / 550 PSI. I I -MONITOR WELL, SMALL FLOW TO TRIP I : „ 1 I I TANK. -RECORD RETURNS EVERY 5 MINUTES. 1 I 5 MIN - 0.2 BBLS I , „ , 110 MIN -0.2 BBLS ! : 15 MIN - 0.1 BBLS , „ [ 20 MIN -0.0 BBLS , I I I ! 25 MIN - 0.0 BBLS „ ; 30 MIN- WELL IS ON A SMALL VAC. , + 12:30 - 18:30 6.00 CLEAN P I I DECOMP R/U AND POH F/ 11000 TO BHA @ 343' MD. 1 I I -STOP AND MONITOR WELL @ 7763' MD. I, -LOSSES @ 4 BPM. ' I 18:30 - 20:30 I 2.00 CLEAN P I . DECOMP I MONITOR WELL @ BHA - 4 BPH LOSSES. -UD BHA 2.5 GAL OF DEBRIS IN BOOT BASKETS. , I ! . I ! : I-- -MILLS IN GAUGE. CLEAN MAGNETS 20:30 - 21:00 : 0.50 CLEAN , P , I DECOMP [ I CLEAR & CLEAN RIG FLOOR. 21:00 - 22:00 1.00 CLEAN P . , DECOMP PJSM. A-CREW PERFORM HAZARD HUNT & ,• ' : AAR. -MENTOR 2 NEWER CREW MEMBERS WHO HAD NEVER BEEN ON HAZARD HUNTS. -48 ITEMS LISTED AND DISCUSSED. 22:00 - 00:00 I 2.00 CLEAN P I DECOMP „ PJSM. P/U & M/U HES RTTS. 1 1 I -RIH 1 MINUTE PER STD. RIH TO 2350' MD. --1--- + _ 3/2/2011 00:00 - 04:00 I 4.00 , CLEAN : P I I DECOMP RIH W/ RTTS ON 4” DP F/ 2350' TO 11000' Md 1 1 , L = 210K, SOW = 106K. 04:00 - 08:30 4.50 CLEAN , P I DECOMP I ATTEMPT TO SET RTTS. I , „ -MAKE ADDITIONAL RH TURNS. CIRCULATE 1 1 , . , -STAND BACK STDS & ATTEMPT TO SET. CIRCULATE. , I -WORK RTTS. RIH W/ STDS. 08:30 - 10:30 2.00 I CLEAN P 1 I DECOMP I CIRCULATE: -S/S WITH 20 BBL HI-VIS SWEEP. -CHASE WITH 20 BBL BRINE, FOLLOWED BY 20 BBL HI VIS SWEEP. -RECOVERED -20 GAL. FRAC SAND. -4 BPM / 390 PSI. , 10:30 - 11:30 , 1.00 EVAL , P DECOMP ' SET PACKER AT 11.000' MD , -PUW = 210K, SOW = 106K -TEST 7" CSG FROM SURFACE TO 11,000' MD -TO 3,800 PSI FOR 30 CHARTED MINUTES. GOOD TEST. -RELEASE RTTS. 11:30 - 12:00 0.50 , CLEAN : P DECOMP R/D & BLOW DOWN LINES & TD. -OBSERVE WELL - 5 BPH LOSS RATE. 12:00 - 13:00 1.00 CLEAN P DECOMP PJSM. PERFORM TD & SKATE INSPECTION. , SERVICE RIG. 13:00 - 23:00 10.00 : CLEAN P : DECOMP : POH. UD DP 1 X 1. UD RTTS. -RTTS CLEAN & IN GOOD SHAPE. 23:00 - 00:00 1.00 : CLEAN ' P ' DECOMP : MONITOR WELL, LOSSES @5 BPH. -PULL WEAR RING. -PLACE PKR & PUPS IN PIPE SHED. -C/O ELEVATORS. -P/U TBG TONGS & SLIPS. : 3/3/2011 00:00 - 01:30 1.50 ' RUNCOM P RUNCMP R/U TO RUN 4-1/2" L-80, 12.6#, IBT-M TBG. , -CLEAN & CLEAR RIG FLOOR. Printed 7/5/2011 9:18:14AM orth America - ALASKA - BP Page 11 of 12 Operation Summary Report ...... LL Well Name: MPF -86 AF—ENO — Event Type: WORKOVER (WO) Start Date: 2/16/2011 End Date: 3/5/2011 X4- 00RVK -E (1,540,000.00 ) ! I_ Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292301800 Active Datum: MPF -86 @42.90ft (above Mean Sea Level) Date 1 From - To Hrs Task Code NPT ' NPT Depth Phase Description of Operations (hr) (ft) - 01:30 - 15:00 13.50 RUNCOM P RUNCMP RUN 4 -1/2" COMPLETION: OPT TQ 3200 ' FT /LBS. ' - UTILIZE BEST -O -LIFE 2000 THREAD I I COMPOUND. I -WLEG,1- JT TBG, KBG-2 MGLM W/ MEMORY I GAUGE, ! -XN NIPPLE W/ RHC -M & PREMIER PKR. 4 -1/2" ` TBG. 19:30 4.50 RUNCOM _ _ _RIH TO 9380' MD. 15:00 1 N HMAN 9,380.00 RUNCMP ; DISCUSSION W/ TOWN ON CHANGING COMPLETION DESIGN. -STAB FLOOR VALVE. . -PJSM FOR UD OF TUBING. 1 UD TUBING FROM 9380' TO 8500' MD. 19:30 - 20:00 0.50 RUNCOM P 1 RUNCMP HELD KICK WHILE TRIPPING DRILL AND AAR I" _ —I' RUNCOM N HMAN WITH CREW. 20:00 - 00:00 4.00 9,380.00 RUNCMP ;CONTINUE TO UD 4 -1/2" TUBING FROM 8500' ' TO 2980' MD. 3/4/2011 00:00 - 03:30 3.50 RUNCOM N , HMAN RUNCMP CONTINUE TO UD 4 -1/2" TUBING FROM 2980' TO COMPLETION ASSEMBLY. -UD COMPLETION ASSEMBLY. - PACKER STILL IN NEW CONDITION. 03:30 - 05:30 2.00 , RUNCOM i P ' 1 RUNCMP . PJSM. _ ' -SLIP & CUT 480' of 1 -1/4" DRLG LINE. 05:30 - 23:00 17.50 RUNCOM N MAN' ! RUNCMP I RUN 4-1/2" COMPLETION: OPT TQ 3200 FT /LBS. -UTILIZE BEST -O -LIFE 2000 THREAD COMPOUND. -WLEG, XN NIPPLE W/ RHC -M, 7" X 4 -1/2" PREMIER PKR, I -1 JT OF 4-1/2" TBG, ' -X NIPPLE, KBG-2 GLM W/ DUMMY VALVE, I - 4-1/2" TBG TO SURFACE. -SET WLEG @ 10989.61' MD. -PUW= 165K. SOW= 92K 23:00 - 00:00 ' 1.00 RUNCOM P 1 RUNCMP I M/U XO F/ FLOOR VALVE. -P /U TBG HANGER. M/U LANDING JT. -RIH & LAND PER FMC. -R/U CELLAR FOR CIRCULATING. 3/5/2011 00:00 - 01:00 1.00 RUNCOM P ' RUNCMP FINISH R/U IN CELLAR. -PT LINES TO 4000 PSI. 01:00 - 03:00 ' 2.00 RUNCOM P RUNCMP ' PUMP 200 BBLS OF 9.8 PPG NACL DOWN IA. -3 BPM / 200 PSI. -PUMP 4 BBLS DIESEL CAP. 03:00 - 04:30 1.50 RUNCOM P RUNCMP BULLHEAD 165 BBLS OF 9.8 PPG NACL DOWN TBG. -3 BPM/ 1400 PSI. 04:30 - 06:30 2.00 RUNCOM P RUNCMP MONITOR WELL FOR BREATHING. -BLEED OFF 5 BBLS EVERY 5 MINUTES. -MONITOR BUILD UP. BLEED OFF 23.6 BBLS TOTAL. 06:30 - 08 :00 1.50 RUNCOM P RUNCMP BULLHEAD 5 BBLS DIESEL CAP DOWN TBG. I -SHUT IN. LET STABILIZE. BLEED BACK 2 BBLS. Printed 7/5/2011 9:18:14AM 1 r ' ortil America ' ALASKA - BP page 12 of 12: . , Operation Summary Report , Common Well Name: MPF-86 AFE No Event Type: WORKOVER (WO) ,' Start Date: 2/16/2011 1 End Date: 3/5/2011 !X4-00RVK-E (1,540,000.00 ) 1 1 1 : Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 1 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292301800 Active Datum: MPF-86 @42.90ft (above Mean Sea Level) Date 1 ! From - To 1 Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 1 . (ft) 08:00 - 09:00 1.00 1 ' RUNCOM P RUNCMP P/U & STAB LANDING JT. DROP BALL & ROD. 1 . ,-UD LANDING JT. CLOSE BLIND RAMS. , I -LRS PRESSURE UP ON TBG T/ 4000 Psi. -SET PKR. BLEED OFF TO 3500 PSI. 1 I -TEST TBG @ 3500 PSI F/ 30 CHARTED , 1 1MINUTES. 1 . I 1 -BLEED DOWN TBG TO 1500 PSI & SHUT IN. , 1 1 1 09:00 - 10:00 1.00 RUNCOM P r- , , RUNCMP PRESSURE UP IA TO 3750 PSI. 1 . 1 ' -CHART F/ 30 MINUTES. -BLEED IA & TBG TO ZERO. 10:00 - 10:30 0.50 RUNCOM P ' T RUNCMP 'FSET TWC. !-TEST F/ ABOVE TO 3500 PSI F/ 10 CHARTED 1 1 : MINUTES. 1 1 -BLEED TO ZERO. 10:30 - 12:00 1.50 RUNCOM P 1 . ' RUNCMP I SHUTDOWN. , [ -CREW ON TOUR TO ATTEND ATP @ MPU BASE CAMP. 12:00 - 14:30 2.50 RUNCOM P r RUNCMP BLOW DOWN ALL SURFACE LINES. DRAIN , I STACK. • -PULL MOUSE HOLE, RISER & TURN BUCKLES. -PREP CELLAR. N/1111OPE_ . : . . -R/D FLOOR FOR DERRICK DOWN MOVE. 14:30 - 21:30 7.00 RUNCOM P RUNCMP N/U ADAPTOR FLANGE. I . -TEST TO 5000 PSI F/ 30 CHARTED MINUTES. . , -N/U TREE & TEST TO 5000 PSI F/ 5 CHARTED MINUTES. I , -RID TEST EQUIPMENT. .-,- 21:30 - 23:00 1.50 , RUNCOM • P . RUNCMP BRIDAL UP AND SECURE DERRICK TO LOWER. , 1 -R/D RIG FLOOR. I . 23:00 - 00:00 1.00 RUNCOM P ' RUNCMP I FOLD TUGGER FORWARD. LOWER CATTLE CHUTE / 1 : -REMOVE DERRICK TORQUE TUBE PINS. , . -PJSM TO LOWER DERRICK. 1 , 1 . . , . --RELEASE RIG @ 24:00 3/5/2011 FROM . , MPF-86 TO MPG-22 SEE 3/6/2011 MPC-22 FOR FURTHER k ' rtra-c- 4 1 v; 1 Printed 7/5/2011 9:18:13AM • • Wirth America � ALASKA - BP Operation Summary Report Common Well Name: MPF -86 FA No Event Type: WORKOVER (WO) Start Date: 6/13/2011 1 End Date: 6/21/2011 T1- 00019- E:F86ETTC (1,910,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 I Spud Date/Time: Rig Release: 6/21/2011 Rig Contractor: DOYON DRILLING INC. iUWI: 500292301800 Active Datum: MPF -86 @42.90ft (above Mean Sea Level) Date 1 From - To Hrs Task Code NPT I NPT Depth Phase Description of Operations ( i (ft) -- 6/13/2011 00:00 - 08:30 8.50 MOB P PRE FINISH ND OF BOP STACK AND NU OF 4 -1/2" DRY HOLE TREE & ADAPTER , TESTING TREE AND ADAPTER FLANGE FOR !F -80 - RIG DOWN & PREP FOR WELL TO WELL _ _RIG MOVE FROM MPF -80 TO MPF -86 08:30 - 13:00 4.50 MOB P PRE ' PJSM/ PULL RIG OFF OF MPF -80 -NOTIFY PAD OPERATOR -WSL, TP, AND PAD OPERATOR OBSERVED MOVING OFF OF WELL I I - MOVE RIG OUT TO THE CENTER OF THE PAD TO TEST THE ESD SYSTEM �' -_MOVING MATS OVER FROM F -80 TO F -86 13:00 - 16:00 3.00 MOB , P PRE PJSM: SPOTTING RIG AND RIG UP - SPOT RIG ON DOUBLE MATS OVER THE WELL, BP WSL , DOYON TP AND PAD I OPERATOR TO WITNESS RIG UP SURFACE LINES RIG WELDER IS WELDING THE NEW TROUGH IN THE PIT ROOM. - SPOT SLOP TANK AND TIGER TANK. RIG EVAC DRILL: H2S HELD AAR: DRILL WENT WELL, ALL PERSONAL ACCOUNTED FOR IN A TIMELY FASHION , ALL THIRD PARTY WERE AWARE OF THE DRILL AND MUSTERED PROPERLY I I 15:00 HRS - LEFT MESSAGE WITH AOGCC OF i UPCOMING BOPE ES P TEST - 24 HR NOTICE - NO I REPLY - ACCEPT RIG AT 1600 HRS. 16:00 18:00 2.00 KILLW P j DECOMP TAKING ON 9.8 PPG NACL BRINE FOR CIRC OUT. I - RU HARD LINES TO THE TIGER TANK, FINISH RIG UP FOR CIRC OUT OF WELL - OLD GREEN TIGER TANK WAS BROUGHT BACK OUT TO LOCATION WITH PAPER WORK FROM THE INSPECTOR, FOR IT'S RETURN TO SERVICE. - TIGER TANK BAFFLE WOULD NOT FIT IN ' THE TANK, CALLED THE CH2 FOREMAN TO HAVE THE OLD RED ONE BROUGHT BACK OUT. 18:00 - 22:30 4.50 KILLW P DECOMP PRESSURE TEST SURFACE LINES WHILE WAITING ON TIGER TANK FROM I DEADHORSE. - PRESSURE TEST LINES TO 250 LOW AND 3500 PSI. GOOD TEST. -WORK ON WELDING PROJECTS AROUND THE RIG. -SPOT TIGER TANK. -R/U LINES AND TEST TO 250 LOW AND 3500 PSI - GOOD TEST 22:30 23:00 0.50 KILLW P DECOMP BLOW DOWN HARDLINE TO TIGER TANK. 23:00 - 23:30 0.50 KILLW P DECOMP PJSM WITH WELL SUPPORT. -P /U LUBRICATOR AND TIE INTO TREE. Printed 7/5/2011 9:18:59AM , Oth America - ALASKA BP Page 2 of 12 . Operation Summary Report Common Well Name: MPF -86 �� I AFE No Event Type: WORKOVER (WO) I, Start Date: 6/13/2011 I End Date: 6/21/2011 T1- 00019- E:F86ETTC (1,910,000.00 ) Project: Milne Point I Site: M Pt F Pad Rig Name /No.: DOYON 16 I Spud Date/Time: j Rig Release: 6/21/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292301800 Active Datum: MPF -86 ©42.90ft (above Mean Sea Level) Date From - To Hrs 1 Task Code I NPT . NPT Depth I Phase Description of Operations (hr) __I!, (ft) 23:30 - 00:00 0.50 KILLW 0. P DECOMP PRESSURE TEST LUBRICATOR TO 250 PSI 1 LOW AND 3500 PSI HIGH. -GOOD TEST 6/14/2011 I 00:00 - 01:30 1.50 KILLW 1 P DECOMP ' PULL BPV WITH DSM LUBRICATOR. I ' -560 PSI NOTED TO BE ON TUBING AFTER I BPV WAS PULLED. 1 -0 PSI ON IA. I I I -170 BBLS OF DIESEL IN THE IA AND ALL 9.8 I I I PPG BRINE IN THE IA CAUSING OUT OF BALLANCE. , -L/D LUBRICATOR AND BPV. 01:30 - 02:30 1.00 KILLW P I DECOMP 1 PJSM FOR CIRCULATING WELL. I -R/U CIRCULATION LINE AND PRESSURE ! I 1 TEST BREAK TO 3500 PSI. GOOD TEST. I I -OPEN WELL 02:30 - 03:00 I 0.50 I KILLW , P ` DECOMP BLEED TUBING WHICH DROPPED RAPIDLY AND DIESEL WAS SEEN IMMEDIATLY -IA HAD A VACUUM. - TUBING FULL OF DIESEL AND BRINE ON THE I IA_ WELL OUT OF BALANCE. 03:00 P 03:30 0.50 KILLW ! DECOMP REVERSE CIRCULATE WELL TO GET ALL OF , I I DIESEL OUT OF TUBING. ' i -PUMP AT 4 BPM TAKING 33 BBLS TO CATCH FLUID. ICP OF 890 PSI AND FCP OF 1440 PSI. -170 BBLS OF DIESEL THEN CLEAN BRINE. 03:30 05:00 1.50 KILL P SHUT DOWN PUMPS. W -{— — - DECOMP LINE UP TO CIRCULATE DOWN TUBING TAKING RETURNS FROM ANNULUS. ! ' - CIRCULATE 370 BBLS SURFACE TO SURFACE. -PUMP AT 5 BPM AND 700 PSI. } PUMP TOTAL OF -540 BBLS, RECOVERING _ _ AND SENDING OUT 534 BBLS 05:00 - 05:30 0.50 KILLW 1 P DECOMP MONITOR WELL FOR 30 MIN _ I - WELL IS STATIC 05:30 - 06:00 0.50 DHB P DECOMP HOLD RIG EVAC DRILL WITH AAR ' 1 FINDINGS IN AAR: -ALL PERSONEL ON SITE ACCOUNTED FOR -SWEEP OF THE RIG BY DRILLER AND LEAD FLOORHAND WAS EFFECTIVE BECAUSE A WELDER WHO NORMALLY DOESN'T WORK ON THIS RIG DIDN'T HEAR THE EVACUATION ANNOUNCEMENT - LOADER OPERATOR NEEDS TO STAY AT THE ENTRANCE OF THE PAD BLOCKING ACCESS, HE CAN RADIO TO WSUTP THE NAMES ON THE SIGN IN SHEET -ALL TRUCKS SHOULD BE SHUT -OFF 06:00 - 07:00 ' 1.00 DHB P DECOMP PU & MU WELL SUPPORT LUBRICATOR ' - PRESSURE TEST LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MIN EACH. Printed 7/5/2011 9:18:59AM • Oth America - ALASKA - BP Page 3 of 12 Operation Summary Report _— �_- Common Well Name: MPF -86 AFE No Event Type: WORKOVER (WO) Start Date: 6/13/2011 End Date: 6/21/2011 T1- 00019- E:F86ETTC (1,910,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1Rig Release: 6/21/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292301800 Active Datum: MPF -86 @42.90ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations I hr) (ft) 07:00 10:00 3.00 DHB P DECOMP I SET 4" H STYLE TWC 1 1 - TEST TWC TEST FROM ABOVE TO 250 LOW AND 3500 HIGH FOR 10 CHARTED MIN,BOTH TESTS GOOD -20 PSI LOSS IN 10 MIN I TESTED FROM BELOW TO 1000 PSI FOR 10 I CHARTED IN. -TEST FROM BELOW, PRESSURE BLED OFF 200 PSI IN 10 MIN, VERIFIED THAT THE 'PRESSURE WAS LEAKING PAST THE TWC BY HAVING A WHITY VALVE OPEN ON THE I LUBRICATOR. I. ! - WELLBORE CONTAINS FULL COLUMN OF L !� 9.8 PPG NACL -- - -- -- - - -- —' --- - - - - -- -- - - -- - 10:00 DHB 10:30 0.50 P DECOMP BD & LAYDOWN LUBRICATOR I - BD PRESSURE TEST LINES ! i- CLEAN AND CLEAR RIG FLOOR. 10:30 - 12:00 1.50 WHSUR P DECOMP ND 4- 1/16" 5M CIW TREE & ADAPTER (- SET BACK TREE IN CELLAR I- DUMMY RUN WITH TUBING HANGER ' THREAD X -OVER, TOOK 7 TURNS TO MAKE UP. .JIM REGG WITH AOGCC WAIVED THE RIGHT 'TO WITNESS OUR BOPE PRESSURE TEST @ I 15:30 12:00 - 15:30 3.50 BOPSUR P DECOMP NU 13 -5/8" BOPE - STACK CONFIG TOP TO BOTTOM 1 - 13-5/8" "GK" ANNULAR , 3-1/2" X 6" VBR'S , r BS RAMS , MUD CROSS , 2 -7/8" X 5" VBR'S 15:30 - 23:30 8.00 BOPSUR P DECOMP TESTING 13 -5/8" BOPE / TEST BOPE PER WELL PLAN, PERMIT TO "'' DRILL, AND AOGCC REGS. i' ! T EST WITNESS WAIVED BY JIM REGG OF I ' 1 AOGCC -RAMS TESTED TO 250 PSI LOW AND 3,500 / I`'t l l PSI HIGH. L� / -HYDRILL TESTED TO 250 PSI LOW AND 3,500 ----- PSI HIGH , -TEST USING 4.5" AND 4" TEST JOINTS. - PRESSURE TEST FOR 5 CHARTED MIN. -ALL TEST WITNESSED BY BP WSL / DDI TP. -ALL TEST FOLLOW TESTING CRITERIA DOCUMENTED IN CRT - AK -10 -45 23:30 - 00:00 0.50 BOPSUR P DECOMP KOOMEY DRAW DOWN TEST: -2850 PSI DRAWN DOWN TO 1750 PSI. -200 PSI INCREASE IN 21 SECONDS. -FULL PRESSURE IN 90 SECONDS. -5 N2 BOTTLES @ 1925 PSI. 6/15/2011 00:00 - 03:00 3.00 DHB P DECOMP RU DUTCH RISER SUCK OUT STACK AND CLEAN OFF TWC ' RU DSM LUBRICATOR TEST LUBRICATOR TO 250 PSI LOW AND I 3,500 PSI HIGH ATTEMPT TO PULL TWC AND UNABLE RD LUBRICATOR, AND SUCK OUT STACK AGAIN DOES NOT APPEAR TO BE ANYTHING ON I TOP OF PLUG, AND CAN SEE THE THREADS OK Printed 7/5/2011 9:18:59AM orth America ALASKA BP Page 4 of 12 Operation Summary Report . Common Well Name: MPF -86 ; AFE No Event Type: WORKOVER (WO) Start Date: 6/13/2011 End Date: 6/21/2011 T1- 00019- E:F86ETTC (1,910,000.00 ) Project: Milne Point ~Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 6/21/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292301800 Active Datum: MPF -86 ©42.90ft (above Mean Sea Level) Date From - To Hrs Task Code 1 NPT , NPT Depth , Phase Description of Operations 03:00 - 04:00 j 1.00 1 DHB P ' DECOMP hr RU LUBRICATOR AND TEST TO 250 PSI LOW ! I AND 3,500 PSI HIGH I 1 : I ATTEMPT TO PULL TWC PULL TWC WITH VERY SMALL VAC RD DSM LUBRICATOR AND DUTCH RISER P 04:00 - 05:00 1.00 PULL DECOMP PU / MU JNT OF DRILL PIPE TO CROSS OVERS TO PULL TUBING HANGER FMC REP TO BACK OUT LDS SUCK OUT STACK 05:00 - 05:30 0.50 PULL P DECOMP I MU DP JOINT W/ X -OVERS TO TUBING HANGER AND SCREW IN WITH TOP DRIVE -PULL TUBING HANGER TO RIG FLOOR -BROKE OVER AT 155 K WITH 145 TO 150 K I PULLING WEIGHT I ' -CLOSE ANNULAR PREVENTER ON 4 -1/2" TUBING (KICK DRILL AAR) — — I_ -.- 05:30 - 06:30 PULL P ,I DECOMP CIRCULATE RCULATE BOTTOMS UP VOLUME THROUGH CHOKE AND GAS BUSTER WITH ANNULAR PREVENTER CLOSED ' CIRCULATE203 BBLS / 2400 STKS 5 BPM @ 355 PSI 06:30 - 07:30 1.00 PULL 1 P DECOMP MONITOR WELL BLOW DOWN CIRCULATING LINES AND GAS . BUSTER : --- PULL P 07:30 - 20:30 13.00 PULL ! DECOMP PULL 4-1/2" FRAC STRING ' LLD 273 JOINTS OF TUBING, 1 GLM, 1 XN NIPPLE, AND 1 CUT JOINT -CUT JOINT WAS 19.90 FT LONG -CUT LOOKED GOOD AND CLEAN / TYPICAL i JET CUT _.- — -MAX OD ON FLARE OF CUT WAS 4 -7/8" 20:30 - 22:00 1.50 PULL P DECOMP RD FROM PULLING 4 -1/2" TUBING , RU TO RUN 4" DRILL PIPE INSTALL WEAR RING 22:00 - 00:00 2.00 PULL P ' DECOMP RIH WITH 4 ", 14# XT 39 DP ' -PU 59 JOINTS BY CREW CHANGE 6/16/2011 00:00 - 03:30 3.50 WHSUR P DECOMP PJSM FOR RUNNING 4" XT -39 DP ' - CONTINUE TO SINGLE IN FROM PIPE SHED FROM JOINT 59 TO 130 -SMALL LEAK IN PIT #3 WAS DISCOVERED @ 00:45 AND REPORTED TO RWO SUPT & MP 03:30 - 04:00 ' 0.50 WHSUR P DECOMP MAN DOWN DRILL -MOTOR MAN CALLED A MAN DOWN DRILL IN ' THE CELLAR -GOOD RESPONSE BY CREW -HELD AAR AND DISCUSSED CLEAR ASSIGNMENTS OF WHO SHOULD GET WHAT EQUIPMENT FROM WHERE -ALSO READ THE MAN DOWN PROCEDURE ' OF DOYONS AND DISCUSSED 04:00 - 08:00 4.00 WHSUR ' P ' DECOMP PJSM FOR RUNNING 4" XT -39 DP '- CONTINUE TO SINGLE IN FROM PIPE SHED TO 6,791' -PUW 105K , SOW 92K 08:00 - 08:30 0.50 WHSUR P DECOMP PU / MU HES 7" RTTS , - RIH WITH RTTS TO - 99' BELOW THE kG , i-LOOK 08:30 - 10:00 1.50 WHSUR P ' DECOMP SET AND TEST RTTS - TEST RTTS TO 1000 PSI FOR 10 CHARTED MIN, TEST GOOD Printed 7/5/2011 9:18:59AM ,. -. arch Ame ,. . , rica - ALASKA - BP Page 5 of 12 Operation- Summary Re Common Well Name: MPF -86 ' AFE No Event Type: WORKOVER (WO) Start Date: 6/13/2011 End Date: 6/21/2011 T1- 00019- E:F86ETTC (1,910,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 6/21/2011 Rig Contractor DOYON DRILLING INC. UWI: 500292301800 Active Datum: MPF -86 @42.90ft (above Mean Sea Level) Date From - To Hrs Task ' Code ' NPT NPT Depth Phase Description of Operations (hr) - (ft) _ ... 10:00 - 13:00 3.00 WHSUR I P DECOMP PJSM FOR WELL HEAD WORK j- PULL WEAR RING - PU/ MU PACK OFF PULLING TOOL ON A 1 JOINT OF DP. - J INTO PACK OFF , MU TO TOP DRIVE - FMC REP TO BOLDS AND PULL PACK OFF I THROUGH THE BOP STACK TO THE RIG FLOOR ' - CHANGE OUT PACK OFF AND RUN BACK IN , RILDS 13:00 - 14:00 1.00 WHSUR P , DECOMP ; OUT AND LD PACK OFF PULLING `TOOL. I - FMC REP TO TEST PACK OFF TO 5000 PSI i FOR 30 MIN CHARTED — I ' — �I 14:00 16:30 2.50 WHSUR '� P DECOMP !ND D BOP AND INSTALL 14" TC -60 TUBING , 1SPOOLSPACER OFF LOAD PITS IN ORDER TO RAISE THE RIG FOR ADDITIONAL CLEARANCE TO NU THE BOP'S 16:30 - 17:00 0.50 ' WHSUR P DECOMP ; DISCONNECT HARD LINE, AND PULL AWAY . CUTTINGS BOX I -PREP TO LIFT RIG - WELLSUPPORT TRUCK TO MOVE SLOP I !TANK. 17:00 - 19:30 2.50 1 WHSUR P DECOMP SET MATS UNDER FRONT TIRES AND RAISE RIG TO SET DOWN ON ADDITIONAL RIG MATS (NOW 4 HIGH) –24" ' RE -SHIM AND SET DOWN RIG 1 I SPOT IN CUTTINGS BOX AND RU FLOW BACK TANK 19:30 - 21:30 2.00 WHSUR j P , DECOMP NU BOPS AND FILL PITS WITH 9.8 PPG BRINE ' - SET TEST PLUG IN THE TC -60 TUBING ! 1SPOOL SPACER PROFILE 121:30 - 23:30 2.00 WHSUR P r DECOMP RU TEST EQUIPMENT ' - TEST BOP FLANGE TO 250 LOW AND 3,500 PSI HIGH FOR 5 MIN CHARTED, TEST GOOD ' - TESTING AGAINST THE TEST PLUG SET IN THE TC -60 PROFILE - PULL TEST PLUG 23:30 - 00:00 0.50 WHSUR P DECOMP PU RTTS RUNNING TOOL - RIH WITH RUNNING TOOL ON ONE STAND OF 4" DP. 6/17/2011 00:00 - 01:00 1.00 WHSUR P ' DECOMP PU RTTS RUNNING TOOL ' - RIH WITH RUNNING TOOL ON ONE STAND I OF 4" DP. - CREW CHANGE AND PJSM 01:00 - 03:30 2.50 WHSUR P DECOMP MU RTTS RUNNING TOOL TO RTTS AND RELEASE PER HES REP DIRECTION ' - POOH & LD RTTS - POOH W/ DP STANDING BACK 27 STANDS IN DERRICK - PU & MU RTTS RIH ONE STAND AND SET I –98' BELOW RIG FLOOR. 03:30 - 04:00 0.50 WHSUR P DECOMP CLOSE THE UPPER VBR RAMS TO TEST THE ' TC -60 FLANGE PRESSURE TESTING AGAINST THE RTTS AND THE VBR'S - PRESSURE TEST TC -60 TUBING SPOOL FLANGE TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MIN, GOOD TEST. Printed 7/5/2011 9:18:59AM t)Lt Anieric4 - ALASKA.. BP Page 7 of 12 • Operatio Summary Report Common Well Name: MPF -86 AFE No Event Type: WORKOVER (WO) , Start Date: 6/13/2011 End Date: 6/21/2011 `T1- 00019- E:F86ETTC (1,910,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 I Spud Date/Time: Rig Release: 6/21/2011 Rig Contractor: DOYON DRILLING INC. ! UWI: 500292301800 Active Datum: MPF -86 @42.90ft (above Mean Sea Level) Date From - To Hrs Task Code ' NPT NPT Depth Phase Description of Operations (hr) (ft) ' I 6/18/2011 1 00:00 - 01:00 1.00 FISH P DECOMP I POH WITH E LINE CONVEYED TUBING I I PUNCH BHA ! - LOSSES INCREASING TO + 40 BPH TO KEEP I ! I HOLE FULL I I - CHANGE TO CONTINUOUS HOLE FEED AT 01:00 03:00 2.00 P DECOMP 1 20 BPH FISH PJSM / TAG UP WITH E LINE TOOLS -CLOSE BLINDS AND REESTABLISH HOLE I FEED AT 20 BPH ' -RD E LINE TOOLS AND OFF LOAD FROM RIG -MOVE OUT SLB E LINE EQUIPMENT 03:00 - 04:30 1.50 FISH P DECOMP ! MOVE VAC TRUCK TO DRILLERS SIDE OF RIG :NOW -LOAD FISHING TOOLS INTO PIPE SHED AND I ORGANIZE -PREP RIG FLOOR TO MU BHA AND TRIP PIP E 04:30 - 05:30 1.00 FISH P DECOMP MU FISHING BHA WITH - 4 -1/2" DRESS OFF SHOE I I BUSHING I - OVERSHOT W/ 4-1/2" GRAPPLE I I - BUMPER SUB -JAR - 3 -1/2" PUMP OUT SUB ' -9 4-3/4" DC'S 05:30 - 06:00 ' 0.50 FISH P DECOMP KICK WHILE TRIPPING DRILL WITH NON - SHEARABLE EQUIPMENT ACCOST THE ,STACK I ! - GOOD RESPONSE TIME BY CREW -AAR TO DISCUS LL AND REVIEW DOYON , _ PROCEDURE 06:00 - 15:00 9.00 1 FISH P ' I DECOMP I TRIP IN HOLE TO - 6,000' WITH THE FISHING ! I BHA ON 4" XT -39 DP FROM THE DERRICK. , ' - TIH FROM -6,000 PICKING UP SINGLES I I FROM THE PIPE SHED - TIH TO 10,887' , TAG TOP OF 4 -1/2" TUBING STUB PU TO OBTAIN PARAMETERS. - PUW 200 K , SOW -115K , ROT WT 150K - SET DOWN WITH 3K DOWN TO DRESS OFF STUB @ 10,887' - PUMPING AT 3 BPM WITH 550 PSI - DERRICK MAN SENT UP THE DERRICK FOR A PRE JARRING DERRICK INSPECTION. 15:00 - 17:00 2.00 FISH P DECOMP S1 inF OVFR THE TOP OF THE STUB & LATCH - CONFIRM LATCH WITH 215 K UP - START JARRING OPERATIONS AS DIRECTED BY THE BACKER TOOL REP. - ATTEMPTED A STRAIGHT PULL OF 320 K , PKR DID NOT RELEASE - STARTED JARRING WITH 275 K WORKING UP TO 300 K. - JARRED UNSUCCESSFULLY 20 TIMES, - SHUT DOWN FOR ANOTHER DERRICK INSPECTION. - CONT JARRING OPERATIONS, PACKER , FINALLY CAME FREE. - CONFIRMED PACKER IS FREE BY GOING BACK DOWN PAST THE 10,887' MARK. Printed 7/5/2011 9:18:59AM Oh- America - ALASKA - BP Page 8 of 12 Operation Summery Report ._■■ __ Common Well Name: MPF -86 AFE No . __�- Event Type: WORKOVER (WO) ' Start Date: 6/13/2011 End Date: 6/21/2011 T1- 00019- E:F86ETTC (1,910,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 1 Spud Date/Time: j Rig Release: 6/21/2011 Rig Contractor: DOYON DRILLING INC. 1 UWI: 500292301800 Active Datum: MPF -86 @42.90ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:00 - 18:00 1.00 FISH P DECOMP SHUT IN THE ANNULAR PREVENTER AND BULL HEAD DOWN THE IA - BULL HEAD 25 BBS AT 4 BPM WITH 1950 PSI, MONITOR WELL I 1-WELL RETURNED TO LOSSES / ESTABLISH 30 BPH STATIC LOSS RATE 1 - ESTABLISH 20 BPH HOLE FEED WITH 9.8 _ PPG BRINE 18:00 - 00:00 , 6.00 FISH 1 P � DECOMP LD DRILL PIPE TO PIPE SHED FROM 10,0887 FT to 6618 FT AT END OF TOWER DAILY LOSSES TO THE WELL = 537 BBLS OF 9.8 BRINE 6/19/2011 00:00 - 07:30 1 , 7.50 FISH P i ' DECOMP CONTINUE TO LAY DOWN DRILL PIPE FROM 6618 FT -MAINTAIN CONTINUOUS HOLE FEED AT 20 ;BPH WITH 9.8 PPG NACL BRINE 1 - LAYING DOWN JOINT #315 OF 330 TOTAL !TILL BHA - STOPPED THE TRIP PRIOR TO PULLING BHA INTO THE STANCK, MONITORED THE WELL FOR FLOW FOR 10 MIIN. NO FLOW , DETECTED. - DISCUSSED THE PLAN FOR A WELL ' CONTROL EVENT WITH NON SHEARABLES ACROSS THE BOP. 07:30 - 08:00 0.50 _. FISH P ; DECOMP MONITOR WELL. FISH P -M/U FOSV TO JNT. OF DP. 08:00 09:30 1.50 I DECOMP UD 4 3/4" DC'S IN PIPE SHED 1 -KICK DRILL & AAR WITH WSL. 109:30 - 10:30 1.00 FISH P I DECOMP THA _ -B /O & UD DRESS OFF /GRAPPLE BHA - 10:30 11:30 - -- - -- - - - -- -- — - — —_ 1.00 i FISH P DECOMP THA -UD FISH, 4 1/2" TUBING, PACKER, XN NIPPLE. TUBING WAS PERFORATED 11:30 - 12:30 1.00 FISH P 1 DECOMP PULL WEAR RING 1 -B /D SAFETY JNT. -CLEAN RIG FLOOR. 12:30 - 16:00 3.50 RUNCOM P RUNCMP R/U RIG FLOOR -LOAD PIPE SHED -DRIFT & STRAP 265 JNTS. OF 4.5" 521 HYDRIL TBG. -LOAD & STRAP PUMP /MOTOR ASSEMBLY. - PU BANDS CLAMPS AND OTHER TOOLS TO THE RIG FLOOR. ��R - FILLING THE HOLE AT 20 BPH 16:00 19:00 3.00 RUNCOM P RUNCMP PU & MU MOTOR ASSEBLY AS DIRECTED BY CFNTRII IFT RIH WITH MOTOR ASSEMBLY ON ONE JOINT OF 4 -1/2" TBG, SET IN SLIPS PU & MU TTC PUMP ASSEMBLY RUNNING BHA , TO TO BOTTOM 1 JNT OF 2 -7/8" HT PAC XO 3 -1/8" BUMPER SUB XO XO- TO 3/4" SUCKER ROD FOR MECHANICAL "GS" SPEAR - CONT LOADING AND STRAPPING 4.5" HYDRILL TBG Printed 7/5/2011 9:18:59AM Qrth America - ALASKA - BP Page 9 of 12 Operation Summary Report �_ Common Well Name: MPF -86 AFL No Event Type: WORKOVER (WO) Start Date: 6/13/2011 End Date: 6/21/2011 I'T1- 00019- E:F86ETTC (1,910,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: I Rig Release: 6/21/2011 Rig Contractor: DOYON DRILLING INC. I UWI: 500292301800 Active Datum: MPF -86 @42.90ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 19:00 - 22:00 ' I, 3.00 RUNCOM P (ft) RUNCMP I PU TWO PUMP ASSEMBLIES AND RUN INTO THE 4 -1/2" , HANGING THEM OFF AT THE STUB I - PU "GS" SPEAR ASSEMBLY AND MAKE UP I ITO THE PUMP ASSEMBLY, RIH I I - POOH , PU & RIH WITH THE TTC PACK OFF ' ASSEMBLY ON THE :GS" SPEAR I I- SET AND TEST THE PACK OFF ASSEBLY I - TESTED PACK OFF FOR 15 MIN TO 1000 PSI - I LOST 50 PSI - REMOVED PACK OFF TEST TOOL ! -SET TUBING STOP 22:00 00:00 2.00 RUNCOM ' P RUNCMP , SPOT IN SPOOLING UNIT AND RU CABLE I SHEAVE IN DERRICK. -PULL INJECTION LINE A ND ESP CABLE ' THROUGH SHEAVE _ 6/20/2011 00:00 - 00:45 0.75 RUNCOM I P RUNCMP ! CREW CHANGE AND RU FLOOR TO RUN 1 I COMPLETION I MAINTAINING CONTINUOUS HOLE FEED AT 20 BPH WITH 9.8 BRINE 00:45 - 02:30 '' 1.75 RUNCOM P RUNCMP I MU ESP PENATRATOR AND CLAMP TO ESP ASSEMBLY I - CONNECT THE 3/8" CAPALIARRY TUBE - HAD TO RE -RUN ESP CABLE THROUGH SHEAVE IN DERRICK TO GET TWIST OUT OF I CABLE STARTED TO GET VERY SMALL RETURNS. SHUT DOWN HOLE FEED TO MONITOR AND WELL WAS STILL ON VAC CONTINUE TO FEED HOLE AT SLIGHTLY I LESS THAN 20 BPH 02:30 - 03:00 1 0.50 RUNCOM P RUNCMP ',TEST ESP PENTRATOR AND CHEMICAL INJECTION LINE - CENTRILIFT CHECKING THE CONDUCTIVITY I FOR THE ESP , - PUMPING THRU THE INJECTION LINE TO CHECK THE CHECK VALVE, INJECTION LINE WAS FREE 03:00 - 06:00 3.00 RUNCOM P ' RUNCMP PU JOINT #2 OF 4 -1/2 ", 12.6 #, L -80, HYDRILL 521 I MAKE UP 4 -1/2 HYDRILL ESP COMPLETION WITH 3/8" CHEMICAL INJECTION LINE & FLAT ESP CABLE - TORQUE TO 4700 FT POUNDS WITH JET 1 LUBE SEAL GUARD PIPE DOPE INSTALL CANNON CLAMP ON EVERY JOINT MAINTAINING CONTINUOUS HOLE FEED AT ' 20 BPH GETTING PARTIAL RETURNS WHILE PIPE IS RUN IN HOLE. - 15 BPH LOSS RATE ON JOINT # 36 OF 259 JOINTS AT 06:00 Printed 7/5/2011 9:18:59AM Ai gorth America - ALASKA - BP Page 10 of 12 Operation Summary Report Common Well Name: MPF -86 AFE No Event Type: WORKOVER (WO) 1 Start Date: 6/13/2011 End Date: 6/21/2011 T1- 00019- E:F86ETTC (1,910,000.00 ) Project: Milne Point T Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 6/21/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292301800 Active Datum: MPF -86 ©42.90ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth 1 Phase I Description of Operations (hr) (ft) 06:00 08:00 2.00 RUNCOM P RUNCMP CONTINUE RIH WITH TTC-ESP ON 4 -1/2" 521 1 HYDRILL TUBING I 1 - RIH WITH A CLAMP ON EVERY COLLAR F/ JNT #36 TO JNT #50 I- CHECKING THE ESP CABLE CONDUCTIVITY I I EVERY 2,000' , PUMPING THROUGH THE 3/8" CAPILARY _ TUBE EVERY 2,000' 08:00 - 08:30 0.50 RUNCOM Ir P RUNCMP ESP CABLE CONDUCTIVITY TESTED GOOD ' - PUMP 5 BBLS AT 1 BPM WITH 980 FUNCTION TEST THE 3/8" CAP TUBE BY PUMPING — 2 GAL THRU THE CHECK VALVE, VERIFIED BY THE CENTRILIFT REP THAT THE ' I OIL RESIVOR WAS GOING DOWN. - MAINTIAN CONTINUOUS HOLE FILL @ — 15 IBPH 08:30 13:00 4.50 RUNCOM P RUNCMP . CONTINUE RIH WITH TTC-ESP ON 4 -1/2" 521 ' HYDRILL TUBING - RIH WITH A CLAMP ON EVERY COLLAR F /JNT # 50 TO JNT # 100 - CHECKING THE ESP CABLE CONDUCTIVITY EVERY 2,000' I - PUMPING THROUGH THE 3/8" CAPILARY `TUBE EVERY 2,000' -- MAINTIAN CONTINUOUS HOLE FILL @ — 15 BPH 13:00 - 13:30 0.50 RUNCOM T P ! I RUNCMP . ESP CABLE CONDUCTIVITY TESTED GOOD - PUMP 5 BBLS AT 1 BPM WITH 980 I - FUNCTION TEST THE 3/8" CAP TUBE BY PUMPING — 2 GAL THRU THE CHECK VALVE, I VERIFIED BY THE CENTRILIFT REP THAT THE OIL RESIVOR WAS GOING DOWN. 13:30 - 18:00 1 4.50 I RUNCOM P RUNCMP I CONTINUE RIH WITH TTC-ESP ON 4 -1/2" 521 . HYDRILL TUBING - RIH WITH A CLAMP ON EVERY COLLAR . I 'F /JNT# 100 TO JNT #151 - CHECKING THE ESP CABLE CONDUCTIVITY EVERY 2,000' - PUMPING THROUGH THE 3/8" CAPILARY TUBE EVERY 2,000' ' ' -- MAINTIAN CONTINUOUS HOLE FILL @ 15 BPH 18:00 18:30 0.50 RUNCOM P RUNCMP ESP CABLE CONDUCTIVITY TESTED GOOD - PUMP 5 BBLS AT 1 BPM WITH 980 - FUNCTION TEST THE 3/8" CAP TUBE BY PUMPING — 2 GAL THRU THE CHECK VALVE, VERIFIED BY THE CENTRILIFT REP THAT THE OIL RESIVOR WAS GOING DOWN. 18:30 - 20:30 2.00 RUNCOM P RUNCMP CONTINUE RIH WITH TTC-ESP ON 4-1/2" 521 ' HYDRILL TUBING - RIH WITH A CLAMP ON EVERY COLLAR F /JNT # 151 - MAINTIAN CONTINUOUS HOLE FILL @ — 15 BPH -RUN COMPLETION TO JOINT # 176 20:30 00:00 3.50 RUNCOM P RUNCMP PERFORM ESP REEL TO REEL SPLICE SPLICE Printed 7/5/2011 9:18:59AM orth Amenca - A LASKA BP Page t t of 12 Operati Su Report ' Common Well Name: MPF -86 — ! AFE No Event Type: WORKOVER (WO) Start Date: 6/13/2011 I End Date: 6/21/2011 T1- 00019- E:F86ETTC (1,910,000.00 ) -L 1 Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 i Spud Date/Time: 1Rig Release: 6/21/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292301800 Active Datum: MPF -86 @42.90ft (above Mean Sea Level) Date From - To Hrs Task Code ! NPT NPT Depth Phase Description of Operations (ft) 6/21/2011 00:00 00:45 0.75 RUNCOM P I RUNCMP CHANGE AND TEST ESP CABLE SPLICE CONDUCTIVITY TESTED GOOD - PUMP 5 BBLS AT 1 BPM WITH 980 . FUNCTION TEST THE 3/8" CAP TUBE BY !PUMPING - 2 GAL THRU THE CHECK VALVE, VERIFIED BY THE CENTRILIFT REP THAT THE I OIL RESIVOR WAS GOING DOWN. RUNCMP 00:45 02:30 1.75 RUNCOM P !CONTINUE RIH WITH TTC -ESP ON 4 -1 /2" 521 HYDRILL TUBING WITH JOINT #177 `- RIH WITH A CLAMP ON EVERY COLLAR F /JNT# 100 TO JNT #151 - MAINTIAN CONTINUOUS HOLE FILL @ - 15 !BPH RUNCOM -RUN TO JOINT #200 02:30 - 03:00 0.50 P RUNCMP ESP CABLE CONDUCTIVITY TESTED GOOD - PUMP 5 BBLS AT 1 BPM WITH 980 FUNCTION TEST THE 3/8" CAP TUBE BY PUMPING - 2 GAL THRU THE CHECK VALVE, VERIFIED BY THE CENTRILIFT REP THAT THE OIL RESIVOR WAS GOING DOWN. 03:00 - 08:30 5.50 RUNCOM RUNCMP CONTINUE RIH WITH TTC -ESP ON 4 -1/2" 521 . HYDRILL TUBING RIH WITH A CLAMP ON EVERY COLLAR - MAINTIAN CONTINUOUS HOLE FILL @ - 15 . BPH . RIH TO 10,790' WITH 259 JOINTS . CENTRILIFT MAKING CONDUCTIVITY TESTS, AND CAP TUBE FUNCTION TEST 08:30 - 09:00 0.50 RUNCOM P . RUNCMP PU MU LANDING JOINT WITH TIW MADE UP MAKE UP TO THE 11" X 4 -1/2" TUBING HANGER 09:00 14:00 5.00 RUNCOM i P RUNCMP CLEAN AND CLEAR RIG FLOOR SPACE OUT ESP CABLE FOR SPLICE TO TUBING HANGER - CENTRILIFT REPS MAKING LOWER PENETRATOR ESP CONNECTION SPLICE & 3/8" CAPILARY TUBE TERMINATION - INSTALL TWC -LAND TUBING HANGER IN WELL HEAD ' -PUW = 163,000 LBS -SOW = 105,000 LBS TOTAL CLAMP COUNT AS FOLLOWS: 259 TOTAL CANNON CLAMPS ' 2 SPLICE CLAMPS 3 PROTECTOLIZER CLAMPS 2ARMSTERGUARDS 14:00 - 17:00 3.00 WHSUR P WHDTRE RIJN IN LDS -TEST TWC FROM ABOVE TO 250/1000 PSI FOR 10 MIN -ROLLING TEST FROM BELOW AT 1 BPM FOR 500 PSI FOR 10 MIN -RD AND BD TEST LINES ! START FILLING THE IA AT 10 BPH 17:00 18:00 1.00 WHSUR P WHDTRE ND BOPS AND SECURE 18:00 - 20:00 2.00 WHSUR P WHDTRE NU TREE ADAPTOR FLAGE AND TEST -NEW ADAPTOR FLANGE - 11" x 4- 1/16" 5K, ' ROTATING FLANGE ' - 250 LOW FOR 5 MIN AND 5000 PSI FOR 30 MIN Printed 7/5/2011 9:18:59AM orth America - ALASKA - BP Page 12 of 12 Aeration Summary_ Report Common Well Name: MPF -86 -- _- u- ___-- __ - -_— AFE No �_ —�� Event Type: WORKOVER (WO) l Start Date: 6/13/2011 End Date: 6/21/2011 T1- 00019- E:F86ETTC (1,910,000.00 ) Project: Milne Point Site: M Pt F Pad I Rig Name /No.: DOYON 16 I Spud Date/Time: Rig Release: 6/21/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292301800 Active Datum: MPF -86 @42.90ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 1 (ft) 20:00 - 00:00 4.00 WHSUR P WHDTRE NU TREE AND TEST ' - SAME TREE REUSED - 4- 1/16" 5M CAMERON IRON WORKS - 250/5000 PSI FOR 5 MIN RIG RELEASED FROM MPF -86 AT 00:00 Printed 7/5/2011 9:18:59AM ~ STATE OF ALASKA ~ ALA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ~ RepairWell ~ PlugPerforations ~ Stimulate0 Oth~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver~ Time Extensi~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re~nter Suspended W~ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: . Permit to Drill Number: Name: DevelopmeM ^~ Exploratory ': 201-0870 3. Address: P.O. Box 196612 Stratigraphic^ Service . API Number: Anchorage,AK 99519-6612 50-029-23018-00-00 8. Property Designation ( ase Number) : . Well Name and Number: ADLO-355018 MPF-86 10. Field/Pool(s): MILNE POINT FIELD / KUPARUK RIVER OIL POOL 11. Present Well Condition Summary: Total Depth measured,~ 11317 feet Plugs (measured) 11126' BULL PLUG feet true vertical 7288.06 feet Junk (measured) None feet Effective Depth measured 11206 feet Packer (measured) 10987' true vertical 7180 feet (true vertical) 6968' Casing Length Size MD ND Burst Collapse Structural Conductor 78 20" SURFACE - 112 SURFACE - 112 1490 470 Surface 6485 9-5/8" 40# L-80 SURFACE - 6518 SURFACE - 4269 5750 3090 Intermediate 11263 7" 26# L-80 33 - 11296 33 - 7266 7240 5410 Production ,~~.-~.~~~~ i~~~y J ~ F~' ~~~U~ Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 2-7/8" 6.5# L-80 SURFACE - 10916 SURFACE - 6900 Packers and SSSV (type, measured and true vertical depth) 7" HES VTA RETRIEVABLE PKR 10987' 6968' ~~~~~~~~ 12. Stimulation or cement squeeze summary: ~~~ ~ ~' ~Qp~ Interoals treated (measured): Aleske Oil & Gas Cons. Carr~nission Treatment descriptions including volumes used and final pressure: a~~hp~8~8 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 277 173 319 264 Subsequent to operation: 269 192 321 275 14. Attachments: 1 Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Servic[] Daily Report of Well Operations X . Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ^ 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: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 11/10/2009 ~8~M3 NOV ~. 31009 ~~~-~ 1/ ~3•0 Form 10-404 Revised 7/2009 "~"' i~ ~Submit Original Only ~.,.~. ~ l~~G,f M PF-86 201-087 PFRF OTTO(:HMENT • ~ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPF-86 8/10/01 PER 11,068. 11,071. 7,046.46 7,049.36 MPF-86 8/10/01 PER 11,089. 11,090. 7,066.76 7,067.73 MPF-86 8/10/01 PER 11,096. 11,097. 7,073.54 7,074.5 MPF-86 8/11/01 BPS 11,075. 11,085. 7,053.23 7,062.9 MPF-86 8/17/01 BPP 11,075. 11,085. 7,053.23 7,062.9 MPF-86 8/18/01 APF 11,048. 11,050. 7,027.13 7,029.06 MPF-86 8/19/01 BPS 11,055. 11,065. 7,033.89 7,043.56 MPF-86 8/22/01 BPP 11,055. 11,065. 7,033.89 7,043.56 MPF-86 8/26/01 FIL 11,045. 11,097. 7,024.23 7,074.5 MPF-86 8126/01 APF 11,086. 11,096. 7,063.86 7,073.54 MPF-86 8/26/01 APF 11,047. 11,057. 7,026.16 7,035.83 MPF-86 8/26/01 APF 11,064. 11,074. 7,042.59 7,052.26 MPF-86 8/27/01 FIL 9,910. 11,045. 5,984.85 7,024.23 MPF-86 8/28/01 FCO 9,910. 11,189. 5,984.85 7,163.63 MPF-86 8/31/01 FIL 10,875. 11,074. 6,860.21 7,052.26 MPF-86 9/17/01 FCO 10,875. 11,057. 6,860.21 7,035.83 MPF-86 9/18/01 FIL 11,057. 11,097. 7,035.83 7,074.5 MPF-86 6/2/06 APF 11,068. 11,108. 7,046.46 7,085.15 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~ CJ MPF-86 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/5/2009ICTU #9 w/ 1.75" ct [ Job scope squeeze :Travel from NK-38 to MPF-86 __ _ _ _____,.._ . _.~._...._--- _------ -__-- ---- ---- --_____. ______---- 11/6/2009 CTU #9 w/ 1.75" ct [ Job scope squeeze acid thru ESP ] Travel from NK-38 to MPF ' 1-86. [ Perform weekly BOP test ] RIH w/2" JSN. Washed across GLM @ 169'. Got~ communication from IA to tbg. RIH and tag pump. Wash off top of pump w/KCL, jdisplace well to diesel. Start acid treatment. Continued on WSR 11-07-2009. j _.____. . _ _ _ _ _ __ _ _ _ _ _ _ _ _- 11/7/2009:CTU #9 w/1.75" OD CT. Job scope - Acidize ESP. Continued from WSR 11-06- 2009. Spot 10 bblls acid to top ESP. Squeeze acid through ESP while runniing pump in forward and reverse. POOH. ESP pumping at min rate. Flowed well to tanks until PH - 7. Return well back to production at 06:45. RDMO. Job complete. ~ FLUIDS PUMPED BBLS 58 1 % KCL W/776 10 DAD ACID 158 DIESEL 19 60/40 METH 245 Total Tree: 2 9/16", 5M Wellhead:11" Gen 5 FMC w/11 x 2-7/8" NSTC T&B Hgr. w/2.5" CIW 'H' BPV profile 112` 9-5/8" TAM Port Collar 1010` 9-5/8", 40#/ft., L-80 BTRC 6,517` 2 7/8" 6.5 ppf, L-80 8rd EUE tubing (drift ID = 2.347", cap = 0.00592 bpf) 7" 26#/ft., L-80 BTC-MOD Production Casing, (Drift ID = 6.151", cap. = 0.03E KOP C~ 400` to 3200` Max. h~ole Angle = 64 deg. Max. Hole Angle Thru Perfs. = 15 deg. Stimulation Summarv: 152.8K# of 16/20 Carbolite and 48.3k# of 12/18 behind pipe Perforation Summarv: Ref. Log SWS jewelry log 8/10/ Size SPF Interval TVC 3-3/8" 6 11047`-11057 7026`-7C 3-3/8" 6 11064`-11074 7043'-7C 3-3/8" 6 11086`-11096 7064`-7C Bull Plug 111. Nabors 3S FCO to 11128' 2-~ IA Tested to 1000 psi 2-4-07 6/4/06 L Hulme ESP Completion Nabors 3S 2/6/07 M. Ross FCO & Screens Added $ ESP Completion Nabors 3S 8l24/08 REH ESP RWO BY Nabors 4ES 5/13/09 L Hulme ESP RWO - Add Cap Tube - Nabors 3S Orig.~Elev. = 42.9` (N27E) Orig. Elev. = 10.9' RT to Tbg. Spool = 32.0` (N27E) Camco 2-7/8" x 1" 169' sidepocket KBMM GLM 3/8" Capillary tube for chemicals Camco 2-7/8" x 1" sidepocket KBMM GLM 10611' 2-7/8" XN nipple ~ 0795' (No-Go ID 2.205") arge Head 10847` S ~m Pumps, SXD 10848` -11, 18-P75 >eparator 10877' =TXAR H6 Intake ND - 6862' lem Seal Section 5B3DB U7/LT SB/SB PFSA/FSA CL5 ~ ~~~2~ r - Model KMHG 10896' ip/2415 volU48 amp npMate XTO 10912` i Fin Centralizer PumpMate ND - 6896' > `VTA' Retrievable Pkr 10987' ierford Duragrip Screen 11042`-1111 `I (PBTD) 11,206' 7" Float Collar 11,212` 7" Float Shoe 11,296 MPF-86 STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMIS N REPORT OF SUNDRY WELL OPERATIONS ~~~EI~'~~ ~CT 1 ~ 20d~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate~ . I Performed: Alter Casing ~ Pull Tubing ~ PerForate New Pool ~ Waiver~ Time Extensi~p Anchorage Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re`` nter Suspended W~ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Drill Number: Name: Development ^~ Exploratory ^ 201-0870 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage,AK 99519-6612 ~ 50-029-23018-00-00 8. Property Designation (Lease umber) : 9. Well Name and Number: ~ ~ ADLO-355018 MPF-86 10. Field/Pool(s): ~ MILNE POINT FIELD / KUPARUK RIVER OIL POOL 11. Present Well Condition Summary: ~ Total Depth measured 11317 feet Plugs (measured) 11126' BULL PLUG feet true vertical 7288.06 feet Junk (measured) None feet Effective Depth measured 11206 feet Packer (measured) 10987' true vertical 7180 feet (true vertical) 6968' Casing Length Size MD ND Burst Collapse Structural Conductor 78 20" SURFACE - 112 SURFACE - 112 1490 470 Surface 6485 9-5/8" 40# L-80 SURFACE - 6518 SURFACE - 4269 5750 3090 Intermediate Production 11263 7" 26# L-80 33 - 11296 33 - 7266 7240 5410 Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 2-7/8" 6.5# L-80 SURFACE - 10916 SURFACE - 6900' Packers and SSSV (type, measured and true vertical depth) 7" HES VTA RETRIEVABLE PKR 10987' 6968' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions induding 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: 211 144 287 294 Subsequent to operation: 219 143 291 305 14. Attachments: ~Well Class afterwork: Copies of Logs and Surveys Run Exploratory^ Development Q Servic~ Daily Report of Well Operations X Well Status after work: Oil ~ Gas WDSPL GS OR ^ WAG ^ GINJ^ WINJ^ SPLUG ^ 17. I hereby ceRify 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 Prebl Title Data Management Engineer Signature Phone 564-4944 Date 10/13/2009 Form 10-404 Revised 7/2009 ~~,''~'1.S ~'~ (1 ~ f C ~' ~1 ~ ~~ •~Ya9 Submit Original Only IOtt MPF-86 201-087 PFRF ATT~4CHMENT • • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPF-86 8/10/01 PER 11,068. 11,071. 7,046.46 7,049.36 MPF-86 8/10/01 PER 11,089. 11,090. 7,066.76 7,067.73 MPF-86 8/10/01 PER 11,096. 11,097. 7,073.54 7,074.5 MPF-86 8/11/01 BPS 11,075. 11,085. 7,053.23 7,062.9 MPF-86 8/17/01 BPP 11,075. 11,085. 7,053.23 7,062.9 MPF-86 8/18/01 APF 11,048. 11,050. 7,027.13 7,029.06 MPF-86 8/19/01 BPS 11,055. 11,065. 7,033.89 7,043.56 MPF-86 8/22/01 BPP 11,055. 11,065. 7,033.89 7,043.56 MPF-86 8/26/01 FIL 11,045. 11,097. 7,024.23 7,074.5 MPF-86 8/26/01 APF 11,086. 11,096. 7,063.86 7,073.54 MPF-86 8/26/01 APF 11,047. 11,057. 7,026.16 7,035.83 MPF-86 8/26/01 APF 11,064. 11,074. 7,042.59 7,052.26 MPF-86 8/27/01 FIL 9,910. 11,045. 5,984.85 7,024.23 MPF-86 8/28/01 FCO 9,910. 11,189. 5,984.85 7,163.63 MPF-86 8/31/01 FIL 10,875. 11,074. 6,860.21 7,052.26 MPF-86 9/17/01 FCO 10,875. 11,057. 6,860.21 7,035.83 MPF-86 9/18/01 FIL 11,057. 11,097. 7,035.83 7,074.5 MPF-86 6/2/06 APF 11,068. 11,108. 7,046.46 7,085.15 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~ ~ MPF-86 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY T/I/0=1000/1040/60 ESP Acid Treatment. Pump 20 bbis crude down Tbg to establish Inj rate @ 2 bpm. Pump 10 bbls 10% DAD acid followed by 3 bbis 60/40 meth & 33 bbls crude down Tbg. Saw 200 psi break. Pumped remaining 17 bbls crude down FL. DSO notified swab wing shut, ssv master ia oa open. FW HP's=1000/1160/60 ~ FLUIDS PUMPED BBLS 70 CRUDE 10 10% DAD ACID 3 60/40 METH 83 TOTAL STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS ~'"~ ~, ~.- A~ ~'~ ~~a„ y'~.-: ~. ~.. _ . ~;.~° ~.... ~ ~' ~.~. ~.. F ~, ~ ,~ '~ ~ %~;.;4i 1. Operations Abandon ~ Repair Weli ~ Plug Perforations ~ Stimulate0 ~.~~,~(J~i~,~~ ; ~~_ ,~ ~,n ;e 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: rvame: De~elopment ~ Exploratory ~ 2o~-os~o % 3. Address: P.O. Box 196612 St1`dtigr'dphiC ~` Service J~ 6. API Number: Anchorage, AK 99519-6612 50-029-23018-00-00 / 7. KB Elevation (ft): 9. Well Name and Number: 42.9 DF MPF-86 8. Property Designation: 10. Field/Pool(s): ADLO-355018 MILNE POINT Field/ KUPARUK RIVER OIL Pool .:~ 11. Present Well Condition Summary: Total Depth measured 11316 feet Plugs (measured) 11126' BULL PLUG true vertical 7287 feet Junk (measured) None Effective Depth measured 11206 feet true vertical 7180 feet Casing Length S+ze MD TVD Burst Collapse Conductor 78 20" Surface - 112 Surface - 112 1490 470 Surface 6485 9-5/8" 40# L-80 Surface - 6518 Surface - 4269 5750 3090 Production 11263 7" 26# L-80 33 - 11296 33 - 7266 7240 5410 - ~~ , ~, . i4; ~. n.., .~. . . ,.. . t ~ ~t ~' . Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 SURFACE -10916' 0 0 - Packers and SSSV (type and measured depth) 7" HES VTA RETRIEVABLE PKR 10987' 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: 256 69 390 285 Subsequent to operation: 259 68 379 290 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory T~ Deuelopment ~'' S@I'VIC@ ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas ~ WAG ~ GINJ I~ WINJ 1~ WDSPL Ir 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 Prebl Title Data Management Engineer Signature Phone 564-4944 Date 8/28/2009 Form 10-404 Revi~d 04/2006 ~~ ~~~~ ~r.G t~ ~ 7~~9 ~ Submit Origina~nly ~ ~ ~ `t,~''~. ~C> z~ M PF-86 201-087 PFRF OTTO(:HMFNT ~ • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPF-86 8/10/01 PER 11,068. 11,071. 7,046.46 7,049.36 MPF-86 8/10/01 PER 11,089. 11,090. 7,066.76 7,067.73 MPF-86 8/10/01 PER 11,096. 11,097. 7,073.54 7,074.5 MPF-86 8111/01 BPS 11,075. 11,085. 7,053.23 7,062.9 MPF-86 8/17/01 BPP 11,075. 11,085. 7,053.23 7,062.9 MPF-86 8/18/01 APF 11,048. 11,050. 7,027.13 7,029.06 MPF-86 8/19/01 BPS 11,055. 11,065. 7,033.89 7,043.56 MPF-86 8/22/01 BPP 11,055. 11,065. 7,033.89 7,043,56 MPF-86 8/26/01 FIL 11,045. 11,097. 7,024.23 7,074.5 MPF-86 8/26/01 APF 11,086. 11,096. 7,063.86 7,073.54 MPF-86 8/26/01 APF 11,047. 11,057. 7,026.16 7,035.83 MPF-86 8/26/01 APF 11,064. 11,074. 7,042.59 7,052.26 MPF-86 8/27/01 FIL 9,910. 11,045. 5,984.85 7,024.23 MPF-86 8/28/01 FCO 9,910. 11,189. 5,984.85 7,163.63 MPF-86 8/31/01 FIL 10,875. 11,074. 6,860.21 7,052.26 MPF-86 9/17/01 FCO 10,875. 11,057. 6,860.21 7,035.83 MPF-86 9/18/01 FIL 11,057. 11,097. 7,035.83 7,074.5 MPF-86 6/2/06 APF 11,068. 11,108. 7,046.46 7,085.15 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MiS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ! i MPF-86 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 8/14/2009~T/I/0=450/360/40 Acid Treatment Pumped 10 bbls crude, 10 bbis DAD Acid, 3 bbls 60/40 methanol & 44 bbls crude down Tbg. DSO notified swab wing ssv shut, master ia oa open. FWHP's=450/500/60 FLUIDS PUMPED BBLS 54 CRUDE 3 60/40 METH 10 DAD ACID 67 TOTAL STATE OF ALASKA ALA OIL AND GAS CONSERVATION CO~SION RECEI~i'EI~ REPORT OF SUNDRY WELL OPERATIONS i~~ti`( ~~ ~ 2009 ~i~~„~n ~'ii ~ ~~~ Cans. C®mmissi~ra 1. Operations Performed: An~~tCl'8~~' ^ Abandon ' ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Atter Casing • ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Oul ESP, Adtl Cappillary luDe ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. •® Development ^ Exploratory 201-087 " 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23018-00-00 7. KB Elevation (ft): 42 90 9. Well Name and Number: MPF-86 8. Property Designation: 10. Field /Pool(s): p~ / d~-^ ,~k ADL 355018 • Milne Point Unit / Kuparuk River s %.- j 11. Present well condition summary Total depth: measured 11316 'feet . true vertical 7287 ' feet Plugs (measured) 11126' Effective depth; measured 11206 feet Junk (measured) N/A true vertical 7180 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' 1490 470 Surface 6485' 9-5/8" 6518' 4269' 5750 3090 Intermediate Production 11263' 7" 33' - 11296' 33' - 7268' 7240 5410 Liner Perforation Depth MD (ft): 11048' - 11108' Perforation Depth TVD (ft): 7027' - 7085' 2-7/8", 6.5# L-80 10916' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" HES 'VTA' Retrievable Packer 10987' Weatherford Duragrip Screen 11042' - 11112' 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~.,,,~~~`. S~ ~ ~~ ._ Treatment description including volumes used and final pressure: ~~~ 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 900 0 Subsequent to operation: 187 27 205 350 284 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ° ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram . ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Hank Baca, 564-5444 N/A Printed Na Sondra Sie an Title Drilling Technologist S' nature Phone 564-4750 Date Prepared By NameJNumber • ZCO(~~So dra Stewman, 564-4750 Form 10-404 Revised 0~7200~ ~, ;l`~N ~ ~ 2~~~ ~ R I G 1 ~ A L ~ ub it Origin I Only ~. ~~r C5 //~~ Tree: 2 9/16", 5M ~ M P F-86 Orig Elev. = 42.9` (N27E) Wellhead;11" Gen 5 FMC Orig~ Elev. = 10.9' w/11 x 2-7/8" NSTC T&B Hgr. RT to Tbg. Spool = 32.0` (N27E) w/2.5" CIW 'H' BPV profile 112` 9-5/8" TAM Port Collar 1010` 9-5/8", 40#/ft., L-80 BTRC 6,517` 2 7/8" 6.5 ppf, L-80 8rd EUE tubing (drift ID = 2.347", cap = 0.00592 bpf) 7" 26#/ft., L-80 BTC-MOD Production Casing, (Drift ID = 6.151", cap. = 0.0383 b KOP (a~ 400` to 3200` Max. ole Angle = 64 deg. Max. Hole Angle Thru Perfs. = 15 deg. Stimulation Summary: 152.8K# of 16/20 Carbolite and 48.3k# of 12/18 behind pipe Qgrforation Summary: Ref. Log SWS jewelry log 8/10/01 Size SPF Interval TVD 3-3/8" 6 11047'-11057 7026`-7036' 3-3/8" 6 11064'-11074 7043`-7053' 3-3/8" 6 11086`-11096 7064`-7074' Bull Plug 11126' Nabors 3S FCO to 11128' 2-4-07 IA Tested to 1000 psi 2-4-07 Camco 2-7/8" x 1" 169' sidepocket KBMM GLM 3/8" Capillary tube for chemicals Camco 2-7/8" x 1" sidepocket KBMM GLM 10611' 2-7/8" XN nipple 10795` (No-Go ID 2.205") Discharge Head 10847` GPDIS Tandem Pumps, SXD 10848` 161-P-11, 18-P75 Gas Separator 10877' GRSFTXAR H6 Intake TVD - 6862` Tandem Seal Section 10882` Model GSB3DB UT/LT SB/SB PFSA/FSA CLS Motor -Model KMHG 10896` 190 hp/2415 volt/48 amp PumpMate XTO 10912' w/ 6 Fin Centralizer PumpMate TVD - 6896` HES `VTA' Retrievable Pkr 10987` Weatherford Duragrip Screen 11042`-1111 `I 500 Micron tt/uti/u~ muc.~ urm ~ rtun rrac ~tnng. Iv-z/t M.Linder Initial erforations 6/4/06 L Hulme ESP Completion Nabors 3S 2/6/07 M. Ross FCO & Screens Added & ESP Completion Nabors 3S 8/24/08 REH ESP RWO BY Nabors 4ES 5/13/09 L Hulme ESP RWO -Add Cap Tube -Nabors 3S (PBTD) 11,206` 7" Float Collar 11,212` 7" Float Shoe 11,296 MILNE POINT UNIT WELL MPF-86 ,!`KUP) API No. 50-029-23018 BP EXPLORATION ~AK)~ • • BP Operations Summary Report Legal Well Name: MPF-86 Page 1 of 4 ~ Common Well Name: MPF-86 Spud Date: Event Name: WORKOVER Start: 4/29/2009 End: 5/13/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/13/2009 Rig Name: NABORS 3S Rig Number: 5/s/Dose 15:oom 19 0o Ho4.ool Task 'Code' NPT ~- RIGD ~P 19:00 - 21:30 2.50 RIGD N 21:30 - 00:00 2.50 RIGD P 5/9/2009 ~ 00:00 - 05:00 ~ 5.00 MOB ~ P 05:00 - 09:30 4.50 MOB P 09:30 - 13:00 3.50 RIGU P 13:00 - 16:00 3.00 RIGU P 16:00 - 19:00 3.00 KILL P 19:00 - 19:30 0.50 KILL P 19:30 - 21:30 I 2.001 KILL I P 21:30 - 00:00 I 2.501 KILL I P Phase Description of Operations PRE Rlg down floor. Scope and lay down Derrick. Jack up pits and pipe shed and pin. Roll tires on carrier. PRE Wait on Peak trucks from Deadhorse. PRE Trucks on location. Hold PJSM with drivers. Move under pits and pipe shed. Connect truck to generator house. Make notification to Milne Pt. Move rig off well slot with Pad-operator witness. PRE Move rig and components from MPJ-pad to MPF-pad. Rig on location at 0345 hrs. Disconnect from pit and shed module. Road back to MPJ-pad to mobilize camp, shop and upright tank. PRE Connect to shop and camp. Move camp to MPF-pad. Get rig lined up on well and set herculite around well. PRE Set BOPE behind well. Jack up rig. Position camp at edge of pad. Set pipe shed and pits. Berm cellar and pits. Hook up steam, water and electrical between modules. PRE Raise and scope Derrick. Rig up floor and hook up mud lines. Accept rig at 1600 hrs. Load pits and upright with 140 degF seawater. Send trucks back to Deadhorse and wait for kill weight order. DECOMP Hook up Tiger Tank and lines. Rig up to kill well. Put second annulus valve on IA. RU to tree for well kill. DECOMP RU lubricator to tree. P/T to 500 si with diesel and pull BPV. Initial ressures: TBG = 920 si IA = 870 si, OA = 80 psi. DECOMP Pressure test surface lines to 3,500 psi. Test lines to Tiger Tank downstream of choke to 500 psi. Blow down lines. DECOMP Open choke and bleed IA from 870 psi to 70 psi, TBG fell to ,530 si. Bleed TBG from 530 si to 210 si to i er Tank. Initial ressures for well kill: TBG = 240 si IA = 260 si. Break circulation with 140 degF seawater down tubing taking returns thru choke to Tiger Tank at 2 BPM / 500 psi. Finish tubing circulation of 65 bbls at 3 BPM / 860 psi and 580 psi on IA. Returned 57 bbls of gas and crude back to Tiger Tank (88% returns). Close choke and bullhead 60 bbls down tubing into formation at 2.5 BPM / 1,480 psi on tubing and 1,570 psi on IA. Shut down pump and monitor for 15 min, tubing fell to 570 psi and IA fell to 1,030 psi. 5/10/2009 100:00 - 01:30 I 1.501 KILL I P 01:30 - 03:00 I 1.501 KILL I P 03:00 - 11:00 I 8.001 KILL I N Open well and circulate heated seawater down tubing taking returns thru choke to Tiger Tank. Circulate holding constant tubing pressure with choke at 3.5 BPM / 1,450 psi. DECOMP Circulated a total of 447 bbls down tubing thru choke to Tiger tank at 3.5 BPM / 1,450 psi. Returned 315 bbls of crude and gas (71% returns). Well cleaned up to seawater returns. Have vac truck evacuate crude and seawater from Tiger Tank. Blow down lines. DECOMP Monitor well. Initial pressures after shutting in: TBG = 400 psi, IA = 410 si. ressure topping on tubing and IA -10 psi every 10 min. TBG = 290 psi, IA = 300 psi at 0230 hrs. Well stabilized with TBG = 290 psi, IA = 300 psi. FLUD DECOMP Calculate kill weight fluid with Dav man, confirm numbers with Printed: 5/18/2009 9:56:08 AM • • BP Operations Summary Report Page 2 of 4 ~ Legal Well Name: MPF-86 Common Well Name: MPF-86 Spud Date: Event Name: WORKOVER Start: 4/29/2009 End: 5/13/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/13/2009 Rig Name: NABOBS 3S Rig Number: Date From - To i Hours Task Code' NPT ' Phase Description of Operations 5/10/2009 03:00 - 11:00 -- 8.00 KILL N FLUD - _ -- - DECOMP mud engineer. Calculated kill fluid with +75 psi overbalance is 9.5 brine. Order fluids from mud plant. Wait on kill fluid. Clean rig floor and service rig. 11:00 - 11:30 0.50 KILL P DECOMP Trucks on location. Load pits and upright with 9.5 ppg brine. 11:30 - 14:00 2.50 KILL P OECOMP Open choke and bleed Tbg from 240 psi to 10 psi to Tiger Tank. Initial pressures for well kill: TBG = 10 psi, IA = 240 psi. Break circulation with 70 degF 9.5 PPG Brine down tubing taking returns thru choke to Tiger Tank at 4 BPM / 1200 psi. Finish tubing circulation of 65 bbls at 4 BPM / 1010 psi and 75 psi on IA. Returned 65 bbls of seawater back to Ti erg Tank (100% returns). Close choke and bullhead 40 bbls down tubing into formation at 3 BPM / 1,300 psi on tubing and 870 psi on IA. Open well and circulate 9.5 PPG brine down tubing taking returns thru choke to Tiger Tank. Circulated a total of 430 bbls down tubing thru choke to Tiger tank at 4 BPM / 1,300 psi. Returned 400 bbls of seawater (93% returns). Returns C~ 9.5 PPG shut down and monitor well for 30 min. (Well on vac.) 14:00 - 15:00 1.00 KILL P DECOMP Allow well to U-tube. Monitor well, tubing and IA on vac: Blow down kill lines. 15:00 - 17:00 2.00 BOPSU P DECOMP PU T-bar and drv rod TWC with FMC rep. Test from above to i BPM / 650 si for 10 min -charted. Pum ed 36 bbls and bled back 3 bbls to its. 17:00 - 17:30 0.50 BOPSU P DECOMP RD kill lines and remove kill manifold from cellar. 17:30 - 18:30 1.00 BOPSU P DECOMP ND tree. Inspect hanger threads with FMC rep. Prep tubing spool for DSA. Gravity feed well 9 bbl/hr. 18:30 - 21:30 3.00 BOPSU P DECOMP NU BOPE and DSA. Function test BOPE and purge air from choke. Strap RKB. 21:30 - 00:00 2.50 BOPSU P DECOMP Test BOPE 250 psi low / 3,500 psi high. Test witnessed by WSL and NAD Tourpusher. AOGCC rep John Crisp waived the state's right to witness at 1915 hrs on 5-10-09. Gravity feed well 9 bbl/hr. 5/11/2009 00:00 - 01:00 1.00 BOPSU P DECOMP Complete BOPE test 250 psi low / 3,500 psi high. Test with 2-7/8" test joint on 2-7/8" x 5" VBR's. Complete Koomey draw down test. Suck out stack and blow down lines. Gravity feed IA with 9.5 during test at 9 bbl/hr. 01:00 - 02:30 i.50 PULL P DECOMP PUMU Opso-Lopso, pump-n-sub and lo-torque. Screw into hanger. MU lubricator to OL. P/T lubricator to 500 psi with diesel. Pull TWC. Tubin and IA on vac. LD lubricator and OL. MU TIW to landing joint and screw into hanger. Shut TIW valve. 02:30 - 03:00 0.50 PULL P DECOMP Conduct weekly safety meeting with rig crew. Discuss how each individual has made safety personal at home and at the job site. Review lessons learned. 03:00 - 04:00 1.00 PULL P DECOMP BOLDS with FMC rep. Check IA thru 2", IA on vac. Pull hanger free with 85K ahd space out below bag. MU circulating hose to TIW valve. Tubing on vac. 04:00 - 06:30 2.50 PULL P DECOMP CBU at 3.5 BPM / 930 psi. Circulate 360 bbls back to pits (accounting for 10% loss rate to annulus volume). 9.5 ppg in and out durina circulation. traces of crude in returns. Monitor Printed: 5/18/2009 9:56:08 AM r~ u g p Page 3 of 4 Operations Summary Report Legal Well Name: MPF-86 Common W ell Name: MPF-86 Spud Date: Event Nam e: WORKO VER Start : 4/29/2009 End: 5/13/2009 Contractor Name: NABOB S ALAS KA DRI LLING I Rig Release: 5/13/2009 Rig Name: NABOB S 3S Rig Number: f O ~ Date From - To Hours .Task Code NPT Phase Description o perations 5/11/2009 04:00 - 06:30 2.50 PULL P DECOMP well, on vac. 06:30 - 08:00 1.50 PULL P DECOMP Pull hanger to floor. Break out ESP cable and penetrator. LD landing joint and hanger. Tie in ESP cable to spooling unit. 08:00 - 18:00 10.00 PULL P DECOMP POH with 2-7/8" tubin standin back in Derrick. Maintain continuous hole fill houl losses = 12 bbl/hr. Swap ESP spools at 1100 hrs to 1200 hrs. 18:00 - 23:00 5.00 PULL P DECOMP LD ESP assembly as per Centrilift. Hourly losses = 12 bbl/hr. Clean and clear rig floor. Put new spools in spooling unit. 23:00 - 00:00 1.00 BUNCO P RUNCMP PUMU new ESP assembly as per Centrilift. 5/12/2009 00:00 - 04:30 4.50 BUNCO P RUNCMP Continue to MU new ESP assembly as per Centrilift. Tie in motor lead and service motor. Tie in ESP cable. Position 3/8" SS capillary tubing end at pump intake, pics in folder. Install tandem check valves in 3/8" tubing. 04:30 - 00:00 19.50 BUNCO P RUNCMP RIH with 2-7/8" 6.5#, 8rd tubin out of Derrick. Use Cannon clamps to secure ESP cable and capillary tubing on every joint to surface. Check conductivity every 2,000' and circulated 10 bbls to flush pump at .5 BPM / 1600 psi. Use Best-O-Life pipe dope on all connections, MU torque = 2,300 ft-Ibs. Maintain continuous hole fill with 9.5 brine loss rate = 7 bbl hr. Make ESP cable and capillary splice at 1730 hrs. 5/13/2009 00:00 - 02:00 2.00 BUNCO P RUNCMP Continue to RIH with 2-7/8", 6.5#, 8rd tubing out of Derrick. Use Cannon clamps to secure ESP cable and capillary tubing on every joint to surface. Use Best-O-Life pipe dope on all connections, MU torque = 2,300 ft-Ibs. Maintain continuous hole fill with 9.5 ppg brine, loss rate = 7 bbl/hr. MU circulating pin and conduct final flush of 10 bbls at .5 BPM / 1,600 psi. Ran a total of 342 re-used joints, 2 ea. GLMs, 1 ea. 2.205" XN ass'y, 348 Cannon clamps, 4 steel bands, 6 protectilizers, 3 armster guards. 02:00 - 03:00 1.00 BUNCO P RUNCMP PU landing joint with TIW valve and MU to tubing hanger. MU hanger to tubing string. Install penetrator and shipping caps with FMC. FMC plugged seal sleave to capillary tubing in hanger. 03:00 - 05:00 2.00 BUNCO P RUNCMP Make penetrator splice with Centrilift rep and check conductivity. Terminate 3/8" capillarty tubing in tubing hanger. 05:00 - 05:30 0.50 BUNCO P RUNCMP Final weights: PUW = 80K, SOW = 37K. Land tubing hanger. RILDS with FMC re . 05:30 - 07:30 2.00 BUNCO P RUNCMP PU T-bar and d rod TWC with FMC rep. Test TWC from above to 3,500 si for 10 min and conduct rolling test from below at 2 bpm / 620 psi (tested with 34 bbls, bleed back 7, injected 27 bbls) both test charted for 10 minutes. 07:30 - 08:30 1.00 BOPSU P RUNCMP Pump out BOP stack and blow down lines and kill manifold. 08:30 - 09:30 1.00 BOPSU P RUNCMP ND flow nipple, choke /kill lines and remove Turnbuckles. 09:30 - 16:00 6.50 BOPSU P RUNCMP Remove VBR and Blind rams blocks from BOP and ND ram sets and Annular to reconfigure to 4 ram stack on MPF-79. 16:00 - 19:00 3.00 WHSUR P RUNCMP NU production tree and adapter flange. FMC wellhead tech tested tubing hanger void to 5,000 psi for 30 minutes. Test tree to 5,000 psi for 5 min -charted. Centrilift make final checks on ESP cable: BHP = 3,372 psi, BHT = 160.5 degF, Phase to Phase = 4.4 ohms, Phase to Ground = 600 meg ohms. 19:00 - 21:30 2.50 WHSUR P RUNCMP RU lubricator to tree and test to 500 psi with diesel. Pull TWC and install BPV. Test from below. rollino test for 5 min at 500 Printed: 5/18/2009 9:56:08 AM . ~ . g P Page 4 of 4 Operations Summary Report Legal Well Name: MPF-86 Common Well Name: MPF-86 Spud Date: Event Name: WORKOVER Start: 4/29/2009 End: 5/13/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/13/2009 Rig Name: NABOBS 3S Rig Number: Date From - To Hours ' Task Code NPT Phase I Description of Operations 5113/2009 19:00 - 21:30 2.50 WHSUR P RUNCMP psi -charted. Pumped 22 bbls and bled back 3, injected 19 bbls. Blow down lines. 21:30 - 00:00 2.50 WHSUR P RUNCMP Clean and suck out pits of dirty 9.5 ppg brine. Secure cellar. Move spooler and Upright to edge of pad. Rig released at 2400 hrs on 5-13-09. Printed: 5/18/2009 9:56:08 AM v MPF-86 Well History Date Summary 04/05/09 RAN 2.08" CENT, DUAL SPARTEK GAUGES. 15 MIN GRADIENT STOP @ 10,325' SLM (10,288' MD). TAG TOP OF ESP @ 10,862' SLM (10,825' MD) + 37 FT CORRECTION. 3 HR BHP STOP @ 10,859' SLM (10,822' MD) PULL ST.2, 1" DUMMY GLV FROM @ 10,609' MD (pocket left open), PULL ST.1, 1" BEK S/O GLV FROM ST.2 @ 168' MD. SET ST.1, 1" BK DUMMY GLV. 04/16/09 The Well Support Techs rigged up and remove the wellhouse, flowline and foundation. BPV was already set. 05/07/09 RAN 2.10" CENT, SOFT SET, DUAL SPARTEK GAUGES, AS PER PROGRAM 05/11/09 SET 1" DGLV-BK IN GLM #1 AND 1" DPSOV-BK IN GLM #2 IN 3S PIPE SHED. MANDRAL'S MARKED AND DPSOV IS FLAGGED. 05/14/09 T/I/0=0/0/0. (Post RWO freeze protect) Freeze protect IA w/ 65 bbls crude. Freeze protect tbg w/ 15 bbls crude. FWHP=450/360/0. 05/14/09 The Well Support Techs rigged up and set the foundation, flowline and wellhouse. They then removed the back pressure valve and pressure tested the flowline to 4500 psi. All flanges were torque to spec. NOTE: The BPV was left OUT and the pressure test was GOOD Page 1 of 1 STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Contractor: Nabors Rig No. Rig Rep.: J.Greco / J. Fritts Rig Phone: Operator: BP Op. Phone: Rep.: O'Neil Coyne/V. Volpe 3S 659-4487 659-4485 DATE: 5/11/2009 Rig Fax: 659-4486 Op. Fax: 659-4628 Field/Unit & Well No.: MPU F-86 PTD #2010870 Operation: Drlg: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Annular: 250/3500 Valves: 250/3500 TEST DATA MISC. INSPECTIONS: Test Result Test Result Location Gen.: P Well Sign P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13 5/8 5m P Pipe Rams 1 2 7/8 X 5 P Lower Pipe Rams 0 NA Blind Rams 1 Blind P Choke Ln. Valves 1 3 1 /8" 5m P HCR Valves 1 2 1/16" 5m P Kill Line Valves 1 2 1/16" 5m P Check Valve 0 NA FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure System Pressure 2950 Pressure After Closure 1700 MUD SYSTEM: Visual Test Alarm Test 200 psi Attained 35 sec Trip Tank P P FuN Pressure Attained 2 min 40 sec Pit Level Indicators P P Bind Switch Covers: All stations Flow Indicator P P Nitgn. Bottles (avg): 4@2100 Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 0 Test Time: 3_5 Hours Repair or replacement of equipment will be made within days. Inspector 659-3607, follow with written confirmation to Superviser at: Remarks: Tested against 2 wav checkvalve /tested w!2 7/8 tubin~a 24 HOUR NOTICE GIVEN YES x NO Date 05/08/09 Time est start 2100 hrs Finish BOP Test (for rigs) BFL 11/14/07 ; . ,~: '" ~~}fit' ;.:F .I 1800 hrs Test Result P P P P P Components tested ALL Notify the North Slope By John Witness Jimmv Fritis / Vince Nabors 3S BOP Test MPU F-86 5-11-2009 .xls STATE OF ALASKA ~4~'?-0~ AL~ OIL AND GAS CONSERVATION CO~SION ~; ~~~ r? '~' REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 201-087 r 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23018-00-00 7. KB Elevation (ft): 42.90 , 9. Well Name and Number: MPF-86 8. Property Designation: 10. Field/Pool(s): _ ADL 355018 ~ Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 11316 - feet true vertical 7287 ~ feet Plugs (measured) N/A Effective depth: measured 11202 feet Junk (measured) N/A true vertical 7176 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' Surface 6485' 9-5/8" 6518' 4269' 5750 3090 Intermediate Production 11263' 7" 33' - 11296' 33' - 7268' 7240 5410 Liner t~~l-'+~l1l~6n~ ~L~ ~' r~. LU~~ Perforation Depth MD (ft): 11048' - 11108' Perforation Depth TVD (ft): 7027' - 7085' 2-718", 6.5# L-80 10893' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" HES'VTA' Retrievable Packer 10987' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 N/A Printed Sondra Stewman Title Drilling Technologist ~~~~ Prepared ey NameMumber. Si ature Phone 564-4750 Dat Sondra Stewman 564-4750 Form 10-404 Revised 04/2`Odb~- (~+ ~~~` ~~P 2 ~ 2~~8 Submit Original Only 1 ~IC ,~ ~ 1-a~ Tree: 2 9/16", 5M ~ M PF-~6 Ori~ Elev. = 42.9` (N27E) Wellhead:11" Gen 5 FM Ori L Elev. = 10.9' w/11 x 2-7/8° NSTC T&B Hgr. ~ RT to Tbg. Spool = 32.0' (N27E) w/2.5" CIW 'H' BPV profile 112` 9-5/8" TAM Port Collar 1010` 9-5/8", 40#/ft., L-80 BTRC 6,517` Camco 2-7/8" x 1" 168' sidepocket KBMM GLM Camco 2-7/8" x 1" sidepocket KBMM GLM 10609" 2 7/8" 6.5 ppf, L-80 8rd EUE tubing (drift ID = 2.347", cap = 0.00592 bpf) 2-7/8" XN nipple 10783' 7" 26#/ft., L-80 BTC-MOD Production I (ID 2.205") Casing, (Drift ID = 6.151", cap. = 0.0383 bpf Discharge Head 10825` GPHVDIS KOP a~ 400` to 3200` Triple Pumps 54 stage P-11 ` Max. Hole Angle = 64 deg. 99 stg. P-11 10826 Max. Hole Angle Thru 18 stg. P-75 Perfs. = 15 deg. Tandem Gas Separator 10854' GRSFTXAR H6 Stimulation Summary: 152.8K# of 16/20 Carbolite and 48.3k# of 12/18 behind pipe Perforation Summary: Ref. Log SWS jewelry log 8/10/01 Size SPF Interval TVD 3-3/8" 6 11047`-11057 7026'-7036' 3-3/8" 6 11064'-11074 7043'-7053' 3-3/8" 6 11086'-11096 7064'-7074' Bull Plug 11126` Nabors 3S FCO to 11128' 2-4-07 IA Tested to 1000 psi 2-4-07 Tandem Seal Section 10858` Motlel GS83OB UT/LT SB/SB PFSA/FSA CLS Motor- Model KMH 10872' 190 hp/2415 volt/48 amp Phoenix XTO 10889` w/ 6 Fin Centralizer HES 'VTA' Retrievable Pkr 10987' Weatherford Duragrip Screen 11042'-1111 `I uiuniu~ n/iuv M.Linder UI'lll 2k KUn rraC 5ifing. rv-L/t Initi I erfor tions 6/4/06 L Hulme ESP Completion Nabors 3S 2/6/07 M. Ross FCO & Screens Added & ESP Completion Nabors 3S 8/24/08 REH ESP RWO BY Nabors 4ES (PBTD) 11,206' 7" Float Collar 11,212` 7" Float Shoe 11,296 MILNE POINT UNIT WELL MPF-86 (KUP) API No. 50-029-23018 BP EXPLORATION (AKII • • BP Page 1 of 2 Operations Summary Report Legal Well Name: MPF-86 Common Well Name: MPF-86 Spud Date: Event Name: WORKOVER Start: 8/21/2008 End: 8/24/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/24/2008 Rig Name: NABORS 4ES Rig Number: 4ES ~ '~, Task .Code NPT Phase Description of Operations Date !From - To Hours 8/21/2008 06:00 - 08:00 2.00 RIGD P PRE PJSM -Rigging down. Prepare rig components for mobilization. Scope and lower derrick. 08:00 - 10:30 2.50 RIGD P PRE Move pipe shed and pits. Pull sub off of well. MPU Tract 14 pad operator present when sub pulled off well. 10:30 - 16:00 5.50 MOB P PRE Move rig components and equipment to MPF-86. 16:00 - 18:00 2.00 RIGU P PRE Spot sub, pits, pipe shed and satellite camp. PJSM -Raising and scoping derrick. Raise derrick. 18:00 - 19:00 1.00 RIGU P PRE Scope up derrick. R/U pit lines. ACCEPTED RIG ~ 1900 hrs. 19:00 - 20:00 1.00 WHSUR P DECOMP P/U lubricator & test to 500 si Ok. Pull BPV & UD same. 20:00 - 21:30 1.50 RIGU P DECOMP R/U lines to tiger tank & tree. Test lines to 3500 psi. Take on 2% KCI brine. 21:30 - 22:00 0.50 KILL P DECOMP Hold PJSM & Pre-spud meeting w/all hands. 22:00 - 00:00 2.00 KILL P DECOMP O en well. SITP = 210 si SICP = 850 si, OAP = 100 psi. Bleed off gas. Circulate well w/ 8.4 ppg 2% KCI brine. Pump 3 BPM & increase to 4 BPM ~ 1350 psi. CP 260 psi. 8/22/2008 00:00 - 01:30 1.50 KILL P DECOMP Con't to circulate well. Pump 4 BPM ~ 1380 psi, CP = 120 psi. Pumped 440 bbls. S/D & monitor well. Well not dead 70 psi SITP. Pump additional 50 bbls. 8.4 PPG in & out. S/D & monitor well. SITP 70 psi. Confer w/field operator. Infector running w/ 1100 si in'ection ressure. A reed to S . ecovered 325 bbls into tiger tank. 01:30 - 02:00 0.50 KILL P DECOMP Notify town engineer of need to weight up. Agreed to weight up to kill wt (after 1 hr SI) then go .2 ppg over kill wt. New Kill wt calculates to be 8.8 .Begin weighting up remaining volume in pits to 8.8 ppg. BHP - 3153 psi. 02:00 - 08:00 6.00 KILL P DECOMP Ordered addtional bulk NaCI for pit weight up & 580 bbls of 8.8 ppg NaCI from mud plant. Wait on kill fluid. SITP ~ 04:00 hrs = 45 si ~ 05:30 hrs = 40 si. SITP/SICP C~3 07:30- r . _ 40/4 , 580-Bbls. 8.8 ppg NaCI arrived at 07-00-hrs. Monitor well and discuss plan forward with Anchorage engineering before proceeding with 8.8 ppg brine well kill. Anchorage engineering concurred with plan forward. 08:00 - 10:00 2.00 KILL P DECOMP Circulated well ~ 5.0-bpm ~ 1700-1100 psi with 8.8-ppg NaCI brine. Circulated 532-Bbls. taking returns to Tiger Tank and obtained 8.8-ppg returned brine. Lost 76-bbls. brine to formati 10:00 - 11:00 1.00 KILL P DECOMP Shut in and monitored well for 45 minutes. ISITP/ISICP = 70/70. SITP/SICP after 45 minutes = 0/0. 11:00 - 12:00 1.00 WHSUR P DECOMP FMC d rod set TWC and verified proper travel for 100% engagement of TWC in hanger profile. P/T TWC from below to 500- si and from above to 3500- si for 10-charted minutes each. 12:00 - 13:30 1.50 WHSUR P DECOMP Crew changeout. Safety standdown to discuss "Safety Focus" memo, current rig scorecard and "8 Golden Rules" with an emphasis on vehicle safety. 13:30 - 15:00 1.50 WHSUR P DECOMP Bled hanger void pressure and nippled down tree. Inspected top hanger thread and screwed 2-7/8" 8RD. XO in and found to be O.K. 15:00 - 16:30 1.50 BOPSU P DECOMP NU BOPE. AOGCC -John Crisp waived states right to witness BOPE testing. 16:30 - 20:00 3.50 BOPSU P DECOMP Pressure test BOPE as er BP/AOGCC re uirements. LP 250 psi, HP 3500 psi. Test annular 250/3500 psi. Used 2 7/8" test joint. No failures. R/D test equip. Printed: 9/8/2008 11:12:00 AM • • gp Page 2 of 2 Operations Summary Report Legal Well Name: MPF-86 Common Well Name: MPF-86 Spud Date: Event Name: WORKOVER Start: 8/21/2008 End: 8/24/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/24/2008 Rig Name: NABOBS 4ES Rig Number: 4ES Date ;From - To Hours I! Task Code NPT Phase Description of Operations 8/22/2008 20:00 - 21:00 1.00 WHSUR P DECOMP P/U lubricator & test to 500 si. Pull TWC & UD same.. 21:00 - 22:00 1.00 PULL P DECOMP M/U landing jt into hanger. BOLDS. Pull hanger to floor. came free w/ 94K. Pull to floor w/ 85K. Break out & UD landing jt & hanger. 22:00 - 23:30 1.50 PULL P DECOMP M/U circulating head. Circulate bottoms up. Pumped 4.7 BPM ~ 1400 psi. Pump total of 447 bbls. Lost 40 bbls during circulation. No gas to surface. Obtained SPR, 2 BPM ~ 220 psi. 23:30 - 00:00 0.50 PULL P DECOMP Monitor well. fluid level dro in . R/U to ull ESP com letion. 8/23/2008 00:00 - 05:00 5.00 PULL P DECOMP POOH &standback 2 7/8" ESP completion. Use double dis lacement method while POOH. Spool up ESP cable. OOH w/ 80 stands ~ 05:00-hrs. 05:00 - 06:00 1.00 PULL P DECOMP Cut ESP cable at splice (reel full). Change out reels in spooling unit. Pre-tour meeting/crew change. Daily derrick inspection, check PVT's and rig service. 06:00 - 09:00 3.00 PULL P DECOMP POOH &standback 2 7/8" ESP completion. Use double dis lacement method while POOH. Spool up ESP cable. OOH w/ 80 stands ~ 06:00-hrs. Lost 25-Bbls. brine to formation while POH. 09:00 - 13:00 4.00 PULL P DECOMP Centrilift disassemble and inspect ESP assembly. 13:00 - 16:30 3.50 BUNCO RUNCMP Centrilift assemble and service new ESP assembly: Centralizer, Pressure Monitor, Motor, Seal Section x 2, Gas Separator, Pump x 3 and Discharge Head. 16:30 - 23:30 7.00 BUNCO RUNCMP RIH with 2-7/8" ESP com letion a ui ment and ESP cable. installed Lasalle cable clamps on first 9 tubing couplings and then every second tubing coupling thereafter. Also installed Lasalle cable clamps on every tubing pup except pup below tubing hanger. Filled hole with double steel displacement while running in hole. RIH w/ 75 stands. 23:30 - 00:00 0.50 BUNCO RUNCMP Make reel to reel splice in ESP power cable. 8/24/2008 00:00 - 01:00 1.00 BUNCO RUNCMP Change out reels in spooler. Make reel to reel splice. Test connection. 01:00 - 03:00 2.00 BUNCO RUNCMP Con't to RIH w P om letion. Install LaSalle clamps on every other connection & all pups. Use double displacement method while RIH. RIH w/ 108 stands. 03:00 - 04:00 1.00 BUNCO RUNCMP M/U landing jt & hanger. Install penetrator in hanger. P/U Wt 85K, S/O Wt = 40K. 04:00 - 06:00 2.00 BUNCO RUNCMP Make field splice. Plug into penetrator & test same. Pre-tour crew change meeting. Reviewed nipple down BOPE procedure. daily derrick inspection, check PVT's and service rig. 06:00 - 06:30 0.50 BUNCO RUNCMP La 06:30 - 07:30 1.00 WHSUR P RUNCMP P/T TWC from above to 3 0 - - - below. Charted both tests. 07:30 - 09:00 1.50 BOPSU P RUNCMP Nipple down BOPE and set back on stump. 09:00 - 11:00 2.00 WHSUR P RUNCMP Nipple up lockdown flange, tubing adapter and tree. P!T adapter and tree to 5000-psi for 5-minutes. Pad operator verified tree orientation and accepted tree. Centrilift made final electrical checks. All O.K. 11:00 - 13:00 2.00 WHSUR P RUNCMP Make up lubricator to swab valve and P/T' to 500-psi. MPU Well Support pull TWC and set BPV. P/T BPV to 500-psi from below for 5 charted minutes. Secure tree and cellar. RELEASE RIG ~ 13:00-hrs. Printed: 9/8/2008 11:12:00 AM ~a~e-1 of 1 Well: MPF-86 Well History Well Date Summary MPF-86 7/8/2008 T/I/0=250/300/140 Acid Treatment (ESP Washl -Pumped tbg w/10 bbls crude, 10 bbls 7.5% DAD HCL acid, 3 bbls 60/40 methanol & 44 bbls crude. At 44 bbls crude away TP broke back 175 psi. Shutdown displacement 11 bbls early & begin soak. Casing, master &SSV valves open. Swab, wing & choke closed. Turn well over to operator for 30 min soaWESP run & flow back. Final WHP's=275/460/140 MPF-86 8/13/2008 ***WELL S/I ON ARRIVAL*** (rwo prep) PULL BK-DGLV FROM STA#1 C 10637' MD, ***POCKET LEFT OPEN*** PULL BEK-DPSOV FROM STA#3 @ 170' MD, SET BK-DGLV. ***WELL S/I ON DEPART*** MPF-86 8/13/2008 T/I/0=800/800/100. (Pre-RWO freeze protect). Freeze protect Flw/ 2 bbls 60/40 meth,n 3 bbls diesel, & 2 bbls 60/40 meth. Bleed FL pressure down to 0 psi. Freeze protect tbg w/ 15 bbls diesel. FWHP=400/880/100. MPF-86 8/16/2008 Well Techs set BPV ,then demobe well house flow lines and foundation .All blinds are TQ spec. MPF-86 8/23/2008 ***SURFACE WORK 3S*** SET 1" BEK-DPSOV IN SPM TO BE RUN ON TOP (MARKED AND FLAGGED) PULLED AND RE-RAN 1" BK-DGLV IN SPM TO BE RUN ON BOTTOM (MARKED "dummy") ***NOTIFIED COMPANY REP OF STATUS OF MANDRELS*** MPF-86 8/24/2008 (Freeze Protect Post RWO T/I/0=0/0/60 Pumped 65 bbls Dead Crude down IA. Pumped 15 bbls Dead rue own tubing @ .6 bpm and 2700 psi. this is a slower rate and high pressure than before the RWO was done. FWHP= 0/0/60 Swab, Wing, SSV closed. Master, IA, OA open to guages. MPF-86 8/24/2008 The Well Support Techs rigged up and set the foundation, flowlines ,and wellhouse. They then pulled the BPV and leak tested the flowlines to 5000 psi. Note: The BPV was left OUT and the leak test was GOOD. MPF-86 8/25/2008 T/I/0=0/0/60 (Scale Inhibitor Treatment) Pumped 27.4 bbls O3VM082 down tubing. Followed by 85 bbls Dead Crude. Continue on~~U MPF-86 8/26/2008 T/I/0=0/0/60 (Scale Inhibitor Treatment) Continued from 08-25-08 AWGRS. Pumped remaining 258 bbls Dead Crude overflush down tubing for total of 343 bbls. Tag well, swab, wing & ssv closed. Master, IA/OA open. Notify operator. FWHP=475/240/70 Print Date: 9/19/2008 Page 1 of 1 STATE OF ALASKA s~,~~8' ALA OIL AND GAS CONSERVATION COMII~IC~t~' ~ ' ;~`;`?`1 REPORT OF SUNDRY WELL OP~#~;AT,14~IS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate0 ~ `bth~' °AEI ~#REATMENT~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Ezt~Pfsion ~ ESP WASH 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 2o1-os7o 3. Address: P.O. Box 196612 Stratigraphic Service ~' 6. API Number: Anchorage, AK 99519-6612 50-029-23018-00-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: 42.9 DF / MPF-86 8. Property Designation: 10. Field/Pool(s): ADLO-355018 ` MILNE POINT Field/ KUPARUK RIVER OIL Pool 11. Present Well Condition Summary: Total Depth measured 11316 ~ feet Plugs (measured) None true vertical 7287 ~ feet Junk (measured) None Effective Depth measured 11202 feet true vertical 7176 feet Casing Length Size MD TVD Burst Collapse Conductor 78' 20" Surface - 112' Surface - 112' Surface 6485' 9-5/8" 40# L-80 Surface - 6518' Surface - 4269' 5750 3090 Productiob 11263' 7" 26# L-80 33' - 11296' 7 268' 7240 5410 33' - 11 5S pp~~ ''i (~ ~~t'1Litltl~~ Jvt ~ ~ Z~~B ~ Perforation depth: Measured depth: See attached - True Vertical depth: _ _ _ _ Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 Surface - 10898' 0 0 - Packers and SSSV (type and measured depth) 7" HES VTA RETRIEVABLE PKR 10987' 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: 211 37 349 255 Subsequent to operation: 213 36 359 254 14. Attachments: 15. Weli 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 w 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 Pre Title Data Management Engineer Signature Phone 564-4944 Date 7/16/2008 Form 10-40 Revised 04/2006 ~ ~ ~~ /~ t ~ ` ` Submit Original Only / EL1E EL.. ~ 1 MPF-86 201-087 PERF ATTArHMENT .] • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPF-86 8/10/01 PER ' 11,068. 11,071. 7,046.46 7,049.36 MPF-86 8/10/01 PER 11,089. 11,090. 7,066.76 7,067.73 MPF-86 8/10/01 PER 11,096. 11,097. 7,073.54 7,074.5 MPF-86 8/11/01 BPS 11,075. 11,085. 7,053.23 7,062.9 MPF-86 8/17/01 BPP 11,075. 11,085. 7,053.23 7,062.9 MPF-86 8/18/01 _ APF 11,048. 11,050. _ 7,027.13 7,029.06 MPF-86 8/19/01 BPS 11,055. 11,065. 7,033.89 7,043.56 MPF-86 8/22/01 BPP 11,055. 11,065. 7,033.89 7,043.56 MPF-86 8/26/01 APF 11,047. 11,057. 7,026.16 7,035.83 MPF-86 8/26/01 APF 11,064. 11,074. 7,042.59 7,052.26 MPF-86 8/26/01 APF 11,086. 11,096. 7,063.86 7,073.54 MPF-86 8/26/01 FIL 11,045. 11,097. 7,024.23 7,074.5 MPF-86 8/27/01 FIL 9,910. 11,045. 5,984.85 7,024.23 MPF-86 8/28/01 FCO 9,910. 11,189. 5,984.85 7,163.63 MPF-86 8/31/01 FIL 10,875. 11,074. 6,860.21 7,052.26 MPF-86 9/17/01 FCO 10,875. 11,057. 6,860.21 7,035.83 MPF-86 9/18/01 FIL 11,057. 11,097. 7,035.83 7,074.5 MPF-86 6/2/06 APF 11,068. 11,108. 7,046.46 7,085.15 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMO VED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SOF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • r 1 L...~ MPF-86 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 7/8/2008 T'I/0=250/300/140 Acid Treatment (ESP Wash) -Pumped tbg w/10 bbls crude, 10 bbls 7.5% DAD HCL acid, 3 bbls 60/40 methanol & 44 bbls crude. At 44 bbls ', crude away TP broke back 175 psi. Shutdown displacement 11 bbls early & begin!, soak. Casing, master & SSV valves open. Swab, wing & choke closed. Turn well '; ,over to operator for 30 min soak/ESP run & flow back. Final WHP's=275/460/140 FLUIDS PUMPED BBLS 54 CRUDE 3 60/40 METH 10 7.5% DAD ACID 67 Total • STATE OF ALASKA ~ .~~ ~ ~ ~ ®~Q~J'$ AL/~ OIL AND GAS CONSERVATION COM~SION REPORT OF SUNDRY WELL OPERAI~~~~it ~ Gas Cons. Commission 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate 0 - ' ID TREATMENT 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 ~ 2o1-os7o' 3. Address: P.O. Box 196612 StratlgraphlC ' Service 6. API Number: Anchorage, AK 99519-6612 50-029-23018-00-00 7. KB Elevation (ft): 9. Well Name and Number: 42.9 MPF-86 J 8. Property Designation: 10. Field/Pool(s): ADLO-355018 " MILNE POINT Field/ KUPARUK RIVER OIL Pool 11. Present Well Condition Summary: Total Depth measured 11316 - feet Plugs (measured) None true vertical 7287 ' feet Junk (measured) None Effective Depth measured 11202 feet true vertical 7176 feet ... Casing Length Size MD TVD Burst Collapse Conductor 78' 20" Surface - 112' Surface - 112' Surface 6485' 9-5/8" 40# L-80 Surface - 6518' Surface - 4269' 5750 3090 Production 11263' 7" 26# L-80 33' - 11296' 33' - 7268' 7240 5410 ~~,~ JUN ~ 2D08 Perforation depth: Measured depth: SEE ATTACHMENT True Vertical depth: _ _ Tubing: (size, grade, and measured depth) 2-7/8" 6.5# ~ L-80 _ .........Surface - 10898' 0 0 - Packers and SSSV (type and measured depth) 7" HES VTA RETRIEVABLE PACKER 10987' 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: 221 44 286 289 Subsequent to operation: 201 33 253 294 14. Attachments: 15. Well Class after proposed work Copies of Logs and Surveys Run Exploratory ~. Development Service i 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 Preble Title Data Management Engineer ~~ Signature Phone 564-4944 Date 5/29/2008 Form 10-404 Revi ed 04/2006 ~ R 1 G 1 N A L ~s ~~ .xUfV ~ ~ ?Q~~ Submit Original Only MPF-89 201-0870 PFRF ATTACHMENT Wellbore: MPF-86 MDT MDB TVDT TVDB 8/10/2001 8/11/2001 8/17/2001 8/18/2001 8/19/2001 8/22/2001 8/26/2001 6/2/2006 11,047 11,048 7026 7027 APF 11,048 11,050 7027 7029 APF APF 11,050 11,055 7029 7034 APF 11,055 11,057 7034 7036 APF 11,064 11,068 7043 7046 APF 11,068 11,071 7046 7049 PER BPS BPP APF APF 11,071 11,074 7049 7052 APF APF 11,074 11,075 7052 7053 APF 11,075 11,086 7053 7064 APF 11,086 11,089 7064 7067 APF APF 11,089 11,090 7067 7068 PER BPS BPP BPS BPP APF APF 11,090 11,096 7068 7074 APF APF 11,096 11,097 7074 7075 PER BPS BPP BPS BPP APF 11,097 11,108 7075 7085 APF I AB ABANDON ED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULL ED SL SLOTTED LINER __ BPS BRIDGE PLUG SET _ SPR SAND PLUG REMOV ED FCO FILL CLEAN OUT _ SPS SAND PLUG SET FIL FILL _ SOF EEZE FAILED SQ U ___ MIR MECHANICAL ISOLATED REMO VED SOZ _ _ SQUEEZE __ MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED _ MLK MECHANICAL LEAK STO __ STRADDLE PACK, OPEN , _ OH OPEN HOLE _ __ _ • • • • MPF-86 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTNITYDATE ~ SUMMARY _ J 5/23/2008: (Acid Treatment) T/I/0= 325/340/120 Pump 10 bbls dead crude down TBG 'followed by 10 bbls Acid then 55 bbls dead crude for Acid Treatment. FW H P= 350/360/120 FLUIDS PUMPED BBLS 65 DEAD CRUDE 3 NEET METH 68 Total I~CGC1YCaV ~~• sia-off STATE OF ALASKA ~ MAY 0 9 'l_00$ ALA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OP~I1~1isCons.Commission 1. Operations Abandon ~ RepairWell ~ PlugPerforations ~ Stimulate0- nC C)(~I~r ~ ACID TREATMENT 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 ~~? 2o1-os7o' 3. Address: P.O. Box 196612 Stratigraphic ' Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-23018-00-00 7. KB Elevation (ft): 9. Well Name and Number: 42.9 MPF-86 - 8. Property Designation: 10. Field/Pool(s): .~ ADLO-355018 ' MILNE POINT Field/ KUPARUK RIVER OIL Pool 11. Present Well Condition Summary: Total Depth measured 11316 feet Plugs (measured) None true vertical 7287. feet Junk (measured) None Effective Depth measured 11202 feet true vertical 7176 feet Casing Length Size MD TVD Burst Collapse Conductor 78' 20" Surface - 112' Surface - 112' Surface 6485' 9-518" 40# L-80 Surface - 6518' Surface - 4269' 5750 3090 Production 11263' 7"26# L-80 33' - 11296' 33' - 7268' 7240 5410 ~~~ MAC ~. ~ 200 Perforation depth: Measured depth: SEE ATTACHMENT = _ _ True Vertical depth: _ _ _ Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 Surface - 10898' 0 0 - Packers and SSSV (type and measured depth) 7" HES VTA RETRIEVABLE PACKER 10987' 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: 221 44 286 289 Subsequent to operation: 201 33 253 294 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: NIA Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 5/7/2008 ~'"'~"" Form 10-404 Revised 04/2006 ~~ / Submit Original Only 'ter I t ~~ ~~~ ~... L',7Q1~'~1 l i ~ MPF-89 201-0870 PERF ATTACHMENT Wellbore: - ---- --- ------------- MPF-86 .MDT MDB TVDT TVDB 8/10/2001 8!11/2001 8/17!2001 8/18!2001 8/19!2001 8/22/2001 8!26/2001 6/2/2006 11,047 11,048 7026 7027 APF 11,048 11,050 7027 7029 APF APF 11,050 11,055 7029 7034 APF 11,055 11,057 7034 7036 APF 11,064 11,068 7043 7046 APF 11,068 11,071 7046 7049 PER BPS BPP APF APF 11,071 11,074 7049 7052 APF APF 11,074 11,075 7052 7053 APF 11,075 11,086 7053 7064 APF 11,086 11,089 7064 7067 APF APF 11,089 11,090 7067 7068 PER BPS BPP BPS BPP APF APF 11,090 11,096 7068 7074 APF APF 11,096 11,097 7074 7075 PER BPS BPP BPS BPP APF 11,097 11,108 7075 7085 APF AB ABANDON ED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULL ED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOV ED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, C LOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • MPF-86 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 4/29/2008 (Acid Treatment) T/I/0= 200/240/120 Pump 10 bbls dead crude then 10 bbls : Acid followed by 55 bbls dead crude. Flush transport lines with 3 bbls neet meth. Awgers Continued on 04-30-08. 4/30/2008;;.. (Acid Treatment) T/I/0= 200/2401120 Pump 10 bbls dead crude down TBG 'followed by 10 bbls Acid then 55 bbls dead crude for Acid Treatment. Flush :;Acid Transport with 3 bbls neet meth. FWHP= 200/420 FLUIDS PUMPED BBLS 65 DEAD CRUDE 3 NEET METH 10 ACfD 78 Total «. STATE OF ALASKA ~-~~~GVEIV~® ALASKA OIL AND GAS CONSERVATION COM11111~SION REPORT OF SUNDRY WELL OPERATIONS JAN 0 8 Z~~~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Alaska OiP~2~> ~i 7s C~i~~T~ Performed: Alter Casing ~ Pull Tubing] Perforate New Pool ~ Waiver Time Extensi n ~ p Change Approved Program ~ Operat. Shutdown[] Perforate ~ Re-enter Suspended Weff ~orage 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ' ~ Exploratory ~ 201-0870 ' 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-23018-00-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 42.9 DF ~ MPF-86 ~ 8. Property Designation: 10. Field/Pool(s): ~ ADLO-355018. MILNE POINT Field/ KUPARUK RIVER OIL Pool 11. Present Well Condition Summary: Total Depth measured 11316 ~ feet Plugs (measured) None true vertical 7278 feet Junk (measured) None Effective Depth measured 11202 feet true vertical 7176 feet Casing Length Size MD TVD Burst Collapse Conductor 78' 20" Surface - 112' Surface - 112' Surface 6485' 9-5/8" 40# L-80 Surface - 6518' Surface - 4269' 5750 3090 Production 11263' 7" 26# L-80 33' - 11296' 33' - 7268' 7240 5410 ~~y~;tl~t8'CL`~ JH1~ .