The URL can be used to link to this page

Home My WebLink About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y Anne Prysunka at 2:55 pm, Nov 15, 2022 'LJLWDOO\VLJQHGE\7RULQ 5RVFKLQJHU '1FQ 7RULQ5RVFKLQJHU RX 8VHUV 'DWH 7RULQ5RVFKLQJHU RBDMS JSB 111722 WCB 11-29-2024 DSR-11/15/22 tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ EϯͲϭϭ ^Zηϭ ϱϬͲϬϮϵͲϮϭϴϰϴͲϬϬͲϬϬ ϭϴϴͲϬϴϳ ϭͬϯϭͬϮϬϮϮ ϵͬϮϵͬϮϬϮϮ ϮͬϮͬϮϬϮϭ ,ŽŽŬƵƉƌŝŐƚŽŚŝŐŚůŝŶĞƉŽǁĞƌ͕ƵŶͲŚŽŽŬƉŽƌƚĂďůĞŐĞŶĞƌĂƚŽƌ͘ŽŶƚŝŶƵĞƚŽŚŽŽŬƵƉŵŝƐĐ͘ůŝŶĞƐĂŶĚĞƋƵŝƉŵĞŶƚ͘/ŶƐƚĂůůƚĂƌƉƐĂŶĚ ǁŝŶƚĞƌŝǌĞƌŝŐĨŽƌŽƉĞƌĂƚŝŽŶƐ͕ǁĂƌŵƵƉƐƚĂĐŬĂŶĚůŝŶĞƐ͘/ŶƐƚĂůůϮĨƚǆϭϯͲϱͬϴϱŵƐƉŽŽůŽŶĂŶŶƵůĂƌ͕ƉͬƵƚĞƐƚũƚ͘ƌŝŶŐWŽǁĞƌƐǁŝǀĞů ĚŽǁŶƚŽƌŝŐĨůŽŽƌĨŽƌĞůĞĐƚƌŝĐŝĂŶƚŽƚƌŽƵďůĞƐŚŽŽƚǁŽďďůĞƐǇƐƚĞŵ͘&ŝůůƐƚĂĐŬĨŽƌƐŚĞůůƚĞƐƚͲƵŶĂďůĞƚŽƚĞƐƚĂŶŶƵůĂƌǁŝƚŚϮϳͬϴƚĞƐƚ ũƚ;ϯϱϬϬƉƐŝͿ͘ĚũƵƐƚĂŶŶƵůĂƌĐůŽƐŝŶŐƉƌĞƐƐƵƌĞƚŽǀĂƌŝŽƵƐƚŝŵĞƐƌĂŶŐŝŶŐĨƌŽŵϵϬϬƚŽϭϱϬϬƉƐŝ;ĨĂŝůĞĚƚĞƐƚƐͿ͘WͬhϰϭͬϮΗƚĞƐƚũƚĂŶĚ ƚĞƐƚĂŶŶƵůĂƌ;ϯϱϬϬƉƐŝͿĨĂŝůĞĚƚĞƐƚ͘ůŽǁĚŽǁŶƐƚĂĐŬĂŶĚEͬƐƉŽŽů͘>ŽĐĂƚĞŶĞǁĂŶŶƵůĂƌĞůĞŵĞŶƚ;/ͲƌŝŐͿ͘ŚĂŶŐĞŽƵƚĂŶŶƵůĂƌ ĞůĞŵĞŶƚ͘dĞƐƚŐĂƐůĂƌŵƐͲŐŽŽĚƚĞƐƚ͘ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ EͬƉƌŽĚƵĐƚŝŽŶƚƌĞĞ͕EͬhKW^͕ƐĞƚŝŶĨůŽŽƌĂŶĚƌŝŐƐƚĂŝƌƐ͕ƐƚĂƌƚƉƌĞͲŚĞĂƚŐůǇĐŽůƵŶŝƚ͘^ƉŽƚƌŝŐĂŶĚƌĂŝƐĞŵĂƐƚ͘ZŝŐƵƉƉƵŵƉĂŶĚ ĂĐĐƵŵƵůĂƚŽƌůŝŶĞƐ͘,ŽŽŬƵƉƌŝŐƚŽŚŝŐŚůŝŶĞƉŽǁĞƌ͘ŽŶƚŝŶƵĞƚŽŚŽŽŬƵƉŵŝƐĐ͘ůŝŶĞƐĂŶĚĞƋƵŝƉŵĞŶƚ͘/ŶƐƚĂůůƚĂƌƉƐĂŶĚǁŝŶƚĞƌŝǌĞ ƌŝŐĨŽƌŽƉĞƌĂƚŝŽŶƐ͘^ƉŽƚƵƉƌŝŐŚƚƐĂŶĚƚŝŐĞƌƚĂŶŬƐ͘ZĞŵŽǀĞĚŽŽƌƚŽĂĚũĂĐĞŶƚǁĞůůŚŽƵƐĞĂŶĚƐƉŽƚĐĂƚǁĂůŬͬƉŝƉĞƐŚĞĚ͘ZĞƉůĂĐĞ ŚŽŬĞůŝŶĞ,Z͘ DŽǀĞƌŝŐĂŶĚĞƋƵŝƉŵĞŶƚƚŽŶĚŝĐŽƚƚ͕ƐƉŽƚŵĂƚƚŝŶŐďŽĂƌĚƐ͕ZĞŵŽǀĞKǀĂůǀĞĂŶĚƌĞŝŶƐƚĂůůŽŶŽƉƉŽƐŝƚĞƐŝĚĞŽĨǁĞůůŚĞĂĚ͘^ƉŽƚ ŵƵĚďŽĂƚ͕ƉƵƐŚĞƌƐƐŚĂĐŬ͕ĐŽ͘DĂŶƚƌĂŝůĞƌ͕ĐŚĂŶŐĞƌŽŽŵ͘hŶĂďůĞƚŽƐƉŽƚƉŝƚƐĚƵĞƚŽĂĚũĂĐĞŶƚǁĞůůŚŽƵƐĞ;ůĞĨƚƐŝĚĞ͘ĚũƵƐƚŵƵĚ ďŽĂƚ͕ƌĞŵŽǀĞůĂĚĚĞƌŽŶƌŝŐŚƚƐŝĚĞǁĞůůŚŽƵƐĞ͘^ƉŽƚƉŝƚƐĂŶĚŚŽŽŬƵƉŐĞŶĞƌĂƚŽƌ͕ƐƉŽƚĐĞůůĂƌďŽǆ͘ ϮͬϭͬϮϬϮϮ ϭͬϯϭͬϮϬϮϮ ϮͬϯͬϮϬϮϭ ŚĂŶŐĞŽƵƚĂŶŶƵůĂƌĞůĞŵĞŶƚ͕ƉƵƌŐĞĂŝƌĨƌŽŵĂŶŶƵůĂƌĂŶĚƉƌĞƐƐƵƌĞƵƉŬŽŽŵĞǇ͕ĐŚĞĐŬĨŽƌůĞĂŬƐͲŐŽŽĚ͘&ŝůůƐƚĂĐŬĂŶĚŝŶƐƚĂůůƚĞƐƚ ũƚ͘&ƵŶĐƚŝŽŶĞůĞŵĞŶƚĐůŽƐĞͬŽƉĞŶϴy͕ƐŚĞůůƚĞƐƚͲŐŽŽĚ͘EŽƚŝĨǇƐƚĂƚĞZĞƉ͘:ŝŵZĞŐŐͲŐŝǀĞŶŽŬƚŽƉƌŽĐĞĞĚǁŝƚŚƚĞƐƚǁŝƚŚŽƵƚƐƚĂƚĞ ǁŝƚŶĞƐƐ͘dĞƐƚKW͘͘͘ǁͬϮͲϳͬϴΗĂŶĚϰ͘ϱΗƚĞƐƚũƚƐƚŽϮϱϬͬϱϬϬϬƉƐŝŽŶƚŚĞƉŝƉĞƌĂŵƐĂŶĚďůŝŶĚƌĂŵƐ͕ϮϱϬͬϯϱϬϬƉƐŝŽŶĂŶŶƵůĂƌĂŶĚ ĂůůŽƚŚĞƌĐŽŵƉŽŶĞŶƚƐĂƐƉĞƌ^ƵŶĚƌǇ͘WĞƌĨŽƌŵĚƌĂǁĚŽǁŶƚĞƐƚͲ/ŶŝƚŝĂůƉƐŝͲϯϭϬϬ͕ĨŝŶĂůƉƐŝϭϳϬϬ͕ϭϮƐĞĐϮϬϬƉƐŝƌĞĐŚĂƌŐĞ͕ϭϭϬƐĞĐ ĨƵůůƌĞĐŽǀĞƌǇ͕ϮϵƐĞĐĂŶŶƵůĂƌĐůŽƐƵƌĞ͕ϲ͘ϱƐĞĐƌĂŵĐůŽƐƵƌĞ͕ϭƐĞĐ,ZĐůŽƐƵƌĞ͘ZŝŐĂĐĐĞƉƚĞĚΛϭϵ͗ϯϬŚƌƐ͘WƵůůdtdƵďŝŶŐŽŶ ǀĂĐƵƵŵ͕/ϰϬƉƐŝͲͲǁĞůůhͲƚƵďŝŶŐ͘ZŝŐƵƉůŝŶĞƐƚŽĐŝƌĐƵůĂƚĞĚŽǁŶƚƵďŝŶŐƚĂŬŝŶŐƌĞƚƵƌŶƐƵƉ/ƚŚƌƵĐŚŽŬĞƚŽƚŝŐĞƌƚĂŶŬ͘ůŽǁĂŝƌ ƚŚƌƵůŝŶĞƐĂŶĚĨŽƵŶĚůŝŶĞƐĨƌŽǌĞ͕ůŽĐĂƚĞĂŶĚƚŚĂǁŽƵƚƐĂŵĞ;ϯ͘ϱŚƌƐͿ͘WƌĞƐƐƵƌĞƚĞƐƚƉƵŵƉƚƌƵĐŬůŝŶĞƐƚŽϰϱϬϬƉƐŝ;ƚĞƐƚŐŽŽĚͿ͘ ŝƐƉůĂĐĞĨƌĞĞǌĞƉƌŽƚĞĐƚĨůƵŝĚƚŽƐĞĂǁĂƚĞƌ;ϴϬďďůƐͿ͘^ŚƵƚŝŶĂĚŵŽŶŝƚŽƌƉƌĞƐƐƵƌĞ͘dƵďŝŶŐĂŶĚ/ďŽƚŚƐƚĂƚŝĐ͘ůŽǁĚŽǁŶůŝŶĞƐ͕ K>ΖƐ͕ŝŶƐƚĂůůůĂŶĚŝŶŐũƚ͘ƉƵůůŚĂŶŐĞƌƚŽĨůŽŽƌ;ϭϯ<ͿĂŶĚ>ͬƐĂŵĞ͘^ƚƌŝƉĨůŽǁƌŝƐĞƌƐƉŽŽůƐŽǀĞƌƚƵďŝŶŐĂŶĚZͬhĨůŽǁůŝŶĞ͘^ƉŽƚ ĂŶĚZͬhƉŝƉĞƐŚĞĚ͘WKK,ĂŶĚ>ͬϰϭͬϮΗŬŝůůƐƚƌŝŶŐ͘ ϮͬϰͬϮϬϮϭ WKK,ĂŶĚ>ͬϰϭͬϮΗŬŝůůƐƚƌŝŶŐ͘hŶůŽĂĚϰ͘ϱΗƚďŐĨƌŽŵƉŝƉĞƐŚĞĚ͕ƉͬƵůĂŶĚŝŶŐũƚĂŶĚǁĞĂƌƌŝŶŐƌƵŶŶŝŶŐƚŽŽů͕ƐĞƚǁĞĂƌƌŝŶŐ͕>ͬ ƌƵŶŶŝŶŐƚŽŽůĂŶĚůĂŶĚŝŶŐũƚ͘>ŽĂĚƐŚĞĚǁŝƚŚ,ηϭĂŶĚϰ͘ϳϱΗ͘͘^ƚƌĂƉĂŶĚƚĂůůǇ͘͘͘Wͬh,ηϭ͕;ϭϰ<ůďƐͿ͕Z/,ǁŝƚŚϯϭͬϮΗW,Ͳ ϲƚŽϭϭϭϵΖ͘/ŶƐƚĂůů<ĞůůǇŚŽƐĞĂŶĚyͬKƐĂǀĞƌƐƵď͘ĚũƵƐƚďĂŝůůŝŶŬĂŐĞĨŽƌĐŽŶŶĞĐƚŝŽŶƐ͘ůŽǁĂŝƌƚŚƌƵĂůůůŝŶĞƐͲŐŽŽĚ͘^ƚĂŐĞƵƉ ƉƵŵƉƐƚŽϴďƉŵͬϮϬϬϬƉƐŝ͕ǁĂƐŚĚŽǁŶĂŶĚƚĂŐĐĞŵĞŶƚΛϭ͕ϭϳϭŵĚΖWͬhĂŶĚĞƐƚĂďůŝƐŚŵŝůůŝŶŐƉĂƌĂŵĞƚĞƌƐƉƵǁƚϮϯ͘ϱ<͕ĚŶǁƚ Ϯϯ<͕ƌŽƚƌƉŵϲϬ͕ŽĨĨďŽƚƚŽŵƚƋϯϬϬĨƚͬůďƐ͘ƌŝůůͬŵŝůůĐĞŵĞŶƚƌĞƚĂŝŶĞƌĂŶĚĐĞŵĞŶƚĨƌŽŵϭϭϳϭΖƚŽϭϭϳϰΖͲtKϯͲϴ<͕ϯϬͲϲϬƌƉŵ͕ ŽŶďŽƚƚŽŵƚƋϴϬϬƚŽϭϱϬϬĨƚͬůďƐ͘dŽƉŽĨĐĞŵĞŶƚƌĞƚĂŝŶĞƌΛϭϭϳϮΖŵĚ͘ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ EϯͲϭϭ ^Zηϭ ϱϬͲϬϮϵͲϮϭϴϰϴͲϬϬͲϬϬ ϭϴϴͲϬϴϳ ϭͬϯϭͬϮϬϮϮ ϵͬϮϵͬϮϬϮϮ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ ϮͬϱͬϮϬϮ ŽŶƚ͘ĚƌŝůůͬŵŝůůĐĞŵĞŶƚƌĞƚĂŝŶĞƌĂŶĚĐĞŵĞŶƚĨƌŽŵϭϭϳϰΖƚŽϭϮϬϳΖͲtKϯͲϴ<͕ϯϬͲϲϬƌƉŵ͕ŽŶďŽƚƚŽŵƚƋϴϬϬƚŽϭϱϬϬĨƚͬ͘ůďƐ͘dĂŐ ƚŽƉŽĨ&ĂƐƚĚƌŝůƌĞƚĂŝŶĞƌΛϭϮϬϳΖŵĚ͘ŝƌĐƵůĂƚĞďŽƚƚŽŵƐƵƉ͕ƚŚĞŶƉƵŵƉϯϱďďůƐͲϭϰϬǀŝƐ/ŶǀŝƐƐǁĞĞƉ͕ŚĞĂǀǇƌĞƚƵƌŶƐĂƚͬh͘ ŽŶƚŝŶƵĞŵŝůůŝŶŐĨĂƐƚĚƌŝůƌĞƚĂŝŶĞƌĨͬϭϮϬϳΖƚͬϭϮϬϵΖĂŶĚƉůƵŐĚƌŽƉƉĞĚĂǁĂǇ͘ŝƌĐƵůĂƚĞďŽƚƚŽŵƐƵƉĂŶĚƐǁĞĞƉŚŽůĞǁŝƚŚϭϱďďůƐ ϭϰϬǀŝƐ/ŶǀŝƐƐǁĞĞƉ͕ŚĞĂǀǇƌĞƚƵƌŶƐĂƚƐǁĞĞƉͬh͘ŚĂƐĞƉůƵŐƚͬϭϲϴϬ͕ŶĞǀĞƌƐĞĞŶƚĂŐŝƚĂŐĂŝŶ͘ZͬhĂŶĚƚĞƐƚϵͲϱͬϴΗĐĂƐŝŶŐƚŽ ϮϱϬϬƉƐŝĨŽƌϯϬŵŝŶĂƐƉĞƌK'ͲƚĞƐƚŐŽŽĚ͘K'ĂƉƉƌŽǀĞĚĨŽƌĐŽŶƚŝŶƵŝŶŐŽŶ^ƵŶĚƌǇΛϭϱ͗ϰϬŚƌƐ͘WKK,ǁͬϯ͘ϱǁŽƌŬƐƚƌŝŶŐ ĂŶĚ,ηϭ͘ůĞĂƌƉŝƉĞƐŚĞĚŽĨ,ηϭĂŶĚůŽĂĚ,ηϮ͕WŝĐŬƵƉ,ηϮ͘hŶĂďůĞƚŽŵĂŬĞƵƉƐƚƌŝŶŐŵŝůůŽŶƌŝŐĚƵĞyͬKŽĚ͘^ĞŶƚ ƚŽƐŚŽƉƚŽŚĂǀĞĂĚĚŝƚŝŽŶĂůƐƵďƐŵĂĚĞƵƉƚŽĂĐĐŽŵŵŽĚĂƚĞƌŝŐĐĂƉĂďŝůŝƚŝĞƐ͘WĞƌĨŽƌŵŵĂŝŶƚĞŶĂŶĐĞĂŶĚĐůĞĂŶƌŝŐǁŚŝůĞǁĂŝƚŝŶŐŽŶ ƐƚƌŝŶŐŵŝůů͘ŽŶƚƚŽWͬh,ηϮ;ϭϱ<ǁƚͿ͘Z/,ǁŝƚŚϯϭͬϮΗW,ͲϲƚŽϭϮϮϱΖ;ϮϱŬǁƚͿ͘ŚĂŶŐĞŽǀĞƌŚĂŶĚůŝŶŐĞƋƵŝƉŵĞŶƚ͕ůŽĂĚƉŝƉĞ ƐŚĞĚĂŶĚƚĂůůǇϮϳͬϴΗW,Ͳϲ͘;WŝƉĞŵŝƐƐŝŶŐƚŚƌĞĂĚƉƌŽƚĞĐƚŽƌƐĂŶĚƉĂĐŬĞĚĨƵůůŽĨƐŶŽǁͿ͘Z/,ǁŝƚŚϮϳͬϴ͟W,ͲϲƚŽϮϬϮϲΖ͘ ϮͬϲͬϮϬϮϮ Z/,ǁŝƚŚϮϳͬϴ͟W,ͲϲĨͬϮϬϮϲΖƚͬϱϮϮϱΖ͘Z/,ǁŝƚŚϮϳͬϴ͟W,ͲϲĨͬϱϮϮϱΖƚͬϳϮϮϱΖͬ͘ŽŚĂŶĚůŝŶŐĞƋƵŝƉŵĞŶƚĨͬϮͲϳͬϴƚͬϯ͘ϱ͘Z/, ǁͬϯ͘ϱΗW,ͲϲĨͬϳϮϮϱΗƚͬϭϮ͕ϮϱϮΖ͘tŚŝůĞƌŝŐŐŝŶŐƵƉƉŽǁĞƌƐǁŝǀĞůŬĞůůǇŚŽƐĞďƌŽŬĞ͕ƌĞŵŽǀĞŬĞůůǇŚŽƐĞ͘ŽůĚǁĞĂƚŚĞƌƌĞƐƚƌŝĐƚŝŽŶͲ ϰϬĚĞŐ&͘ ϮͬϳͬϮϬϮϮ ZͬhƚŽĚŝƐƉůĂĐĞǁĞůůĂŶĚƐƵƌĨĂĐĞ͘ΛϬϵ͗ϭϱŚƌƐƌŝŐŚĂŶĚŽƉĞŶĞĚǀĂůǀĞƐƚŽůŝŶĞƵƉƚŽ,ĂůŝďƵƌƚŽŶƉƵŵƉĞƌĨƌŽŵƉŝƚƐǁŝƚŚŽƵƚ ǁĂůŬŝŶŐƚŚĞůŝŶĞͲϰďďůƐĞĂǁĂƚĞƌƐƉŝůůƚŽƉĂĚ͘EŽƚŝĨǇ^ŶǀŝƌŽŶŵĞŶƚĂůZĞƉ͘ůĞĂŶƵƉĨƌŽǌĞŶƐĞĂǁĂƚĞƌ͘WƌĞͲũŽďǁͬĂůůŝŶǀŽůǀĞĚ ŝŶĚŝƐƉůĂĐĞŵĞŶƚƚŽƐůŝĐŬďƌŝŶĞ͘tĂůŬůŝŶĞƐƐƚĂƌƚĚŝƐƉůĂĐĞŵĞŶƚ͘DƵůƚŝƉůĞůŝŶĞƐĨƌĞĞǌŝŶŐ͘ŽůĚǁĞĂƚŚĞƌƌĞƐƚƌŝĐƚŝŽŶƐͲϰϬĚĞŐ͘ŽůĚ ǁĞĂƚŚĞƌƌĞƐƚƌŝĐƚŝŽŶƐͲϰϬĚĞŐ͘ůĞĂŶĂŶĚŽƌŐĂŶŝǌĞƌŝŐĂŶĚĞƋƵŝƉŵĞŶƚ͘ ϮͬϴͬϮϬϮϮ ŽůĚǁĞĂƚŚĞƌƌĞƐƚƌŝĐƚŝŽŶƐͲϰϬĚĞŐ͘ůĞĂŶĂŶĚŽƌŐĂŶŝǌĞƌŝŐĂŶĚĞƋƵŝƉŵĞŶƚ͘ŽůĚǁĞĂƚŚĞƌƌĞƐƚƌŝĐƚŝŽŶƐͲϰϬĚĞŐ͘ůĞĂŶĂŶĚ ŽƌŐĂŶŝǌĞƌŝŐĂŶĚĞƋƵŝƉŵĞŶƚ͘^ŚŝƉƐůŝĐŬǁĂƚĞƌƚŽŚŽƚŽŝůƚŽŚĞĂƚƵƉ͘ŽůĚǁĞĂƚŚĞƌƌĞƐƚƌŝĐƚŝŽŶƐͲϰϬĚĞŐ͘ůĞĂŶĂŶĚŽƌŐĂŶŝǌĞƌŝŐ ĂŶĚĞƋƵŝƉŵĞŶƚ͕ůŽǁĚŽǁŶƚŚƌƵĂůůƉƵŵƉůŝŶĞƐƚŽĞŶƐƵƌĞƚŚĞǇĂƌĞĐůĞĂƌŽĨŝĐĞ͘ ϮͬϵͬϮϬϮϭ ŽůĚǁĞĂƚŚĞƌƌĞƐƚƌŝĐƚŝŽŶƐͲϰϬĚĞŐ͘ůĞĂŶĂŶĚŽƌŐĂŶŝǌĞƌŝŐĂŶĚĞƋƵŝƉŵĞŶƚ͘ůŽǁĚŽǁŶƚŚƌƵĂůůƉƵŵƉůŝŶĞƐƚŽĞŶƐƵƌĞƚŚĞǇĂƌĞ ĐůĞĂƌŽĨŝĐĞ͘WƌĞƉĨŽƌĚŝƐƉůĂĐĞŵĞŶƚŽĨŚŽůĞǁŝƚŚƐůŝĐŬƐĞĂǁĂƚĞƌ͘WƌĞͲ:Žď͕ĚŝƐƉůĂĐĞǁĞůůǁŝƚŚϭϬϬϬďďůϴ͘ϲηϭй<ůǁŝƚŚĂƌĂůƵďĞ ĂŶĚ'ĞŽsŝƐ͘KĨĨůŽĂĚƌĞƚƵƌŶƐƚŽǀĂĐƚƌƵĐŬƐĨŽƌĚŝƐƉŽƐĂůĂƚ'Θ/͘hŶͲůŽĂĚĐŽŵƉůĞƚŝŽŶĞƋƵŝƉŵĞŶƚĨƌŽŵƐŚĞĚ͘ŽůĚǁĞĂƚŚĞƌ ƌĞƐƚƌŝĐƚŝŽŶƐͲϰϬĚĞŐ͘ůŽǁĚŽǁŶƚŚƌƵĂůůƉƵŵƉůŝŶĞƐƚŽĞŶƐƵƌĞƚŚĞǇĂƌĞĐůĞĂƌŽĨŝĐĞ͘ZͬhŬĞůůǇŚŽƐĞĂŶĚƉŽǁĞƌƐǁŝǀĞů͕ƉƌĞƉƚŽ ŐĞƚƉĂƌĂŵĞƚĞƌƐ͘ Passing MIT on 9-5/8" casing is a COA on Sundry 321-589 for variance to 20AAC 25.285(c)(2)(B)(i). -WCB ZͬhĂŶĚƚĞƐƚϵͲϱͬϴΗĐĂƐŝŶŐƚŽ ϮϱϬϬƉƐŝĨŽƌϯϬŵŝŶĂƐƉĞƌK'ͲƚĞƐƚŐŽŽĚ͘K'ĂƉƉƌŽǀĞĚĨŽƌ ĐŽŶƚŝŶƵŝŶŐŽŶ^ƵŶĚƌǇΛ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ EϯͲϭϭ ^Zηϭ ϱϬͲϬϮϵͲϮϭϴϰϴͲϬϬͲϬϬ ϭϴϴͲϬϴϳ ϭͬϯϭͬϮϬϮϮ ϵͬϮϵͬϮϬϮϮ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ ϮͬϭϬͬϮϬϮϭ WƌĞͲũŽď͕ƚĂŬĞƉĂƌĂŵĞƚĞƌƐ͗ϲďƉŵсϮϰϱϬƉƐŝ͕ƚƌƋсϮϯͲϮϱϬϬĨƚͬηΛϰϬƌƉŵ͕ƵƉǁƚ͘сϭϬϳŬ͕ĚǁŶǁƚ͘сϵϯŬ͖ϲ͘ϴďƉŵсϯϮϬϬƉƐŝ͕ƚƌƋсϮϲϬϬ ĨƚͬηΛϲϬƌƉŵ͕ƵƉǁƚ͘сϭϭϬŬ͕ĚǁŶǁƚ͘сϴϴŬ͖ƵƉǁƚŶŽͲƌŽƚ͘сϭϮϮŬ͕ĚǁŶǁƚ͘ŶŽͲƌŽƚсϴϬŬ͕ƚƌƋΛϯϬƌƉŵсϮϰϬϬ͕ƚƌƋΛϰϬƌƉŵсϮϱϬϬ͕ ƚƌƋΛϲϬƌƉŵсϮϲϬϬ͕ǁĂƐŚĚŽǁŶĨͬϭϮ͕ϮϱϮΖƚͬϭϮ͕ϮϳϵΖ͕Λϲ͘ϴďƉŵ͕ϯϭϬϬƉƐŝ͕ƵƉǁƚсϭϮϭŬ͕ĚǁŶǁƚсϴϭŬ͕ĂƚƚĞŵƉƚƚŽƐǁĂůůŽǁƚďŐ ƐƚƵŵƉǁͬƐůŽǁƌŽƚĂƚŝŽŶĂŶĚƉƵŵƉͲŶŽŐŽ͘ƐƚĂďůŝƐŚƉĂƌĂŵĞƚĞƌƐϯϬƌƉŵ͕ϵϯŬƌŽƚǁƚ͘&ƌĞĞƚƌƋсϮϲϬϬ͕DŝůůĨͬϭϮ͕ϮϳϳΖƚͬϭϮ͕ϮϴϬΖ͕ϱŬ tK͕ϯͲϰŬƚƌƋ͕ƉĂƌĂŵĞƚĞƌĐŚĂŶŐĞΛϭϮ͕ϮϳϵΖ;ƐůŽǁŵŝůůŽĨĨͿŝŶĐƌĞĂƐĞǁƚ͘ƚͬϴŬ͕ǁƚ͘ĨĞůůŽĨĨ͕ƐƚŽƉƌŽƚĂƚŝŽŶ͘tĂƐŚĚŽǁŶĨͬϭϮ͕ϮϴϬΖ ƚͬϭϮ͕ϮϵϯΖƚĂŐǁͬϭϬŬ͘WĂƌĂŵĞƚĞƌĐŚĂŶŐĞΛϭϮ͕ϮϵϰΖŵŝůůϮĨƚƉĂƐƚ͘tŽƌŬƐƚƌŝŶŐŵŝůŽĨĨƚŚĞƚďŐƐƚƵŵƉ͕ƐƚŽƉƌŽƚĂƚŝŽŶ͕ĂŶĚĚƌŝĨƚ ŽǀĞƌƐƚƵŵƉ͕ƐĂǁƚŽƉŽĨƚďŐƐƚƵŵƉΛϭϮ͕ϮϴϮΖĂŶĚƐǁĂůůŽǁĞĚƐƚƵďƚͬϭϮ͕ϮϵϲΖǁͬϭϬŬĚǁŶǁƚ͘ŝƌĐƵůĂƚĞͬh͕ƉƵŵƉϯϬďďůƐǁĞĞƉ͘ WKK,ĨͬϭϮ͕ϮϵϲΖƚͬϰ͕ϵϱϬΖ͘ ϮͬϭϭͬϮϬϮϭ ŽŶƚ͘WKK,ǁͬǁŽƌŬƐƚƌŝŶŐĂŶĚ,ηϮĨͬϰ͕ϵϱϬΖƚͬϯϳϱΖ͘>ͬ,ηϮ͕ƉƵůůǁĞĂƌƌŝŶŐ͕ƐĞƚƚĞƐƚƉůƵŐ͘ZͬhƚŽƚĞƐƚKWΖƐ͘^ŚĞůůƚĞƐƚͲ ŐŽŽĚ͘dĞƐƚKWΖƐǁŝƚŚϰ͘ϱΗƚĞƐƚũƚƚŽϮϱϬůŽǁͬϯϱϬϬŚŝŐŚĨŽƌϱŵŝŶĞĂĐŚ͘hŶĂďůĞƚŽĂĐŚŝĞǀĞϯϬƐĞĐĐůŽƐƵƌĞŽŶĂŶŶƵůĂƌ͘ZĞͲ ƌŽƵƚĞŚǇĚ͘ůŝŶĞƐĂŶĚĂĚũƵƐƚŚĞĂƚĞƌƐ͘ZĞƉůĂĐĞƋƵŝĐŬĚŝƐĐŽŶŶĞĐƚƐǁͬŚŝͲĨůŽŚǇĚĐŽŶŶĞĐƚŝŽŶƐŽŶĂĐĐƵŵƵůĂƚŽƌŚŽƐĞƐ͘WĞƌĨŽƌŵĚƌĂǁ ĚŽǁŶƚĞƐƚͲ/ŶŝƚŝĂůƉƐŝͲϯϬϱϬ͕ĨŝŶĂůƉƐŝͲϭϱϱϬ͕ϮϬϬƉƐŝƌĞĐŚĂƌŐĞͲϮϮƐĞĐ͕ĨƵůůƌĞĐŽǀĞƌǇͲϵϭƐĞĐ͕ϮϵƐĞĐĨŽƌĂŶŶƵůĂƌĐůŽƐƵƌĞ͘/ŶƐƚĂůů ϭϯϱͬϴΗƌŝƐĞƌƐĞĐƚŝŽŶĂŶĚZͬhĨ&ůŽǁůŝŶĞ͘>ͬƚĞƐƚƉůƵŐ͘DŽǀĞƉŝƉĞƐŚĞĚĂŶĚZͬƌŝŐƚŽŶŐƐ͕ZͬhƚƵďŝŶŐƚŽŶŐƐĂŶĚƐƉŽƚƉŽǁĞƌ ƉĂĐŬĨŽƌ'ZƚŽŶŐƐ͕ŝŶƐƚĂůůƉŝƉĞƐŚĞĚ͘ ϮͬϭϮͬϮϬϮϮ >ŽĂĚĐŽŵƉůĞƚŝŽŶũĞǁĞůƌǇĂŶĚƚƵďŝŶŐ͘^ƚƌĂƉĂŶĚƚĂůůǇƐĂŵĞ͘ĂĐŬůŽĂĚϯ͘ϱΗǁŽƌŬƐƚƌŝŶŐ͕ǇĞůůŽǁũĂĐŬĞƚƚŽŽůĂŶĚĂŬĞƌƐƚƌŝŶŐŵŝůů͘ ;ŶĞŐĂƚŝǀĞϰϬĚĞŐ͘&Ϳ͘Z/,ǁŝƚŚĐŽŵƉůĞƚŝŽŶĂƐƉĞƌĚĞƚĂŝů͖ŽǀĞƌƐŚŽƚ͕yEͲŶŝƉƉůĞǁͬZ,͕ϭũƚϰ͘ϱΗ:&ͲĞĂƌdďŐ͕dEdWĂĐŬĞƌ͕yͲ ŶŝƉƉůĞƚͬϮ͕ϵϭϮΖ͘ŽůĚǁĞĂƚŚĞƌƌĞƐƚƌŝĐƚŝŽŶƐͲϰϬĚĞŐ͘tŽƌŬŽŶŵƵĚƉƵŵƉ͘ ϮͬϭϯͬϮϬϮϮ ŽŶƚ͘Z/,ǁŝƚŚĐŽŵƉůĞƚŝŽŶĨͬϮϵϭϮΖƚͬϰϲϭϲΖ͘ŽŶƚ͘Z/,ǁŝƚŚĐŽŵƉůĞƚŝŽŶĨͬϰϲϭϲΖƚͬϳ͕ϭϯϴΖ͘ŽŶƚ͘Z/,ǁŝƚŚĐŽŵƉůĞƚŝŽŶĨͬϳ͕ϭϯϴΖ ƚͬϴ͕ϭϬϵΖ͘,ĂĚĞůĞĐƚƌŝĐĂůŝƐƐƵĞƐǁŝƚŚƌŝŐĐŽŶƚƌŽůƐ͕ŚĞĂƚĞůĞĐƚƌŝĐĂůũƵŶĐƚŝŽŶďŽǆ͘ŽŶƚ͘Z/,ǁŝƚŚĐŽŵƉůĞƚŝŽŶĨͬϴ͕ϭϬϵΖƚͬϭϬ͕ϰϳϳΖ͘ ϮͬϭϰͬϮϬϮϮ ŽŶƚ͘Z/,ǁŝƚŚĐŽŵƉůĞƚŝŽŶĨͬϭϬ͕ϰϳϳΖƚͬϭϬ͕ϴϴϲΖ͘Wͬh^^^sΛϭ͕ϯϵϱΖͲϭ͕ϰϬϬΖD͘ŽŶŶĞĐƚĐŽŶƚƌŽůůŝŶĞĂŶĚƉƐŝƚĞƐƚƚŽϲϱϬϬƉƐŝĨŽƌϱ ŵŝŶ͘&ƵŶĐƚŝŽŶǀĂůǀĞϯƚŝŵĞƐͲͲǀĞƌĂŐĞͲͲŽƉĞŶŝŶŐϮϯϱϬƉƐŝ͕ĐůŽƐŝŶŐϭϯϬϬƉƐŝ͕ĨůƵŝĚďůĞĚďĂĐŬϭϵϬŵů͘ŽŶƚ͘Z/,ǁŝƚŚĐŽŵƉůĞƚŝŽŶ ĨͬϭϬ͕ϴϴϲΖƚͬϭϮ͕ϮϵϮΖ͘^ǁĂůůŽǁƚŽƉŽĨƐƚƵŵƉΛϭϮ͕ϮϳϵΖ͘^ŚĞĂƌĞĚďŽƚŚƐĞƚƐŽĨŽĨƐŚĞĂƌƉŝŶƐǁŝƚŚϴ<ǁƚĂŶĚƐĞƚϭϬŬĚŽǁŶŽŶŶŽͲ ŐŽ͘;ϭϯϴ<ƵƉǁƚ͘ͿWͬhĂŶĚƐƉĂĐĞŽƵƚǁŝƚŚƉƵƉƐĂŶĚŚĂŶŐĞƌǁŝƚŚϴΖŽĨƐǁĂůůŽǁ͘dĞƌŵŝŶĂƚĞĐŽŶƚƌŽůůŝŶĞĂŶĚƉƌĞƐƐƵƌĞƚĞƐƚƚŽ ϲϱϬϬƉƐŝĨŽƌϱŵŝŶ͘ĨƵŶĐƚŝŽŶǀĂůǀĞϯƚŝŵĞƐ͘ϯϳĐŽŶƚƌŽůůŝŶĞĐůĂŵƉƐŝŶƐƚĂůůĞĚ͘ZͬhƚŽƌĞǀĞƌƐĞĐŝƌĐƵůĂƚĞ͘ŝƐƉůĂĐĞǁĞůůǁŝƚŚϰϲϬ ďďůƐĐŽŵƉůĞƚŝŽŶĨůƵŝĚĨŽůůŽǁĞĚďǇϮϬϬďďůƐŽĨ^ůŝĐŬ<>͘ϯ͘ϳďƉŵΛϲϬϬƉƐŝ͘ >ŽĂĚĐŽŵƉůĞƚŝŽŶũĞǁĞůƌǇĂŶĚƚƵďŝŶŐ͘^ƚƌĂƉĂŶĚƚĂůůǇƐĂŵĞ͘ ŽŶƚ͘Z/,ǁŝƚŚĐŽŵƉůĞƚŝŽŶĨͬϮϵϭϮΖƚͬϰϲϭϲΖ͘ŽŶƚ͘Z/,ǁŝƚŚĐŽŵƉůĞƚŝŽŶĨͬϰϲϭϲΖƚͬϳ͕ϭϯϴΖ͘ŽŶƚ͘Z/,ǁŝƚŚĐŽŵƉůĞƚŝŽŶĨͬϳ͕ϭϯϴΖ ƚͬϴ͕ϭϬϵΖ͘,ĂĚĞůĞĐƚƌŝĐĂůŝƐƐƵĞƐǁŝƚŚƌŝŐĐŽŶƚƌŽůƐ͕ŚĞĂƚĞůĞĐƚƌŝĐĂůũƵŶĐƚŝŽŶďŽǆ͘ŽŶƚ͘Z/,ǁŝƚŚĐŽŵƉůĞƚŝŽŶĨͬϴ͕ϭϬϵΖƚͬϭϬ͕ϰϳϳΖ͘ ŽŶƚ͘Z/,ǁŝƚŚĐŽŵƉůĞƚŝŽŶ ĨͬϭϬ͕ϴϴϲΖƚͬϭϮ͕ϮϵϮΖ͘^ǁĂůůŽǁƚŽƉŽĨƐƚƵŵƉΛϭϮ͕ϮϳϵΖ͘^ŚĞĂƌĞĚďŽƚŚƐĞƚƐŽĨŽĨƐŚĞĂƌƉŝŶƐǁŝƚŚϴ<ǁƚĂŶĚƐĞƚϭϬŬĚŽǁŶŽŶŶŽͲ ŐŽ͘;ϭϯϴ<ƵƉǁƚ͘ͿWͬhĂŶĚƐƉĂĐĞŽƵƚǁŝƚŚƉƵƉƐĂŶĚŚĂŶŐĞƌǁŝƚŚ ϴΖŽĨƐǁĂůůŽǁ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ EϯͲϭϭ ^Zηϭ ϱϬͲϬϮϵͲϮϭϴϰϴͲϬϬͲϬϬ ϭϴϴͲϬϴϳ ϭͬϯϭͬϮϬϮϮ ϵͬϮϵͬϮϬϮϮ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ ϮͬϭϱͬϮϬϮϮ >ĂŶĚŚĂŶŐĞƌƌƵŶŝŶ>^͕^>ƚĞƐƚ^^^sͲŐŽŽĚ͘ZͬhƚŽƐĞƚƉĂĐŬĞƌ͕ĚƌŽƉďĂůůĂŶĚƌŽĚ͘WƌĞƐƐƵƌĞƵƉƚďŐƚͬϴϬϬƉƐŝͲĐŚĞĐŬĨŽƌůĞĂŬƐ͕ ĐŽŶƚ͘ƉƌĞƐƐƵƌĞƵƉƚďŐƚͬϯϳϬϬƉƐŝĨŽƌϱŵŝŶ͘WĂĐŬĞƌƐĞƚ;ϯ͘ϰďďůƉƵŵƉĞĚͿ͘ůĞĞĚƚďŐƚͬϭϲϱϬƉƐŝ͕ƉƌĞƐƐƵƌĞƵƉŽŶƚŚĞ/ƚͬϮϳϬϬƉƐŝ ĂŶĚŚŽůĚĨͬϯϬŵŝŶ͘ϱϬƉƐŝůŽƐƐŝŶϯϬŵŝŶ͘;ϴďďůƉƵŵƉĞĚͿ͘ůĞĞĚŽĨĨƚŚĞƚďŐĨͬϭϲϱϬƚͬϳϱϬĂŶĚƵƉƉĞƌ'>DƐŚĞĂƌĞĚŽƵƚ͘ůĞĚŽĨĨ/ ĂŶĚƚďŐƚͬϬ͘ZͬƚĞƐƚĞƋƵŝƉŵĞŶƚ͘^ĞƚWs͕>ͬ'ZĞƋƵŝƉŵĞŶƚ͕ƉƵůůĐĂƚǁĂůŬ͕ŽĨĨůŽĂĚƉŝƚƐƚŽǀĂĐƚƌƵĐŬ͕ĐůĞĂƌƌŝŐĨůŽŽƌ͕ƐƵĐŬŽƵƚ ƐĞǁĞƌĂŶĚ,ϮKĨƌŽŵƚƌĂŝůĞƌƐ͕>ŽǁĞƌƚŽƉŵĂƐƚƐĞĐƚŝŽŶ͕ƌĞŵŽǀĞƉŽǁĞƌƐǁŝǀĞů͘>ŽǁĞƌŵĂƐƚ͘ZŝŐĚŽǁŶĞůĞĐƚƌŝĐĂůĂŶĚŚǇĚƌĂƵůŝĐ ůŝŶĞƐĨƌŽŵĐĂƌƌŝĞƌ͕ZͬƐƚĂŝƌƐĂŶĚƌŝŐĨůŽŽƌ͘EͬKWĂŶĚůŽĂĚŽŶƚƌƵĐŬĨŽƌďĂĐŬůŽĂĚ͕EͬhƉƌŽĚƵĐƚŝŽŶƚƌĞĞ͕ƚĞƐƚǀŽŝĚĂŶĚƚƌĞĞ ƚŽϱ<ŚŝŐŚͬϱϬϬůŽǁĨŽƌϱŵŝŶĞĂĐŚ͕ZͬĐĞůůĂƌďŽǆĂŶĚZͬhƚŽĨƌĞĞǌĞƉƌŽƚĞĐƚǁĞůů͘ ϮͬϭϲͬϮϬϮϭ ŽŶƚ͘ZͬhĨŽƌĨƌĞĞǌĞƉƌŽƚĞĐƚ͕ŚŽŽŬƚƌƵĐŬƵƉƚŽƉŝƚƐ͕ŵŽǀĞĐƵƚƚŝŶŐƐďŽǆ͕ŽƉĞŶ^^^s͕ĐƵƚƐŚŽƌĞƉŽǁĞƌƚŽƚƌĂŝůĞƌƐĂŶĚŐĞƚŽŶ ŐĞŶƐĞƚ͕ƉŝĐŬĐĞůůĂƌǁŝƚŚĐƌĂŶĞĂŶĚƐĞƚŽŶƚƌƵĐŬ͕ůŽĂĚŵƵĚďŽĂƚŽŶƚƌĂŝůĞƌ͕ƉŝĐŬŚĞĂƚĞƌƐǁŝƚŚĐƌĂŶĞĨƌŽŵďĞŚŝŶĚǁĞůů͕ŵŽǀĞ ĐƌĂŶĞ͕ƉƵůůŵƵĚƉŝƚƐŽƵƚƚŽƌŽĂĚǁŝƚŚĐĂƌƌŝĞƌĂŶĚƌŝŐĨůŽŽƌĂŶĚĐĞůůĂƌ͘^ƉŽƚƚŚƵŶĚĞƌďŝƌĚƉƵŵƉĞƌĂŶĚĚŝĞƐĞůƚƌƵĐŬŝŶĨƌŽŶƚŽĨǁĞůů͘ ^ƉŽƚǀĂĐƚƌƵĐŬĂƚƚŝŐĞƌƚĂŶŬƐĨŽƌƌĞƚƵƌŶƐĨƌŽŵĨƌĞĞǌĞƉƌŽƚĞĐƚ͘dŚƵŶĚĞƌďŝƌĚZͬh͘&ƌŽǌĞƐƉŽƚŝŶůŝŶĞ͕ŐĞƚŵŽƌĞŚĞĂƚĞƌƐŽŶůŝŶĞĂŶĚ ǁĂƌŵƵƉ͘&ƌĞĞǌĞƉƌŽƚĞĐƚǁĞůů͘WƵŵƉϭϲϱďďůƐ^>ĚŽǁŶĂŶŶƵůƵƐ͘ůůŽǁǁĞůůƚŽhͲƚƵďĞĂŶĚƐĞĐƵƌĞǁĞůů͘ŽŶƚ͘ƚŽĚĞͲŵŽďƌŝŐ͕ ĐůĞĂŶĂŶĚŽƌŐĂŶŝǌĞůŽĐĂƚŝŽŶ͘>ĂƐƚƌĞƉŽƌƚĨŽƌ^Zηϭ͘ ϮͬϭϳͬϮϬϮϭ t>>^,hdKEZZ/s>͘Wh>>/Z͘s>sΛϯ͕ϳϱϯΖ^>D͘^dZ<Ͳ'>sΛϯ͕ϳϱϯΖ^>D͘t>>^,hdKEWZdhZ͘ ϮͬϭϴͬϮϬϮϭ ^ƚĂƚĞǁŝƚŶĞƐƐĞĚϮϱϬϬW^/D/dͲ/;ƉĂƐƐĞĚͿ͘;dĞƐƚǁĂŝǀĞĚďǇƵƐƚŝŶDĐ>ĞŽĚͿ͘ ϮͬϭϵͬϮϬϮϮ t>>^,hdKEZZ/s>͘Wh>>'>s^dd/KEηϭΛϯ͕ϳϱϯΖ^>D͘ZEϭϯΖΖyd͘ǁͬϭ͘ϳϱΖΖ>/d'Λϱ͕ϬϰϳΖ^>Dͬϱ͕ϬϲϯΖ^>D͕ ,/DWZ^^/KEK&d,Z^͕EK>d,KEs>s͘Wh>>'>s^dd/KEηϯΛϲ͕ϬϭϵΖ^>D͘^d>'>s;ϭϰͬϱϰΖΖdZK͕ϭϳϬϬηͿ ^dd/KEηϭΛϯ͕ϳϱϯΖ^>Dͬϯ͕ϳϱϳΖD͘^d>'>s;ϮϬͬϱϰΖΖdZK͕KZ/&/Ϳ^dd/KEηϯΛϲ͕ϬϭϵΖ^>Dͬϲ͕ϬϱϵΖD͘Wh>>>>Θ ZKΛϭϮ͕ϮϱϮΖ^>D͘Wh>>Z,W>h'ΛϭϮ͕ϮϲϭΖ^>D͘ϯ͘ϲϴΖΖZ/&dEd'dKΛϭϮ͕ϱϳϰΖ^>D͘t>>^,hdKEWZdhZ͘ ϰͬϭϲͬϮϬϮϮ dhηϵͲϭ͘ϳϱΗd͘:ŽďKďũĞĐƚŝǀĞ͗hŶĚĞƌƌĞĂŵĞŵĞŶƚĂƉ͕&K͘dƌĂǀĞůĨƌŽŵ^>ǇĂƌĚƚŽEϯͲϭϭ͘D/ZhΘƉĞƌĨŽƌŵKWƚĞƐƚ͘ WƵŵƉϭ͘ϮϱΗĚƌŝĨƚďĂůů͘DhϮͲϳͬϴΗŵŽƚŽƌǁŝƚŚ,ĂŝůĞǇhZĚƌĞƐƐĞĚĨŽƌϳΗϮϵηůŝŶĞƌĂŶĚϯ͘ϳϬΗWŵŝůů͘WKWǁĞůůƚŚƌŽƵŐŚtĞůůdĞƐƚ ƵŶŝƚĂŶĚZ/,͘ŽŶƚŝŶƵĞĚŽŶt^ZϰͲϭϳͲϮϮ͘ >ĂŶĚŚĂŶŐĞƌƌƵŶŝŶ>^͕^>ƚĞƐƚ^^^sͲŐŽŽĚ͘ZͬhƚŽƐĞƚƉĂĐŬĞƌ͕ĚƌŽƉďĂůůĂŶĚƌŽĚ͘WƌĞƐƐƵƌĞƵƉƚďŐƚͬϴϬϬƉƐŝͲĐŚĞĐŬĨŽƌůĞĂŬƐ͕ ĐŽŶƚ͘ƉƌĞƐƐƵƌĞƵƉƚďŐƚͬϯϳϬϬƉƐŝĨŽƌϱŵŝŶ͘WĂĐŬĞƌƐĞƚ;ϯ͘ϰďďůƉƵŵƉĞĚͿ͘ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ EϯͲϭϭ ^Zηϭ ϱϬͲϬϮϵͲϮϭϴϰϴͲϬϬͲϬϬ ϭϴϴͲϬϴϳ ϭͬϯϭͬϮϬϮϮ ϵͬϮϵͬϮϬϮϮ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ ϰͬϭϳͬϮϬϮϮ dhηϵͲϭ͘ϳϱΗd͘ŽŶƚ͘ĨƌŽŵt^ZϰͲϭϲͲϮϮ͘:ŽďKďũĞĐƚŝǀĞ͗hŶĚĞƌƌĞĂŵĞŵĞŶƚĂƉ͕&K͘Z/,ĂŶĚƚĂŐdKĂƚϭϮϱϰϯΖdD͘ hŶĚĞƌƌĞĂŵĐĞŵĞŶƚĐĂƉϭϮ͕ϱϰϯΖͲϭϮ͕ϲϯϴΖdD͘ůĞĂŶŽƵƚƐĂŶĚĚŽǁŶƚŽϭϮϴϴϱΖďĞĨŽƌĞĞŶĐŽƵŶƚĞƌŝŶŐĐĞŵĞŶƚƐƚƌŝŶŐĞƌƐ͘Dŝůů ĚŽǁŶƚŽϭϮϴϵϰdDǁŚŝĐŚĂƉƉĞĂƌƐƚŽďĞĐĞŵĞŶƚƌĞƚĂŝŶĞƌĂĨƚĞƌŵƵůƚŝƉůĞƐƚĂůůƐ͘WƵŵƉĨŝŶĂůŐĞůƐǁĞĞƉĂŶĚĐŚĂƐĞŝŶƚŽƚƵďŝŶŐ ƚĂŝů͘KƉĞŶĐŝƌĐƐƵďĂŶĚƉƵůůŝŶƚŽƚƵďŝŶŐ͘WKK,ǁŚŝůĞǁĞůůĨůŽǁŝŶŐ͘ĞŐŝŶZŝŐĚŽǁŶdh͘ŽŶƚŝŶƵĞĚŽŶt^ZϰͲϭϴͲϮϮ͘K ĞǆŚŝďŝƚĞĚƌĞƉƌĞƐƐƵƌŝǌĂƚŝŽŶ͘WŽƚĞŶƚŝĂůĨŽƌ/ǆKĐŽŵƵŶŝĐĂƚŝŽŶŝĨŶŽƚƌĞĚƵĐĞĚŽŶĐĞǁĞůůŵŽƌĞƚŚĞƌŵĂůůǇƐƚĂďůĞ͘ ϰͬϭϴͬϮϬϮϮ dhηϵͲϭ͘ϳϱΗdΎΎΎŽŶƚ͘ĨƌŽŵt^ZϰͲϭϳͲϮϮΎΎΎ :ŽďKďũĞĐƚŝǀĞ͗hŶĚĞƌƌĞĂŵĞŵĞŶƚĂƉ͕&K ZŝŐĚŽǁŶdh͘ ϰͬϮϯͬϮϬϮϮ t>>^,hdͲ/EKEZZ/s>͕WdWϯϬϬ>ͬϯϮϬϬ,͘^dϰͲϭͬϮΗWyEW>h'Kz/EyEͲE/WW>dϭϮ͕ϮϲϯΖD͘^dWͲWZKE'/EϰͲ ϭͬϮΗWyEW>h'KzdϭϮ͕ϮϲϯΖD͘>dh/E'WZ^^hZ&ZKDϮϵϬϬƉƐŝdKϯϱϬƉƐŝ;,ŽůĚŝŶŐͿ͘t>>^,hdͲ/EKE WZdhZ͕EKd/&/WKW͘ ϰͬϮϰͬϮϬϮϮ dͬ/ͬKсϭϬϬͬϭϱϬͬϭϬ͘>Z^ϳϮD/dͲdǆ/ƚŽϮϱϬϬƉƐŝ͘WƵŵƉĞĚϭϯϲďďůƐŽĨϭϰϬΎ&ϭй<ůǁĂƚĞƌĂŶĚϱϬďďůƐŽĨϵϬΎ&ĚŝĞƐĞůŝŶƚŽƚŚĞ d'͘WƵŵƉĞĚϮϯϰďďůƐŽĨϭϰϬΎ&ϭй<ůĂŶĚϵϴďďůƐŽĨĚŝĞƐĞůŝŶƚŽƚŚĞ/͘D/dͲdǆ/ƚŽϮϱϬϬƉƐŝ;ϮϳϱϬŵĂǆĂƉƉůŝĞĚͿ /ŶĐŽŶĐůƵƐŝǀĞ͘dͬ/ůŽƐƚϭϴϭͬϭϵϵĚƵƌŝŶŐƚŚĞĨŝƌƐƚϭϱŵŝŶƵƚĞƐ͘>>ZdсϬ͘ϭϭďƉŵ;ĐŽƵůĚďĞƚŚĞƌŵĂůͿ͘&ŝŶĂůdͬ/ͬKсϮϳϮϳͬϮϰϯϱͬϵ͘ ϰͬϮϱͬϮϬϮϮ WĞƌĨŽƌŵĞĚD/ddǆ/ǁŝƚŚƚƌŝƉůĞǆƚŽϮϱϬϬƉƐŝ͘WĂƐƐĞĚ͘ůĞĚd'ĚŽǁŶƚŽϰϱϲƉƐŝĂŶĚ/ƚŽϮϰϳ͘WƌĞƐƐƵƌĞĚƵƉ/ǁŝƚŚŐĂƐƚŽ ϭϱϬϬƉƐŝ͕ƚƵďŝŶŐĐĂŵĞƵƉƚŽϭϯϱϬƉƐŝ͘tĂŝƚĞĚƚǁŽŚŽƵƌƐĂŶĚďůĞĚϱďďůƐŽĨĚŝĞƐĞůŽĨĨƚŚĞƚƵďŝŶŐ͘dͬ/ͬKϭϭϬϬͬϭϯϭϱͬϭϯ͘ tĂŝƚĞĚƚǁŽŚŽƵƌƐĂŶĚƉƌĞƐƐƵƌĞĚƵƉ/ƚŽϭϱϬϬW^/͘sĞƌǇůŝŐŚƚďƵďďůŝŶŐŽƵƚŽĨƚŚĞĨůƵƚĞƐĚƵƌŝŶŐƚŚĞĚĂǇ͘ ϰͬϮϲͬϮϬϮϮ ŽŶƚŝŶƵĞĚƚŽďůĞĞĚƚƵďŝŶŐĂŶĚŵŽŶŝƚŽƌKƉƌĞƐƐƵƌĞ͘&ůƵŝĚůĞǀĞůǁĞŶƚĨƌŽŵϴϵϬΖƚŽϭϮϱϬΖ͘KƌĞŵĂŝŶĞĚĐŽŶƐƚĂŶƚĂƌŽƵŶĚϭϮ ƉƐŝ͘sĞƌǇůŝŐŚƚďƵďďůŝŶŐŝŶĨůƵƚĞƐ͘ ϰͬϮϳͬϮϬϮϮ ŽŶƚŝŶƵĞĚƚŽďůĞĞĚƚƵďŝŶŐĂŶĚŵŽŶŝƚŽƌKƉƌĞƐƐƵƌĞ͘&ůƵŝĚůĞǀĞůĚŽǁŶƚŽϭϲϴϬ͘KƌĞŵĂŝŶĞĚĐŽŶƐƚĂŶƚĂƌŽƵŶĚϭϮƉƐŝ͘sĞƌǇůŝŐŚƚ ďƵďďůŝŶŐŝŶĨůƵƚĞƐ͘ƚϭϯ͗ϬϬŽƉĞŶĞĚǁŝŶŐĂŶĚĐŝƌĐƵůĂƚĞĚŐĂƐ͘KƉƌĞƐƐƵƌĞƌĞŵĂŝŶĞĚĂƌŽƵŶĚϭϱƉƐŝƵŶƚŝůϮϯ͗ϬϬŝƚǁĂƐƵƉƚŽϮϭ ƉƐŝ͘ ϵͬϱͬϮϬϮϮ t>>&>Kt/E'KEZZ/s>͕WdWϮϱϬ>ͬϯϱϬϬ,͘Z/&dtͬϮϬΖǆϯ͘ϳϬΗDzt,/W^dK<&KZ,yW>h'^ͬdϭϮ͕ϯϬϲΖ^>D hE>dKtKZ<W^d͘ZEϮϬΖǆϯ͘ϳϬΗDzt,/W^dK<Z/&dtͬϯ͘ϳϬΗdWWZ^t'dKϭϮ͕ϯϬϲΖ^>D͕hE>dK tKZ<W^d͘;ƐĞĞůŽŐͿ :ŽďKďũĞĐƚŝǀĞ͗hŶĚĞƌƌĞĂŵĞŵĞŶƚĂƉ͕&K͘Z/,ĂŶĚƚĂŐdKĂƚϭϮϱϰϯΖdD͘ hŶĚĞƌƌĞĂŵĐĞŵĞŶƚĐĂƉϭϮ͕ϱϰϯΖͲϭϮ͕ϲϯϴΖdD͘ůĞĂŶŽƵƚƐĂŶĚĚŽǁŶƚŽϭϮϴϴϱΖďĞĨŽƌĞĞŶĐŽƵŶƚĞƌŝŶŐĐĞŵĞŶƚƐƚƌŝŶŐĞƌƐ͘Dŝůů ĚŽǁŶƚŽϭϮϴϵϰdDǁŚŝĐŚĂƉƉĞĂƌƐƚŽďĞĐĞŵĞŶƚƌĞƚĂŝŶĞƌĂĨƚĞƌŵƵůƚŝƉůĞƐƚĂůůƐ͘WƵŵƉĨŝŶĂůŐĞůƐǁĞĞƉĂŶĚĐŚĂƐĞŝŶƚŽƚƵďŝŶŐ ƚĂŝů͘KƉĞŶĐŝƌĐƐƵďĂŶĚƉƵůůŝŶƚŽƚƵďŝŶŐ͘WKK,ǁŚŝůĞǁĞůůĨůŽǁŝŶŐ͘ĞŐŝŶZŝŐĚŽǁŶdh WĞƌĨŽƌŵĞĚD/ddǆ/ǁŝƚŚƚƌŝƉůĞǆƚŽϮϱϬϬƉƐŝ͘WĂƐƐĞĚ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ EϯͲϭϭ ^Zηϭ ϱϬͲϬϮϵͲϮϭϴϰϴͲϬϬͲϬϬ ϭϴϴͲϬϴϳ ϭͬϯϭͬϮϬϮϮ ϵͬϮϵͬϮϬϮϮ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ ϭϭͬϭͬϮϬϮϮ KWZd/KE^E'/EZ/^EKddKWhZ^hWZ&KZd/KE^͘ ϵͬϲͬϮϬϮϮ t>>&>Kt/E'KEZZ/s>͕WdWϮϱϬ>ͬϮϱϬϬ,͘ZE͕ϯ͘ϳϬϱΗdWWZ^t'dKϭϮ͕ϵϬϰΖ^>DͬϭϮ͕ϵϭϮΖD;ƌĞƐƚƌŝĐƚŝŽŶƐ ĂƚǆŶͲŶŝƉĂƚϭϮ͕ϮϲϯΘƚďŐƐƚƵďĂƚϭϮ͕ϮϬϯ͕ƐĞĞůŽŐͿ͘ZEϰͲϭͬϮΗZh^,tͬϯ͘ϳϬϱΗ^t'͘Zh^,&ZKDϭϮ͕ϮϬϬΖKhdd'd/> dϭϮ͕ϱϬϬΖD;ƐĞĞůŽŐĨŽƌĚĞƚĂŝůƐ͕ƌĞƐƚƌŝĐƚŝŽŶƐĐůĞĂƌͿ͘Z/&dtͬϮϬΖǆϯ͘ϳϬΗDzt,/W^dK<dKϭϮ͕ϵϮϭΖD;ϴΖĐŽƌƌĨƌŽŵǆŶ ŶŝƉĂƚϭϮ͕ϮϲϯΖŵĚͿ ϵͬϭϬͬϮϬϮϮ ϵͬϮϴͬϮϬϮϮ Wh>>,yW>h'&ZKDϭϮ͕ϳϱϲΖ^>D;ϭϮ͕ϴϮϬΖDͿ͕D/^^/E'ΕϭͬϯZK&>DEd͘Z/,tͬKd>KdKZtͬϰϭͬϮΖΖͲZh^, ϯ>'t/Z'Zϯ͘ϬϳϰΖΖd'ΛϭϮϮϮϲΖ^>D͘Z/,tͬ^W/EEZW^/͕dDW>K'dKK>ϭϬϬΖWZ͕D/EKtEdKϭϮϴϲϬΖ^>D ;ϭϮϵϱϰΖDͿΘDϮϭϬŵŝŶ^dKW^tͬt>>Kͬ>ΛdZ'dWZ^^hZK&ϭϱϱϬƉƐŝ^WZWZK'ZDZ&ZdK:K>K' &KZd/>^͘^dz&KZDDKZz,EdKZZ/s&ZKDK/>:KKE>ͲϰdKsZ/&zd͘ ϵͬϮϵͬϮϬϮϮ DDKZz,EZZ/sKE>K͕;ŐŽŽĚĚĂƚĂͿ͕Z/'KtE͕dhZEt>>KsZdKKWW^͘t>>^ͬ/KEWZdhZ͕^K EKd/&/͘ t>>^ͬ/KEZZ/s>͘K:d/s͗^d,yW>h'͘D/Zhz>>Kt:<dͲ>/E͘WdWϮϱϬW^/>Ktͬ͘ϯϱϬϬW^/,/',͘Z/,tͬ /EdZt>>,yW>h'tͬϮϵηKEsZ^/KE</d͘^d,yW>h'D/>>DEddϭϮϴϮϬΖ͘>dKD/>DEdϭϵ͘ϮϵΖ> ^dKWWd,ϭϮϴϬϬ͘ϳΖ͘dKWK&d,W>h'ΛϭϮϴϭϰ͘ϰΖ͘^>/W^ΛϭϮϴϮϯ͘ϮΖ͘KddKDK&d,W>h'ΛϭϮϴϮϰ͘ϱΖ͘Wd,^ KZZ>ddK^>d>K'ϬϳͲ^WͲϴϴ͘ZDKz>>Kt:<d>/E͘ ϵͬϮϯͬϮϬϮϮ t>>&ͬ>KEZZ/s>͕^KEKd/&/͘WdWϮϱϬ>͕W^/EϯϬϬϬ,͕W^/͘ZEϯ͘ϲϴΖΖEd͕ϰͲϭͬϮΖΖ'^;Z^^Ϳtͬ,/EW ϭϮϳϰϵΖ^>D:ZhW&KZϭ,Z^,ZK&&͘ZEϯ͘ϲϴΖΖEd͕ϰͲϭͬϮΖΖ'^;Z^^Ϳtͬ,/EWϭϮϳϰϵΖ^>D:ZhW&KZϭ,Z ^,ZK&&͘Wh>>K&&^EϯͲϮϱt>>,ZW/ZKDW>d͘t>>^ͬ/KEWZdhZ͕^KEKd/&/͘ ϵͬϮϳͬϮϬϮϮ t>>Kͬ>KEZZ/s>͕^KEKd/&/͕WdWϮϱϬ>ͬϯϱϬϬ,͘ZEϯ͘ϲϴΗEd͕ϰͲϭͬϮΗ'^Ϯd/D^KtEdK,yW>h'Λ ϭϮ͕ϳϱϲΖ^>D;ϭϮ͕ϴϮϬΖDͿ͕,yW>h'D&ZKE^KEZhE͕,hE'hW/EyEE/WΛϭϮ͕ϰϯϮΖ^>D;ϭϮ͕ϰϴϴΖDͿ͘ Wh>>K&&^EϯͲϮϱt>>,ZW/ZKDW>d t>>^ͬ/KEZZ/s>͘K:d/s͗^d,yW>h'͘D/Zhz>>Kt:<dͲ>/E͘WdWϮϱϬW^/>Ktͬ͘ϯϱϬϬW^/,/',͘Z/,tͬ /EdZt>>,yW>h'tͬϮϵηKEsZ^/KE</d͘^d,yW>h'D/>>DEddϭϮϴϮϬΖ͘ ZEϯ͘ϲϴΗEd͕ϰͲϭͬϮΗ'^Ϯd/D^KtEdK,yW>h'Λ ϭϮ͕ϳϱϲΖ^>D;ϭϮ͕ϴϮϬΖDͿ͕,yW>h'D&ZKE^KEZhE͕,hE'hW/EyEE/WΛϭϮ͕ϰϯϮΖ^>D;ϭϮ͕ϰϴϴΖDͿ͘ Wh>>,yW>h'&ZKDϭϮ͕ϳϱϲΖ^>D;ϭϮ͕ϴϮϬΖDͿ͕D/^^/E'ΕϭͬϯZK&>DEd [7173DFNHU ;1LSSOH,' ;11LSSOH,' '+$655:2 -HWFXWWXELQJDW 162YHUVKRW 'ULYH3LSH &U-)(%($5WXELQJ 75669 750$;;( '%SURILOH ^d D ds s s>s >d, d ϲ ϯϳϱϳ ϯϳϭϲ Ϯϳ ŽŵĞ ϭ͘ϱΗ ϮͬϭϵͬϮϮ ϱ ϱϬϲϯ ϰϲϵϴ ϰϳ Dz ϭ͘ϱΗ ϮͬϭϮͬϮϮ ϰ ϲϬϱϵ ϱϯϵϮ ϰϲ ^K ϭ͘ϱΗ ϮͬϭϵͬϮϮ ϯ ϳϭϲϱ ϲϬϵϱ ϱϯ Dz ϭ͘ϱΗ ϮͬϭϮͬϮϮ Ϯ ϴϯϭϯ ϲϳϵϱ ϱϭ Dz ϭ͘ϱΗ ϮͬϭϮͬϮϮ ϭ ϵϯϵϭ ϳϰϵϳ ϰϳ Dz ϭ͘ϱΗ ϮͬϭϮͬϮϮ WĂƚĐŽ'ĂƐ>ŝĨƚDĂŶĚƌĞůƐ Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/7/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221107 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# END 03-11 500292184800 188087 9/28/2022 Halliburton SPINNER/TEMP/PRESSURE MPU F-13 500292254900 195027 10/11/2022 Halliburton MFC Please include current contact information if different from above. T37241 T37242 END 03-11 500292184800 188087 9/28/2022 Halliburton SPINNER/TEMP/PRESSURE Kayla Junke Digitally signed by Kayla Junke Date: 2022.11.08 12:34:15 -09'00' 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov October 25, 2022 Ms. Joleen Oshiro Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number: OTH-22-032 Well Testing Endicott 3-11 (PTD 188-087) Duck Island Unit Dear Ms. Oshiro: By letter dated September 27, 2022, Hilcorp Alaska, LLC (Hilcorp) requested approval of an alternative well testing methodology for the Endicott 3-11 well in the Duck Island Unit. The well was a long term shut in well that was recently returned to service and is seeing attic oil benefits from an offset injector. Its flow is limited by velocity constraints in its 4” flowline. In order to allow the well to perform at its full capabilities Hilcorp proposes installing a 6” flowline to the wellhead and then teeing the 6” line into two 4” lines (the existing 4”flowline for the 3-11 well and the unused flowline for the 3-13 well) downstream of the choke and surface safety valve components. Configuring the well’s flowlines like this should allow for increased ultimate recovery by accelerating oil recovery from the well and pool. Hilcorp proposes an alternate method of well testing by summation of the individual well tests of the twinned Endicott 311 flowlines. Performing the well tests of each flowline back-to-back will ensure consistent plant conditions and therefore sufficient accuracy for allocation purposes. Because the flowlines are being split downstream of the safety valve system, instead of having both flowlines connect directly to the wellhead as has been done on several other well twining projects, the safety valve system for the well will be configured the same way as it currently is just on a 6” flowline instead of a 4” one. The AOGCC APPROVES Hilcorp’s request to use the alternate well testing methodology as described in the application for the Endicott 3-11 well. Any questions regarding this approval should be directed to Dave Roby at 907-793-1232. Sincerely, Jessie L. Chmielowski Commissioner Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.10.25 12:01:30 -08'00' September 27, 2022 Mr. David Roby Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Endicott 3-11 (PTD # 188-087) Request for Approval of Well Testing Changes In Support of Twinned Flowline Dear Mr. Roby, Hilcorp Alaska, LLC (HAK) requests approval to use alternative well testing on well Endicott 3-11 (PTD #188-087) in support of a flowline twinning project. Background Endicott 3-11 is a producer that was recently worked over and returned to production after a long shut-in period. 