~. ~ L~~~ Perforation depth: Measured depth: 11047' - 11108' _ _ True Vertical depth: 7027 - 7085 _ _ _ _ Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 - 10898' 0 0 - Packers and SSSV (type and measured depth) 7" HES VTA RETRIEVABLE PACKER 10987' 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: 257 82 294 270 Subsequent to operation: 271 90 300 274 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 Preble Title Data Management Engineer Signature Phone 564-4944 Date 1/4/2008 Form 10-404 Re~sed 04/2006 ~'~~ ~~" `)~~ ~~ `~ EI)~~ ~"`~'l~ Submit Original Only • • MPF-86 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE~ SUMMARY __ 12/14/2007T/I/0=500/660/80 (ESP Acid Wash) ':Pumped 10 bbls Diesel for In}ectivity, 13 bbls 10% DAD Acid, 3 bbls Neet Meth, ', ', ;and 33 bbls Crude into TBG. (Cut Displacement Short due to Acid Falling to 'ESP, Milne & Town PE's made this decision) Turn Well over to Pad Op for Soak ', '!and ESP Circulate. Final WHP's=700/680/80 FLUIDS PUMPED BBLS 10 DIESEL 13 10% DAD ACID 33 DEAD CRUDE 3 NEAT METH 59 Total STATE OF ALASKA ~ //~s~/-D~ ALAS A OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS(~~(,~11,/~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ~1 ACID TREATMENT Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Et~~yi~io~[~ ~~~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: ~ Name: Development Exploratory #70 3. Address: P.O. Box 196612 Stratigraphic '' Service 6. API Number: Anchorage, AK 99519-6612 50-029-23018-00-00 7. KB Elevation (ft): 9. Well Name and Number: 42.9 MPF-86 ' 8. Property Designation: 10. Field/Pool(s): ADLO-355018 - MILNE POINT Field/ KUPARUK RIVER OIL Pool 11. Present Well Condition Summary: MM C Total Depth measured 11316 - feet Plugs (measured) None true vertical 7287 ~ feet Junk (measured) None Effective Depth measured 11202 feet true vertical 7176 feet Casing Length Size MD TVD Burst Collapse Conductor 78' 20" Surface - 112' Surface - 112' Surface 6485' 9-5/8" 40# L-80 Surface - 6518' Surface - 4296' 5750 3090 Production 11263' 7" 26# L-80 33' - 11296' 33' - 7268' 7240 5410 ~~~~~,~~~~ NOV ~ ~ 200? Perforation depth: Measured depth: 11047' - 11057' 11064' - 11108' _ _ _ True Vertical depth: 7026' - 7036' 1061' - 7085' _ _ _ Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 Surface - 10898' 0 0 - Packers and SSSV (type and measured depth) 7" hes vta retrievable packer 10987' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ~ ~~, ~~~f ~ '~ ~QQ/ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 317 55 294 271 Subsequent to operation: 306 55 423 272 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: Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 10/31/2007 Form 10-404 Revised,04/2006 U R ~ ~ ~ n t ~ ~ ~ ~`~ ~ ~ Submit Original Only M ~ ~ • MPF-86 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDAT~ SUMMARY ~ 10/20/2007: ESP Acid Wash. T/I/0=320300/100 Pumped 10 bbls Crude, 11 bbls 10% DAD acid, 3 bbls 60/40 Meth, 53 bbls Crude 'and 2 bbls 60/40 meth into TBG. Final WHP's=1000/380/100 FLUIDS PUMPED BBLS 63 CRUDE 5 60/40 METH 11 10% HCL ACID 79 TOTAL 1. Operations Performed: o Abandon ~ I STATE OF ALASKA _ ,/'-'?~.t?? R ALA OILAND GAS CONSERVATION COM_ION k ECEIVED REPORT OF SUNDRY WELL OPERATIONS . )(?Æ, FEe 2 02007 181 Repair Well 181 Pull Tubing o Operation Shutdown as ons. COfTJmi s;on o Re-Enterâo~ Well 181 Other Change Out ESP o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): o Plug Perforations 0 Stimulate o Perforate New Pool 0 Waiver o Perforate 0 Time Extension 4. Well Class Before Work: 5. Permit To Drill Number: 181 Development 0 Exploratory 201-087 ¡ o Stratigraphic 0 Service 6. API Number: 50-029-23018-00-00 I 8. Property Designation: ADL 355018 ' 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Length Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 99519-6612 42.90 .¡ 9. Well Name and Number: MPF-86 j 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands I 11316 ( 7287 ( 11202 7176 feet feet Plugs (measured) N/A feet Junk (measured) N/A feet Size MD TVD 20" 112' 112' 9-5/8" 6518' 4269' 7" 33' - 11296' 33' - 7268' 5410 Burst Collapse 78' 6485' 5750 3090 11263' 7240 ~f~NNED FEB 2 6 2007 11048' - 11108' 7027' - 7085' 2-7/8",6.5#, L-80 10898' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): , r .. ' 7" HES 'VTA' Retrievable Packer _..,~. _ ...,' ..............".,...,.....,..t...... 10987' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Oil-Bbl Tubin Pressure Re resentative Dail Gas-Mcf Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 181 Daily Report of Well Operations 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Bryan McLellan, 564-5516 Title Technical Assistant Phone Sandra Stewman, 564-4750 Submit Original Only Prepared By Name/Number: r1 P , h 11\1 ^ I ~ 29/16", 5M ~ Wellhead :11" Gen 5 FM w/11 x 2-7/8" NSTC T&B gr. w/2.5" CIW 'H' BPV profile MPF-86 Size SPF Interval 112' 9-5/8" TAM Port COllar1010' 9-5/8", 40#/ft., L-80 BTRC I 6,517' I 2 7/8" 6.5 ppf, L-80 8rd EUE tubing (drift ID = 2.347", cap = 0.00592 bpf) 7" 26#/ft., L-80 BTC-MOD Production Casing, (Drift ID = 6.151", cap. = 0.0383 bpf KOP @ 400' to 3200' Max. Role Angle = 64 deg. Max. Hole Angle Thru Perfs. = 15 deg. Stimulation Summary: 152.8K# of 16/20 Carbolite and 48.3k# of 12/18 behind pipe Peñoration Summary: Ref. Log SWS jewelry log 8/10101 3-3/8" 6 3-3/8" 6 3-3/8" 6 11047'-11057 11064'-11074 11086'-11096 Bull Plug 111126'1 Nabors 3S FCC to 11128' 2-4-07 IA Tested to 1000 psi 2-4-07 OA.TE 8/06/01 08/25/01 6/4/06 2/6/07 ÆV. BY MDO M.Linder L Hulme M. Ross OJMMENTS Drill & Run Frac String. N-27E Initial perforations ESP Completion Nabors 3S FCO & Screens Added & ESP Completion Nabors 3S or;. Elev. = 42.9' (N27E) Ori Elev. = 10.9' RT t bg. Spool = 32.0' (N27E) Camco 2-7/8" x 1" sidepocket KBMM GLM I 170' I Camco 2-7/8" x 1" sidepocket KBMM GLM I 413' I Camco 2-7/8" x 1" sidepocket KBMM GLM 110637" I 2-7/8" XN nipple (ID 2.205") 110780'1 110825'1 110830'1 Discharge Head GPHVDIS Tandem Pumps 137P17 Model SXD 16GCNPSH Model GPMTAR 1:1 Tandem Gas Separator I 858' I GRSFTXAR H6 (400 Series Guts) 10 Intake 10858' MD = 6841' TVD Tandem Seal Section Model GSB3DB UTlL T S8/SB PFSA/FSA ClS 110862' Motor, 228 HP, 2305 volt, 60 amp, Model KMH 110876'1 Phoenix XT-1 w/ 6 Fin Centralizer Phoenix XT-1 TVD 110897' I 16880' I HES 'VTA' Retrievable Pkr 110987' I Weatherford Duragrip Screen 111042'-1111 ~' 500 MIcron (PBTD) 111,206' 7" Float Collar I 11,212'1 7" Float Shoe I 11,2961 MILNE POINT UNIT WELL MPF-86 (KUP) API No. 50-029-23018 BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-86 MPF-86 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 1/22/2007 Rig Release: 2/6/2007 Rig Number: N3S Spud Date: End: 1/22/2007 00:00 - 00:00 24.00 RIGD P PRE R&R transmission and prepare to RID and move off W-29. 1/23/2007 00:00 - 00:00 24.00 RIGD P PRE R&R transmission and prepare to RID and move off W-29. First and second gears in the replacement transmission were incorrectly assembled at Allison's rebuild facilities. The transmission was removed and stripped down by 1500-hrs, parts have been ordered. 1/24/2007 00:00 - 00:00 24.00 MOB PRE Change Transmission. 1/25/2007 00:00 - 18:00 18.00 MOB P PRE RID and pull away from W-29i. Move to MPF-86. 18:00 - 00:00 6.00 RIGU P PRE Spot Herculite, spot and set Carrier and Pits. 1/26/2007 00:00 - 05:00 5.00 RIGU P PRE Raise and Scope Derrick. RlU Steam Lines and Mud Lines. Construct berming for Tiger Tank. Lay hardline to Tiger Tank. 05:00 - 10:00 5.00 DHB P DECOMP Accept Rig @ 0500-hrs. PJSM. Pull BPV. T/IA= 010 psi. RlU lines to tree in Cellar to circ out the freze protect fluid. Test line to TT to 1,000-psi. Blow down and get ready to circulate. 10:00 - 16:00 6.00 KILL P DECOMP PJSM for Well Kill circulation. Starting pressures: Csg 11-psi, Tbg 70-psi, but both bled to zero immediately when circulation started. Took 60-Bbls to bring fluid to the surface, which was mostly oil in the returns. SID at 90-Bbls when flange started leaking in wing line from tree. Re-tighten bolts and bring circulation slowly up to 4-BPM with 560-psi on tubing and 140-psi on the casing. Bring rate up to 4-BPM. At 1330-hrs pumped 340-Bbls and had -270-Bbls returned to the Tiger Tank. Complete circulation, 480 Bbls circulated and 390 Bbls in Tiger Tank. Returns are clean seawater. Lost 90 Bbs to formation. T and IA = 0 psi. 16:00 - 17:30 1.50 KILL DECOMP Monitor well. T/IA=O/O psi. 17:30 - 18:30 1.00 DHB P DECOMP Install TWC. Attempt to Test from Below to 1000 psi. TWC is leaking. Bleed IA to 0 psi. IA is flowing pure crude oil. Decide to continue circulating. 18:30 - 19:45 1.25 DHB P DECOMP Pull TWC using Lubricator. 0 psi on Tubing. Line up to circulate down tubing while taking returns out the IA to the Tiger Tank. 19:45 - 22:00 2.25 KILL P DECOMP Thaw frozen Hardline. Circulate 70 Bbls of 120 degree seawater at 4 BPM and 980 psi while taking returns to the Tiger Tank. 22:00 - 00:00 2.00 KILL P DECOMP Monitor well. T/IA = 010 psi. Wait on seawater. 1/27/2007 00:00 - 01 :00 1.00 KILL P DECOMP Monitor Well and wait on Seawater. T/IA = 0/0 psi. 01 :00 - 04:00 3.00 DHB P DECOMP Install 2nd TWC with FMC hands on location. PIT from below to 1000 psi for 10 minutes and chart. Passed test. PIT from above to 3500 psi for 10 minutes and chart. Lost 750 psi in 2 minutes. Repeat test, failed again. Systematically eliminate other potential leak paths. TWC is leaking. Wells Support to bring 3rd TWCto location. Energize LDS and test again to 3500 psi from above. Test failed. 04:00 - 07:00 3.00 DHB P DECOMP Pull 2nd TWC with Lubricator. TWC looked clean and had no visible deficiencies. T/IA = 0/0 psi. Install 3rd TWC with Dry Rod with FMC on location. PIT from above to 3500 psi for 10 minutes and chart. Test to 1000 psi from below, lose 50 psi in 10 minutes. Test from above to 3500 psi and hold good for 10 minutes. 07:00 - 11 :30 4.50 DHB P DECOMP Blow down circ lines to tiger tank. Annulus pressure to 8 psi, fluid flowing past TWC and filling tree. Bleed annulus. Pressure from below to 100 psi, TWC holding, pressure loss of 20 psi in 20 min to 80 psi on annulus. No fluid flow past TWC. Printed: 2/12/2007 10:13:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-86 MPF-86 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 1/22/2007 Rig Release: 2/6/2007 Rig Number: N3S Spud Date: End: 1/27/2007 07:00 - 11 :30 4.50 DHB P DECOMP Test check from above to 500 psi, ok. Rig up and bleed annulus through 2" observing no flow past TWC. Diesel/crude in bleed back fluid. Shut in lA, 4 psi on gauge, fluid flowing up into tree past TWC. 12:00 - 16:00 4.00 KILL P DECOMP Call for MPU wells support crew. PU lubricator. Pull TWC. Fluid in tubing flowing past TWC wI minimal pressure, 40 psi on annulus. Pump 80 bbls down tbg, returns thru choke from annulus, to tiger tank. Close choke pressure to 2000 psi wI 3 bbls SW. Shut down and bleed 300 psi in 20 minutes. Open choke and circulate @ 4 BPM, 680 psi surface to surface. 16:00 - 17:00 1.00 KILL P DECOMP Discuss options with town and make decision to weight up to 9.0 brine. Call MI and Veco for trucks and 290 bbls of 120 deg F brine. 17:00 - 18:00 1.00 KILL P DECOMP 600 Bbls pumped.Shut down and check tbg and IA pressures. o pressure on Tbg, well flowing from annulus. 10 psi SI IA pressure. Continue to circulate SW until 9.0 # brine arrive on location. 18:00 - 00:00 6.00 KILL P DECOMP Another 1000 Bbls circulated.Shut down and check tbg and IA pressures @ OOOO-hrs. Well flowing from Tbg although gauge reads 0 psi, well flowing from annulus. 8 psi SI IA pressure. Continue to circulate SW until 9.0 # brine arrive on location. 1/28/2007 00:00 - 04:30 4.50 KILL P DECOMP Continue to circulate seawater until 9 ppg brine arrives. Pumping at 4 BPM and 860 psi. R/U sheave, Elephant Trunk, and 2-7/8" completion pulling equipment. 04:30 - 07:30 3.00 KILL P DECOMP Circulate 150 Bbls of seawater at 4 BPM and 860 psi while taking returns to the Tiger Tank. Circulate 421 Bbls of 9 ppg brine at 4 BPM and 1030 psi while taking returns to the Tiger Tank. Final circulation pressure on Tbg of 980 psi. 07:30 - 08:00 0.50 KILL P DECOMP o Tbg psi, 0 IA psi. IA on slight vacuum. Monitor for 30 minutes. PSJM for psi testing, ND/NU processes. 08:00 - 10:00 2.00 KILL P DECOMP Dry rod in TWC. Test from below to 800 psi, held like a jug. Test from above to 3500 psi and chart for 10 minutes. Bleed and rig down circulationlwell kill hard lines. 10:00 - 12:00 2.00 BOPSU P DECOMP ND Tree. FMC bleed test ports. Screw XO's for landing joint and Opso-Lopso into hanger to confirm integrity of the threads. 9 1/2 turns (to hand tight). Nipple up spacer spool wI 90 deg mud cross. PJSM for picking up 135/8" stack. Slide BOPE stack and cradle into cellar and stand upright. MU stack. 12:00 - 00:00 12.00 BOPSU DECOMP NU BOPE 1/29/2007 00:00 - 09:00 9.00 BOPSU DECOMP Test BOPE to 250 psi low and 3500 psi high. Test Annular Preventer to 3500 psi. Lou Grimaldi with AOGCC waived witness. Repaired stem packing on HCR. Blow down Choke and suck out stack. 09:00 - 10:00 1.00 PULL P DECOMP PU Opso-Lopso. Torque XO on bottom, screw into tubing hanger. RU pump in sub on Opso. MU lubricrator and pulling tool for TWC. Pull TWC. 0 psi on Tbg., IA on vacuum. 10:00 - 12:00 2.00 PULL P DECOMP BOLDS, Pull hanger to the floor wI 67K #'s PU weight. Fill hole with 5 Bbls. Rig not centered over well properly. Hang up on rotary table with Tbg Hgr. Attach tugger and pull pipe over and pull hanger above table. Cut and band ESP cable to Tbg. Check cable @ 4.0/3.9/3.9 ohms phase to phase, infinity to ground. Break out and lay down Tbg Hanger. RIH w/1 joint of DP. 40K #'s RIH weight. Printed: 2/12/2007 10:13:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-86 MPF-86 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 1/22/2007 Rig Release: 2/6/2007 Rig Number: N3S Spud Date: End: 1/29/2007 12:00 - 15:00 3.00 PULL N DECOMP Unable to properly use the pipe skate due to way the rig was spotted and rigged up. Secure the well with TIW valve. Work on upper skate section braces and adjust pipe shed location by jacking and shimming. 15:00 - 16:00 1.00 PULL P DECOMP PU singles of 2 7/8" Tubing and RIH to tag @ 10.986' (110' of fill). POH leave 1 joint of 2 7/8" without the cable across BOPE. Stab TIW valve and prep to slip and cut Drill line. 16:00 - 20:00 4.00 PULL P DECOMP Slip and cut Drill line. 20:00 - 21 :30 1.50 PULL P DECOMP PUMU RTTS and Storm Valve. RIH 2-jts and set @ 60'. POH and UD 2-jts. PIT to 1000 psi. 21 :30 - 00:00 2.50 PULL N DECOMP Blow down Stack and Lines. Remove Riser and de-energize Accumulator. Release tie down lines from Stack. Make a mark from Rotary Table to Stack as a reference point. 1/30/2007 00:00 - 01 :30 1.50 RIGD N SURE Inspect Derrick and prep for scoping down. Pull BOP Stack clear of braces for the upcoming jacking up of Carrier. Bleed air out of Derrick cylinders. 01 :30 - 02:30 1.00 RIGD N SURE PJSM. Scope and UD Derrick. 02:30 - 03:30 1.00 REST N SURE PJSM. Jack up back end of Carrier approximately 2" on oft-Driller's side and 3" on Driller's Side. 03:30 - 04:30 1.00 RIGU N SURE Raise and scope Derrick. 04:30 - 05:00 0.50 RIGU N SURE Lower Blocks and check adjustment. Adjustment is to high on Driller side of Carrier. 05:00 - 07:00 2.00 RIGU N SURE Scope and UD Derrick. Adjust level of sub structure. Raise and Scope Derrick. Check alignment of Blocks and level of sub. OK. 07:00 - 08:00 1.00 RIGU P SURE Rig up pitcher nipple and auxilliary equipment for de-completion. 08:00 - 10:00 2.00 PULL P SURE PU Storm valve stinger on 2 joints of 2 7/8" tubing. Sting into packer with 0 psi on tubing. Unseat packer. Well stable. Monitor then POH wI RTTS and Storm Valve. Break out and lay down. Rig is centered I leveled over the hole better than previously. Will need to be monitored prior to running ESP. 10:00 - 12:00 2.00 PULL P SURE RU elephant trunk and equipment for pulling ESP completion and spooling unit. Circulate well @ 3 BPM, 600 psi while rigging up. 12:00 - 14:30 2.50 PULL P SURE 150 Bbls pumped, well out of balance, flowing from Tbg. Circulate @ 4 BPM I 800 psi to condition brine prior to POOH. Pump surface to surface volume of 485 Bbls of 9 # brine. 0 losses. 14:30 - 00:00 9.50 PULL P SURE POH ESP and cable over shieve and attach to spooling unit. POOH standing back 2 7/8" Tbg in Derrick. 5 stnds OOH @ 1600 hrs; 32 stnds OOH @ 1830 hrs; 48 stnds OOH @ 2015 hrs; 89 stnds OOH @ 0000 hrs. Held D1 Drill - Kick While Tripping. 1/31/2007 00:00 - 07:00 7.00 PULL P SURE POH, standing back 2-7/8" tubing. 15 Bbls 9 # brine lost to formation while POOH. 07:00 - 10:00 3.00 PULL P SURE Break out and lay down ESP BHA. 10:00 - 11 :00 1.00 PULL P SURE C & C rig floor. 11 :00 - 00:00 13.00 CLEAN N SURE Phase 3 weather conditions on roads and pads. Secure well and standby on weather. 2/1/2007 00:00 - 06:00 6.00 CLEAN N SURE Phase 3 weather conditions on roads and pads. Secured well and standby on weather. Performed general rig housekeeping. 06:00 - 07:00 1.00 CLEAN N SURE Inspect Derrick and rig equipment post Blow. Well stable with Printed: 2/12/2007 10:13:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-86 MPF-86 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 1/22/2007 Rig Release: 2/6/2007 Rig Number: N3S Spud Date: End: 2/112007 06:00 - 07:00 1.00 CLEAN N SURE no losses during weather shutdown. 07:00 - 08:00 1.00 P DECOMP PUMU Baker BHA #1: 4 3/4" Sawtooth muleshoe, joint of 2 7/8" Tbg, 7" Csg scraper, bumper sub. 08:00 - 15:30 7.50 P DECOMP RIH wI FCO BHA on 2 7/8" Tbg from Derrick. 170 Stands total. 55K #'s PU wt, 35K 3's SO wt. No losses to formation. 15:30 - 16:00 0.50 P DECOMP Rig down elephant trunk. Prep to PU singles from the pipe shed. 16:00 - 18:00 2.00 P DECOMP Single in w/2 7/8" Tbg. Swap out elevators and rig up circulation lines and single in 1 joint of 27/8" PAC DPto tag fill @ 10986'. Establish reverse circulation. 2 BPM @ 325 psi on annulus I 3 BPM @ 550 psi on annulus. 18:00 - 00:00 6.00 P DECaMP Reverse circulate FCO from 10986' to 11034'. Rev circ 30 bbl Flo-Vis sweep to surface. CBU each joint down. 2/2/2007 00:00 - 06:00 6.00 P DECOMP Cant rev circ FCO from 11034' to 11124'. CBU each joint down. Recovered approx. 2 bbls of solids resembling frac sand, pieces of IBP rubber, and small rocks. Fluid loss rate varying from 20 - 50 bbl/hr while circ, no loss otherwise. Total losses during FCO of 160 Bbls (rate of 38 Bbls/Hr). Rev circ until returns clean. 06:00 - 09:00 3.00 P DECOMP POOH laying down 5 joints of 27/8" PAC DP. Change elevators, slips. MU circulating head and lines, circulate the long way @ 4 BPM 770 psi. Pump 30 Bbls of Flo-Vis sweep surface to surface. Well stable with no flow, and no losses. 09:00 - 12:00 3.00 P DECaMP RBIH picking up 6 singles of 2 7/8" Tbg. Tag @ 11124'. Reverse FCO to 11155'. PU to 11153' and reverse until clean returns. 12:00 - 15:00 3.00 P DECOMP POOH to 10990' and circulate the long way while waiting on 9.3 #/gal brine trucks to arrive. Circulate @ 2 1/2 BPM / 300 psi. 13 Bbls lost to formation in 2 hours. 15:00 - 20:00 5.00 P CLEAN Displace the hole with clean, filtered, 9.3 #/gal brine. 20:00 - 00:00 4.00 P CLEAN POOH standing back 2 7/8" Tbg in Derrick. Double displacement of Tbg as POOH. 2/3/2007 00:00 - 07:30 7.50 P CLEAN Cont POOH, standing back 2 7/8" tbg. Double displaced tbg as POOH. Shot well fluid levels of 100' and 200'. Filled rig pits with 9.3 ppg brine. Lost an additional 87 bbls fluid to formation. 07:30 - 09:00 1.50 P OTHCMP Break out and lay down Baker BHA. Lower shieve for ESP. 09:00 - 10:30 1.50 P OTHCMP ND riser. NU shooting flange and 10' lubricator extension. 10:30 - 12:30 2.00 P OTHCMP RU SLB wireline equipment, BOPE, Lubricator etc. on rig floor. 12:30 - 13:30 1.00 P OTHCMP PUMU PDS memory GR/CCL wI 6.01 " GR on bottom and 5.5" Swage on top. Fill hole with 24 Bbls of 9.3 # brine. 13:30 - 18:00 4.50 P OTHCMP RIH wI GR I GR-CCL I swage on rollerstem. RIH rate of 50 ftImin. Tag bottom @ 11109 ft. SLM. Log up for 500' and POOH wI logging tools. Log showed TD @ 11114' ELMD. 18:00 - 23:00 5.00 P OTHCMP RD SLB wireline equipment, BOPE, Lubricator etc. RD shooting flange and riser. Held PJSM prior to each discrete task. Filled well with 19 bbls 9.3 brine. 23:00 - 00:00 1.00 P OTHCMP RU, MU sand screenlpacker assembly. 2/4/2007 00:00 - 01 :30 1.50 P OTHCMP Cont MU sand screen/packer assembly. 01:30 - 10:00 8.50 P OTHCMP RIH with screenlpacker ass'y. 10:00 - 11 :30 1.50 P OTHCMP 175 Stands from Derrick. PU wt of 61 K #'s, SO wt of 36K #'s. PU single and tag bottom @ 11128' Tbg MD. Correct depths to ELMD. Load hole with 16 Bbls of 9.3 #/gal brine. MU head Printed: 2/12/2007 10:13:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-86 MPF-86 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 1/22/2007 Rig Release: 2/6/2007 Rig Number: N3S Spud Date: End: 2/412007 10:00 - 11 :30 1.50 P OTHCMP pin and circulation lines. Position BHA to ELMO as follows: bottom of screen=11, 112' I top of screen=11 ,042' I center of pkr elements=10,989' I Top of HES Versatrieve Pkr=10,987'. Drop ball 11 :30 - 12:30 1.00 P OTHCMP Pump down Tbg @ 1 1/2 BPM, 190 psi. Catch fluid @ 15 Bbls. Displace wI 44 Bbls total and ball on seat. Pressure to 750 psi and hold 5 minutes, pressure to 1500 psi and hold 5 minutes. Pull10K #'s overpulll SO 10K #'s down. Pressure to 2300 psi on tubing. 12:30 - 13:00 0.50 P OTHCMP Close annular and test packer and IA to 1000 psi. Held jug tight. Bleed pressure on IA to 0 psi. PU 7 K overpull. See pressure drop and release from packer at same time. 13:00 - 14:30 1.50 P OTHCMP PU 20' and circulate @ 3 BPM, 480 psi circ pressure. Hang shieve and prep for running ESP while circulating. 14:30 - 15:00 0.50 P OTHCMP Circulated bottoms up. Shut down observe well. Fluid level falling slowly. 15:00 - 23:30 8.50 P OTHCMP POOH lay down 6 stands of tubing. POOH standing back 2 7/8" tubing in the Derrick. Double displacement as POOH. 23:30 - 00:00 0.50 P OTHCMP Break out and lay down HES running tool. Load hole with 8 Bbls of 9.3 #/gal brine. 2/5/2007 00:00 - 01 :00 1.00 P OTHCMP Pulled wear ring. Prep rig floor for running ESP 01 :00 - 07:30 6.50 P RUNCMP MU ESP, RU to run same. Load hole with 18 Bbls prior to RIH. 07:30 - 18:00 10.50 P RUNCMP RIH wI ESP completion assembly on 2 7/8" Tbg. Load the hole wI 9.3 #/gal @ 12:00 noon. Well took 14 Bbls of fluid to fill. Losses of 2.8 bbls/hr. Filled hole with 18 bbls 9.3 ppg brine @ 1800 hrs; loss rate 3 bbls/hr. 117 stands in the hole @ 18:00 18:00 - 00:00 6.00 P RUNCMP Centralift make splice in cable 2/6/2007 00:00 - 02:00 2.00 N RUNCMP Centralift finish splice after 8 hours. 02:00 - 06:30 4.50 P RUNCMP RIH wI ESP completion ass'y on 2-718" tbg. Filled hole with 14 bbls 9.3 ppg brine @ 0030 hrs; loss rate approx. 2.5 bbls/hr. Held spill drill. 06:30 - 08:00 1.50 P RUNCMP Centralift cut and make up cable end for connecting to penetrator. Completion RIH with 3-Armsterguards (flat guards), 5-Protectolizers, and 180-LaSalle Clamps. 08:00 - 09:30 1.50 P RUNCMP PU wt of 75K #'s, SO wt of 45K #'s. Test penetrator and Phoenix gauge. BHT of 155 deg F, BHP of 3240 psi. 3.6 ohm phase to phase and 656 meg phase to ground. Land hanger and RILDS. Back out landing joint. 09:30 - 10:30 1.00 P RUNCMP Dry rod TWC. Attempt to test from below, pump 30 bbls wI 200 psi, no leakage. Test to 1000 psi from above and chart for 10 minutes. 10:30 - 15:30 5.00 P RUNCMP Nipple down BOPE. 15:30 - 20:00 4.50 P RUNCMP NU and tested tree to 5000 psi. Secured tree and cellar. Release rig @ 2000 hrs, 02/06/2007. Notified AOGCC (Crisp) of BOPE test on MPJ-08A. 20:00 - 00:00 4.00 P POST RD rig components. Move Centrilift spooler to enable Pipe Shed disconnect from Rig Carrier. Printed: 2/12/2007 10:13:41 AM . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To; AOGCC Records Department 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection[Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 Jewlery Log EDE Disk MPU F - 86 03-Feb-07 1 ) 2J 3J 4) 5J 6) 7) ~ED fEB 2 1 2007 c::::JD1- O~+ ~ /tl5tX).. Print Name: (1_ iL-- ~lt(i~l~~ {YbrA[AkRM 2 1 Z007 Signed : Date ~~l~ ûii& Gas C~ng. Anchorage PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: ?DSANCHORAGE@MEMCRYLOG.COM WEBSITE : \¡'",",Pi'J.MEMORYl..OG.COM C:\Docwnents and Settings\PDS Anchorage - MPLIDesktoplTransmit_Origjnal.doc N~ b) Ji lOb _ STATE OF ALASKA . ALAWA Oil AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS RECE\VED JUL 1 4 2006 01 & G Cons Commission àlA~ka I as 1. Operations Performed: Anchorage o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver 181 Other o Change Approved Program o Operation Shutdown 181 Perforate o Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 201-087 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23018-00-00 7. KB Elevation (ft): 42.90 9. Well Name and Number: MPF-86 8. Property Designation: 10. Field 1 Pool(s): ADL 355018 Milne Point Unit 1 Kuparuk River Sands 11. Present well condition summary Total depth: measured 11316 feet true vertical 7287 feet Plugs (measured) N/A Effective depth: measured 11202 feet Junk (measured) N/A true vertical 7176 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' Surface 6485' 9-518" 6518' 4269' 5750 3090 Intermediate Production 11263' 7" 33' -11296' 33' - 7268' 7240 5410 Liner ;;¡,{..: < ".'. , C~ or ""......^S~''\j<i..'' ...,... Perforation Depth MD (ft): 11 048' - 11108' Perforation Depth TVD (ft): 7027' - 7085' 2-7/8",6.5#, L-80 10897' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Dailv AveraQe Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl CasinQ Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: o Exploratory 181 Development o Service 181 Daily Report of Well Operations 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman Title Technical Assistant ~ "; __7 Prepared By Name/Number: S· t q{!;')'Ç 4/ j-~-"'" Phone 564-4750 Date C)l-/ :;; ('(['Sandra Stewman, 564-4750 '. Igna ure i" 'C"'I..A"þ\'- Form 1'0404 Revised'0472mf6 ~":." .". Submit Original Only ORiG r~AL (-y...Jþh..·-, MOMS 8FL JUl J 4 200& Iœ.e.;, 29/16", 5M ..a Wellhead :11" Gen 5 FM'-W w/11 x 2-7/8" T&B Hgr. w/2.5" CIW 'H' BPV profile 112' 9-5/8" TAM Port collar1010' KOP ~ 400' to 3200' Max. 140le Angle = 64 deg. Max. Hole Angle Thru Perfs. = 15 deg. 9-5/8", 40#/ft., L-80 BTRC 1 6,517' 27/8" 6.5 ppf, L-80 8 rd EUE tubing (drift ID = 2.347", cap = 0.00592 bpf) 7" 26#/ft., L-80 BTC-MOD Production Casing, (Drift ID = 6.151", cap. = 0.0383 bpf) Stimulation Summary: 152.8K# of 16/20 Carbolite and 48.3k# of 12/18 behind pipe Perforation SummarY: Ref. Log SWS jewelry log 8/10/01 Size SPF Interval TVD 3-3/8" 6 3-3/8" 6 3-3/8" 6 11047'-11057 7026'-7036' 11064'-11074 7043'-7053' 11086'-11096 7064'-7074' Tag TD 5/31/06 @ 11147' [)A.TE 8/06/01 08/25/01 9/26/01 6/4/06 ÆV. BY MOO M.Linder GMH L Hulme CX>MMENTS Drill & Run Frac String. N-27E Initial perforations ESP Completion Nabors 4ES ESP Completion Nabors 3S MPF-86 OriaB Elev. = 42.9' (N27E) Ori_L Elev. = 10.9' RT to Tbg. Spool = 32.0' (N27E) Cameo 2-7/8" x 1" sidepocket KBMM GLM 169' I Cameo 2-7/8" x 1" sidepocket KBMM GLM I 442' I Cameo 2-7/8" x 1" sidepocket KBMM GLM 110637" 1 2-7/8" XN nipple (ID 2.205") 110780'1 110821' 27/8" EU 8rd Discharge Head GPDIS Triple Tandem Pump, 27/122/18110822'1 GC2200/GC2200/P75 GPMTAR 1:1 & PMSXC 1:1 Tandem Gas Separator 110855' I GRSFTXAR(400 Series Guts) Intake 10855' MD = 6841' TVD Tandem Seal Section ModeJ GSB3DB UT/L T ABlHSN PFSAlFSA CL5 110860'1 Motor, 228 HP, 2305 volt, 60 amp, Model KMH 110874'1 PumpMate w/ 6 Fin Centralizer PumpMate TVD 110893'1 16878' I (PBTD) 111,206'1 7" Float Collar 111,212'1 T' Float Shoe I 11,2961 MILNE POINT UNIT WELL F-86 (KUP) API No. 50-029-23018 BP EXPLORATION (AK) e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-86 MPF-86 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 5/28/2006 Rig Release: 6/4/2006 Rig Number: N3S Spud Date: End: 6/4/2006 5/30/2006 00:01 - 19:30 19.48 RIGU P PRE MIRU Nabors 3S on MPF-86. 19:30 - 21 :00 1.50 RIGU P PRE Accept Rig at 2000-hrs. Rig up Tiger Tank, hardline, and choke and kill lines to Tree. 21 :00 - 21 :45 0.75 KILL P DECOMP PJSM. SITP = 630 psi, lAP = 870 psi, OAP = 0 psi. Bleed gas off tubing to Tiger Tank. 21 :45 - 22:05 0.33 KILL P DECOMP Break circulation down tubing with returns to Tiger Tank. Pump 1.0 BPM to establish parameters. Increase pump rate to 4.0 BPM @ 30 psi. Pump 63 bbls. to clear tubing to GLM @ 10630'. No returns to Tiger Tank noted. Shut in inner annulus and bullhead 20 bbls. to clear annulus below GLM and ESP to mid-perf at 11069'. 22:05 - 22:45 0.67 KILL P DECOMP SID pump and swap circulating lines to bullhead down IA. 22:45 - 00:00 1.25 KILL P DECOMP Close super choke and commence bullheading at 4.0 BPM at 20 psi. down inner annulus. SITP = 20 psi. Caught fluid at 250 bbls away. Slowed pump rate to 3.0 BPM. 5/31/2006 00:00 - 00:30 0.50 KILL P DECOMP Bullhead kill well at 3.0 BPM at 30 psi. lAP. lAP increasing to 350 psi at 330 bbls. away. Tubing and IA clear of wellbore fluids. 00:30 - 02:00 1.50 KILL P DECOMP Open super choke to take returns to Tiger Tank. lAP decreased to 140 psi and tubing pressure decreased to 30 psi. Increase pump rate to 3.5 BPM. lAP = 230 psi, Tubing pressure = 40 psi. Returned -70 bbls. to Tiger tank. Shut in tubing and bullhead an additional 190 bbls to perfs. Total fluid bullheaded to formation = 520 bbls. SID pump and allow pressure to bleed to formation. 02:00 - 03:00 1.00 KILL P DECOMP Open tubing to Tiger Tank and monitor well for no-flow. Tubing static and IA on vacuum. Rig down circulating lines. 03:00 - 04:00 1.00 WHSUR P DECOMP FMC set TWC. Tested good to 1000 psi from above. No test from below. Well on vacuum. 04:00 - 05:00 1.00 WHSUR P DECOMP NID production Tree. 05:00 - 15:30 10.50 BOPSU P DECOMP N/U BOPE. 15:30 - 19:30 4.00 BOPSU P DECOMP PT BOPE 250-psi low and 3,500-psi high. Chuck Scheve waived AOGCC witness of the BOPE tests. 19:30 - 20:15 0.75 PULL P DECOMP Rig up floor and ESP cable handling eqpt. 20:15 - 21:00 0.75 PULL P DECOMP PUMU lubricator. Pull TWC. UD lubricator. 21 :00 - 22:00 1.00 PULL P DECOMP P/U 2-7/8" EUE BRD. L80 landing it. M/U landing it. into tubing hanger. BOLDS. Unland and pull tubing hanger to rig floor. PUW = 95K. SOW = 41 K. Pump 23 bbls. seawater in hole for well control while RIH to tag fill. UD landing it. and tubing hanger. Cut ESP cable off 2' above first Lasalle cable clamp at top of first full joint of tubing below tubing hanger. Banded ESP cable w/7 each carbon steel 1-1/4" Superbands to tubing directly above Lasalle cable clamp. 22:00 - 23:30 1.50 PULL P DECOMP P/U 2-7/8" L80 8rd. tubing 1x1 and RIH to dry tag fill. Dry tag fill 4' in on it. #9 (11,147'). Set down on fill w/5K. POH and UD one it. tubing to come out on even stands in derrick. 23:30 - 00:00 0.50 PULL P DECOMP POH w/ESP completion standing tubing back in derrick. Pull 4 stds. and lay down 8' tubing pup that was in string directly below 3' pup screwed into tubing hanger. Filling hole with double pipe displacement every 5 stds. while POH. Strapping pipe in derrick as pipe is POH. 6/1/2006 00:00 - 13:00 13.00 PULL P DECOMP POH wlESP completion standing tubing back in derrick. Spooling ESP cable on empty cable reels in cable spooler. Printed: 6/5/2006 11 :45:23 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-86 MPF-86 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 5/28/2006 Rig Release: 6/4/2006 Rig Number: N3S Spud Date: End: 6/4/2006 6/1/2006 00:00 - 13:00 13.00 PULL P DECOMP Filling hole with double pipe displacement every 5 stds. while POH. Strapping pipe in derrick as pipe is POH. 132 jts. pulled and stood back in derrick at 0430-hrs. 13:00 - 19:00 6.00 PULL P DECOMP Break-out and UD ESP 18:00 - 19:30 1.50 PULL P DECOMP Clear and clean rig floor. Clear & clean pipe shed. Shoot sonic fluid shots to determine hole fill requirements for perf gun shot. First fluid shot @ 1900-hrs. = -1705 feet to fluid (3.1 seconds). Second fluid shot @ 1925_hrs. = 1760 feet to fluid (3.2 seconds). BHP calculated = 2369 psi. at 7048' mid-perf TVD. EMW = 6.35. 19:30 - 00:00 4.50 PULL P DECOMP Continue clear and clean floor and pipe shed. UD and replace bad jts. on stand #'s 162, 163 and 173. Prepare to PUMU TCP guns. 6/2/2006 00:00 - 03:00 3.00 PERFO P OTHCMP PUMU 40' of 4-1/2",6 SPF Power Jet Omega TCP guns - 2 x 20' guns, 1 blank gun - 1 x 10', gun puncher, CBF firing head, disconnect sub and RA PIP collar. Verified that 5/8" firing ball passes through disconnect sub. 03:00 - 09:00 6.00 PERFO P OTHCMP RIH wlTCP BHA on 2-7/8" EUE 8rd. L80 tubing to position guns for GRlCCL logging/correlation pass. Pump 30 bbls. water downhole for well control. xx stds. tubing RIH @ 0530-hrs. 59 stds. RIH @ 0515-hrs. Run rate -30 stds.lhr. SLB E-line unit arrived @ 0600-hrs; spot unit and RlU same. 09:00 - 10:00 1.00 PERFO P OTHCMP Tag fill with Gun Bottom Nose @ 11,134', space-out with 10' and 8' pup joints and set pipe in slips, with bottom of guns @ -11,133' . 10:00 - 11 :00 1.00 PERFO OTHCMP P/U and install SLB Pump-in Sub and Une Wiper and secure E-Une Sheaves. 11 :00 - 12:00 1.00 PERFO OTHCMP RIH with E-Une GR Tubing Correlation Log and correlate gun depth with formation. Find that guns are -30' high. Review original Tubing Tally and as-run tally and cannot find a "bust". Confer with engineers and decide to perforate interval from 11,068' to 11,108'. This will provide 12' of new perforations below the bottom of the existing perforations @ 11,096'. 12:00 - 15:00 3.00 PERFO P OTHCMP POH and RID SLB E-line equipment. 15:00 - 17:00 2.00 PERFO P OTHCMP Get Sonic Fluid Level at 2100'. Fill annulus with 100-Bbls. Drop and chase 5/8" ball with 35-Bbls at 2.5 BPM, 200-psi. Slow down pump rate to 1.5 BPM, 20-30 psi. See pressure start to build at 49-Bbls in, slow down pump rate to 1/2 BPM and guns fire at 2,700-psi at 1700-hrs. SLB recording instrument shows two tell-tale spikes indicating successful firing. 17:00 - 18:00 1.00 PERFO P OTHCMP POH and UD two pup joints, and SIB 2-stands of 2-7/8" tubing. Monitor well; well on vacuum. Install TIW valve and continue to monitor well; well on vacuum. 18:00 - 00:00 6.00 PERFO P OTHCMP POH and SIB tubing in Derrick. 5 stds. out at 1830-hrs. Shut down to shoot sonic fluid level shot. Unable to get fluid shot. Well on vacuum. 100 stds. OOH @ 2230-hrs. Fluid losses = 21-28 bbls/hr. Filling hole with produced water from MPU processing facility. 6/312006 00:00 - 01 :00 1.00 PERFO P OTHCMP POH wlTCP BHA and 2-7/8" Tubing. SID POH w/200 ft. tubing and guns in hole for PJSM with all crew. 01 :00 - 01 :30 0.50 PERFO P OTHCMP PJSM all crew. Review procedure and process for laying down TCP. Identified hazards and mitigating factors for hazards. 01 :30 - 03:00 1.50 PERFO P OTHCMP POH wlremaining 200' tubing and TCP guns. UD TCP BHA Printed: 6/5/2006 11 :45:23 AM , . e .. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-86 MPF-86 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 5/28/2006 Rig Release: 6/4/2006 Rig Number: N3S Spud Date: End: 6/4/2006 per Schlumberger service tech. No trapped pressure observed. All shots fired. Closed blind rams. 03:00 - 06:00 RUNCMP Clear and clean rig floor and pipe shed. Prep to PUMU new ESP equipment. Take sonic fluid level shot. Good shot - 2.3 sec. BHP = 2428 psi, EMW = 6.62 ppg. 06:00 - 09:30 3.50 RUNCMP P/U and M/U ESP Components. Pull ESP Cable over Sheave. Make cable connection to pigtail. 09:30 - 17:00 7.50 RUNCMP RIH new ESP Assembly on Tubing from Derrick. Stand #65 RIH @ 1430-hrs. Stand # 122 @ 1700-hrs. 17:00 - 20:30 3.50 RUNCMP Make Reel-to-Reel cable splice. 20:30 - 23:00 2.50 RUNCMP RIH new ESP Assembly on Tubing from Derrick. Pump 30 bbls. produced water down tubing through pump to clear pump of any possible debris. 23:00 - 00:00 1.00 RUNCMP P/U landing jt. and tubing hanger. MU tubing hanger. Centrilift make up lower field attachable connector splice. 6/4/2006 00:00 - 03:00 3.00 RUNCMP P/U landing jt. and tubing hanger. MU tubing hanger. Centrilift make up lower field attachable connector splice. 03:00 - 04:00 1.00 RUNCMP Land tubing hanger. RILDS. Dry rod set TWC and test to 1000 psi from above. P/U weight 77,000-lbs; SIO weight 45,000-lbs. Used 169 LaSalle clamps, 6 Protectolizers, and 3 Amsterguards (Flat Guards). 04:00 - 09:00 RUNCMP N/D BOPE. 09:00 - 12:00 RUNCMP N/U Adaptor Flange and Tree. Centrilift makes final conductivity tests--all good. Test Tree to 5,000 psi. P/U Lubricator, install on Tree, and pull TWC. Install BPV. Release Rig at 1200-hours. 12:00 - 22:00 10.00 RIGD P POST Rig down and prepare for move to MPC-24. Rig carrier broke down at 2300-hrs. on L pad. 22:00 - 00:00 2.00 RIGD P POST Rig pits and pipe shed on C pad @ OOOO-hrs. Printed: 6/5/2006 11 :45:23 AM e e .-~ ~·~'·'ch_, ~". MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _Marker. doc Permit to Drill 2010870 DATA SUBMITTAL COMPLIANCE REPORT 7/30/2003 Well Name/No. MILNE PT UNIT KR F-86 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-23018-00-00 MD 11316 TVD 7287 Completion Dat 8/10/2001 Completion Statu 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N._9o Sample N__9o Directional Survey o-N'5'--V ~ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt i~-~ C De Density (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH / Dataset Name Scale Media No Start Stop CH Received Number Comments 1 304 11316 Open 2/6/2002 Z.1-0537 ED ,ED C Ind Induction/Resistivity C Ne Neutron D Directional Survey Directional Survey 1 304 11316 Open 2/6/2002 "1'0537 1 304 11316 Open 2/6/2002 t'~537 FINAL ch 9/5/2001 FINAL ch 9/5/2001 Directional Survey Digital Data Directional Survey Paper Copy Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/~.¥ Chips Received? .--Y~' N- Analysis ~ R~.n~.iv~.d? Daily History Received? ~ N Formation Tops ~/N Date: 2/6/2002 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 1783 Company Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Milne Point F' Well Job # )tion Date CD Sepia BL MPF-86 21382 M10, DIN & CD~ 08/01/01 1 MPF-86 21382 MD CDR RESISTIVITY 08/01/01 1 1 MPF-86 21382 TVD CDR RESISTIVITY 08/01/01 1 1 MPF-86 21382 MD VISION D/N-QUADRANT 08/01/01 1 1 MPF-86 21382 TVD VISION DIN -QUADRANT 08/01/01 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc, Petrotectnical Data Center MB3-3 900 E, Benson Bivd, Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED FEB 0 8 2.00?_. .~ask80il & Gas Cons, Commis~i~r' Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie STATE OF ALASKA I" ALASKA OIL AND GAS CONSERVATION COMMIbSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service [] TSUSP 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-087 '3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23018-00 4. Location of well at surface .~ ~:'.?.' ,' .-'i'~'.--;"'i ' 9. Unit or Lease Name 2089' NSL, 2941' WEL, SEC. 06, T13N, R10E, UM i ~ ~ Milne Point Unit At top of productive interval I -~--.: ..... j..d.~_ 853' NSL, 4092' WEL, SEC. 36, T14N, R09E, UM ; V[_:i:;~:...:.;; : 10. Well Number At total depth i , 884' NSL, 4152' WEL, SEC. 36, T14N, R09E, UM~ ...... -,'~ -~['] ~ MPF-86 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Milne Point Unit / Kuparuk River Sands KBE = 42.90' ADL 355018 12. Date Spudded 113. DateT. D. Reached114. Date Comp., Susp., or Aband. 115. Water depth, if offshore 116. Nc. of Completions 7/17/2001 7/31/2001 8/10/2001 N/A MSL I One 17. Total Depth (MD.TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 11316 7287 FTI 11202 7176 FTI []Yes []NoI N/A MDI 1800'(Approx.) 22. Type Electric or Other Logs Run MWD, GR, GYRO, PWD 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 92# H-40 34' 112' 30" 260 SX Arctic Set (Approx.) 9-5/8" 40# L-80 33' 6518' 12-1/4" 1000 sx PF~ 225 sx of Class 'G' 7" 26# L-80 33' 11296' 8-1/2" 200 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 4 spf 2-7/8", 6.5#, L-80 10906' N/A' MD TVD MD TVD 11048' - 11050' 7027' - 7029' 11089' - 11090' 7067' - 7068' 26. AcD, FRACTURE, CEMENT SQUEEZE, ETC. 11096' - 11097' 7074' - 7075' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11047' - 11096' Fractured with 205200 #'s of Carbolite 16 / 20 and 12 / 18. Placed 201 100 #'s Behind pipe. 2000' Freeze Protected 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) September 04, 2001 Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR IOIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-Hour RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or wateb~j~,h~,, I.~ OCT 0 2 2001 Alaska 0il & Gas Cons. Commission ~ ~ I /'" I ~ I A! Anchorage Form 10-407 Rev. 07-01-80 ORIGINAL Submit In Duplicate ~9. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top of Kuparuk D 10879' 6864' Top of Kuparuk B 11023' 7003' Top of Kupauk A 11043' 7022' TKA3 11047' 7026' TKA2 11062' 7041' TKA1 11085' 7063' Top of Miluveach 11148' 7124' RECEIVED OCT 0 2 200 Alaska Oil & Gas Cons. Commission Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Post Rig Summary and Leak Off Test Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~/~)~ , ~~._ Title Technical Assistant Date MPF-86 201-087 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and Icg 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORIGINAL Legal Name: MPF-86 Common Name: MPF-86 Test D'~:: :Surface Pressure Leak Off Pressure (BHP) EMW 7/25/2001 LOT (ft) 4,040.0 (ft) (PPg) (psi) (psi) (PPg) 7/26/2001 LOT 66,566.0 (ft) 4,294.0 (ft) 8.90 (ppg) 625 (psi) 2,610 (psi) 11.70 (ppg) 7/27/2001 LOT 6,555.0 (ft) 4,294.0 (ft) 8.90 (ppg) 625 (psi) 2,610 (psi) 11.70 (ppg) Printed: 8/21/2001 3:58:33 PM BP AMOCO Page 1 of 7 Operations Summa Report Legal Well Name: MPF-86 Common Well Name: MPF-86 Spud Date: 7/17/2001 Event Name: DRILL+COMPLETE Start: 7/16/2001 End: Contractor Name: NABORS Rig Release: 8/6/2001 Rig Name: Nabors 27E Rig Number: Date From - To Hours IActivity Code NPT Phase Description of Operations 711712001 12:00 - 14:00 2.00 DRILL P SURF Calibrated MWD lab and tools - work on top drive bails 14:00 - 17:00 3.00 DRILL P SURF Pick up 5" HWDP and jars - Mixing spud mud 17:00 - 18:00 1.00 DRILL P SURF Divertor function test - witnessed by AOGCC Chuck Sheive 18:00 - 19:00 1.00 DRILL P SURF Clean floor and prepare to spud 19:00 - 20:30 1.50 DRILL P SURF Spud meeting with crew, MWD tech, DD, Pushers, Co Men, Tech Limit Trainer, Mud engineer's 20:30 - 22:00 1.50 DRILL P SURF RIH tag up 75' - started washing through conductor pipe from 75' to 97' 22:00 - 23:00 1.00 DRILL P SURF raise vis from 87 to 130 before drilling into the gravel - wash from 97' to 112' 23:00 - 23:30 0.50 DRILL P SURF Drlg from 112' to 160' - hi vis coming out stop to circ hole cond mud - RPM 40/50 - WOB 10/15 - SPM 100 - 415gpm - 800psi 23:30 - 00:00 0.50 DRILL P SURF circ and condition - hi-vis coming back - slow rate to keep from losing over shakers / over drilling nipple 7/18/2001 00:00 - 01:30 1.50 DRILL P SURF Circ and cond hi-vis mud - pump at reduced rate to keep from losing over shakers / drlg nipple 01:30 - 02:00 0.50 DRILL P SURF Drill from 160' to 185' with bit and hwdp to make room for directional BHA 02:00 - 02:30 0.50 DRILL P SURF POH - break bit off 5" hwdp and bit sub - stand back 02:30 - 09:00 6.50 DRILL P SURF Pick up directional BHA: Pick up Anadrill 9 5/8" Slow speed motor with 1.83 deg BH, Anadrill MWD / GR - Orient MWD - Make up Hughes MXC-1 jetted with 3-14's 1-11, Pick up 12 1/4" stabilizers and Monel drill collar 09:00 - 10:00 1.00 DRILL P SURF Break circulation at 130' - Pump pressure too high - 2300 psi at 210 gpm - Check surface equipment - ok 10:00 - 10:30 0.50 DRILL P SURF Pooh stand back BHA - Found two jets plugged with gravel- Suspect gravel in mud pits from mud running over back of #1 shale shaker 10:30 - 11:00 0.50 DRILL P SURF Pick up stand of Hwt drill pipe - Run in hole to 80' - Circulate thru open ended hwt to clean up mud system to prevent plugging bit. 11:00 - 13:00 2.00 DRILL P SURF make up same BHA as before - trip in to 160' - break circ - 400gpm - 600 psi 13:00 - 00:00 11.00 DRILL P SURF Tag bottom at 185 - directional drill ahead to 1105' - WOB 20~25 RPM 62 sliding 122 rotating - pump 120spm - 509gpm - 1170 psi 7/19/2001 00:00 - 01:00 1.00 DRILL P SURF Directional Drilling from 1105' to 1196' 01:00 - 01:30 0.50 DRILL P SURF Rig service top drive 01:30 - 05:00 3.50 DRILL P SURF Directional drill from 1196' to 1387' 550gpm 1200psi building angle at 2deg per 100 60 rpm - tq on btm 6k tq off btm 4k P/U 110 S/O 100k 05:00 - 05:30 0.50 DRILL P SURF Change oil in pipe handler on top drive 05:30 - 14:00 8.50 DRILL P SURF Directional drill from 1387' to to 2291' 500gpm 1225psi building 2deg per 100 - 60 rpm - tq on btm 7k tq off btm 5k P/U 115k S/O 105K 14:00 - 14:30 0.50 DRILL P SURF Circ sweep around for short trip 14:30 - 16:00 1.50 DRILL P SURF Short trip from 2130' to 997' - pump out 10 stds - pull 4 stds - hole in good shape 16:00 - 17:00 1.00 DRILL P SURF Service top drive 17:00 - 18:00 1.00 DRILL P SURF Trip in hole - no tight spots seen - hole in good condition - precautionary wash from 2223' to 2291' 18:00 - 21:30 3.50 DRILL P SURF Directional drilling from 2291' to 2665' building 2.5 per 100 - 500 gpm 1250 psi 60rpm tq 8k on btm 5k off btm P/U 130k S/O Printed: 8/21/2001 3:58:44 PM BP AMOCO Page 2 of 7 Operations Summary Report Legal Well Name: MPF-86 Common Well Name: MPF-86 Spud Date: 7/17/2001 Event Name: DRILL+COMPLETE Start: 7/16/2001 End: Contractor Name: NABORS Rig Release: 8/6/2001 Rig Name: Nabors 27E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/19/2001 18:00-21:30 3.50 DRILL P SURF 110k 21:30 - 22:30 1.00 DRILL N 'RREP SURF Hi-line power down - start rig engines #3 engine on line at 21:45hrs #1 engine on line at 22:15hrs ~ engine on line at 22:45hrs. (ground fault -will investigate to determine cause in the A.M.) 22:30 - 00:00 1.50 DRILL P SURF Directional drilling from 2665' to 2793' (hi-line power back on rig engines off line) WOB 25 - RPM 60 (sliding 62) Rotating 122 - tq on btm 9K - tq off btm 6k - spm 122 - gpm 500 - 1400 psi - P/U 140k - SO 115k 7/20/2001 00:00 - 09:30 9.50 DRILL P SURF Directional drilling from 2793' to 3700' - WOB 20/30, RPM 60, GPM 550, 2000 psi on btm, 1900, psi off btm, tq on btm 10/12k, tq off btm 8/9k, P/U 140k, S/115k 09:30 - 10:30 1.00 DRILL P SURF Circulate bottoms up for short trip 10:30 - 13:00 2.50 DRILL P SURF Short trip from 3700' to 1380' - pump out 20 stds - pull 5 stds to 1380' 13:00 - 14:00 1.00 DRILL P SURF Rig service top drive - drawworks 14:00 - 15:00 1.00 DRILL P SURF RIH from 1380' to 3700' - hole in good shape 15:00 - 23:00 8.00 DRILL P SURF Directional Drill from 3700' to 4603' - WOB 20/30, RPM 60, GPM 630, 2200 on btm, 2000, off btm, tq on btm 10/12k, tq off btm 8/9k, P/U 155k, S/O 115k, 23:00 - 00:00 1.00 DRILL P SURF Circ/clean hole with one pump 120 spm - change swab in pump #1 7/21/2001 00:00 - 13:00 13.00 DRILL P SURF Driectional drill from 4603' to 5797' WOB 20/30, Rpm 60, GPM 630, 2400 psi, tq on btm 14-17, tq off btm 12-13, P/U 160, S/O 125 13:00 - 13:30 0.50 DRILL P SURF Pick up wt increasing to 30K over normal - Circulate, Increase flow rate 635 gpm to 677 gpm - increase RPM while circulating to 80 from 60 while drilling 13:30 - 00:00 10.50 DRILL P SURF Directional drill from 5797' to 6533 MD' WOB 20/30 Rpm 80, GPM 677, 2700psi on btm, 2500psi off btm, tq on btm 13-15, tq off btm 11-13, P/U 145, S/O 125- TD surface hole at 6,533' MD, 4277 TVD 7/22/2001 00:00 - 02:30 2.50 DRILL P SURF Circ condition mud and hole for short trip - 677gpm - 2700 psi - 80 rpm - tq 12k/13k - circ two bottoms 02:30 - 08:30 6.00 DRILL P SURF Short trip from 6533' to 820' - pumped out from 6533' to 5698' - 110 spm at 1300psi - pull to 3970' tight - pump out from 3980' to 3726' work each stand to clean up hole section - 140spm - 1650psi - 25k overpull - con't pooh from 3726' to 820' w/o pump 08:30 - 09:00 0.50 DRILL 3 SURF Clean rig floor from short trip - pulled wet. 09:00 - 09:30 0.50 DRILL ~ SURF Rig service top drive - crown :09:30 - 13:00 3.50 DRILL 3 SURF RIH from 820' to 6533'- hole in good shape no problems on trip in 13:00 - 16:00 3.00 DRILL ~ SURF Circ / condition mud and hole for 9 5/8" casing - GPM 677 - ;2700 psi- RPM 80 16:00 - 21:30 5.50 DRILL 3 SURF POOH to run 9 5/8" casing to bha 21:30 - 22:00 0.50 DRILL ~ SURF PJSM (laying down bha - new hands not done this task) 21:30 - 00:00 2.50 DRILL ~ SURF Lay down BH^ - Lay down - XO, 3 NMDC, 1 MWD, 3 NM STAB - break bit off motor - drain motor 7/23/2001 00:00 - 00:30 0.50 DRILL ~ SURF Con't lay down bha - 2 NM lead collars - 9 5/8" motor & bit - Bit in good condition 00:30 - 01:00 0.50 DRILL ~ SURF Clean rig floor 01:00 - 04:00 3.00 DRILL ~ SURF Rig up Nabors 350 ton casing equipment to run 9 5/8" casing 04:00 - 04:30 0.50 DRILL P SURF PJSM (running casing) Printed: 8/21/2001 3:58:44 PM BP AMOCO Page 3 of 7 Operations Summary Report Legal Well Name: MPF-86 Common Well Name: MPF-86 Spud Date: 7/17/2001 Event Name: DRILL+COMPLETE Start: 7/16/2001 End: Contractor Name: NABORS Rig Release: 8/6/2001 Rig Name: Nabors 27E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/23/2001 04:30 - 06:30 2.00 DRILL P SURF Running 9 5/8" casing (total joints run 160, 9 5~8" 40# Buttress, feet ran 6473.94, shoe at 6517.62, float collar 6433') torque 9,000 ft/# 06:30 - 07:00 0.50 DRILL N SFAL SURF Hi-line power dropped off - due to Milne Point electrical relay -Start rig engines - on rig power at 0630 hrs - 10 minutes to get one warn engine on line - 30 minutes to get two engines on line 07:00 - 15:30 8.50 DRILL P SURF Running 9 5~8" casing - Land casing on btm @ 15:30 hrs - Shoe depth at 6518' - F/C 6433' - Ran total of 160 jts 15:30 - 18:00 2.50 DRILL P SURF Circulate and condition hole / mud for cement job (circ rate 107 stks at 450 gpm, 750 psi, 2 casing volumes) - did not reciprocate casing 18:00 - 18:30 0.50 DRILL P SURF Rig up cement head and lines - Hold PJSM (on cementing) 18:30 - 00:00 5.50 DRILL P SURF Cement 9 5/8" casing - Pump 5 bbls water - test lines to 4000 psi - drop btm plug - pump 45 bbls water - pumped 75 bbls of Alpha spacer mixed at 10.5ppg added dye in first 5 bbls pumped - dropped 2nd btm plug - mixed and pumped 1000 sxs, 739 bbls, of Class L, yield 4.15 cf/sx, 10.7ppg - 225 sxs, 46 bbls, Class G, yield 1.15 cf/sx, of 15.8 ppg cement- dropped top plug- displaced with 30 bbls water Howco - 461 bbls of mud with rig pump - Bump plug with 1950 psi, 4574 stks - bleed off pressure check floats ok - 200 bbls cement to surface. 7/24/2001 00:00 - 00:30 0.50 CEMT P SURF Flush 20" diverter system with fresh water until clean 00:30 - 04:30 4.00 CEMT P SURF Lay down Halliburton cement head, Landing jr., Lay down Nabors casing tools & Franks fill up tool 04:30 - 11:00 6.50 BOPSUF P SURF Nipple down and remove 20" diverter system from cellar 11:00 - 13:00 2.00 WHSUR P PROD1 Install FMC slip on x 11" 5000 Casing head, Nipple up FMC Gen 5 11" 5000 x 11" 5000# Tubing head - Test Casing head to 1000 psi - ok - Nipple up 11" 5000 x 13 5/8" 5000# adapter spool 13:00 - 20:00 7.00 BOPSUF P PROD1 Nipple up Hydril113 5/8" 5000# BOP stack - Install 4 1/2" x 7" variable bore rams in top set, Blind rams in middle, 5" pipe rams in bottom 20:00 - 00:00 4.00 BOPSUF P PROD1 Pre-Job safety meeting - Rig up test joint and lines - Test BOP to 3500 psi high/250 Iow - Repair leak on Choke line unibolt - Continue testing Bop at 00:00 hrs 7/25/2001 00:00 - 08:30 8.50 BOPSUF P PROD1 Continue testing Bop: Test all rams, lines and valve to 3500 high / 250 Iow - Test annular to 2500 high / 250 Iow - Test floor valve, Top drive IBOP and Manual valve to 3500 and 250 - Valve #6 & #3 on choke manifold failed to test - Repair leak on choke line Uni-bolt. Trip tank monitor did not work. - Choke manifold valves to be repaired and tested before drilling out of shoe. bop test was witness by John Crisp of ^OGCC 08:30 - 11:00 2.50 BOPSUF P PROD1 N/U drilling nipple and remodify same 11:00 - 12:00 1.00 BOPSUIq P PROD1 prejob safey meeting and install wear ring 12:00 - 14:00 2.00 BOPSUIq P PROD1 N/U drip pan under floor and install flow line 14:00 - 16:00 2.00 DRILL P PROD1 Picking up motor and BHA, Bit # 2 SD566, Motor 6 3/4 ×P motor 1.15 w/8 3/8 stab, NM dc, NM stab, cdr, mwd, adh w/ source, 2 NM flex dcs, xo, 4 jts hwdp, jars, 16 jts hwdp 16:00 - 16:30 0.50 DRILL P PROD1 Load source in logging tool 16:30 - 17:00 0.50 DRILL P PROD1 Tripping in with hw pipe Printed: 8/21/2001 3:58:44 PM BP AMOCO Page 4 of 7 Operations Summary Report Legal Well Name: MPF-86 Common Well Name: MPF-86 Spud Date: 7/17/2001 Event Name: DRILL+COMPLETE Start: 7/16/2001 End: Contractor Name: NABORS Rig Release: 8/6/2001 Rig Name: Nabors 27E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/25/2001 17:00 - 18:30 1.50 DRILL N DFAL PROD1 Attemt to cir¢ plugged string, pull out with wet string, motor plugged not bit, lay down motor 18:30- 19:00 0.50 DRILL N DFAL PROD1 Clearfloor 19:00 - 19:30 0.50 DRILL N DFAL PROD1 Picked up one stand of hw pipe and ¢irc pit volume 450 bbls 19:30 - 22:30 3.00 DRILL N DFAL PROD1 Picking up new motor, had to break float sub off plugged motor and install on new motor, Trip in with bha 22:30 - 23:00 0.50 DRILL P PROD1 check shot survey 23:00 - 00:00 1.00 DRILL P PROD1 Picking up drill pipe out of pipe shed, circ ever 50 jts 7/26/2001 00:00 - 06:00 6.00 DRILL P PROD1 Picking up drill pipe 06:00 - 06:30 0.50 DRILL P PROD1 Trip in w/4 sd. of pipe to 6250 06:30 - 07:00 0.50 DRILL P PROD1 Madpass from 6250 to 6427 tag cement @ 6427 07:00 - 07:30 0.50 DRILL P PROD1 Circ for csg test 07:30 - 08:30 1.00 DRILL P PROD1 Test 9 5/8 csg to 3500 for 30 min ok 08:30 - 09:30 1.00 DRILL P PROD1 Rig up Schlumberger 09:30 - 10:30 1.00 DRILL N DFAL PROD1 Run #1 Gyro tool failed shorting out 10:30 - 12:00 1.50 DRILL N DF^L PROD1 Pull and repair logging tool, rehead 12:00 - 14:00 2.00 DRILL N DFAL PROD1 Run #2 Gyro run tool in to 5660 hung tool in top of HW pipe had to pull free, tool not reading proper 14:00 - 16:30 2.50 DRILL N DFAL PROD1 Pull out of hole with gyro 16:30 - 18:00 1.50 DRILL N DFAL PROD1 Rehead and change out Gyro 18:00 - 21:00 3.00 DRILL P PROD1 Run #3 run in and gyro from 5600 ft. 21:00 - 21:30 0.50 DRILL P PROD1 Rig down Schlumberger 21:30 - 22:30 1.00 DRILL P PROD1 Drilling cement and float and shoe from 6427 to 6533 22:30 - 23:00 0.50 DRILL P PROD1 Drilling from 6533 to 6566 23:00 - 00:00 1.00 DRILL P PROD1 Circ for LOT 7/27/2001 00:00 - 00:30 0.50 DRILL P PROD1 Circ. @ shoe 00:30 - 01:30 1.00 DRILL P PROD1 Attempt PWD test no data MWD Failure 01:30 - 02:30 1.00 DRILL P PROD1 Leak off test with 8.9 mw and 625# pump press. = 11.7 emw done leak off three times 02:30 - 03:00 0.50 DRILL N DF^L PROD1 Attempt PWD test no data MWD failure 03:00- 06:00 3.00 DRILL N DFAL PROD1 Trip out for MWD tool 06:00- 09:00 3.00 DRILL N DFAL PROD1 Down load ADW-CDR 09:00 - 10:00 1.00 DRILL P PROD1 Service topdrive and service wear ring 10:00 - 13:00 3.00 DRILL N DFAL PROD1 Lay down MWD and picked up new Mwd and & CDR& orient tools 13:00- 16:30 3.50 DRILL N DFAL PROD1 Trip in to 6427 16:30 - 17:30 1.00 DRILL P PROD1 Cut drlg line 80 ft. 17:30- 18:30 1.00 DRILL N RREP PROD1 Repair brakes 18:30- 19:30 1.00 DRILL N RREP PROD1 Repair Gripper on top drive 19:30 - 21:30 2.00 DRILL P PROD1 PWD test ( had to unplug jets in bit) 21:30 - 22:00 0.50 DRILL ,P PROD1 Drilling to 6614 22:00 - 23:00 1.00 DRILL N RREP PROD1 Repair hyd. line on topdrive 23:00 - 00:00 1.00 DRILL P PROD1 Drill and slide drill from 6614 to 6771 ,bit wt 6000 to 12000, rpm 70 530 gals min @ 1600 #, rt time .7 slide time .3 ECD starting was 9.6 7/28/2001 00:00 - 12:30 12.50 DRILL P PROD1 Drill and slide drill from 6771 to 7928 ,bit wt 6000 to 12000, rpm 120, 544 gals min @ 2450 #, ECD 11.0 12:30 - 13:30 1.00 DRILL P PROD1 circ to lower ECD drop to 10.7 13:30 - 17:00 3.50 DRILL P PROD1 Drill and slide drill from 7928 to 8210 ,bit wt 6000 to 12000, rpm 120, 544 gals rain @ 2450 #, 17:00 - 17:30 0.50 DRILL P PROD1 Service rig Printed: 8/21/2001 3:58:44 PM BP AMOCO Page 5 of 7 Operations Summa Report Legal Well Name: MPF-86 Common Well Name: MPF-86 Spud Date: 7/17/2001 Event Name: DRILL+COMPLETE Start: 7/16/2001 End: Contractor Name: NABORS Rig Release: 8/6/2001 Rig Name: Nabors 27E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/28/2001 17:30 - 22:30 5.00 DRILL P PROD1 Drill and slide drill from 8210 to 8678 ,bit wt 10000 to 12000, rpm 120, 544 gals min @ 2500 # 22:30 - 23:30 1.00 DRILL P PROD1 Cir¢ to lower ECD 11.2 to 10.6, started Lubetex for 2% over two circ. 23:30 - 00:00 0.50 DRILL P PROD1 Drill and slide drill from 8678 to 8710 ,bit wt 10000 to 12000, rpm 120, 544 gals min @ 2500 # 7/29/2001 00:00 - 19:30 19.50 DRILL P PROD1 Continue Directional drill 8,710 to 9894 - Art 7.5 hrs, Ast 9.75 hrs, Average Rop 68.6 fi/hr - Start angle drop section at 9,049' - drop angle at 3 deg / 100' - Add 2% lub-tex to mud system at 8,700' - reduce torque from 21,000 Ft/Ib to 19,000 fi/lb - Added 1% FIo-lube to mud system at 9,400'- Reduced torque from 19 to 20,000 fi/lb to 15 to 17,000 fi/lbs - Maintain mud wt. 9.1 ppg - Pumping 550 gpm, 2650 psi- 120 rpm -Wob 10-12,000 lbs 19:30 - 20:00 0.50 DRILL P PROD1 Service rig 20:00 - 00:00 4.00 DRILL P PROD1 Continue Directional drill to 9894 to 9995 - Art .50 hrs, Asr 2.75 hrs, Average Rop 31.0 fi/hr Maintain mud wt. 9.1 ppg - Pumping 550 gpm, 2650 psi - 120 rpm - Wob 10-12,000 lbs 7/30/2001 00:00 - 11:30 11.50 DRILL P PROD1 Continue Directional drill to 9995 to 10426 - Art 2 hrs, Asr 6 hrs, Average Rop 53.8 fi/hr Maintain mud wt. 9.1 ppg - Pumping 550 gpm, 2650 psi - 120 rpm - Wob 10-12,000 lbs 11:30 - 14:00 2.50 DRILL P PROD1 Circ, 3 bottoms up, monitor well 14:00 - 16:00 2.00 DRILL P PROD1 Tripping out to 6517 no problem, hole in good shape 116:00 - 17:00 1.00 DRILL P PROD1 Service rig 117:00 - 18:00 1.00 DRILL N RREP PROD1 Repaired top drive 18:00 - 20:30 2.50 DRILL P PROD1 Tripping in to bottom, 10426 no problems 20:30 - 21:00 0.50 DRILL P PROD1 Wash and ream to bottom 60 ft. no fill 21:00 - 00:00 3.00 DRILL P PROD1 Continue Directional drill 10426 to 10553 - Art .50 hrs, Asr 2 hrs, Average Rop 50.8 fi/hr raising mud wt. to 9.6 ppg - Pumping 550 gpm, 2800 psi- 120 rpm -Wob 10-12,000 lbs 7/31/2001 00:00 - 15:30 15.50 DRILL P PROD1 Continue Directional drill 10553 to TD @ 11316 - Art 7.5 hrs, Asr 3.5 hrs, Average Rop 69.3 fi/hr mud wt. 9.6 ppg - Pumping 550 gpm, 2800 psi - 120 rpm - Wob 10-12,000 lbs 15:30 - 17:30 2.00 DRILL P PROD1 Cir¢ 3 bottoms up rt. 120 RPM 550 GPM 2800#PP 17:30 - 19:00 1.50 DRILL P PROD1 Monitor well, pull 25 sds. out no problems 19:00 - 19:30 0.50 DRILL P PROD1 Service rig 19:30 - 20:30 1.00 DRILL P PROD1 Trip in, wash 90 ft. to bottom, no problems, no fill 20:30 - 23:00 2.50 DRILL P PROD1 Circ 4 bottoms up, rt. 120RPM 550 GPM 2800#PP 23:00 - 00:00 1.00 DRILL P PROD1 Monitor well, tripping out for csg, getting torque and drag, sim 8/1/2001 00:00 - 07:00 7.00 DRILL P PROD1 Tripping out getting tq. and drag data 07:00 - 11:00 4.00 DRILL P PROD1 Laying down HW pipe and BHA, down load ADW tool 11:00 - 11:30 0.50 DRILL P PROD1 Clear floor of tools 11:30- 12:00 0.50 DRILL P PROD1 Pull wear ring 12:00 - 15:00 3.00 DRILL P PROD1 Rig up csg tools 15:00 - 15:30 0.50 DRILL P PROD1 PJSM on running csg 15:30 - 23:00 7.50 DRILL P PROD1 Picking up 155 jts 7 in, csg run turbos on first 27 jts, make up tq 8500#, getting pick up and slack off every 10 jts. 23:00 - 00:00 1.00 DRILL P PROD1 circ @ csg shoe 6500, thin mud, total 4300 ps, 6 bbls min 550 psi 8/4/2001 00:00 - 09:30 9.50 CEMT N DPRB PROD1 Tripped in hole with singles of 3-1/2" drill pipe to 10889'. 