3-11 is seeing attic oil benefits from gas injector 4-26A, and it is currently choked back due to surface velocity constraints through its one, 4” flowline. Hilcorp proposes the following: 1)The 4” flowline from the wing valve to the choke be up-sized to 6”. 2)Downstream of the choke, the 6” flowline will split into two, 4” flowlines that will tie into slots 3-11 and 3-13. Note that no changes will be made to the safety system. Justification Twining 3-11 will accelerate production from the Kekiktuk reservoir and will increase ultimate recovery by pulling reserves forward into Endicott’s economic field life. Well Testing Methodology During this period of twinning, Hilcorp will utilize an alternate method of well testing if acceptable to the commission as per 20 AAC 25.230(a). 3-11’s well tests would be obtained through a summation of individual tests of the original and twin 3-11 flowlines. Currently 3-11 is tested a minimum of once monthly. With the addition of once monthly tests from the twinned flowline, a minimum of 2 tests would be taken to ensure a combined 3-11 well test per month. Individual tests from the original and twin flowlines would be completed back to back to ensure as consistent plant conditions and back pressure as possible. Typically the test separator and production header pressures track closely, within +/- 10 psi. Daily production allocation methodology would remain 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907/777-8300 Fax: 907/777-8301 Page |2 the same utilizing individual tests and flowline On/Off times as determined by the wing valves’ open/closed position. Production values for each flowline would then be combined and reported as a single value for 3-11. This methodology would result in no change or disruption to 3-11’s well test or production reporting. If you have any additional questions, please contact me at 650-483-4774 or Joleen.oshiro@hilcorp.com Sincerely, Joleen Oshiro Operations Engineer Hilcorp Alaska, LLC CC James Regg Attachments -3-11 (Twinned) Proposed P&ID -3-11 Twinning Aerial View Page |3 Endicott 3-11 (Twinned) Proposed P&ID Page |4 Endicott 3-11 Twinning Aerial View CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Walbert Schulpen To:Joleen Oshiro; Roby, David S (OGC); Regg, James B (OGC) Subject:RE: [EXTERNAL] RE: END 3-11 (PTD #188-087): Request for Approval of Well Testing Changes in Support of Twinned Flowline Date:Monday, October 17, 2022 2:52:38 PM Hi Dave, Essentially what this twinning entails, is that we have a single safety valve and a single 6” choke. Downstream the choke will be the PSL. Downstream the PSL will be a 6” tee. Each of the 6” legs from the tee will reduce to a 4” flowline back to the header. Hydraulically the dual 4” headers would act similar to a single 6” header, both in terms of flowrate/velocity and pressure. The PSL would therefore detect a leak in both 4” legs. For the safety system there would be no difference between a twinned well (using above described method) and an single flowline well because inbetween the wellhead and the choke, no changes are made, and no additional flowlines or chokes are added to the wellhead. Kind regards, Walbert Schulpen From: Joleen Oshiro <Joleen.Oshiro@hilcorp.com> Sent: Monday, October 17, 2022 1:39 PM To: Walbert Schulpen <wschulpen@hilcorp.com> Subject: FW: [EXTERNAL] RE: END 3-11 (PTD #188-087): Request for Approval of Well Testing Changes in Support of Twinned Flowline From: Roby, David S (OGC) <dave.roby@alaska.gov> Sent: Monday, October 17, 2022 11:47 AM To: Joleen Oshiro <Joleen.Oshiro@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: [EXTERNAL] RE: END 3-11 (PTD #188-087): Request for Approval of Well Testing Changes in Support of Twinned Flowline Hi Joleen, In the application it states there will be no changes to the safety valve system. I realize this is different than the typical flowline twinning applications that do require changes to the safety valve system since the two flowlines are connected to different valves on the wellhead instead of splitting CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. off further downstream, but could you provide more justification for why you think changes to the safety valve setup won’t be necessary here? Similarly, would a PSL on the 6” line be able to detect a small leak in one of the downstream 4” lines that would be detectable if there was a PSL on the 4” line? Thank you, Dave Roby (907)793-1232 From: Joleen Oshiro <Joleen.Oshiro@hilcorp.com> Sent: Monday, October 17, 2022 9:20 AM To: Roby, David S (OGC) <dave.roby@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: RE: END 3-11 (PTD #188-087): Request for Approval of Well Testing