09:30- 11:30 2.00 CEMT N DPRB PROD1 Washed from 10889'to 11206' (float collar at 11212'). No firm cement in casing. Rt. 75 rpms 10,000 torque PP 1200# 5 bbls min Printed: 8/21/2001 3:58:44 PM BP AMOCO Page 6 of 7 Operations Summary Report Legal Well Name: MPF-86 Common Well Name: MPF-86 Spud Date: 7/17/2001 Event Name: DRILL+COMPLETE Start: 7/16/2001 End: Contractor Name: NABORS Rig Release: 8/6/2001 Rig Name: Nabors 27E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/4/2001 09:30 - 11:30 2.00 CEMT N DPRB PROD1 11:30 - 13:00 1.50 CEMT N DPRB I pROD1 Pumped 70 bbls high vis sweep and circulated hole clean. No cement with bottoms up. 13:00 - 15:30 2.50 CASE P PROD1 Pressure tested casing to 3500 psi for 30 minutes. Lost 350 psi in 30 minutes. Isolated pumps and standpipe valves, pressure tested 7" casing to 3500 psi for 30 minutes. Lost 100 psi in 30 minutes - good test. 15:30 - 18:00 2.50 CASE N DPRB PROD1 Pump Sweep, displace hole with seawater 72spm 2150psi 18:00 - 00:00 6.00 CASE N DPRB PROD1 Lay down 3.5 pipe (250 jts) 8/5/2001 00:00 - 02:30 2.50 CASE N DPRB PROD1 Finished laying down 3-1/2" drill pipe. 02:30 - 03:30 1.00 CASE N DPRB PROD1 Laid down BHA. 103:30 - 07:00 3.50 BOPSUF.N DPRB PROD1 Pulled 3-1/2" block rams and installed 4-1/2" X 7" varible bore rams and tested ram body to 500 psi. ~07:00 - 08:00 1.00 CASE P PROD1 Rigged up tubing tongs and tubing running equipment. 08:00 - 19:30 11.50 CASE P PROD1 Made up WLEG and XN nipple assembly with RHC plug installed, 7' X 4-1/2" Premier Packer, Baker CMU sliding sleeve with 3.81" ' X' profile, 4 jts of 4-1/2" 12.6# L-80 IBT tubing and 4-1/2" X 1" KBG-2-LS GLM with RP shear valve. Finished running 252 jts 4-1/2" 12.6# L-80 IBT tubing to surface, pick up wt 160,000 slack off 100,000 19:30 - 21:00 1.50 CASE P PROD1 Pick up hanger and land tubing and w/TWC tested TWC to 1000# 21:00 - 00:00 3.00 CASE P PROD1 Change lower rams to 3.5 in and nipple down BOPS 8/6/2001 00:00 - 01:30 1.50 BOPSUF.P PROD1 Finished nippling down BOP stack. 01:30 - 03:30 2.00 WHSUR P PROD1 Nippled up 4-1/16" 5000 psi Gen 5 tree. 03:30 - 04:30 1.00 WHSUR P PROD1 Tested tubing hanger and tree to 5000 psi for 10 minutes. Pulled TWC. 04:30 - 07:00 2.50 WHSUR P PROD1 Dropped 1-7/8" ball and waited for ball to set in RHC plug at 10815'. Attempted to pressure up on tubing and ball was not seated. Rigged up circulating lines and circulated ball on seat. 07:00 - 09:00 2.00 WHSUR P PROD1 Pressure up on tubing to 2500 psi to set slips on packer and 4200 psi to set elements. Held 4200 psi for 10 minutes. Bled pressure back to 3500 psi and tested tubing to 3500 psi for 30 minutes and recorded on chart. Good test. Bled pressure on tubing to 2500 psi and pressure tested annulus to 3500 psi for 30 minutes and recorded on chart. Good annulus test. Bleed pressure off of tubing and sheared RP shear valve. 09:00 - 12:30 3.50 WHSUR P PROD1 Pumped 70 bbls of diesel down the tubing taking returns to the pits. Hooked up jumper line to annulus and allowed diesel to U-tube into the annulus. Freeze protected to 2000'. Printed: 8/21/2001 3:58:44 PM BP AMOCO Page 7 of 7 Operations Summary Report I Legal Well Name: MPF-86 Common Well Name: MPF-86 Spud Date: 7/17/2001 Event Name: DRILL+COMPLETE Start: 7/16/2001 End: Contractor Name: NABORS Rig Release: 8/6/2001 Rig Name: Nabors 27E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/6/2001 12:30 - 13:30 1.00 WHSUR P PROD1 Set BPV in tubing hanger and secure well. Remove extra annulus valve from wellhead. 13:30 - 16:30 3.00 WHSUR P PROD1 Change top drive back to 5 in, Cut drilling line RIG RELEASE FOR RIG MOVE 16:30 hrs 8/6/2001 Printed: 8/21/2001 3:58:44 PM Well: MPF-86 Rig Accept: 07/16/01 Field: Milne Point Unit / Kuparuk River Sands Rig Spud: 07/17/01 APl: 50-029-23018-00 Rig Release: 08/06/01 Permit: 201-087 Drilling Rig: Nabors 27E POST - RIG WORK 08/10101 Four holes shot in the 'Al ', two at 11096' - 11097' and two at 11089'- 11090'. Four shots in the 'A2' in three-foot interval at 11068' - 11071 '. A Baker bridge plug was set between the intervals with Petredat gauges hung below them. Another set of gauges was run in the XN-Nipple. 08/17/01 Pulled Baker IBP with gauges. 08118/01 & 08119/01 Perforate 11048' - 11050' with 2.5" power jet 4 shots, set Baker IBP above the 'A' sands at 11060'. 08/22/01 Pulled IBP. 08126/01 Fractured 'A' Sands perforating 11047' - 11096' with 205.2K# Carbolite (157# 16 / 20 and 48.3K# 12 / 18). Placed 201.1K# behind pipe, left 4.2# in CSG EST TOS = 11045' MD. Intentionally under flushed by 7 bbls with 20# GEL water to surface, well not freeze protected. 08/27/01 Tagged fill at 9910' SLM. 08128/01 MIRU CTU #5, RIH with TS #1 pumping minimum rate until 9800', increase pump rate to 2 BPM. Wash down to 10160'; chase 3 BIO slugs to 4100'. Dry tag Carbolite at 10932' CTMD. Clean out to PBTD of 11189' CTMD. POH circulating freeze protect Well to 2500' with Methanol. 08/30/01 RIH with 3" BDN, Attempt to reverse but unable to raise WHP sufficiently, 3 BPM = 400 WHP, .5 BPM returns. Unable to reverse well, jet FCO from 6200' CTD, Consistent 1:1 returns on bbl counts. FCO to 11160' CTD, (64' Rat hole) chasing to tail with gel pull 5K over at 10822' CTD, pull 8K over at 10805' CTD, could be lost IBP rubber. 20% loss of returns when perfs uncovered, losses increase to 40% while FCO of tubing. Jet tubing back up to 5500' CTD, RBIH to 10800' CTD, Chase 80 bbls gel pill POOH at 50%. Wireline tagged sand at 3644'. Ran back in hole pumping 2 BPM while well is shut in. Flushed entire tubing out tubing tail down to 10875' CTD. BP AMOCO Page 1 of 2 Operations Summary Report Legal Well Name: MPF-86 Common Well Name: MPF-86 Spud Date: Event Name: COMPLETION Start: 9/21/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 4ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations .... .... 9/20/2001 06:00 - 0o:00 18.0o MOB COMP MOVE FROM MP G-14 TO MP F-86. RIG MOVE HELD UP DUE TO TIRE PROBLEM ON RIG SUB. 9/21/2001 00:00 - 01:00 1.00 MOB I COMP RAISE & SCOPE UP DERRICK. 01:00 - 02:30 1.50 MOB COMP HOOK UP HCR & TIGER TANK. ACCEPTED RIG @ 1:00 AM. 02:30 - 04:30 2.00 MOB COMP PULL BPV. TEST LINES. 04:30 - 08:30 4.00 MOB COMP OPEN UP WELL. TBG. 370 PSI. CSG. 50 PSI. KILL WELL W/9.0 PPG BRINE. 5 BPM @ 800 PSI. MONITOR WELL. DEAD. 08:30 - 10:30 2.00 MOB I COMP SET & TEST TWC. ND TREE. 10:30 - 13:00 2.50 MOB COMP NU BOPE. 13:00 - 16:30 3.50 MOB COMP TEST BOPE 250~3500 AS PER BP/AOGCC SPECS. WITNESSING WAIVERED BY CHUCK SHEVE 13:00 PM 09~21/2001. 16:30 - 17:30 1.00 MOB iCOMP LD TWC. 17:30 - 22:00 4.50 MOB i COMP PU LANDING JT. WORK PIPE @ 166K TO FREE UP PACKER. WORKED HANGER TO FLOOR. LD HANGER. 22:00 - 00:00 2.00 MOB COMP CUT PIT BRINE WT. TO 8.9 PPG. CIRC. HOLE W/8.9 BRINE. 9/22/2001 00:00 - 01:00 1.00 PULL COMP RU FLOOR TO LD 4 1/2" TBG. 01:00 - 03:00 2.00 PULL COMP WORK PIPE TO 166K. 03:00 - 07:30 4.50 PULL i COMP RU SWS. RUN CCL & CONFIRM PACKER HADN'T MOVED. POOH. 07:30 - 13:30 6.00 PULL COMP PU CHEMICAL CUTTER. RIH & CUT TBG. @ 10,784" ELM. POOH. RD SWS. 13:30 - 23:30 10.00 PULL COMP POOH LD 4 1/2" TBG. 23:30 - 00:00 0.50 PULL COMP CLEAR FLOOR. RU TO RUN FISHING ASSM. & 3 1/2" DP. 9/23/2001 00:00 - 02:00 2.00 PULL COMP CLEAR RIG FLOOR. RU TO RUN DP. INSTALL WEAR RING. 02:00 - 03:30 1.50 PULL COMP PU OVERSHOT, BUMPER SUB. JARS & 9-4 3/4" DCs. 03:30 - 06:00 2.50 PULL COMP PU 3 1/2" DP & RIH. 06:00 - 06:30 0.50 PULL COMP SERVICE RIG. 06:30 - 15:00 8.50 PULL COMP CONT. RIH W/3 1/2" DP. 15:00 - 16:00 1.00 PULL COMP PU KELLY. TAG FISH @ 10,779" SLM. LATCH BAKER SOLID NUT ANCHOR. 16:00- 17:00 1.00 PULL COMP CIRC. BTTMS. UP. 17:00 - 00:00 7.00 PULL COMP POOH WI 3 1/2" DP & FISH. 9/24/2001 00:00 - 00:30 0.50 PULL COMP CONT. POOH W/BAKER SOLID NUT ANCHOR & 3 1/2" DP. 00:30 - 02:00 1.50 PULL COMP LD FISH & BHA. CLEAR FLOOR. PREP TO FISH BAKER PACKER. 02:00 - 03:00 1.00 PULL COMP PU CUTTER. 03:00 - 06:00 3.00 PULL COMP RIH W/CUTTER & 3 1/2" DP. 06:00 - 06:30 0.50 PULL COMP SERVICE RIG. 06:30 - 07:30 1.00 PULL COMP CONT. RIH W/3 1/2" DP. 07:30 - 10:00 2.50 PULL COMP PU KELLY. TAG PACKER @ 10,794' SLM. CUT INNER MANDRIL. 10:00 - 13:00 3.00 PULL COMP CIRC. BTTMS. UP. 3 BPM @ 1700 PSI. 13:00 - 20:00 7.00 PULL COMP POOH W/FISH & 3 1/2" DP. 20:00 - 21:30 1'.50 PULL COMP OOH. LD BAKER PACKER & TBG. TAIL. 21:30 - 00:00 2.50 PULL COMP LD DCs. CLEAR & CLEAN FLOOR. 9/25/2001 00:00 - 01:00 1.00 PULL P COMP MADE UP 6" BIT, 6 JTS OF 3 1/2 DP AND CASING SCRAPPER 01:00 - 04:30 3.50 PULL P COMP RIH WITH 3 1/2" DP TO 10,668'. 04:30 - 06:00 1.50 PULL P COMP PICKED UP 3 1/2 DP SINGLES FROM PIPE SHED 06:00 - 06:30 0.50 PULL P COMP SERVICED RIG Printed: 10/2/2001 9:28:34 AM BP AMOCO Page 2 of 2 Operations Summary Report Legal Well Name: MPF-86 Common Well Name: MPF-86 Spud Date: Event Name: COMPLETION Start: 9/21/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 4ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/25/2001 06:30 - 14:00 7.50 PULL P COMP CONTINUED TO RIH WITH SINGLES. TAGGED FILL AT 11,043'. PICKED UP KELLY. REVERSED CIRCULATED AND WASHED FROM 11,042 TO 11,202. CIRCULATED AT 3.5 BPM AT 800 PSI. 14:00 - 16:30 2.50 PULL P COMP CONTINUED TO REVERSE CIRCULATE AND DISPLACED WELL WITH 8.9 PPG BRINE. 16:30 - 22:30 6.00 PULL P COMP POH LAYING DOWN 3 1/2" DP. 22:30 - 23:30 1.00 PULL P COMP CUT AND SLIPPED DRILL LINE. ADJUSTED BRAKES. 23:30 - 00:00 0.50 PULL P COMP CONTINUED TO POH LAYING DOWN DP. 9/26/2001 00:00 - 04:30 4.50 PULL P COMP CONTINUED TO POH LAYING DOWN 3 1/2 DP. 04:30 - 04:30 24.00 PULL P COMP PULLED WEAR RING. 04:30 - 00:30 20.00 PULL P COMP CLEARED AND CLEANED RIG FLOOR. SERVICED RIG. 06:30 - 07:30 1.00 PULL P COMP RIGGED UP TO RUN 2 7/8 TBG AND ESP COMPLETION. 07:30 - 15:00 7.50 PULL P COMP MADE UP ESP MOTOR AND PUMP. THE PHOENIX MULTI SENSOR DID NOT TEST. 15:00 - 21:00 6.00 PULL N COMP CHANGED OUT PHOENIX MULTI SENOR FOR PUMP MATE. TESTED SAME AND SERVICED ESP PUMP. 21:00 - 00:00 3.00 PULL P COMP RIH WITH ESP ASSY. TEST EVERY 1,800'. HAD 3,500' IN AT MIDNIGHT. Printed: 10/2/2001 9:28:34AM Client ................... : BP Exploratio~ Field .................... : Milne Point Well ..................... : MPF-86 API number ............... : 50-029-23018-G EnGineer ................. : Harmer RiG: ..................... : Nabors 27E State: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvat ANADRILL SCHLUMBERGER Survey report (Alaska) ure Method for DLS ........... : Mason & Taylo~ Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 10.90 ft KB above permanent ....... : N/A ft DF above permanent ....... : 42.90 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 3021.73 degrees 31-Jul-2001 19:26:05 PaGe 1 of 7 Spud date ................ : 18-Jul-01 Last survey date ......... : 31-Jul-01 Total accepted surveys...: 163 MD of first survey ....... : 0.00 ft MD of last survey ........ : 11316.52 ft GeomaGnetic data MaGnetic model ........... : BGGM version 2000 MaGnetic date ............ : 17-Jul-2001 MaGnetic field strength..: 1148.85 HCNT MaGnetic dec (+E/W-) ..... : 26.19 degrees MaGnetic dip ............. : 80.81 degrees MWD survey Reference Criteria Reference G .............. : 1002.69 mGal Reference H .............. : 1148.85 HCNT Reference Dip ............ : 80.81 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections ................ MaGnetic dec (+E/W-) ..... : 26.21 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 26.21 degrees (Total az corr = magnetic dec - Grid cony) SaG applied (Y/N) ........ : No degree: 0.00 [(c)2001 Anadrill IDEAL ID6 lC 10] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 2 100.00 0.32 297.32 3 200.00 0.44 301.26 4 300.00 0.47 299.09 5 400.00 0.78 304.44 6 500.00 1.51 312.77 7 600.00 2.34 310.31 8 700.00 4.47 309.71 9 800.00 5.79 311.28 10 900.00 6.85 324.50 11 1000.00 7.74 331.41 12 1100.00 9.56 322.59 13 1200.00 11.61 316.40 14 1300.00 15.07 307.03 15 1350.00 17.13 303.28 16 1400.00 18.65 301.57 17 1450.00 18.79 301.92 18 1500.00 19.63 301.69 19 1550.00 20.44 301.66 20 1600.00 21.96 301.71 0.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 50.00 50.00 50.00 50.00 50.00 50.00 21 1650.00 23.51 302.13 50.00 22 1700.00 24.45 302.38 50.00 23 1750.00 25.82 302.46 50.00 24 1800.00 25.99 302.29 50.00 25 1850.00 26.29 302.38 50.00 26 1900.00 26.34 302.70 50.00 27 1950.00 26.84 302.93 50.00 28 2000.00 28.44 303.40 50.00 29 2050.00 30.06 303.70 50.00 30 2100.00 31.88 303.62 50.00 31-Jul-2001 19:26:05 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) 0.00 100.00 200.00 299.99 399.99 499.97 599.91 699.73 799.33 898.72 997.91 1096.78 1195.07 1292.37 1340.41 1387.99 1435.34 1482.56 1529.53 1576.15 1622.26 1667.95 1713.21 1758.19 1803.07 1847.89 1892 60 1936 89 1980 52 2023 39 0.00 0.00 0.00 0.28 0.13 -0.25 0.94 0.46 -0.82 1.73 0.85 -1.51 2.82 1.44 -2.43 4.80 2.72 -3.96 8.12 4.93 -6.48 14.01 8.74 -11.04 22.87 14.56 -17.83 33.40 22.75 -25.08 44.84 33.51 -31.77 58.56 46.02 -40.04 76.15 59.91 -52.02 98.90 75.03 -69.35 112.75 82.99 -80.69 128.11 91.21 -93.66 144.15 99.66 -107.31 160.60 108.33 -121.29 177.73 117.32 -135.87 195.81 126.82 -151.25 215.13 137.04 -167.65 235.45 147.88 -184.84 256.68 159.27 -202.76 278.53 170.97 -221.21 300.55 182.75 -239.82 322.72 194.67 -258.51 345.10 206.80 -277.32 368.29 219.49 -296.73 392.72 232.99 -317.09 418.45 247.25 -338.51 Page Total displ (ft) At Azim (deg) .00 .28 .94 .74 .82 0.00 297.32 298.93 299.48 300.62 4 8 14 23 33 .8O .15 .08 .02 .86 304.47 307.27 308.39 309.24 312.20 46 61 79 102 115 .18 .00 .34 .17 .75 316.53 318.98 319.03 317.26 315.80 130 146 162 179 197 .74 .45 .62 .51 .38 314.24 312.88 311.77 310.81 309.98 216.53 236.71 257.84 279.58 301.52 323.61 345.94 369.09 393.49 419.19 309.26 308.66 308.15 307.70 307.31 306.98 306.71 306.49 306.31 306.15 2 of 7 DLS (deg/ 100f) 0.00 0.32 0.12 0.03 0.32 0.75 0.83 2.13 1.33 1.79 1.25 2.25 2.34 4.07 4.61 3.22 0.36 1.69 1.62 3.04 3.12 1.89 2.74 0.37 0.61 0.30 1.02 3.23 3.25 3.64 Srvy tool type TIP GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR Tool qual type [(c)2001 Anadrill IDEAL ID6 lC 10] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 31 2150.00 33.38 304.00 32 2200.00 33.50 304.01 33 2250.00 33.71 303.94 34 2300.00 34.52 303.50 35 2350.00 35.90 302.92 50.00 50.00 50.00 50.00 50.00 36 2400.00 38.36 302.75 50.00 37 2450.00 40.41 302.42 50.00 38 2500.00 42.38 302.55 50.00 39 2550.00 44.06 302.51 50.00 40 2600.00 45.42 302.50 50.00 41 2650.00 47.86 302.95 50.00 42 2700.00 49.55 304.07 50.00 43 2750.00 50.56 304.17 50.00 44 2800.00 51.28 303.71 50.00 45 2850.00 51.49 303.50 50.00 46 2900.00 53.25 303.96 47 2950.00 55.06 304.82 48 3000.00 56.47 305.57 49 3050.00 57.99 305.60 50 3100.00 58.50 305.62 50.00 50.00 50.00 50.00 50.00 51 3150.00 59.57 305.49 52 3200.00 60.43 305.28 53 3250.00 59.80 304.91 54 3300.00 60.15 304.58 55 3350.00 60.91 304.27 50.00 50.00 50.00 50.00 50.00 56 3400.00 62.36 303.97 50.00 57 3450.00 63.44 303.65 50.00 58 3500.00 63.45 303.33 50.00 59 3550.00 63.71 303.34 50.00 60 3600.00 62.49 303.29 50.00 [ (c) 2001 Anadrill IDEAL ID6_iC_10] TVD depth (ft) 31-Jul-2001 19:26:05 Page 3 of 7 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 2065.50 445.40 262.26 -360.91 446.13 306.00 2107.22 472.95 277.67 -383.75 473.67 305.89 2148.86 500.61 293.13 -406.70 501.33 305.78 2190.26 528.65 308.70 -430.02 529.35 305.67 2231.11 557.48 324.48 -454.14 558.15 305.55 2270.97 587.66 340.85 -479.50 588.30 305.41 2309.61 619.38 357.93 -506.23 619.99 305.26 2347.12 652.44 375.69 -534.12 653.01 305.12 12383.55 686.68 394.10 -562.99 687.22 304.99 2419.07 721.88 413.01 -592.67 722.38 304.87 3.03 0.24 0.43 1.69 2.84 4.92 4.12 3.94 3.36 2.72 ~453.40 758.23 432.66 -623.25 758.71 304.77 4.92 ~486.39 795.79 453.41 -654.56 796.26 304.71 3.78 2518.49 834.11 474.91 -686.30 834.59 304.68 2.03 2550.01 872.91 496.58 -718.50 873.40 304.65 1.61 2581.22 911.97 518.20 -751.04 912.46 304.60 0.53 2611.74 951.56 540.19 -783.97 952.05 304.57 2641.02 992.08 563.08 -817.41 992.58 304.56 2669.15 1033.37 586.91 -851.19 1033.92 304.59 2696.21 1075.36 611.37 -885.38 1075.95 304.63 2722.53 1117.82 636.13 -919.94 1118.46 304.66 2748.25 1160.64 661.06 2773.25 1203.90 686.13 2798.17 1247.21 711.06 2823.19 1290.48 735.73 2847.78 1333.99 760.34 1161.33 1204.63 1247.98 1291.27 1334.80 304.70 304.72 304.73 304.73 304.72 1378.79 1423.29 1468.01 1512.78 1557.35 304.70 304.68 304.~4 304.60 304.57 2871.54 1377.97 785.01 2894.31 1422.47 809.78 2916.67 1467.19 834.46 2938.91 1511.97 859.07 2961.54 1556.56 883.56 -954.82 -990.12 -1025.59 -1061.17 -1097.07 -1133.50 -1170.48 -1207.78 -1245.19 -1282.45 3.59 3.88 3.08 3.04 1.02 2.15 1.76 1.41 0.90 1.61 2.95 2.23 0.57 0.52 2.44 GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 61 3650.00 62.01 303.50 62 3700.00 61.72 303.36 63 3750.00 62.42 302.92 64 3800.00 63.47 302.52 65 3850.00 64.39 302.23 66 3900.00 64.82 302.09 67 3950.00 65.26 302.16 68 4000.00 65.31 302.16 69 4050.00 65.84 302.09 70 4100.00 65.41 302.14 71 4150.00 64.89 302.15 72 4200.00 64.89 302.25 73 4250.00 64.29 302.30 74 4300.00 64.63 302.44 75 4350.00 63.82 302.33 76 4400.00 63.91 302.20 77 4450.00 64.04 302.48 78 4500.00 63.65 302.69 79 4550.00 64.19 302.74 80 4600.00 63.87 302.66 81 4650.00 63.14 302.77 82 4700.00 63.48 302.97 83 4750.00 63.28 303.42 84 4800.00 63.40 303.42 85 4850.00 63.07 303.50 86 4900.00 63.89 303.40 87 4950.00 63.77 302.79 88 5000.00 63.46 302.41 89 5050.00 64.02 302.56 90 5100.00 63.69 302.87 50.00 50.00 50.00 50.00 50.O0 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 5O.O0 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 50.00 [(c)2001 Anadrill IDEAL ID6 lC 10] 31-Jul-2001 19:26:05 Page TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 2984.82 3008.39 3031 81 3054.56 3076.53 3097.97 3119.07 3139.98 3160.65 3181.29 3202.30 3223 52 3244.97 3266.53 3288 27 3310.29 3332.23 3354.27 3376.25 3398 15 3420.46 3442.91 3465.32 3487.75 3510.27 1600.80 1644.89 1689.06 1733.59 1778.50 907.91 -1319.39 932.20 -1356.19 956.35 -1393.18 980.42 -1430.64 1004.47 -1468.58 1823.67 1869.00 1914.42 1959.94 2005.48 2050.85 2096.12 2141.28 2186.39 2231.42 2276.30 2321.23 2366.11 2411.02 2455.97 2500.72 2545.39 2590.09 2634.77 2679.41 2724.15 2769.02 2813.81 2858.65 2903.53 1028.51 -1506.81 1052.62 -1545.20 1076.79 -1583.65 1101.00 -1622.21 1125.21 -1660.78 1149.35 -1699.20 1173.48 -1737.51 1197.60 -1775.69 1221.75 -1813.80 1245.86 -1851.82 1269.83 -1889.78 1293.86 -1927.74 1318.03 -1965.55 1342.30 -2003.34 1366.59 -2041.17 1390.77 -2078.82 1415.02 -2116.34 1439.49 -2153.74 1464.10 -2191.04 1488.72 -2228.28 1513.38 -2265.61 1537.88 -2303.20 1562.01 -2340.94 1586.09 -2378.76 1610.35 -2416.53 3532.59 $554.65 $576.87 $598.99 $621.02 1601.59 1645.68 1689.84 1734.35 1779.23 1824.37 1869.67 1915.06 1960.55 2006.07 2051.41 2096.66 2141.80 2186.90 2231.91 2276.78 2321.69 2366.56 2411.46 2456.40 2501.14 2545.81 2590.51 2635.19 2679.83 2724.57 2769.44 2814.23 2859.06 2903.93 304.53 304.50 304.47 304.42 304.37 304.32 304.26 304.21 304.16 304.12 304.07 304.03 304.00 303.96 303.93 303.90 303.87 303.84 303.82 303.80 303.78 303.77 303.76 303.75 303.75 303.74 303.73 303.71 303.69 303.68 4 of 7 DLS (deg/ 100f) 1.03 0.63 1.60 2.22 1.91 0.90 0.89 0.10 1.07 0.86 1.04 0.18 1.20 0.73 1.63 0.29 0.57 0.87 1.08 0.66 1.47 0.77 0.90 0.24 0.68 1.65 1.12 0.92 1.15 0.86 Srvy tool type GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR Too1 qual type ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 91 5150.00 63.63 302.84 92 5200.00 63.78 302.87 93 5250.00 63.41 303.12 94 5300.00 63.47 303.14 95 5350.00 63.46 303.21 50.00 50.00 50.00 50.00 50.00 96 5400.00 62.72 303.87 50.00 97 5450.00 62.05 304.65 50.00 98 5500.00 61.53 305.04 50.00 99 5550.00 62.49 305.07 50.00 100 5600.00 62.31 305.29 50.00 101 5650.00 62.61 305.43 102 5660.00 62.38 305.43 103 5727.39 62.56 303.42 104 5822.34 62.37 303.21 105 5916.23 63.21 301.50 50.00 10.00 67.39 94.95 93.89 depth (ft) 31-Jul-2001 19:26:05 Page 5 of 7 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim '(de~/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 3643.20 2948.34 1634.66 -2454.17 2948.74 303.67 3665.35 2993.17 1658.98 -2491.82 2993.56 303.65 3687.59 3037.95 1683.37 -2529.38 3038.34 303.64 3709.95 3082.68 1707.81 -2566.84 3083.06 303.64 3732.28 3127.41 1732.29 -2604.28 3127.79 303.63 3754.91 3778.09 3801.73 3825.19 3848.36 3171.99 1756.92 -2641.44 3172.38 303.63 3216.28 1781.86 -2678.06 3216.68 303.64 3260.31 1807.04 -2714.22 3260.73 303.65 3304.42 1832.39 -2750.36 3304.87 303.67 3348.69 1857.92 -2786.58 3349.16 303.69 3871.47 3392.98 1883.58 -2822.73 3393.48 303.71 3876.09 3401.84 1888.72 -2829.96 3402.35 303.72 3907.24 3461.57 1922.50 -2879.25 3462.10 303.73 3951.14 3545.76 1968.75 -2949.61 3546.29 303.72 3994.07 3629.25 2013.43 -3020.14 3629.76 303.69 106 6009.88 63.28 301.36 93.65 4036.23 107 6104.41 62.98 302.10 94.53 4078 96 108 6200.21 63.36 302.26 95.80 4122 19 109 6294.80 62.93 302.91 94.59 4164 92 110 6387.91 62.43 301.99 93.11 4207 66 111 6461.77 61.84 301.03 73.86 14242.18 112 6529.58 61.06 300.96 67.81 14274 59 113 6621.24 61.75 300.91 91.66 4318 46 114 6718.49 62.46 300.58 97.25 4363 96 115 6815.39 63.55 300.11 96.90 4407 94 91.11 93.37 93.02 95.25 94.73 116 6906.50 64.02 300.15 117 6999.87 63.74 300.04 118 7092.89 62.98 300.76 119 7188.14 62.27 300.69 120 7282.87 61.62 299.78 3712.85 2057.03 -3091.50 3713.32 303.64 3797.16 2101.38 -3163.22 3797.60 303.60 3882.65 2146.91 -3235.57 3883.06 303.57 3967.03 2192.35 -3306.68 3967.43 303.54 4049.76 2236.74 -3376.48 4050.14 303.52 4115.04 2270.87 -3432.15 4115.40 303.49 4174.57 2301.54 -3483.21 4174.91 303.45 4255.01 2342.91 -3552.24 4255.31 303.41 4340.91 2386.85 -3626.11 4341.17 303.35 4427.17 2430.47 -3700.62 4427.39 303.30 [(c)2001 Anadrill IDEAL ID6 lC 10] 4448.19 4508.83 2471.50 -3771.32 4509.01 303.24 4489.29 4592.57 2513.54 -3843.85 4592.72 303.18 4531.00 4675.65 2555.61 -3915.56 4675.77 303.13 4574.80 4760.18 2598.82 -3988.27 4760.27 303.09 4619.35 4843.70 2640.92 -4060.50 4843.77 303.04 0.13 0.30 0.86 0.13 0.13 1.89 1.93 1.25 1.92 0.53 0.65 2.30 2.66 0.28 1.85 0.15 0.77 0.42 0.76 1.03 1.40 1.15 0.75 0.79 1.21 0.52 0.32 1.07 0.75 1.09 GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR AND/DRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 121 7376.63 62.10 299.05 122 7472.29 63.10 298.93 123 7567.16 63.19 300.90 124 7660.86 62.81 301.11 125 7753.85 62.58 301.23 93.76 95.66 94.87 93.70 92.99 126 7844 . 85 62 . 90 301.35 127 7937.01 62.74 301.83 128 8030.43 62.28 301.68 129 8124 . 15 62 . 64 302 . 15 130 8216.39 62.34 302.63 91.00 92.16 93.42 93.72 92.24 131 8309.84 62.31 302.79 93.45 132 8404.84 61.64 302.92 95.00 133 8496.40 61.67 303.02 91.56 134 8592.46 62.38 303.53 96.06 135 8688.54 62.99 304.23 96.08 136 8781.53 62.66 304.27 137 8876.16 62.25 303.97 138 8969.23 61.41 304.24 139 9062.58 59.87 304.08 140 9155.93 58.34 303.08 141 9250.35 57.26 302.30 142 9343.87 54.95 301.77 143 9434.71 52.81 301.04 144 9528.91 50.05 301.30 145 9620.29 46.67 301.75 92.99 94.63 93.07 93.35 93.35 94.42 93.52 90.84 94.20 9~1.38 146 9714.81 42.89 301.91 94.52 147 9809.40 39.99 300.13 94.59 148 9904.72 37.68 301.35 95.32 149 9999.53 35.23 301.39 94.81 150 10093.29 32.21 300.83 93.76 [(c)2001 Anadrill IDEAL ID6_IC_10] depth (ft) 31-Jul-2001 19:26:05 Vertical Displ section +N/S- (ft) (ft) Displ (ft) Page Total displ (ft) At Azim (deg) 4663.57 4926.24 2681.52 -4132.52 4926.28 302.98 4707.59 5010.98 2722.68 -4206.80 5011.01 302.91 4750.45 5095.51 2764.89 -4280.16 5095.53 302.86 4792.99 5178.96 2807.90 -4351.72 5178.97 302.83 4835.65 5261.56 2850.66 -4422.42 5261.57 302.81 5342.43 2892.68 -4491.55 5342.43 302.78 5424.40 2935.62 -4561.38 5424.40 302.76 5507.25 2979.24 -4631.85 5507.26 302.75 5590.35 3023.17 -4702.38 5590.35 302.74 5672.15 3066.99 -4771.47 5672.15 302.73 4877.33 4919.43 4962.55 5005.88 5048.49 5091.89 5136.53 5180.00 5225.06 5269.15 5754.91 3111.72 -4841.10 5754.91 302.73 5838.77 3157.21 -4911.55 5838.77 302.73 5919.36 3201.06 -4979.15 5919.36 302.74 6004.19 3247.61 -5050.08 6004.19 302.74 6089.53 3295.20 -5120.95 6089.54 302.76 5311.62 6172.23 3341.76 -5189.33 6172.23 302.78 5355.38 6256.11 3388.82 -5258.79 6256.11 302.80 5399.32 6338.13 3434.82 -5326.72 6338.14 302.82 5445.09 6419.46 3480.51 -5394.04 6419.47 302.83 5493.02 6499.55 3524.82 -5460.77 6499.57 302.84 6579.45 3567.97 -5528.01 6579.46 302.84 6657.07 3609.15 -5593.81 6657.08 302.83 6730.42 3647.39 -5656.43 6730.43 302.81 6804.04 3685.50 -5719.45 6804.04 302.80 6872.30 3721.20 -5777.65 6872.31 302.78 5543.33 5595.48 5649.03 5707.75 5768.46 5835.54 6938.86 3756.30 -5834.21 6938.86 302.78 5906.44 7001.42 3788.58 -5887.84 7001.43 302.76 5980.69 7061.15 3819.12 -5939.21 7061.15 302.74 6056.94 7117.47 3848.44 -5987.31 7117.47 302.73 6134.92 7169.49 3875.34 -6031.86 7169.49 302.72 6 of 7 DLS (deg/ 100f) 0.86 1.05 1.85 0.45 0.27 0.37 0.49 0.51 0.59 0.56 0.16 0.72 0.10 0.88 0.91 0.36 0.52 0.94 1.66 1.88 1.34 2.51 2.44 2.94 3.72 4.00 3.31 2.55 2.58 3.24 Srvy tool type IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR Tool qual type ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 151 10188.68 29.07 301.13 95.39 152 10281.40 26.61 301.38 92.72 153 10374.16 23.52 301.74 92.76 154 10471.72 20.24 303.38 97.56 155 10565.94 16.88 303.75 94.22 156 10661.72 15.67 303.36 95.78 157 10757.03 15.39 301.33 95.31 158 10849.63 15.63 301.34 92.60 159 10944.09 15.29 299.83 94.46 160 11037.63 15.00 298.96 93.54 161 11132.80 14.46 297.93 95.17 162 11266.45 13.36 297.81 133.65 Final Survey Projected to Total Depth: 163 11316.52 13.36 297.81 50.07 [ (c) 2001 Binadrill IDEAL ID6_IC_10] 31-Jul-2001 19:26:05 Page TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) · 6216.98 6298.96 6382.98 6473.50 6562.81 6654.75 6746.58 6835.80 6926.85 7017.14 7109.18 7238.91 7218.08 7261.36 7300.64 7336.99 7366.98 7393.81 7419.33 7444.08 7469.24 7493.64 7517.77 7549.78 3900.35 -6073.54 3922.81 -6110.56 3943.37 -6144.04 3962.90 -6174.70 3979.48 -6199.69 3994.32 -6222.05 4007.97 -6243.61 4020.85 -6264.76 4033.66 -6286.43 4045.66 -6307.72 4057.19 -6329.00 4072.21 -6357.40 7561.31 4077.60 -6367.63 7287.62 7218.08 302.71 7261.36 302.70 7300.65 302.69 7336.99 302.69 7366.98 302.70 7393.82 302.70 7419.33 302.70 7444.08 302.69 7469.25 302.69 7493.64 302.68 7517.77 302.66 7549.79 302.64 7 of 7 DLS (deg/ 100f) 3.30 2.66 3.34 3.42 3.57 1.27 0.64 0.26 0.56 0.39 0.63 0.82 Srvy tool type IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR 7561.32 302.63 0.00 Proj Too1 qual type B.P. EXPLORATION F PAD, WELL NO. MPF-86 MILNE POINT FIELD, ALASKA Gyro Continuous Multishot Survey Inside 5" DRILL PIPE Survey date: 27- JULY, 2001 Job number' AK0701GCE516 gyroId CONTENTS JOB NUMBER: AK0701GCE516 1. DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. INRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT I 1. DISCUSSION, SURVEY CERTIFICATION SHEET DISCUSSION JOB NUMBER: AK0701GCE516 Tool 727 and 720 were run in WELL# MPF-86 on SCHLUMBERGER 15/32" wireline inside 5" DRILL PIPE. Experienced lost time due to a leaking swivel and had misruns on the first gyro run due to a problem with the accelerometer data and tool calibration after working the tool free after being stuck. After the decision was made to rerun the survey, the survey was completed without any problems. SURVEY CERTIFICATION SHEET JOB NUMBER: AK0701GCE516 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB J. SHOUP OPERATIONS MANAGER 2. SURVEY DETAILS t SURVEY DETAILS JOB NUMBER: AK0701GCE516 CLIENT: RIG: B.P. EXPLORATION SCHLUMBERGER LOCATION: F PAD WELL: MPF-86 LATITUDE: 70.505 N LONGITUDE: 149.4 W SURVEY DATE: SURVEY TYPE : DEPTH REFERENCE: 27 - J U LY, 2001 GYRO CONTINUOUS MULTISHOT ROTARY TABLE ELEVATION 42.9' MAX. SURVEY DEPTH: 5660' SURVEY TIED ONTO: N/A SURVEY INTERVAL: 0-5660' APl NUMBER: TARGET DIRECTION: 050-029-23018 302.73 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD I II 3. INRUN SURVEY LISTING A Gyrodata Directional Survey for B.P. Exploration Well: MPF-86, 5" DP Location: F PAD, MILNE POINT, ALASKA Job Number: AK0701GCE516 Run Date: 7/27/01 12:23:57 PM Surveyor: Tom Stoddard Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction flom Vertical Reference: 42.90 fl. Azimuth Co~Tection: Gyro: Bearings are Relative to Tree North Proposed Well Direction: 302.730 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local ttorizontal Reference B.P. Exploration Well: MPF-86, 5" DP Location: F PAD, MIl. NE POINT, ALASKA Job Number: AK0701GCE516 MEASURED I N C L AZIMUTH DOGLEG DEPTil SEVERITY feet deg. deg. deg./ 100 fi. 0.0 0.00 0.00 100.0 0.32 297.32 200.0 0.44 301.26 300.0 0.47 299.09 400.0 0.78 304.44 A Gyrodata Directional Survey 500.0 1.51 312.77 600.0 2.34 310.38 700.0 4.47 309.85 800.0 5.79 311.84 900.0 6.85 325.24 VERTICAL SUBSEA VERTICAL DEPTH DEPTI 1 SECTION feet feet feet 1000.0 7.74 332.24 1100.0 9.56 323.57 1200.0 11.61 317.41 1300.0 15.07 308.27 1350.0 17.13 304.52 0.00 0.0 0.0 0.0 0.32 100.0 100.0 0.3 0.13 200.0 200.0 0.9 0.04 300.0 300.0 1.7 0.32 400.0 400.0 2.8 1400.0 18.65 302.81 1450.0 18.79 303.16 1500.0 19.63 302.93 1550.0 20.44 302.90 1600.0 21.96 302.95 0.75 500.0 500.0 4.8 0.83 599.9 599.9 8.1 2.13 699.7 699.7 14.0 1.33 799.3 799.3 22.9 1.81 898.7 898.7 33.4 1650.0 23.51 303.37 1700.0 24.45 303.62 1750.0 25.82 303.70 1800.0 25.99 303.53 1850.0 26.29 303.62 1.26 997.9 997.9 44.7 2.23 1096.8 1096.8 58.4 2.34 1195.1 1195.1 75.8 4.04 1292.4 1292.4 98.5 4.61 1340.4 1340.4 112.4 3.22 1388.0 1388.0 127.7 0.36 1435.3 1435.3 143.8 1.68 1482.6 1482.6 160.2 1.62 1529.5 1529.5 177.3 3.05 1576.1 1576.1 195.4 3.10 1622.3 1622.3 214.8 1.90 1667.9 1667.9 235.1 2.73 1713.2 1713.2 256.3 0.38 1758.2 1758.2 278.1 0.60 1803.1 1803.1 300.2 CLOSURE DIST. AZIMUTtt feet deg. 0.0 0.0 0.3 297.3 0.9 298.9 1.7 299.5 2.8 300.6 4.8 304.5 8.2 307.3 14.1 308.4 23.0 3O9.4 33.9 312.5 46.2 317.0 61.0 319.5 79.3 319.7 102.1 318.0 115.7 316.6 130.8 315.1 146.5 313.8 162.7 312.7 179.6 311.8 197.5 311.0 216.6 310.3 236.8 309.7 257.9 309.2 279.7 3O8.8 301.6 308.4 HORIZONTAL COORDINATES feet 0.00 N 0.13 N 0.45 N 0.85 N 1.44 N 2.73 N 4.94 N 8.76 N 14.62 N 22.89 N 33.75 N 46.39 N 60.48 N 75.94 N 84.14 N 92.65 N 101.39 N 110.36 N 119.67 N 129.50 N 140.07 N 151.28 N 163.05 N 175.14 N 187.32 N 0,00 0.25W 0.82W 1.51 2.43 3.97W 6.49W ll.04W 17.79W 24.94W 31.48W 39.55W 51.29W 68.31W 79.49W 92.27W 105.73W 119.52W 133.91W 149.08W 165.26W 182.20W 199.88W 218.07W 236.42W A Gyrodata Directional Survey B.P. Exploration Well: MPF-86, 5" DP Location: F PAD, MILNE POINT, ALASKA Job Number: AK0701GCE516 MEASURED I N C L AZIMUTIt DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE DEPTH SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH feet deg. deg. deg./ feet feet feet feet deg. 100 fi. tlORIZONTAL COORDINATES feet 1900.0 26.34 303.94 1950.0 26.84 304.17 2000.0 28.44 3{)4.64 2050.0 30.06 304.94 2100.0 31.88 304.86 2150.0 33.38 305.24 2200.0 33.50 305.25 2250.0 33.71 305.18 2300.0 34.52 304.74 2350.0 35.90 304.16 2400.0 38.36 303.99 2450.0 40.41 303.66 2500.0 42.38 303179 2550.0 44.06 303.75 2600.0 45.42 303.74 2650.0 47.86 304.19 2700.0 49.55 305.31 2750.0 50.56 305.41 2800.0 51.28 304.95 2850.0 51.49 304.74 2900.0 53.25 305.20 2950.0 55.06 306.06 3000.0 56.47 306.81 3050.0 57.99 306.84 0.30 1847.9 1847.9 322.3 1.03 1892.6 1892.6 344.7 3.23 1936.9 1936.9 367.9 3.25 1980.5 1980.5 392.3 3.63 2023.4 2023.4 418.0 323.7 308.1 346.1 3O7.8 369.2 307.6 393.6 307.4 419.3 307.3 3.03 2065.5 2065.5 444.9 446.3 0.25 2107.2 2107.2 472.5 473.8 0.43 2148.9 2148.9 500.1 501.5 1.69 2190.3 2190.3 528.1 529.5 2.83 2231.1 2231.1 556.9 558.3 4.92 2271.0 2271.0 587.1 588.4 4.13 2309.6 2309.6 618.8 620.1 3.94 2347.1 2347.1 651.9 653.2 3.36 2383.6 2383.6 686.1 687.4 2.72 2419.1 2419.1 721.3 722.5 4.93 2453.4 2453.4 757.7 758.9 3.78 2486.4 2486.4 795.2 796.4 2.02 2518.5 2518.5 833.5 834.7 1.61 2550.0 2550.0 872.3 873.6 0.53 2581.2 2581.2 911.3 912.6 3.61 2611.7 2611.7 950.9 952.2 3.86 2641.0 2641.0 991.4 992.7 3.08 2669.1 2669.1 1032.6 1034.1 3.04 2696.2 2696.2 1074.5 1076.1 307.1 307.0 306.9 306.8 306.7 306.6 306.4 306.3 306.2 306.0 3O5.9 305.9 305.9 305.8 305.8 305.8 3O5.8 3O5.8 3O5.8 199.65 N 212.18 N 225.29 N 239.23 N 253.95 N 269.43 N 285.33 N 301.29 N 317.35 N 333.66 N 350.56 N 368.22 N 386.58 N 405.61N 425.16 N 445.47 N 466.89 N 489.O7 N 511.43 N 533.76 N 556.46 N 580.07 N 604.62 N 629.82 N 254.84W 273.38W 292.52W 312.58W 333.68W 355.75 W 378.25W 400.86W 423.84W 447.62W 472.61 W 498.97 W 526.46W 554.93 W 584.19W 614.34W 645.20W 676.47W 708.19W 740.26W 772.70W 805.64W 838.90W 872.55W B.P. Exploration Well: MPF-86, 5" DP Location: F PAD, MILNE POINT, ALASKA Job Number: AK0701GCE516 MEASURED IN C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. 3100.0 58.50 306.86 A Gyrodata Directional Survey 3150.0 59.57 306.73 3200.0 60.43 306.52 3250.0 59.80 306.15 3300.0 60.15 305.82 3350.0 60.91 305.51 VERTICAL SUBSEA VERTICAL DEPTH DEPTH SECTION feet feet feet 3400.0 62.36 305.21 3450.0 63.44 304.89 3500.0 63.45 304.57 3550.0 63.71 304.58 3600.0 62.49 304.53 CLOSURE DIST. AZIMUTH feet deg. 3650.0 62.01 304.74 3700.0 61.72 304.60 3750.0 62.42 304.16 3800.0 63.47 303.76 3850.0 64.39 303.47 1.02 2722.5 2722.5 1116.9 1118.6 305.9 3900.0 64.82 303.33 3950.0 65.26 303.40 4000.0 65.31 303.40 4050.0 65.84 303.33 4100.0 65.41 303.38 2.15 2748.3 2748.3 1159.7 1.76 2773.3 2773.3 1202.9 1.41 2798.2 2798.2 1246.2 0.91 2823.2 2823.2 1289.4 1.61 2847.8 2847.8 1332.9 4150.0 64.89 303.39 4200.0 64.89 303.49 4250.0 64.29 303.54 2.95 2871.5 2871.5 1376.8 2.23 2894.3 2894.3 1421.3 0.57 2916.7 2916.7 1466.0 0.53 2938.9 2938.9 1510.7 2.45 2961.5 2961.5 1555.3 1.02 2984.8 2984.8 1599.5 0.64 3008.4 3008.4 1643.6 1.61 3031.8 3031.8 1687.8 2.22 3054.6 3054.6 1732.3 1.90 3076.5 3076.5 1777.2 0.91 3098.0 3098.0 1822.3 0.89 3119.1 3119.1 1867.7 0.10 3140.0 3140.0 1913.1 1.06 3160.7 3160.7 1958.6 0.85 3181.3 3181.3 2004.2 1161.5 305.9 1204.8 305.9 1248.1 305.9 1291.4 305.9 1335.0 305.9 1378.9 305.9 1423.5 305.9 1468.2 305.8 1512.9 305.8 1557.5 305.8 1601.8 305.7 1645.8 305.7 1690.0 305.7 1734.5 305.6 1779.4 305.6 1824.5 305.5 1869.8 305.5 1915.2 305.4 1960.7 305.4 2006.2 305.3 1.05 3202.3 3202.3 2049.5 2051.6 305.3 0.17 3223.5 3223.5 2094.8 2096.8 305.3 1.21 3245.0 3245.0 2140.0 2142.0 305.2 HORIZONTAL COORD~ATES ~et 655.32 N 681.00 N 706.83 N 732.51 N 757.95 N 783.33 N 8O8.79 N 834.35 N 859.83 N 885.24 N 910.53 N 935.68 N 96O.76 N 985.70 N 1010.58 N 1035.44 N 1060.31 N 1085.23 N 1110.24 N 1135.28 N 1160.32 N 1185.29 N 1210.24 N 1235.17 N 906.57W 940.90W 975.65 W 1010.57W 1045.60W 1080.97W 1116.85W 1153.28 W 1190.04 W 1226.91W 1263.63 W 1300.04W 1336.30W 1372.76W 1409.70 W 1447.10W 1484.81 W 1522.67 W 1560.59 W 1598.61W 1636.65 W 1674.53W 1712.31W 1749.97 W B.P. Exploration Well: MPF-86, 5" DP Location: F PAD, MILNE POINT, ALASKA Job Number: AK0701GCE516 A Gyrodata Directional Survey MEASURED I N C L AZIMUTIt DOGIJEG VERTICAL SUBSEA VERTICAL DEPTH SEVERITY DEPTH DEPTH SECTION feet deg. deg. deg./ feet feet feet 100 ft. 0.73 3266.5 3266.5 2185.1 1.64 3288.3 3288.3 2230.1 4300.0 64.63 303.68 4350.0 63.82 303.57 CLOSURE DIST. AZIMUTH feet deg. 4400.0 63.91 303.44 4450.0 64.04 303.72 4500.0 63.65 303.93 4550.0 64.19 303.98 4600.0 63.87 303.90 2187.1 305.2 2232.1 305.2 4650.0 63.14 304.01 4700.0 63.48 304.21 4750.0 63.28 304.66 4800.0 63.40 304.66 4850.0 63.07 304.74 0.30 3310.3 3310.3 2275.0 2276.9 305.1 0.57 3332.2 3332.2 2319.9 2321.9 305.1 0.87 3354.3 3354.3 2364.8 2366.7 305.1 1.09 3376.3 3376.3 2409.7 2411.6 305.0 0.66 3398.2 3398.2 2454.6 2456.6 305.0 4900.0 63.89 304.64 4950.0 63.77 304.03 5000.0 63.46 303.65 5050.0 64.02 303.80 5100.0 63.69 304.11 1.47 3420.5 3420.5 2499.3 0.76 3442.9 3442.9 2544.0 0.89 3465.3 3465.3 2588.7 0.24 3487.8 3487.8 2633.3 0.67 3510.3 3510.3 2678.0 5150.0 63.63 304.08 5200.0 63.78 304.11 5250.0 63.41 304.36 5300.0 63.47 304.38 5350.0 63.46 304.45 1.64 3532.6 3532.6 2722.7 1.10 3554.6 3554.6 2767.5 0.93 3576.9 3576.9 2812.3 1.15 3599.0 3599.0 2857.1 0.87 3621.0 3621.0 2902.0 5400.0 62.72 305.11 5450.0 62.05 305.89 0.13 3643.2 3643.2 2946.8 0.32 3665.4 3665.4 2991.6 0.87 3687.6 3687.6 3036.4 0.13 3710.0 3710.0 3081.1 0.12 3732.3 3732.3 3125.8 1.89 3754.9 3754.9 3170.4 1.92 3778.1 3778.1 3214.6 2501.3 305.0 2546.0 305.0 2590.7 305.0 2635.4 305.0 2680.0 305.0 2724.7 305.0 2769.6 305.0 2814.4 304.9 2859.2 304.9 2904.1 304.9 2948.9 304.9 2993.7 304.9 3038.5 304.9 3083.2 304.9 3128.0 304.9 3172.5 304.9 3216.8 304.9 ttORIZONTAL COORDINATES feet 1260.15 N 1285.08 N 1309.86 N 1334.71N 1359.69 N 1384.77 N 1409.87 N 1434.86 N 1459.91N 1485.18 N 1510.60 N 1536.01N 1561.48 N 1586.79 N 1611.73 N 1636.62 N 1661.69 N 1686.81N 1711.95 N 1737.14 N 1762.39 N 1787.67 N 1813.11N 1838.83 N 1787.54W 1825.03W 1862.46W 1899.89W 1937.18W 1974.43W 2011.72W 2048.84W 2085.82W 2122.69W 2159.45W 2196.15W 2232.94W 2269.99W 2307.19W 2344.48W 2381.71W 2418.82W 2455.94W 2492.96W 2529.87W 2566.77W 2603.39W 2639.46W A Gyrodata Directional Survey B.P. Exploration Well: MPF-86, 5" DP Location: F PAD, MILNE POINT, ALASKA Job Number: AK0701GCE516 MEASURED IN C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 fi. VERTICAL SUBSEA VERTICAL DEPTH DEPTH SECTION feet feet feet 5500.0 61.53 306.28 1.25 5550.0 62.49 306.31 1.93 5600.0 62.31 306.53 0.51 3801.7 3801.7 3258.6 3825.2 3825.2 3302.7 3848.4 3848.4 3346.9 5650.0 62.61 306.67 0.64 5660.0 62.38 306.67 2.27 3871.5 3871.5 3391.1 3876.1 3876.1 3400.0 Final Station Closure: Distance: 3402.50 fl Az: 304.95 deg. CLOSURE DIST. AZIMUTH feet deg. 3260.9 304.9 3305.0 304.9 3349.3 304.9 3393.6 304.9 3402.5 304.9 HORIZONTAL COORDINATES feet 1864.78 N 1890.92 N 1917.22 N 1943.66 N 1948.95 N 2675.07W 2710.65W 2746.31W 2781.90W 2789.02W A Gyrodata Directional Survey for B.P. Exploration Well: MPF-86, 5" DP Location: F PAD, MILNE POINT, ALASKA .lob Number: AK0701GCE5 i 6SS lim~ l)ate: 7/27/I}! 12:23:57 I'M Sm'vcyor: Tom Sloddard Calculalion Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Co~ection fi'om Ve~ical Reference: 42.90 Azimuth Correction: Gyro: Bearings are Relative to Tree North Proposed Well l)ircction: 302.730 dog Vertical Section Calculated from Well H¢ ~tt I )cation Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference B.P. Exploration Well: MPF-86, 5" DP Location: F PAD, MILNE POINrI', ALASKA Job Number: AK0701 (iCES 16SS SUBSEA i N (; 1. AZIMU'I'II I)OGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. -42.9 0.00 0.00 57.1 0.32 297.32 157.1 0.44 301.26 257.1 0.47 299.09 357.1 0.78 304.44 457.1 1.51 312.77 557.0 2.34 310.38 656.8 4.47 309.85 756.4 5.79 311.84 855.8 6.85 325.24 955.0 7.74 332.24 1053.9 9.56 323.57 1152.2 11.61 317.41 1249.5 15.07 308.27 1297.5 17.13 304.52 1345.1 18_65 302.81 1392.4 18.79 303.16 1439.7 19.63 302.93 1486.6 20.44 302.90 1533.2 21.96 302.95 1579.4 23.51 303.37 1625.0 24.45 303.62 1670.3 25.82 303.70 1715.3 25.99 303.53 1760.2 26.29 303.62 0.00 0.32 0.13 0.04 0.32 0.75 0.83 2.13 1.33 1.81 1.26 2.23 2.34 4.04 4.61 A Gyrodata Directional Survey VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. 0.0 0.0 0.0 0.0 100.0 0.3 0.3 297.3 200.0 0.9 0.9 298.9 300.0 1.7 1.7 299.5 400.0 2.8 2.8 300.6 500.0 4.8 4.8 304.5 599.9 8.1 8.2 307.3 699.7 14.0 14.1 308.4 799.3 22.9 23.0 309.4 898.7 33.4 33.9 312.5 997.9 44.7 46.2 317.0 1096.8 58.4 61.0 319.5 1195.1 75.8 79.3 319.7 1292.4 98.5 102.1 318.0 1340.4 112.4 115.7 316.6 IIORIZONTAI, COORDINATES feet 0.00 N 0.13 N O.45 N 0.85 N 1.44 N 2.73 4.94 8.76 14.62 22.89 33.75 46.39 60.48 75.94 84.14 3.22 1388.0 127.7 130.8 315.1 92.65 0.36 1435.3 143.8 146.5 313.8 101.39 1.68 1482.6 160.2 162.7 312.7 110.36 1.62 1529.5 177.3 179.6 311.8 119.67 3.05 1576.1 195.4 197.5 311.0 129.50 3.10 1622.3 214.8 216.6 310.3 140.07 1.90 1667.9 235.1 236.8 309.7 151.28 2.73 1713.2 256.3 257.9 309.2 163.05 0.38 1758.2 278.1 279.7 308.8 175.14 0.60 1803.1 300.2 301.6 308.4 187.32 N N N N N N N N N N N N N N N N N N N N 0.00 E 0.25W 0.82W 1.51W 2.43 W 3.97W 6.49W ll.04W 17.79W 24.94W 31.48W 39.55W 51.29W 68.31W 79.49W 92.27W 105.73W 119.52W 133.91W 149.08W 165.26W 182.20W 199.88W 218.07W 236.42W B.P. Exploration Well: MPF-86, 5" DP Location: F PAD, MILNE POINT, ALASKA Job Number: AK0701GCE516SS S[JBSEA I N C IJ AZIMUTIi DOGLEG DEPTH SEVERITY feet deg. dcg. deg./ 100 fi. A Gyrodata Directional Survey VERTICAl, VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. IIORIZONTAI, COORDINATES feet 1805.0 26.34 303.94 1849.7 26.84 31)4.17 1894.0 28.44 304.64 1937.6 30.06 304.94 1980.5 31.88 304.86 2022.6 33.38 305.24 2064.3 33.50 305.25 2106.0 33.71 305.18 2147.4 34.52 304.74 2188.2 35.90 304.16 2228.1 38.36 303.99 2266.7 40.41 303.66 2304.2 42.38 303.79 2340.7 44.06 303.75 2376.2 45_42 303.74 2410.5 47.86 304.19 2443.5 49.55 305.31 2475.6 50.56 305.41 2507.1 51.28 304.95 2538.3 51.49 304.74 2568.8 53.25 305.20 2598.1 55.06 306.06 2626.2 56.47 306.81 2653.3 57.99 306.84 0.30 i .03 3.23 3.25 3.63 1847.9 322.3 323.7 308.1 1892.6 344.7 346.1 307.8 1936.9 367.9 369.2 307.6 1980.5 392.3 393.6 307.4 2023.4 418.0 419.3 307.3 3.03 2065.5 444.9 446.3 307.1 0.25 2107.2 472.5 473.8 307.0 0.43 2148.9 500.1 501.5 306.9 1.69 2190.3 528.1 529.5 306.8 2.83 2231.1 556.9 558.3 306.7 4.92 4.13 3.94 3.36 2.72 2271.0 587.1 588.4 306.6 2309.6 618.8 620.1 306.4 2347.1 651.9 653.2 306.3 2383.6 686.1 687.4 306.2 2419.1 721.3 722.5 306.0 4.93 2453.4 757.7 758.9 305.9 3.78 2486.4 795.2 796.4 305.9 2.02 2518.5 833.5 834.7 305.9 1.61 2550.0 872.3 873.6 305.8 0.53 2581.2 911.3 912.6 305.8 3.61 3.86 3.08 3.04 2611.7 950.9 952.2 305.8 2641.0 991.4 992.7 305.8 2669.1 1032.6 1034.1 305.8 2696.2 1074.5 1076.1 305.8 199.65 N 212.18 N 225.29 N 239.23 N 253.95 N 269.43N 285.33 N 301.29 N 317.35 N 333.66 N 350.56 N 368.22 N 386.58 N 405.61 N 425.16 N 445.47 N 466.89 N 489.07 N 511.43 N 533.76 N 556.46 N 580.07 N 604.62 N 629.82 N 254.84W 273.38W 292.52W 312.58W 333.68W 355.75W 378.25 W 400.86W 423.84W 447.62W 472.61W 498.97W 526.46W 554.93W 584.19W 614.34W 645.20W 676.47W 708.19W 740.26W 772.70W 805.64W 838,90W 872.55W A Gyrodata Directional Survey B.P. Exploration Well: MPF-86, 5" DP Location: F PAD, MILNE POINT, ALASKA Job Number: AK0701GCE516SS SIIBSEA I N C IJ AZIMUTII DOGLEG DEPTH SEVERITY feel deg. deg. deg./ 100 fl. 2679.6 58.50 306.86 2705_4 59.57 306.73 2730.4 60.43 306.52 2755.3 59.80 306. i 5 2780.3 60.15 305.82 2804_9 60.9 ! 305.51 2828.6 62.36 305.21 2851.4 63.44 304.89 2873.8 63.45 304.57 2896.0 63.71 304.58 2918.6 62.49 304.53 2941.9 62.01 304.74 2965.5 61.72 304.60 2988.9 62.42 304.16 3011.7 63.47 303.76 3033.6 64.39 303.47 3055.1 64.82 303.33 3076.2 65.26 303.40 3097.1 65.31 303.40 3117.8 65.84 303.33 3138.4 65.41 303.38 3159.4 64.89 303.39 3180.6 64.89 303.49 3202.1 64.29 303.54 1.02 2.15 1.76 !.41 0.91 1.61 2.95 2.23 0.57 0.53 2.45 1.02 0.64 1.61 2.22 1.90 0.91 0.89 0.10 1.06 0.85 VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. 2722.5 1116.9 1118.6 305.9 2748.3 1159.7 1161.5 305.9 2773.3 1202.9 1204.8 305.9 2798.2 1246.2 1248.1 305.9 2823.2 1289.4 1291.4 305.9 2847.8 1332.9 1335.0 305.9 2871.5 1376.8 1378.9 305.9 2894.3 1421.3 1423.5 305.9 2916.7 1466.0 1468.2 305.8 2938.9 1510.7 1512.9 305.8 2961.5 1555.3 1557.5 305.8 2984.8 1599.5 1601.8 305.7 3008.4 1643.6 1645.8 305.7 3031.8 1687.8 1690.0 305.7 3054.6 1732.3 1734.5 305.6 3076.5 1777.2 1779.4 305.6 3098.0 1822.3 1824.5 305.5 3119.1 1867.7 1869.8 305.5 3140.0 1913.1 1915.2 305.4 3160.7 1958.6 1960.7 305.4 3181.3 2004.2 2006.2 305.3 1.05 3202.3 2049.5 2051.6 305.3 0.17 3223.5 2094.8 2096.8 305.3 1.21 3245.0 2140.0 2142.0 305.2 HORIZONTAL COORDINATES feet 655.32 N 681.00 N 706.83 N 732.51N 757.95 N 783.33 N 808.79 N 834.35 N 859.83 N 885.24 N 910.53 N 935.68 N 960.76 N 985.70 N 1010.58 N 1035.44 N 1060.31N 1085.23 N 1110.24 N 1135.28 N 1160.32 N 1185.29 N 1210.24 N 1235.17 N 906.57W 940.90W 975.65W 1010.57W 1045.60W 1080.97W 1116.85W 1153.28W 1190.04W 1226.91W 1263.63W 1300.04W 1336.30W 1372.76W 1409.70W 1447.10W 1484.81W 1522.67W 1560.59W 1598.61W 1636.65W 1674.53W 1712.31W 1749.97W B.P. Exploration Well: MPF-S6, 5" DP IJocalion: F PAl), MIl,NE I'OINT, AIJASKA Job Number: AK0701GCE516SS SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. 3223.6 64.63 303.68 3245.4 63.82 303.57 3267.4 63.91 303.44 3289.3 64.04 303.72 3311.4 63.65 303.93 3333.4 64.19 303.98 3355.3 63.87 303.90 3377.6 63.14 304.01 3400.0 63.48 304.21 3422.4 63.28 304.66 3444.9 63.40 304.66 3467.4 63.07 304.74 3489.7 63.89 304.64 3511.7 63.77 304.03 3534.0 63.46 303.65 3556.1 64.02 303.80 3578.1 63.69 304.11 3600.3 63.63 304.08 3622.5 63.78 304.11 3644.7 63.41 304.36 3667.1 63.47 304.38 3689.4 63.46 304.45 3712.0 62.72 305.11 3735.2 62.05 305.89 0.73 1.64 A Gyrodata Directional Survey VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. 3266.5 2185.1 2187.1 305.2 3288.3 2230.1 2232.1 305.2 0.30 3310.3 2275.0 2276.9 305.1 0.57 3332.2 2319.9 2321.9 305.1 0.87 3354.3 2364.8 2366.7 305.1 1.09 3376.3 2409.7 2411.6 305.0 0.66 3398.2 2454.6 2456.6 305.0 1.47 3420.5 2499.3 2501.3 305.0 0.76 3442.9 2544.0 2546.0 305.0 0.89 3465.3 2588.7 2590.7 305.0 0.24 3487.8 2633.3 2635.4 305.0 0.67 3510.3 2678.0 2680.0 305.0 1.64 1.10 0.93 1.15 0.87 0.13 0.32 O.87 0.13 0.12 1.89 1.92 3532.6 2722.7 2724.7 305.0 3554.6 2767.5 2769.6 305.0 3576.9 2812.3 2814.4 304.9 3599.0 2857.1 2859.2 304.9 3621.0 2902.0 2904.1 304.9 3643.2 2946.8 2948.9 304.9 3665.4 2991.6 2993.7 304.9 3687.6 3036.4 3038.5 304.9 3710.0 3081.1 3083.2 304.9 3732.3 3125.8 3128.0 304.9 3754.9 3170.4 3172.5 304.9 3778.1 3214.6 3216.8 304.9 HORIZONTAL COORDINATES feet 1260.15 N 1285.08 N 1309.86 N 1334.71N 1359.69 N 1384.77N 1409.87 N 1434.86 N 1459.91N 1485.18 N 1510.60 N 1536.01N 1561.48 N 1586.79 N 1611.73 N 1636.62 N 1661.69 N 1686.81N 1711.95 N 1737.14 N 1762.39 N 1787.67 N 1813.11N 1838.83 N 1787.54W 1825.03W 1862.46W 1899.89W 1937.18W 1974.43W 2011.72W 2048.84W 2085.82W 2122.69W 2159.45W 2196.15W 2232.94W 2269.99W 2307.19W 2344.48W 2381.71W 2418.82W 2455.94W 2492.96W 2529.87W 2566.77W 2603.39W 2639.46W A Gyrodata Directional Survey B.P. Exploration \Veil: ?',IPF-S6. 5" DP l,t~cation: l' PAI,L N'III~NI: I'(~I,N 1. AI_:\SK:\ .lob Nurnbcr: AK0701GCE516SS 5;I ICNI .\ I N' t I \,'1\11 I'll l)()(;l l)lzP l'l t SEVERITY fcct deg. deg. deg./ 100 fi. 3758.8 61.53 306.28 3782.3 62.49 306.31 3805.5 62.31 306.53 3828.6 62.61 306.67 3833.2 62.38 306.67 Final Station Closure: 1.25 1.93 0.51 0.64 2.27 Distance: 3402.50 fl Az: VF, P, TICAI \'ItR'I'I('AI CI.OSIlRE DEPTIt SECTION DIST. AZIMUTH feet feet feet deg. 3801.7 3258.6 3260.9 304.9 3825.2 3302.7 3305.0 304.9 3848.4 3346.9 3349.3 304.9 3871.5 3391.1 3393.6 304.9 3876.1 3400.0 3402.5 304.9 304.95 deg. IIORIZONTAI. COORDINATES feet 1864.78 N 1890.92 N 1917.22 N 1943.66 N 1948.95 N 2675.07W 2710.65W 2746.31W 2781.90W 2789.02W 4. QUALITY CONTROL III QUALITY CONTROL REPORT JOB NUMBER: AK0701GCE516 TOOL NUMBER: 727/720 MAXIMUM GYRO TEMPERATURE : 68.3 C MAXIMUM AMBIENT TEMPERATURE: 26.5 C MAXIMUM INCLINATION: 65.84 AVERAGE AZIMUTH: 303.74 WIRELINE REZERO VALUE: 0' INRUN REZERO ERROR / K: N/A CALIBRATION USED FOR FIELD SURVEY: 3754 CALIBRATION USED FOR FINAL SURVEY: 3754 PRE JOB MASS BALANCE OFFSET CHECK: -.70 POST JOB MASS BALANCE OFFSET CHECK': USED O.O/N/A CONTINUOUS CONDITION OF SHOCK WATCHES -.82 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS: OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH MWD 5348 63.10 302.62 FINAL SURVEY 5350 63.46 304.45 'l-VD NORTHING EASTING 3732.9 1757 -2587 3732.3 1787.7 -2566.8 FUNCTION TEST JOB NUMBER: AK0701GCE516 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 1300 15.07 15.07 15.07 15.07 15.07 AZIMUTH M.D. ft 1 2 3 4 5 1300 307.03 306.95 307.12 307.16 306.98 5. EQUIPMENT AND CHRONOLOGICAL REPORT EQUIPMENT REPORT JOB NUMBER: AK0701GCE516 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 727 GYRO SECTION DATA SECTION POWER SECTION COMPUTER A0158 POWER SUPPLY C0211 PRINTER C0207 INTERFACE A0527 A0085 A0029 A0166 BACKUP TOOL No. 720 GYRO SECTION DATA SECTION POWER SECTION COMPUTER A0212 POWER SUPPLY C0159 PRINTER C0197 INTERFACE A0693 A0107 A0029 A0165 WIRELINE COMPANY: SCHLUMBERGER CABLE SIZE: 15/32" RUNNING GEAR 2.25" HOUSING w ECCENTRIC BAR TOTAL LENGTH OF .TOOL: 30' MAXIMUM O.D.: 2.25" INCHES TOTAL WEIGHT OF TOOL: 210 POUNDS CHRONOLOGICAL REPORT JOB NUMBER: AK0701GCE516 TUESDAY, 07/24/01 18:15 TO SLOPE 21:00 ARRIVE SLOPE, CHECK TOOLS, O.K., JOB TOMORROW WEDNESDAY, 07/25/01 15:00 TO LOCATION 23:00 MU TOOL, STANDBY THURSDAY, 07/26/01 07:00 08:30 10:00 10:45 12:30 14:30 15:30 17:00 17:30 18:15 20:00 21 '30 22:00 SPOT UNIT, WARM UP TOOL RU WIRELINE, POWER UP TOOL, SAFETY MEETING PICK LIP, GYRO RIH SURVEY IN TO 1300' SHORT, POOH, CO SWIVEL, XO, CENTRALIZER. REBUILD HEAD SURVEY IN TO 5600', CHECK DATA, MISRUN SURVEY OUT, TOOL STUCK AT 5000', WORK TOOL FREE. LD TOOL, CHECK DATA, MISRUN. BD TOOL. RD WIRELINE. ASKED TO RERUN. MU TOOL, RU WIRELINE. PU TOOL, RIH TO 1300', START INRUN AT 5660', CHECK DATA(GooD), START OUTRUN LD TOOL, RD WIRELINE, PROCESS INRUN. TO DEADHORSE. FRIDAY, 07/27/00 06:00 09:00 10:30 CHECK TOOL, PROCESS DATA. 12:00 17:15 TO ANCHORAGE PROCESS OUTRUN. TO MILNE POINT SUBMIT RESULTS TO DEADHORSE ALASKA OIL AND GAS CONSERYA~I~ION COP~ISSION TONY KNOWLES, GOVERNOR 333 W. 7r" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Steve Shultz Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage AK 99519-6612 Re: Milne Point Unit MPF-86 BP Exploration (Alaska) Inc. Permit No: 201-087 Sur Loc: 2089' NSL, 2941' WEL, SEC. 06, T13N, R10E, UM Btmhole Loc. 884' NSL, 4129' WEL, SEC. 36, T14N, R09E, UM Dear Mr. Shultz: 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. Annular disposal has not been requested as part of the Permit to Drill application for Milne Point Unit MPF-86. Blowout preventiOn equipment (BOPE) must be tested in accordance with 20AAc 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION DATED this O~ day of June, 2001 jjc/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASKA O~L .~ND GAS CONSERVATION COMMIS,,..aN PERMIT TO DRILL 20 AAC 25.005 I [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work ~ Drill [] Redrill lb. Type of well [] Service [] Development Gas [] Single Zone [] Multiple Zone Re-Entry [] Deepen 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Planned KBE = 33.5' Milne Point Unit / Kuparuk 3. Address 6. Property Designation River Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 355018 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2089' NSL, 2941' WEL, SEC. 06, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 849' NSL, 4074' WEL, SEC. 36, T14N, R09E, UM MPF-86 Number 2S100302630-277 At total depth 9. Approximate spud date 884' NSL, 4129' WEL, SEC. 36, T14N, R09E, UM 05/22/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'I-VD) ADL 388235, 884' MDI No Close Approach 5083 11310' MD/7270' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 500' MD Maximum Hole Angle 63.5 ° Maximum surface 1550 psig, At total depth (TVD) 7000' / 2250 psig 18. Casing Program Specifications Setting Depth Size To3 Bottom Quantity of Cement Hole Casin.q Weiqht Grade Couplinq Len,qth MD TVD MD TVD (include stare data) 30" 20" 92# H-40 Welded 80' 33' 33' 113' 113' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 6545' 33' 33'_, ~ ~ 815 sx PF~ 556 sx of Class 'G' 8-1/2" 7" 26# L-80 BTC 11304' 33' 33'/ 11310' 7269' 180 sx Class'G' L 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 MD TVD Structural Conductor Surface Intermediate Production Liner ECEtVED MAY 0'8 2001 Perforation depth: measured Alaska Oil & Gas Co~s. Commission true vertical Anchorage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Numbec James Franks, 564-4468 Prepared By Name/Nurnbec Sondra Stewman, 564-4750 ~21. I hereby certify that the for~aeing is true and c.~rer~to the best of my knowledge Signed SteveShultz ~,,z.~l(~~' Title Senior Drilling Engineer Date C5'"~//~"/~'~/ 'Permit NL~i~er ' "I"API Number .... ' ',, 1, j ..... 'Appic~val 'Daie, ' I' See Cover lette'r ' ' ' z 150- O 2. ~.- 2. ,.?c~/~ I ~ J · ~.) I I for other requirements Conditions of Approval: Samples Required [] Yes [~ No Mud Log R~q~ired [] Yes .[~ No Hydrogen Sulfide Measures [] Yes ~ No Directional Survey Required ,~]'Yes [] No Required Working Pressure forBOPE []2K []3K []4K []5K []10K []15K ~.5Kpsi Other: by order of ~lQi~i~[[~ ~(~N~ ~ the commission Approved By ~, ~ ~ ....... Commissioner Date /? Form 10-401 Rev. 12-01-85 ORi tNAL Submit In Triplicate 1. Well Plan Summary MPF-86 Drilling Permit IWellName: IMPF-86 I Type of Well Iproducer or iniector): I Kuparuk Light Oil Producer Surface Location: F,86 Target (injeCtion ...... , Location): F-86 Target (Bottom Hole Location): 2089' FSL, (3190' FNL), 2941' FEL (2217' FWL), SEC. 06, T13N, R10E X - 541621.11 Y = 6035539.54 849, FSL, (4429, FNL), 4074' FEL (1205' FwL), SEC. 36, T14N, R09E X = 535308 Y = 6039547 Z = 6980 TVDss 884' FSL, (4394' FNL), 4129' FEL (1150' FWL), SEC. 36, T14N, R09E X = 535253 Y = 6039582 Z = 7225 TVDss ~ Nabors27E I Estimated Start Date: I May 22, 2001 Operating days to complete: I 18 I [ MDrkb ~ [ TVDrkb(TD) ~7270'~ I Well Desitin (conVentional, slim hole, etc.): I Grassroots Producer Scope: I Drill and Complete a Producer in the Kuparuk sands. Version #1, 4/25/2001 2. Current Well Information MPF-86 Drilling Permit 2.1 General 2.2 2,3 Well Name: MPF-86 APl Number: Well Type: Current Status: BHP: BHT: MPF-86 Development - Kuparuk Producer Conductor Set 2250 psi @ 7000' TVDss Top of the Kuparuk A sands. 165°F @ 7200' TVDss Estimated (SOR) Current Mechanical Condition MPF-86: Nabors 27E: Conductor: Cellar Box above MSL = 10.9' KB / MSL = 44.4' 20", 92 Ib/ft, H-40 Welded set at 80' MD Target Estimates Estimated Reserves: Expected Initial Rate: Expected 6-month avg: 1.31 MMBBL 1500 BOPD 1200 BOPD MPF-86 Drilling Permit 3. Drilling Hazards and Contingencies 3.1. Well Control MANDATORY WELL CONTROL DRILLS: Drill Type Frequency Comments D1 Tripping (1) per week, per crew Conducted only inside casing. D2 Drilling (1) per week, per crew Either in cased or open hole. DO NOT shut-in well in open hole. D3 Diverter N/A N/A D4 Accumulator Prior to spud or RWO Approx. every 30 days, thereafter at convenient times. D5 Well Kill Prior to drill out, Prior to drill out the intermediate and production strings. Never per crew carry out this drill when open hole sections are exposed. 3.2. Kick tolerance 3.2.1. The Kick Tolerance for the production casing based on the expected 6.2 ppg pore pressure across the formation is INFINITE with an FIT of 11.0 ppg EMW. 3.3. Lost Circulation 3.3.1. There is a potential for losses while drilling through the HRZ and Kalubik shale as well as the Kuparuk reservoir section. The lost circulation potential is due to the faulted structure in the HRZ and Kalubik shale as well as the 3+ ppg over balanced MW we must use in order to stabilize the D- shale above the reservoir. Most lost circulation events at 'F' pad have been related to breathing and lifting cement behind production casing. At the time this well is to be drilled, we should.have completed the E-26i well that was drilled with an overbalance of 5+ ppg, so we will need to look at the lessons learned from this well. 3.3.2. In the event we do occur losses, follow the LOST CIRCULATION DECISION MATRIX. Break circulation slowly in all instances and get up to recommended circulating rate slowly for placing cement. 3.3.3. Breathing is well documented at Milne Point between the Schrader Bluff and the HRZ when ECD's reach 11.5 ppg. 3.3.4. If well bore breathing occurs on MPF-86, the ADW RP "Well Bore Breathing" will be followed. As stated in that RP, it is ADW policy that any flow from the well will be treated as a well control problem until a definitive well bore breathing diagnosis is made. 3.4. Unexpected Pressures 3.4.1. It is unlikely there will be unexpected overpressure when drilling to TD. Reservoir pressure is expected to be 6.2 EMW. We will be drilling with a 9.6 ppg mud from the HRZ to TD for shale stability issues. 