Changes in Support of Twinned Flowline Hi Mr. Roby and Mr. Regg, Hope all is well. I wanted to follow up on Hilcorp’s request for approval of well testing changes for the Endicott 3-11 twin project (see attached). Please let me know if there are any questions and if Hilcorp is approved to proceed with this project. Cheers, Joleen Oshiro Alaska Islands Team (Endicott, Northstar, Pt Thomson) 650-483-4774 From: Joleen Oshiro Sent: Tuesday, September 27, 2022 9:44 AM To: Roby, David S (CED) <dave.roby@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov> Subject: END 3-11 (PTD #188-087): Request for Approval of Well Testing Changes in Support of Twinned Flowline Dear Mr. Roby and Mr. Regg, Please see the attached document requesting approval for well testing changes for the Endicott 3-11 twinned flowline project. Please let me know if there are any questions regarding this request. Cheers, Joleen Oshiro Alaska Islands Team (Endicott, Northstar, Pt Thomson) 650-483-4774 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Roby, David S (OGC) To:Joleen Oshiro Cc:Regg, James B (OGC) Subject:RE: END 3-11 (PTD #188-087): Request for Approval of Well Testing Changes in Support of Twinned Flowline Date:Monday, October 17, 2022 11:46:00 AM Hi Joleen, In the application it states there will be no changes to the safety valve system. I realize this is different than the typical flowline twinning applications that do require changes to the safety valve system since the two flowlines are connected to different valves on the wellhead instead of splitting off further downstream, but could you provide more justification for why you think changes to the safety valve setup won’t be necessary here? Similarly, would a PSL on the 6” line be able to detect a small leak in one of the downstream 4” lines that would be detectable if there was a PSL on the 4” line? Thank you, Dave Roby (907)793-1232 From: Joleen Oshiro <Joleen.Oshiro@hilcorp.com> Sent: Monday, October 17, 2022 9:20 AM To: Roby, David S (OGC) <dave.roby@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: RE: END 3-11 (PTD #188-087): Request for Approval of Well Testing Changes in Support of Twinned Flowline Hi Mr. Roby and Mr. Regg, Hope all is well. I wanted to follow up on Hilcorp’s request for approval of well testing changes for the Endicott 3-11 twin project (see attached). Please let me know if there are any questions and if Hilcorp is approved to proceed with this project. Cheers, Joleen Oshiro Alaska Islands Team (Endicott, Northstar, Pt Thomson) 650-483-4774 From: Joleen Oshiro Sent: Tuesday, September 27, 2022 9:44 AM To: Roby, David S (CED) <dave.roby@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov> Subject: END 3-11 (PTD #188-087): Request for Approval of Well Testing Changes in Support of Twinned Flowline Dear Mr. Roby and Mr. Regg, Please see the attached document requesting approval for well testing changes for the Endicott 3-11 twinned flowline project. Please let me know if there are any questions regarding this request. Cheers, Joleen Oshiro Alaska Islands Team (Endicott, Northstar, Pt Thomson) 650-483-4774 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Joleen Oshiro To:Roby, David S (OGC) Cc:Regg, James B (OGC) Subject:RE: END 3-11 (PTD #188-087): Request for Approval of Well Testing Changes in Support of Twinned Flowline Date:Monday, October 17, 2022 9:20:25 AM Attachments:Ltr to AOGCC END 3-11 Twinning Request.pdf Hi Mr. Roby and Mr. Regg, Hope all is well. I wanted to follow up on Hilcorp’s request for approval of well testing changes for the Endicott 3-11 twin project (see attached). Please let me know if there are any questions and if Hilcorp is approved to proceed with this project. Cheers, Joleen Oshiro Alaska Islands Team (Endicott, Northstar, Pt Thomson) 650-483-4774 From: Joleen Oshiro Sent: Tuesday, September 27, 2022 9:44 AM To: Roby, David S (CED) <dave.roby@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov> Subject: END 3-11 (PTD #188-087): Request for Approval of Well Testing Changes in Support of Twinned Flowline Dear Mr. Roby and Mr. Regg, Please see the attached document requesting approval for well testing changes for the Endicott 3-11 twinned flowline project. Please let me know if there are any questions regarding this request. Cheers, Joleen Oshiro Alaska Islands Team (Endicott, Northstar, Pt Thomson) 650-483-4774 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/02/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20220902 Well API #PTD #Log Date Log Company Log Type Notes AOGCC Eset # END 3-11 50029218480000 188087 8/1/2022 Halliburton CALIPER + Report KALOTSA 4 50133206650000 