3.5. Stuck Pipe 3.5.1. Good drilling practices to avoid differential sticking are required. Minimum mud weights and proper mud properties as outlined in the Baroid mud program must be closely followed. 3.5.2. Stuck Pipe: Go immediately to SURE manual, determine stuck pipe mechanism, and follow recommendations. DO NOT JAR UP if packed-off! 3 MPF-86 Drillin~l Permit 3,6. 3.7, 3.8 3.9 3.10 Pad Data Sheet 3.6.1. Please Read the F-Pad Data Sheet thoroughly. Hydrocarbons 3.7.1. Hydrocarbons will be encountered in the Schrader Bluff and Kuparuk intervals. Hydrogen Sulfide 3.8.1. MPF Pad is not designated as an H2S Pad. Below is a summary of the most recent H2S readings: Well F- Location Well Type H2S Status Date taken 80 Surface Producer <2.00 Feb 2001 81 Surface Producer <2.00 Feb 2001 01 BHL Producer <2,00 Feb 2001 14 BHL Producer 6.7 Feb 2000 79 Max recorded Producer 9,5 May 2000 Faults 3.9.1 We will be crossing one fault in the HRZ @ 10475' MD (6674' TVD) with a 50' uncertainty and a 120' throw to the east. One Page Summary 3.10.1 A one-page summary of the Hazards and Contingencies will be generated and posted on the rig floor. 4. Drillin Pro_ ram Overview MPF-86 Drillin~l Permit 4.1. Surface and Anti-Collision Issues Surface Shut-in Wells: No wells need to be shut-in for the rig move on and off MPF-86 Close Approach Wells: There are no close approach wells Close Tolerance Lines: There is one well within 20' of the proposed MPF-86 Well Name Current Production Precautions Status Priority MPF-85 Injection N/A If hit, could result in loss of returns. Will run surface Gyro to miti~late the risk of collision. 4.2. Well Control Expected BHP Max Exp Surface Pressure BOPE Ratin~l Planned BOPE Test Pres. 2250 psi @ 7000' 1550psi 13 5/8" 5M Rams & Valves: 3500 psi/250 psi TVDss/estimated/ /0.1 psi/ft ~las ~radient/ Annular: 2500 psi / 250 psi 4.3. Mud Program 12-1/4" Surface Hole Mud Properties: Density(PPCJ) IFunnelvisc I YP I 8.6 - 9.4 50 - 150 15 - 35 HTHP N/A 8-1/2" Production Hole Mud Properties: OA/OB 9.6 35 - 45 6 - 20 < 10 Spud - LSND Freshwater Mud pH ]APl Filtrate LG Solids 9.0- 10.0I < 15 < 8 KCI-CaCO3 Mud pH APl Filtrate LG Solids 8.5 - 9.5 4 - 6 < 6 LCM Restrictions: Refer to MI mud program for more information. See LCM decision tree. Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1R. MPF-86 Drilling Permit 4.4. Formation Markers Estimated Uncertainty Hydrocarbon Est. Est. Formation Tops (feet) Bearing Pore Press. Pore Press. Formation (TVDss) (Yes/No) (Psi) (ppg EMW) BPRF 1750 SBF2-NA 3895 30 Yes SBA5 (base OB). 4175 30 Yes 1800 ~ °1.'~o '~ THRZ ! TUDZ 6570 30 BHRZ Faulted KLGM Faulted TKUD 6815 Faulted Top TKUC 6955 2O TKUB 6958 2O TKUA 6975 20 6.2 TKA3 6980 20 Yes 6.2 TKA2 6997 20 Yes 6.2 TKA1 7018 20 Yes 2250 6.2 TMLV 7O8O 2O TD 7225 4.5. Casing/Tubing Program Hole Size Csg ! Wt/Ft Grade Conn Length Top Bottom Tb~ O.D. MD / TVDrkb MD / TVDrkb 30" 20" 92# H-40 Welded 80' 33' / 33' 113' / 113' 12-1/4" 9-5/8" 40# L-80 BTC 6545' 33' / 33' 6547' / 4294' 8-1/2" 7" 26# L-80 BTC 11304' 33'/33' 11310'/7269' Tubin~l 4-1/2" 12.6# L-80 IBT +/- 11200' 33'/33' 11200'/7200' 4.6. Cement Calculations ICasin Size I 9-5/8" 40 Ib/ft L-80 BTC-M BasisI 250% excess over gauge hole in permafrost interval, 50% excess over gauge hole below permafrost IA TAM Port Collar will be placed at 1000' MD as a contingency for cement not displacing to surface in one stage Top of Tail cement to be 500' above Total Cement Volume: I Wash I Spacer I Lead I Temp the Schrader Bluff Sands. 50 bbl Freshwater 75 bbl of Viscosified Spacer weighted to 10.20 ppg 645 bbl 10.7 lb/gal Permafrost cement - 815 sacks BHST = 80° F from SOR, BHCT 85° F ICasin9 Size I 7" 26 Ib/ft L-80 BTC-M BasisI 50% excess over gauge hole TOC 1000' above the shoe Total Cement Volume: 20 bbl Freshwater Wash Spacer I Temp 40 bbl of Viscosified Spacer weighted to 11 ppg BHST = 165° F from SOR, BHCT 130° F Estimated MPF-86 Drillin9 Permit 4.7. Survey and Logging Program 12-1/4" Hole Section: Open Hole: DIR/GR 8-1/2" Hole Section: Open Hole: Cased Hole: DIR ! Res ! PWD / GR / Dens-Neutron RFT - drill pipe conveyed None 5. MPF-86 Operations Summary MPF-86 Drilling Permit 5.1. Pre-Rig Operations 1. Grade and level pad. 5.2. Procedure . 8. 9. 10. 11. 12. 13. 14. 15. MIRU Nabors 27E. NU 21-1/4" diverter, pick up 5" DP MU 12-1/4" BHA, spud in drill to planned Surface hole TD (6547' md). Run 9-5/8", 40#, L-80, BTC casing and cement to surface. ND diverter, NU Gen 5 wellhead & 13-5/8" BOP, test. MU 8-1/2" BHA, drill out float equipment plus 30' of new formation, perform FIT (minimum 11.0 ppg EMW). Drill to the planned Production hole TD (11310' md). Run RFT log on Drill Pipe Run 7", 26#, L-80, BTC casing and cement to 1,000' above the shoe. Run 4-1/2" frac completion Land Hanger and set packer. Shear out RP Shear valve in the GLM. Set TWC. Install BPV. ND BOP, NU tree, test to 5,000 Remove TWC, freeze protect, set BPV. RD, move off well. 5.3. Post Rig Operations 1. RU E-line. 2. Pull Ball and RHC Plug and perforate. 3. Pull RP Shear valve and Dummy off GLM 4. Perform Fracture Stimulation 5. Pull Sleeve Protector and install Jet Pump. 6. Clean out well with Jet Pump 7. RU 4ES and pull 4-1/2" Frac String 8. Complete with 2-7/8" tubing with ESP Milne Point F-86: Proposed ComPletion TREE: 4" - 5M Cameron WELLHEAD: 11" - 5M Gen 5 FMC Tubing Hanger: 7-1/16 x 4-1/2 Tubing Head: 11 x 7-1/16 Adapter: 7~1/16 5M x 4 5M 20", 91.1 CC/ft, H-40 @ 113'MD (113' TVD) Cellar Elevation = +10.9' RKB-MSL = +44.4' MW = 9.5 ppg 9-5/8", 40 CC/fi, L-80, BTC @ +/- 6547' MD ( 4294' TVD) 4-1/2" 12.6# L-80, EUE Frac String 4-1/2" x 1" Gas Lift Mandrel Sliding Sleeve for Jet Pump completion 7" x 4-1/2" Production Packer above A-sands TD @ +/- 11310' MD ( 7270' TVD) - 150' below Miluveach MW = 9.6 ppg Wireline entry guide 7", 26 #/ft, L-80, BTC-Mod Date 5-7-01 Rev By Comments JDF Proposed Completion WP3 Milne Point WELL: F-86 APl NO: 50-029-????? BP Alaska Drilling & Wells VERTICAL SECTION VIEW Client: Alaska Drilling & Wells Well: MPF-86 (P4) Field: Milne Point Unit Structure: MPF Section At: 302.73 deg Schlumberger o,,I II ,,%.... -2000 2000- 400O 6000 8000 10000= KBE ................. f KOP 41100500MD 500TVD ................. I 0.00' 306.68" az 0 departure t .................................. ~ Bid 2/100 600 MD 600 TVD 11.00" 306.68" az I 1 departure End Bid 1820 MD 1779TVD ~'"~'" 25.40" 306.68" az 277departur~ ~. .... ' ..... I Bd25/IOO1854MD 1810TVE ...................... ':;;"-"::~:~ ' ................... ~ ............................................................ ~': ~"I', :' '~,' '~" r ~ ~'?. ~,'i'l'~ 1'~~ ~VI" .................... ~ i..'~ ~" 5924". 306 69" az. 1186d~parture : ~ ............ ' ......... End Bid 3443 MD 2~08 TVD ~~ ~ ,x 63.48" 301.~1" az ~ ~ ~ ' '" 4052 departure ......... ~ ~ ~'~ ~, 'O~ ~"' ~ ................................................................ ~ ............... j ~O/~. ~ ~ Drp 3,100 ~ ~'~. '~ ~ / 9011 MD 5394 ~ ~O~, ~ ~ j / 63.48" 301 91"~z ~ ~ Target 1{057MD 7024~D t ...... 15.00" 3pl.91" az 7479 departure "~" - ~ ..... ~;'~ ~'~'r~;: ;TL~:~' ~d~:~ ~;~ ~,'~4'T~O .............................................. ~ ..................................... ~'-'~.::,_ ' ........... ~"~ .......................... / '~ ~U~ ~ ~ '3,1 r~[~ ....... ~,,,~ ..... ~..J~,~ ;,,,~., ............................................................. i ..................................... ~ .......... ';::::"~ ......... ~ .......................... ~'~'K/ I 11096 TD / T' Lnr Pt 11311 MD 7269~D 7S45 depnr~ure 0 2000 4000 6000 8000 Vertical Section Departure at 302.73 deg from (0.0, 0.0). (1 in = 2000 feet) PLAN VIEW Client: Alaska Drillin9 & Wells Well: MPF-86 (P4) Field: Milne Point Unit Structure: MPF Scale: 1 in = 1000 ft Date: 01-May-2001 Schlumberger 4000 A A A -I- 3000 O Z 2000 0 looo v v v -6000 -5000 -4000 -3000 -2000 -1000 0 ~ j Target 11057MD 7~24TVD - _/~ / 15.00" 301.91°az 4~14N 6291W i i i ---Survey · ' i~i !Drp 31tO0 I ~ 19011 MD 5394 TVD TDIT"LnrPt ~ i '~- ,'" ~63-48° 301-91TM 113. ~4D 7269TVD : '~- / :%46, N 53S5W 4079 N 6347 W '~ /' -:' d Dq 10627~ O 6609 TVD ~ 15.oo' 3Ol.9. az i % I i [ ~ i ~ i 3443 MD 2908; VD ,..." 828N 1128W i ~ _ 1 i i i i 1.00° 306.(80az 1N lW · i i i i 0'00° 3~6'680az ON OE -6000 -5000 -4000 -3000 -2000 -1000 0 <<< WEST EAST >>> 40OO 3OOO 200O 1000 Report Date: Client: Field: Structure I Slot: Well: Borehole: UWlIAPI~: Survey Name I Date: Tort I AHD / DDI I ERD ratio: Grid Coordinate System: Location Lat/Long: Location Grid N/E Y/X: Grid Convergence Angle: Grid Scale Factor: MPF-86 Proposed Well Profile - Geodetic Report May 1, 2001 Alaska Drilling & Wells Milne Point Unit MPF / MPF-86 ~ IL.~ J~ ~ MPF-86 ~- ~"~' "' -- MPF-86 (P4) / May 1, 2001 113.678° / 7548.13 ff / 6.126 / 1.03E NAD27 Alaska State Planes, Zone 4, US Feel N 70 30 28.855, W 149 39 34.064 N 6035539.540 ftUS, E 541621.110 ftUS +0.32102130° O.9999O197 Schlumberger {~')~ ~y Survey, DLS Computation Method: Vertical Section Azimuth: ¢~¢y Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North -> True North: Local Coordinates Referenced To: Minimum Curvature / Lubinski 302.730° N 0.000 ft, E 0.000 fl KB 44.4 ft relative to MSL 26.236" 57441.279 nT 80.809° 30-May-01 BGGM 2000 True North 26.236 Well Head Station ID KBE KOP 1/100 Bid 2/100 MD Incl Azim 0.00 500.00 600.00 70O.O0 800.00 0.00 306.68 0.00 306.68 1.00 306.68 3.00 306.68 5.00 306.68 I (ft) 0.00 500.00 599.99 699.93 799.68 (ft) (ft) (ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.87 0.52 -0.70 4.35 2.61 -3.50 11.31 6.77 -9.09 DLS (°~ooftI 0.00 0.00 1.00 2.00 2.00 Grid Coordinates Northing {.US) I 6035539.54 6035539.54 6035540.06 6035542.13 6035546.26 Easting I"US) 541621.11 541621.11 541620.41 541617.60 541611.98 Geo~raphicCoordinates Latitude I Longitude N 70 30 28.855 W149 39 34.064 N 70 30 28.855 W149 39 34.064 N 70 30 28.860 W149 39 34.085 N 70 30 28.880 W149 39 34.167 N 70 30 28.921 W149 39 34.332 900.00 7.00 306,68 899.13 21.74 13.02 -17.47 1000.00 9.00 306.68 998.15 35.62 21.33 -28.63 1100,00 11,00 306,68 1096,62 52.94 31.71 -42,56 1200,00 13,00 306,68 1194,43 73,68 44,13 -59,23 1300,00 15,00 306,68 1291,46 97.82 58,58 -78,63 2.00 2.00 2.00 2.00 2.00 6035552.46 6035560.71 6035571.01 6035583.33 6035597.67 541603.57 541592.36 541578.38 541561.64 541542.16 N 70 30 28.983 W149 39 34.579 N 70 30 29.064 W149 39 34.907 N 70 30 29.166 W149 39 35.318 N 70 30 29.289 W149 39 35.809 N 70 30 29.431 W149 39 36.380 1400.00 17.00 306.68 1387.58 125.31 75.04 -100.73 1500.00 19.00 306.68 1482.68 156.14 93.50 -125.51 1600.00 21.00 306.68 1576.65 190.26 113.94 -152.94 1700.00 23.00 306.68 1669.36 227.63 136.31 -182.98 1800.00 25.00 306.68 1760.71 268.20 160.61 -215.60 2.00 2.00 2.00 2.00 2.00 6035614.01 6035632.33 6035652.61 6035674.81 6035698.92 541519.97 541495.09 541467.55 541437.39 5414O4.64 N 70 30 29.593 W149 39 37.031 N 70 30 29.774 W149 39 37.761 N 70 30 29.975 W149 39 38.569 N 70 30 30.195 W149 39 39.453 N 70 30 30.434 W149 39 40.414 MPF-86 (P4) report.xls Page 1 of 3 5/1/01-4:26 PM Grid Coordinates Geo~[iraphic Coordinates I Station ID I MD I Incl I Azim I TVD I VSec I N/-S I E/-W I DLS Northing I Easting Latitude I Longitude (ft) (o) (o) (ft) t~t) (ft) Irt) I°llooft) (ftus) tf~usl End Bid 1820.10 25.40 306.68 1778.90 276.74 165.73 -222.46 2.00 6035704.01 541397.75 N 70 30 30.484 W 149 39 40.616 Base Permafrost 1837.26 25.40 306.68 1794.40 284.09 170.12 -228.36 0.00 6035708.36 541391.82 N 70 30 30.528 W 149 39 40.790 Bid 2.5/100 1854.10 25.40 306.68 1809.61 291.29 174.44 -234.16 0.00 6035712.65 541386.00 N 70 30 30.570 W 149 39 40.961 1900.00 26.55 306.69 1850.87 311.35 186.45 -250.28 2.50 6035724.57 541369.81 N 70 30 30.688 W 149 39 41.436 2000.00 29.06 306.69 1939.32 357.88 214.31 -287.68 2.50 6035752.21 541332.26 N 70 30 30.962 W 149 39 42.537 2100.00 31.56 306.69 2025.64 408.22 244.46 -328.15 2.50 6035782.13 541291.63 2200.00 34.07 306.69 2109.68 462.28 276.83 -371.60 2.50 6035814.26 541248.00 2300.00 36.57 306.69 2191.27 519.95 311.37 -417.96 2.50 6035848.53 541201.45 2400.00 39.08 306.69 2270.25 581.12 348.01 -467.13 2.50 6035884.89 541152.08 2500.00 41.58 306.69 2346.48 645.68 386.67 -519.02 2.50 6035923.26 541099.98 N 70 30 31.259 W149 39 43.729 N 70 30 31.577 W149 39 45.009 N 70 30 31.917 W149 39 46.374 N 70 30 32.277 W149 39 47.823 N 70 30 32.657 W149 39 49.351 2600.00 44.09 306.69 2419.81 713.50 427.28 -573.54 2.50 6035963.56 541045.24 2700.00 46.59 306.69 2490.09 784.45 469.77 -630.57 2.50 6036005.72 540987.98 2800.00 49.10 306.69 2557.20 858.40 514.06 -690.01 2.50 6036049.68 540928.30 2900.00 51.60 306.69 2621.01 935.21 560.06 -751.75 2.50 6036095.32 540866.31 3000.00 54.11 306.69 2681.39 1014.72 607.68 -815.66 2.50 6036142.58 540802.14 N 70 30 33.057 W149 39 50.957 N 70 30 33.474 W149 39 52.637 N 70 30 33.910 W149 39 54.387 N 70 30 34.362 W149 39 56.206 N 70 30 34.831 W149 39 58.089 Crv 2.5/100 3100.00 56.61 306.69 2738.23 1096.79 656.83 -881.63 2.50 6036191.36 540735.90 3200.00 59.12 306.69 2791.42 1181.26 707.42 -949.53 2.50 6036241.56 540667.73 3205.04 59.24 306.69 2794.00 1185.57 710.00 -953.00 2.50 6036244.12 540664.24 3300.00 60.91 304.74 2841.37 1267.76 758.03 -1019.83 2.50 6036291.77 540597.15 3400.00 62.69 302.75 2888.63 1355.87 806.97 -1093.11 2.50 6036340.29 540523.61 N 70 30 35.314 W149 40 0.032 N 70 30 35.811 W14940 2.032 N 70 30 35.837 W14940 2.134 N 70 30 36.309 W149 40 4.103 N 70 30 36.790 W14940 6.261 End Bid SBF2-NA SBA5 (Base OB) 9-5/8" Csg Pt Drp 3/100 3443.38 63.48 301.91 2908.27 1394.55 827.66 -1125.79 2.50 6036360.80 540490.81 5752.52 63.48 301.91 3939.40 3460.47 1919.81 -2879.67 0.00 6037443.00 538731.02 6379.56 63.48 301.91 4219.40 4021.46 2216.38 -3355.93 0.00 6037736.86 538253.15 6413.15 63.48 301.91 4234.40 4051.51 2232.27 -3381.45 0.00 6037752.61 538227.55 9011.08 63.48 301.91 5394.49 6375.80 3461.01 -5354.67 0.00 6038970.15 536247.67 N 70 30 36.994 W149 40 7.224 N 70 30 47.730 W149 40 58.897 N 70 30 50.645 W149 41 12.931 N 70 30 50.801 W149 41 13.683 N 70 31 2.874 W14942 11.841 9100.00 60.81 301.91 5436.04 6454.40 3502.56 -5421.40 3.00 6039011.32 536180.72 9200.00 57.81 301.91 5487.07 6540.38 3548.01 -5494.39 3.00 6039056.36 536107.48 9300.00 54.81 301.91 5542.53 6623.56 3591.99 -5565.01 3.00 6039099.94 536036.62 9400.00 51.81 301.91 5602.27 6703.73 3634.37 -5633.07 3.00 6039141.93 535968.33 9500.00 48.81 301.91 5666.13 6780.67 3675.04 -5698.39 3.00 6039182.23 535902.79 N 70 31 3.282 W 14942 13.808 N 70 31 3.728 W 149 42 15.960 N 70 31 4.160 W 149 42 18.042 N 70 31 4.576 W 149 42 20.048 N 70 31 4.976 W 149 42 21.974 9600.00 45.81 301.91 5733.92 6854.16 3713.89 -5760.78 3.00 6039220.73 535840.19 9700.00 42.81 301.91 5805.47 6924.00 3750.81 -5820.07 3.00 6039257.31 535780.70 9800.00 39.81 301.91 5880.58 6989.99 3785.70 -5876.10 3.00 6039291.88 535724.48 9900.00 36.81 301.91 5959.04 7051.97 3818.47 -5928.72 3.00 6039324.35 535671.68 N 70 31 5.358 W14942 23.813 N 70 31 5.720 W149 42 25.561 N 70 31 6.063 W149 42 27.213 N 70 31 6.385 W149 42 28.764 MPF-86 (P4) report.xls Page 2 of 3 5/1/01-4:26 PM Grid Coordinates Geo~lraphic Coordinates I Station ID I MD I Incl I Azim I TVD I VSec I N/-S I E/-W I DLS Northing I Easting Latitude J Longitude tft) (°) (°) (ft) (ft) (ft) (rt) t°/~00ft) IftUS) tftUS) 10000.00 33.81 301.91 6040.63 7109.76 3849.02 -5977.78 3.00 6039354.63 535622.46 N 70 31 6.685 W149 42 30.210 10100.00 30.81 301.91 6125.14 7163.20 3877.27 -6023.14 3.00 6039382.62 535576.95 N 70 31 6.962 W149 42 31.547 10200.00 27,81 301.91 6212.33 7212.14 3903,14 -6064.69 3,00 6039408,25 535535.26 N 70 31 7.216 W149 42 32.772 10300.00 24.81 301.91 6301,96 7256.46 3926.57 -6102.31 3.00 6039431.47 535497.51 N 70 31 7,447 W149 42 33.882 10400.00 21.81 301,91 6393,78 7296.02 3947.48 -6135.90 3.00 6039452.19 535463.81 N 70 31 7.652 W149 42 34.872 10500.00 18.81 301,91 6487,56 7330.72 3965.83 -6165.36 3.00 6039470,37 535434.25 N 70 31 7.832 W14942 35.740 10600.00 15.81 301,91 6583,02 7360.47 3981.55 -6190.62 3.00 6039485.95 535408.90 N 70 31 7.987 W 149 42 36.485 End Drp 10627.01 15.00 301.91 6609.05 7367.64 3985.35 -6196.71 3.00 6039489.71 535402.79 N 70 31 8.024 W 149 42 36.665 Top HRZ/TUDZ 10632.54 15.00 301.91 6614.40 7369.08 3986.10 -6197.92 0.00 6039490.46 535401.58 N 70 31 8.031 W 149 42 36.700 TKUD 10886.19 15.00 301.91 6859.40 7434.72 4020.80 -6253.65 0.00 6039524.84 535345.66 N 70 31 8.372 W 14942 38.343 TKUC 11031.13 15.00 301.91 6999.40 7472.23 4040.63 -6285.50 0.00 6039544.49 535313.70 N 70 31 8.567 W 14942 39.282 TKUB 11034.23 15.00 301.91 7002.40 7473.03 4041.06 -6286.18 0.00 6039544.92 535313.02 N 70 31 8.571 W149 42 39.303 TKUA 11051.83 15.00 301.91 7019.40 7477.58 4043.46 -6290.04 0.00 6039547.29 535309.15 N 70 31 8.595 W149 42 39.416 TKA3 11057.00 15.00 301.91 7024.40 7478.92 4044.17 -6291.18 0.00 6039548.00 535308.00 N 70 31 8.602 W149 42 39.450 Target 11057.01 15.00 301.91 7024.40 7478.92 4044.17 -6291.18 0.00 6039548.00 535308.00 N 70 31 8.602 W149 42 39.450 TKA2 11074.61 15.00 301.91 7041.40 7483.48 4046.58 -6295,05 0.00 6039550.39 535304.12 N 70 31 8.625 W14942 39.564 TKA1 11096.35 15.00 301.91 7062.40 7489.10 4049.56 -6299.82 0.00 6039553.34 535299.33 N 70 31 8.654 W14942 39.705 TMLV 11160.53 15.00 301.91 7124.40 7505.72 4058.34 -6313.93 0.00 6039562.04 535285.18 N 70 31 8.741 W14942 40.121 TD / 7" Lnr Pt 11310.54 15.00 301.91 7269.29 7544.54 4078.86 -6346.88 0.00 6039582.37 535252.11 N 70 31 8.942 W149 42 41.092 Le.qal Description: Surface: 2088 FSL 2941 FEL S6 T13N R10E UM Target: 850 FSL 4074 FEL S36 T14N R9E UM BHL: 885 FSL 4130 FEL S36 T14N R9E UM Nodhinq {Y)[ftUS] Eastinq{X) rflus] 6035539.54 541621.11 6039548.00 535308.00 6039582.37 535252.11 MPF-86 (P4) report.xls Page 3 of 3 5/1/01-4:26 PM I,' BP Anticollision Report Date: 4/14/2000 Planned From To ft ft Company: BP Amoco Date: 4/25/2001 Time: 10:29:11 Page: 1 Field: Milne Point Reference Site: M Pt F Pad Co-ordinate(NE) Reference: Well: MPF-86, True North Reference Well: MPF-86 Vertical (TVD) Reference: 100 ' 86 9/28/1997 14:47 43.9 ReferenceWellpath: Plan MPF-86 Db: Sybase NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: Stations Error Model: ISCWSA Ellipse Depth Range: 33.00 to 11310.31 ft Scan Method: Tray Cylinder North Maximum Radius: 10000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Validated: No Version: 21 Survey Toolcode Tool Name 33.00 300.00 Planned: Plan #3 V1 CB-GYRO-SS Camera based gyro single shots 300.00 6500.00 Planned: Plan #3 V1 MWD+IFR+MS MWD + IFR + Multi Station 33.00 6500.00 Planned: Plan #3 V1 GYD-CT-CMS Gyrodata cont.casing mis - Not Used in Program 6500.00 11310.31 Planned: Plan #3 V1 MWD+IFR+MS MWD + IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 6545.37 4293.90 9.625 12.250 9 5/8" 11310.00 7269.30 7.000 8.500 7" Summary < ...................... Offset Wellpath ...................... > Reference Offset ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ff ff ft i ff ft M Pt F Pad MPF-01 MPF-01 V1 5293.11 5705.70 555.12 179.92 395.43 Pass: Major Risk M Pt F Pad MPF-06 MPF-06 V1 4140.21 4303.50 328.01 131.64 196.98 Pass: Major Risk M Pt F Pad MPF-10 MPF-10 V1 2937.62 3152.25 188.38 76.32 128.21 Pass: Major Risk M Pt F Pad MPF-13 MPF-13 V1 591.96 589.30 362.94 10.02 352.92 Pass: Major Risk M Pt F Pad MPF-14 MPF-14 V1 506.33 507.90 261.83 8.21 253.62 Pass: Major Risk M Pt F Pad MPF-18 MPF-18 V1 2271.71 2412.45 165.01 48.82 124.12 Pass: Major Risk M Pt F Pad MPF-22 MPF-22 V3 1434.62 1510.00 214.01 25.90 189.31 Pass: Major Risk M Pt F Pad MPF-25 MPF-25 V1 593.08 600.00 335.87 10.36 325.51 Pass: Major Risk M Pt F Pad MPF-26 MPF-26 V16 600.00 600.00 229.62 9.69 219.93 Pass: Major Risk M Pt F Pad MPF-30 MPF-30 V1 514.81 518.50 225.44 8.15 217.29 Pass: Major Risk M Pt F Pad MPF-34 MPF-34 V7 Plan: Undefi 499.85 512.40 227.32 9.68 217.64 Pass: Major Risk M Pt F Pad MPF-34 Plan MPF-34 L1 V9 Plan 499.85 512.40 227.32 9.63 217.69 Pass: Major Risk M Pt F Pad MPF-34 Plan MPF-34L1 frac V1 499.85 512.40 227.32 9.68 217.64 Pass: Major Risk M Pt F Pad MPF-38 MPF-38 V1 507.96 495.60 230.69 8.61 222.08 Pass: Major Risk M Pt F Pad MPF-42 MPF-42 V6 970.75 1000.00 226.09 17.02 209.18 Pass: Major Risk M Pt F Pad MPF-46 MPF-46 V4 1012.88 1040.00 239.90 17.57 222.54 Pass: Major Risk M Pt F Pad MPF-50 MPF-50 V6 600.00 589.50 265.77 10.07 255.71 Pass: Major Risk M Pt F Pad MPF-54 MPF-54 V3 691.39 689.50 278.79 10.59 268.20 Pass: Major Risk M Pt F Pad MPF-58 MPF-58 V1 945.98 964.10 293.44 18.44 275.03 Pass: Major Risk M Pt F Pad MPF-79 MPF-79 V3 3152.39 3100.00 155.94 87.83 82.01 Pass: Major Risk M Pt F Pad MPF-79PB1 MPF-79PB1 V6 3153.97 3102.80 154.13 87.88 79.90 Pass: Major Risk M Pt F Pad MPF-80A MPF-80AV4 Plan: MPL-4 414.10 400.00 179.96 7.70 172.26 Pass: Major Risk M Pt F Pad MPF-80 MPF-80 V6 Plan: Undefi 327.94 313.85 180.25 5.89 174.36 Pass: Major Risk M Pt F Pad MPF-81 MPF-81 V4 456.88 453.00 148.31 8.16 140.14 Pass: Major Risk M Pt F Pad MPF-82 MPF-82 V3 517.44 484.87 119.71 8.26 111.46 Pass: Major Risk M Pt F Pad MPF-82 MPF-82PB1 V8 517.44 484.87 119.71 8.15 111.57 Pass: Major Risk M Pt F Pad MPF-83 MPF-83 V9 604.98 600.00 86.62 9.27 77.36 Pass: Major Risk M Pt F Pad MPF-84 MPF-84 V16 Plan: Undef 599.82 600.00 62.59 11.89 50.71 Pass: Major Risk M Pt F Pad MPF-84 MPF-84A V9 599.82 594.57 62.59 11.56 51.03 Pass: Major Risk M Pt F Pad MPF-84 MPF-84APB1 V2 599.82 594.57 62.59 11.78 50.82 Pass: Major Risk M Pt F Pad MPF-84 MPF-84B V4 599.82 597.32 62.59 11.67 50.93 Pass: Major Risk M Pt F Pad MPF-85 MPF-85V26 Plan: Undef 999.28 986.00 38.92 19.14 19.78 Pass: Major Risk M Pt F Pad MPF-92 MPF-92 V15 299.39 300.00 181.39 6.03 175.36 Pass: Major Risk M Pt F Pad MPF-95 MPF-95 V13 Plan: Undef 399.39 387.10 272.22 8.43 263.79 Pass: Major Risk MPF-86/Plan MPF-86 400 380 360 340 320 300 280 260 · 240 220 200 180 160 140 120 100 80 60 40 ii :.':...: :ii': ......:..,'. . ..:.. . ,. .,. 20 60 ....... 81) .... 100 ........ 120 ..... 140 ..,. 24') · ,% :, i .,;.,,'. ,,, .... \,~. . ..- ',!!,:,,,,~., ,. '.., .:' ,'.. '.,?.~. r'. ',': ', ;~:. :: ,.~' %. l...-..'s.,,,.,'....'.'-..' . .',11.' L ~; .... '. :::.-..,'.t.',, -.-.. .... ........ ~, : ,',:'~. %;', .~ ','!' ...~...,r. ,,,, ,,..,,,,,..,.,, .'.'7.: ,,, · '~. ~,..~.'..<... '...,... ,, ,.. ,, .,,. ,,;~ ...... ! ~ ,, .' ,, ~ ' . '~, '.,: : '..., .,.. .. . ' ". ". ". i.:" ': 57: :-:"~...?'"?.- "..: .','. :., · .' ." . :-' F'; '.,.'.'.%'!:. "' ....' ';.; ":'. :"..,". ,' · ' ". ~";' 2. '-', ::~-'t.~-' ,' ,:, '"' . "" : :"" 'h'..'i;:;.'::%':':,'...!'?/.::":,:' .':,,,:, . ,. [, ... , .. ,;...-, .. · :,,:'.,. ,.?,.,.,. ;-. ,, ,,,: · " . 'i:":..':.'":".'" '?."'.;~-.'::.'; ..... :."':' '". .' · .' ' ~':' '.,,. ~i?:':.:.":.'.' '/::.. ,,:.'- ' "' ' "~."..:...!..'-.';?':i.:"..':?'.'..." .'"'.,:"?:"].,. ........ . .. ,.....,...?..,:.;-~;: ,, . .... ~,' ,,.~, , } ., ...... '.,.,.:~ ,,, .., .,. .,,.., ,.~ · .. .....v...'. ;'..2';,,..")..~:L'.;'::.;2.'"'...", ' '..',,.v '". ....... '~,;:'"/?&.'.-;"': '." L: ": ,'.. "" .; '", "'..': · '" "'. "~;::":::,'z'.53!:;,':'.."..: :::.'..:::""'.'.~,Y: ',' . , ......,r., ..::....::.~.. ,... ""', "-.C" j % "~ ''~ '., .. I'..~.;.. :~:.-~.t- ...... ..,,:.' ':' :. , .. . [::,.;, ~' .'.:] . ~ ...... -. - ,.;?..., i. . · . . ..... t' :; .,'~ ',~:.'," ".... ' ..'.. '~ ' · . · .." ,.._ :..., .L.;,;. ,.'.,:'.:,..' .' .:.:7...'7.,.-'. '.'".'i '..( ... ' :: ",.. ' ~';'..t:?'..'::.~'-","':..'::'.." /'~::-' .... . ~",'" '".., .'...' ... "'".::"[:: '. ':' "" ':':. ~.'-.'-7".: '~.'..;' .~.;..:.:.t. -:.., ...,..,. /... :..' :,: !';:........: :: :-.. ,,.., ...... ... .....,. _..... ; : .. :: :, ~%. , .,.,. ,' .,y, ..: :.: :,..::(i..'/:...:/".., .... .' .:. ',,'.:,;:,',,::-',::",'.,'!,,.' ':",,~ ', q!::L~.":. ,:.F' ."",:.;, :;).' ~. :. · ." .," '3. :-'. ~":: '?: ", .... :.." · ' .}:~,,/. '.' ,,. · ._ ',f,: ", ,, 4~.,.. ..j ..... ,.. , ,. ., · I ," " ' · ' '%d , ' '"x ,.'" ,,',' o,,,, ...... ."..' ,.. ',' · . ,.. 7'-,'-: .........'~+'~:'.. '.' .'. "' .....'~., '..;., ." ".. ' · ':," ::".7:'.t ,.'"'4"~:!;"~' ',. ' · ,. , .:..:. 7,~...,' ... . ... ..... 160 ....... 180 ...... 200 220 240 260 280 300 ..... 320 ..... 340 ..... 360 ...... 380 .... 400 ". , · , ' '/ I . -. t '".:,,,, ' ''~ ';:" 't '/' . '" "' . ',';'"~" F":."!;.7~2~::...:': ' · ." '."'""' ~'.:'L:,;:..<.~'. "' ,__....,:...;.~..~'~' I ~:, ,~' .;..._~:~.. ;. . , ,,.,. I ::. :-i~.?:~..!':{, ,'. : i " "' ' .~.~.:....t~.~,¢;t .,." ' · ' ~ 22,'., ;' " j ' ,'. ..: ,; . .., .. ,/' :,~.' . ,,. ,' ' "', ' J.':.: ............. : ........ ;;""~. "' '." . I _'.',?:, ','"' '. ,, L,.:...' ....... $,,.:,...,?..::: ./x,...::' , ..... '."h~o .~ .f'7~.:":~"' . ' :'z,,',' ' ,'"';"'"',"3'<". '::"" ~';'"' ,."~. " ' ' . ,' .' 3". , :P'~ L'..:,.' / ' 'x /~'~" ..... ~. ',;':',,'"'-,,,. ,',,;.'""' ,' . .' " · , ', '2~.:. i ~.',,x~",,.i~' ' ' ,%1 ." .... :',,-" .' .... ',~ ~,, ~ . ,.: ,..,,:. ...... '.....,..,".,., . . . . · . ,.,, ,~.,._~. . % . ,.~'~..,- ...... ;,,/. .............. .,,.,,:...,,;, ,,. , ,' . .,~,~,.~,~ · . ,?,., ' ,., ......; ..:.... ......... ../,:. · .....,~..:' , .,. ...... 'x, ' ,,'". .......... :-'"' 'e'I '. ' '...,,".'2:) '' ," x. ';," : ............. '/. '...... -..j,.,, .... . . ,,," ""x '. ............. "'; .................. :%.: ;' "": :'~ :' "" -~"' ' , f" , ,.,:,~ ~,%//..~×/'.r~' ~'2':-' ,',' ' '"'",., I ;' .:,,:'" '".'"",,,,. -~./" .... ' .... , ' · ~'°'"'"'~' I "~., .,,~__'" '~:': '"~ ..... ~' ',: ~I,;;:,>''15o · (M r /[ '-- ,~ ........' Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [ft] CHECK NO. 00188128 VENDOR A _ABKAOILA OD ·le~m 11..~1111../ .I., .I.m~ ~/V DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET __ 041801 CK041801C 100. O0 100. O0 PYMT (:OMMENTS- Perr~it to Drill l-ee HANDL]NO INST' S/H - Terrie Hubl~le X4&28 E ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOV~~II~~ 1 OO. CO 1OO. CO DRDER OO~hh ]-qll" WELL PERMIT CHECKLIST COMPANY z~',/~ WELL NAME ./~eF'- ~'~' PROGRAM: exp dev .~' redrll serv wellbore seg ann. disposal para req FIELD & POOL ~.~_.,5'/,~ ~J INIT CLASS _/'~f=.~.,, /-,~,,'/ GEOL AREA ,¢ ? r-.., UNIT# //~ 2__~ ON/OFF SHORE ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in ddlling unit ............ 8. If deviated, is wellbore plat included ............. ... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... Y N Y !N Y N Y N Y N Y N Y N Y N Y N Y N Y N · 13. Can permit be approved before 15-day wait ........... ~Y N ENGINEERING 14. Conductor stdng provided ................... 15. Surface casing protects all known USDWs ........... ~ N - ' ' · 16. CMT vol adequate to circulate on conductor & surf csg ..... ~ I~1.. : . . . 17. CMT vol adequate to tie-in long string to surf csg .... ' .... ~ ~_~ · ' 18. CMT will cover all known productive hodzons ..... ': .... 19. Casing designs adequate for C, T, B & permafrost ....... ( Y~ N ' ' ' 20. Adequate tankage or reserve pit ................. (~ N (7~.~~ t"[,c I ~-..¢::~ ~¢.S.J2~--~ ~ ~ · 21. If a re-drill, has a 10-403 for abandonment been approved... ~ ~ ~, ~- --~ . ,... ,, ~ . ,., . 22. Adequate wellbore separation proposed ....... ; ...... 23. If diverter required, does it meet regulations .......... 24. Drilling .fluid program schematic & equip list adequate ..... · 25. BOPEs, do they meet regulation ............. '... (V_..} N ' , ~' '~ - ~TE 6. BOPE press rabng appropriate; test to .'~~ ping. II/b_7///// ' 27. Choke manifold complies w/APl RP-53 (May 84) ........ (-'~ N ' - - ~ ' . I1"~ ' - - 28. Work will occur without operation shutdown ........... ~ _.N ,, ' ' II ~. is presence of H2S gas probable ................. Y II .... ~' -3 ~ · ' .~ -r ~'~ . ' II GEOLOGY . 30. Permit can be issued wlo hydrogen sulfide measures ...... Y N .,,/ ' II 31. Data presented on potential overpressure zones ....... Y N,/# /'0 . II ' 32. seismic analysis of shallow gas zones ............. y/f~ II A~PR D~,T,E 33. Seabed condition survey (if off-shore) ............. · /Y N ' . ' . . '~/~ ~/.¢/'~ / 34. Contact name/phone for weekly progress reports [exploratory only]/ Y N . ~ ' . o-rCCdS L- , t- ph- ; , (A) will contain waste in a suitable receiving zone; ....... APPR DATE (B) will not contaminate freshwater; or cause ddlling waste... to surface; ' (C) will not impair mechanical integrity of the well used for diSposal; (D) will not damage producing formation or impair recovery from a pool; .and ...... (E)...will no_t. circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOLOGY:. ENGINEERING: UlC/Annular Y N Y N Y N COMMISSION: Commentsllnstructions: 0 Z 0 z c:Vnsoffice\wordia n~diana\checklist (rev. 11101//00)