217063 7/18/2022 Halliburton PPROF + Processing KBU 22-06Y 50133206500000 215044 7/14/2022 Halliburton PPROF + Processing KTU 24-06H 50133204900000 199073 7/21/2022 Halliburton PPROF + Processing KU 24-05B 50133206830000 219072 7/20/2022 Halliburton PPROF + Processing MPU C-24A 50029230200100 209134 7/28/2022 Halliburton COIL FLAG MPU I-17 50029232120000 204098 7/19/2022 Halliburton FREEPOINT NS-10 50029229850000 200182 7/23/2022 Halliburton CALIPER + Report NS-32 50029231790000 203158 7/24/2022 Halliburton CALIPER + Report PBU 18-02C 50029207620300 213009 7/14/2022 Halliburton CAST/CBL PBU C-10B 50029203710200 211092 7/15/2022 Halliburton PPROF + Processing PBU L5-03 50029236230000 219033 7/25/2022 Halliburton PPROF + Processing Please include current contact information if different from above. T36973 T36974 T36975 T36976 T36977 T36978 T36979 T36980 T36981 T36982 T36983 T36984 50029218480000 188087 /1/202288/Halliburton CALIPEREND 3-11 + + Report Kayla Junke Digitally signed by Kayla Junke Date: 2022.09.07 11:00:16 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:2022-0825 OPERABLE: Producer END3-11 (PTD# 188-087) Post Surface Casing Repair Date:Monday, August 29, 2022 10:20:54 AM Attachments:image002.png image003.png From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Thursday, August 25, 2022 9:24 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: OPERABLE: Producer END3-11 (PTD# 188-087) Post Surface Casing Repair Mr. Regg, END 3-11 (PTD# 188-087) surface casing repairs (Sundry #322-372) have been completed and the well has been placed on production Under Evaluation. There are no indications of leaks post repair. The well is now classified as OPERABLE. Please respond if there are any questions or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Monday, August 1, 2022 3:00 PM To: Regg, James B (CED) <jim.regg@alaska.gov>; 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; 'melvin.rixse@alaska.gov' <melvin.rixse@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: Request UNDER EVALUATION: Producer END3-11 (PTD# 188-087) Post Surface Casing Repair Mr. Regg, We have completed the surface casing excavation and repair (Sundry #322-372) for Producer END3-11 (PTD# 188-087). During the excavation, leaks were identified at depths of ~20’3” and 20’7”. The conductor has now been reinstalled and cemented to surface. The well is now reconnected to production. The well is now classified as UNDER EVALUATION and is on a 28 day clock for evaluation of repairs. Plan Forward 1. Operations to place on production 2. Engineer to evaluate repair and operability Please respond with any questions or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, youare hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, thenpromptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems ordata. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Producer END3-11 (PTD# 188-087) Post Surface Casing Repair Date:Thursday, August 25, 2022 1:20:38 PM Attachments:image002.png image003.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Thursday, August 25, 2022 9:24 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: OPERABLE: Producer END3-11 (PTD# 188-087) Post Surface Casing Repair Mr. Regg, END 3-11 (PTD# 188-087) surface casing repairs (Sundry #322-372) have been completed and the well has been placed on production Under Evaluation. There are no indications of leaks post repair. The well is now classified as OPERABLE. Please respond if there are any questions or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Monday, August 1, 2022 3:00 PM To: Regg, James B (CED) <jim.regg@alaska.gov>; 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; 'melvin.rixse@alaska.gov' <melvin.rixse@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: Request UNDER EVALUATION: Producer END3-11 (PTD# 188-087) Post Surface Casing Repair Mr. Regg, We have completed the surface casing excavation and repair (Sundry #322-372) for Producer END3-11 (PTD# 188-087). During the excavation, leaks were identified at depths of ~20’3” and 20’7”. The conductor has now been reinstalled and cemented to surface. The well is now reconnected to production. The well is now classified as UNDER EVALUATION and is on a 28 day clock for evaluation of repairs. Plan Forward 1. Operations to place on production 2. Engineer to evaluate repair and operability Please respond with any questions or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, youare hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, thenpromptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems ordata. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Request UNDER EVALUATION: Producer END3-11 (PTD# 188-087) Post Surface Casing Repair Date:Tuesday, August 2, 2022 8:37:07 AM Attachments:image002.png image003.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Monday, August 1, 2022 3:00 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: Request UNDER EVALUATION: Producer END3-11 (PTD# 188-087) Post Surface Casing Repair Mr. Regg, We have completed the surface casing excavation and repair (Sundry #322-372) for Producer END3-11 (PTD# 188-087). During the excavation, leaks were identified at depths of ~20’3” and 20’7”. The conductor has now been reinstalled and cemented to surface. The well is now reconnected to production. The well is now classified as UNDER EVALUATION and is on a 28 day clock for evaluation of repairs. Plan Forward 1. Operations to place on production 2. Engineer to evaluate repair and operability Please respond with any questions or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, youare hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, thenpromptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems ordata. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. By Samantha Carlisle at 7:49 am, Aug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y Samantha Carlisle at 1:53 pm, Jun 27, 2022 'LJLWDOO\VLJQHGE\7RULQ 5RVFKLQJHU '1FQ 7RULQ5RVFKLQJHU RX 8VHUV 'DWH 7RULQ5RVFKLQJHU '650*5-8/< ; '/% GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.07.11 15:39:04 -08'00' RBDMS JSB 071222 ^ǆĐĂǀĂƚŝŽŶĂŶĚZĞƉĂŝƌ EϯͲϭϭ Wd͗ϭϴϴϬϴϳ tĞůůEĂŵĞ͗EϯͲϭϭ ^ƵƌĨĂĐĞĂƐŝŶŐ ǆĐĂǀĂƚŝŽŶĂŶĚZĞƉĂŝƌ W/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϭϴϰϴͲϬϬͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗^ŚƵƚ/Ŷ ZŝŐ͗ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ϳͬϬϳͬϮϬϮϮ ƐƚŝŵĂƚĞĚƵƌĂƚŝŽŶ ϭϰ ĚĂǇƐ WƌŽŐƌĂŵĂƚĞ ϳͬϮϭͬϮϬϮϮ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϴϴϬϴϳ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ĂƌĐŝ,ŽƌŶĞƌ ;ϵϬϳͿ ϳϳϳͲϴϰϬϲ ;KͿ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗:ĞƌŝŵŝĂŚ'ĂůůŽǁĂǇ ;ϵϬϳͿ ϱϲϰͲϱϬϬϱ ;KͿ ;ϴϮϴͿ ϱϱϯͲϮϱϯϳ ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗:ŽůĞĞŶKƐŚŝƌŽ ;ϵϬϳͿ ϳϳϳͲϴϰϴϲ ;KͿ ;ϲϱϬͿ ϰϴϯͲϰϳϳϰ ;DͿ ǆƉĞĐƚĞĚZĂƚĞƐ ϱϯϭKW͕ϭϬtWĂŶĚϮϱ ŵŵƐĐĨĚ;ϯϬĂǇ/KZ ʹ ϭϴϬͿ &XUUHQW%RWWRP+ROH3UHVVXUH SVL#¶79' .:)aSSJ %DVHGRQ 6%+36 LQQHDUE\DQDORJXHZHOO$ 0D[$QWLFLSDWHG6XUIDFH3UHVVXUHSVL %DVHGRQSVLIWJDV JUDGLHQW /DVWUHFRUGHGVKXWLQ:+3SVLRQ 6OLFNOLQHGULIWDQGWDJ7,2 ƌŝĞĨtĞůů^ƵŵŵĂƌǇ͗ EϯͲϭϭŝƐĂŶ ĂƌƚŝĨŝĐŝĂůůŝĨƚƉƌŽĚƵĐĞƌƚŚĂƚǁĂƐƌĞĐĞŶƚůǇǁŽƌŬĞĚŽǀĞƌ͘/ŶϮϬϬϲƚŚĞϵͲϱͬϴĐĂƐŝŶŐǁĂƐ ƉƵŶĐŚĞĚ͕ ĂŶĚ ƚŚĞKĐĞŵĞŶƚĞĚŝŶĂŶĞĨĨŽƌƚƚŽƌĞƉĂŝƌĂƐƵƌĨĂĐĞĐĂƐŝŶŐůĞĂŬ͘ƵƌŝŶŐĂŶĚĂĨƚĞƌƚŚĞǁŽƌŬŽǀĞƌĂD/dͲdǆ/ĂŶĚ D/dͲ/ďŽƚŚƉĂƐƐĞĚǁŝƚŚĨůƵŝĚ͘KŶĐĞƚŚĞǁĞůů ǁĂƐďƌŽƵŐŚƚŽŶůŝŶĞ͕ ƚŚĞƐƵƌĨĂĐĞĐĂƐŝŶŐůĞĂŬĂƉƉĞĂƌĞĚƚŽďĞ ƌĞĂĐƚŝǀĂƚĞĚ͘ dǁŽĂƚƚĞŵƉƚƐƚŽƌĞƉĂŝƌƚŚĞůĞĂŬǁŝƚŚtĞůůŽĐŬ ĨĂŝůĞĚƚŽƌĞƉĂŝƌƚŚĞůĞĂŬ͘ ^ƵƐƉĞĐƚĞĚƐƵƌĨĂĐĞĐĂƐŝŶŐ ůĞĂŬŝƐϵͲϭϭĨĞĞƚďĂƐĞĚŽŶƉƌĞǀŝŽƵƐŶĚŝĐŽƚƚƌĞƉĂŝƌƐ͘ tĞůůďŽƌĞŽŶĚŝƚŝŽŶ ϬϯͬϮϬϬϲ͗ ^ƵƌĨĂĐĞĐĂƐŝŶŐůĞĂŬĚĞƉƚŚǁĂƐŶŽƚĚĞƚĞƌŵŝŶĞĚ͘ ZtKƚŽƌĞƉĂŝƌƐƵƌĨĂĐĞĐĂƐŝŶŐůĞĂŬ͘ĞŵĞŶƚĞĚKƚŽ ƐƵƌĨĂĐĞĂŶĚǁĞůůůĞĨƚǁŝƚŚŬŝůůƐƚƌŝŶŐŝŶŚŽůĞ͘ ϬϵͬϮϬϬϳ͗D/dͲKǁŝƚŚEϮƚŽϱϬϬƉƐŝƉĂƐƐĞĚ͘ ϭϭͬϮϬϭϲ͗D/dͲKWĂƐƐĞĚƚŽϱϬϬƉƐŝ͘ ϭϭͬϮϬϮϭ͗D/dͲK&ĂŝůĞĚƚŽϭϬϬϬƉƐŝǁŝƚŚĚŝĞƐĞů͘EŽĨůƵŝĚƌĞƚƵƌŶƐƚŽƐƵƌĨĂĐĞ͘D/dͲdǆ/WĂƐƐĞĚƚŽϮϱϬϬƉƐŝ͘ ϬϮͬϮϬϮϮ͗ZtKŽŵƉůĞƚĞĚĂŶĚK'D/dͲ/WĂƐƐĞĚƚŽϮϱϬϬƉƐŝ͘ ϬϰͬϮϬϮϮ͗KƌĞƉƌĞƐƐƵƌŝǌĂƚŝŽŶĂŶĚĐŽŶĚƵĐƚŽƌďƵďďůŝŶŐďĞŐĂŶǁŚŝů ĞĂƚƚĞŵƉƚŝŶŐƚŽƉƵƚŽŶƉƌŽĚƵĐƚŝŽŶ͘ ϬϰͬϮϬϮϮ͗^ĞƚƉůƵŐĂŶĚD/dͲdǆ/WĂƐƐĞĚƚŽϮϱϬϬƉƐŝ͘ ϬϲͬϮϬϮϮ͗KǁĞůůŽĐŬĂŶĚĐŽŶĚƵĐƚŽƌƚŽƉũŽďĐŽŵƉůĞƚĞĚ;ĐĞŵĞŶƚĨŽƵŶĚĂƚƐƵƌĨĂĐĞͿ͘tĞůůŽĐŬũŽďǁĂƐŶŽƚ ƐƵĐĐĞƐƐĨƵů͘ KďũĞĐƚŝǀĞ͗ǆĐĂǀĂƚĞƐƵƌĨĂĐĞĐĂƐŝŶŐĂŶĚŝŶƐƚĂůůƉĂƚĐŚƚŽŵŝƚŝŐĂƚĞƚŚĞůĞĂŬ͘ WƌĞͲ^ƵŶĚƌǇtŽƌŬ ^ůŝĐŬůŝŶĞ ϭ͘ ^ĞĐƵƌĞǁĞůůǁŝƚŚ ƉůƵŐ ΛϭϮ͕Ϯϲϯ͛ D Ϯ͘ D/dͲdǆ/ƚŽϮϱϬϬƉƐŝ KƉĞƌĂƚŝŽŶƐ ϭ͘ /ŶƐƚĂůůĐŽŵƉĂŶŝŽŶǀĂůǀĞŽŶKĨŽƌEϮƉƵƌŐĞ͘ Ϯ͘ /ŶƐƚĂůůWsͬdt͘ ϯ͘ ŝƐĐŽŶŶĞĐƚĨůŽǁůŝŶĞĂŶĚŝŶƐƚƌƵŵĞŶƚĂƚŝŽŶ͘ ϰ͘ ŽŵƉůĞƚĞĂŶtZ;ƌĞĂŝǀŝůtŽƌŬZĞƋƵĞƐƚͿǁŚŝĐŚŝŶĐůƵĚĞƐĂůŽĐĂƚĞĨŽƌ ƐŚĂůůŽǁďƵƌŝĞĚ ƵƚŝůŝƚŝĞƐ ĂŶĚƵŶĚĞƌŐƌŽƵŶĚŝŶĨƌĂƐƚƌƵĐƚƵƌĞ͘ tZƚŽďĞĐŽŵƉůĞƚĞĚŝŶĂϯϬ͛ƌĂĚŝƵƐĂƌŽƵŶĚƚŚĞǁĞůůŚĞĂĚ͘ ^ǆĐĂǀĂƚŝŽŶĂŶĚZĞƉĂŝƌ EϯͲϭϭ Wd͗ϭϴϴϬϴϳ ϱ͘ ůĞĞĚt,WƐƚŽϬƉƐŝ͘ ϲ͘ ^ŶŝĨĨĐĞůůĂƌĂŶĚĂĚũĂĐĞŶƚĂƌĞĂǁŝƚŚŵƵůƚŝͲŐĂƐŵĞƚĞƌĨŽƌ>>͕K͕,Ϯ^ĂŶĚϬϮ͘ŶƐƵƌĞĐŽŶĨŝŶĞĚƐƉĂĐĞ͕ ĞŐƌĞƐƐĂŶĚǀĞŶƚŝůĂƚŝŽŶŝƐĂĚĞƋƵĂƚĞĨŽƌŽƉĞƌĂƚŝŽŶƐ͘ ϳ͘ sĂĐŽƵƚŐƌĂǀĞůĨƌŽŵǁĞůůĐĞůůĂƌ͘ ϴ͘ ZĞŵŽǀĞĐĞůůĂƌĨůŽŽƌ͘ ^ƵŶĚƌǇZĞƉĂŝƌWƌŽĐĞĚƵƌĞ;ƉƉƌŽǀĂůƌĞƋƵŝƌĞĚƚŽƉƌŽĐĞĞĚͿ Ͳ &ŽƌƐƵŶĚƌǇƌĞƉĂŝƌǁŽƌŬ͕ŵĂŝŶƚĂŝŶĂĚĂŝůǇĂĐƚŝǀŝƚǇůŽŐǁŝƚŚĂďƌŝĞĨĚĞƐĐƌŝƉƚŝŽŶĂŶĚƉŚŽƚŽƐŽĨǁŽƌŬĨŽƌ ƐƵďŵŝƐƐŝŽŶƚŽK'ǁŝƚŚϭϬͲϰϬϰ͘ KƉĞƌĂƚŝŽŶƐ ϭ͘ ^ŶŝĨĨĐĞůůĂƌĂŶĚĂĚũĂĐĞŶƚĂƌĞĂǁŝƚŚŵƵůƚŝͲŐĂƐŵĞƚĞƌĨŽƌ>>͕K͕,Ϯ^ĂŶĚϬϮ͘ŶƐƵƌĞĐŽŶĨŝŶĞĚƐƉĂĐĞ͕ ĞŐƌĞƐƐĂŶĚǀĞŶƚŝůĂƚŝŽŶŝƐĂĚĞƋƵĂƚĞĨŽƌŽƉĞƌĂƚŝŽŶƐ͘ Ϯ͘ ǆĐĂǀĂƚĞĂŶĚ ŝŶƐƚĂůůƐŚŽƌŝŶŐďŽǆ ƚŽĂĚĞƉƚŚŽĨϭϮ͛͘ Ă͘ WƌŝŵĂƌǇƉůĂŶŝƐƚŽƵƐĞ ĂĐŽŵďŝŶĂƚŝŽŶŽĨǁĞůůĐĞůůĂƌĂŶĚ ŵŽĚƵůĂƌƐŚŽƌŝŶŐƐůĞĞǀĞ͘ ď͘ ůůĞǆĐĂǀĂƚŝŽŶƐǁŝůůĐŽŵƉůǇǁŝƚŚƚŚĞ^,ŚĂŶĚďŽŽŬĂŶĚK^, ZĞŐƵůĂƚŝŽŶƐ͘ Đ͘ /ŶƐƚĂůů Ăŝƌ ŵŽǀĞƌƐ ƚŽ ŵĂŝŶƚĂŝŶ ĨĂǀŽƌĂďůĞ ĂƚŵŽƐƉŚĞƌŝĐ ĐŽŶĚŝƚŝŽŶƐ ŝŶ ĂĐĐŽƌĚĂŶĐĞ ǁŝƚŚ ǀĞŶƚŝůĂƚŝŽŶƉůĂŶ͘ Ě͘ ƋƵĂůŝĨŝĞĚ ƉĞƌƐŽŶǁŝůůďĞŽŶƐŝƚĞĚƵƌŝŶŐƚŚĞĞǆĐĂǀĂƚŝŽŶ͘dŚĞĞǆĐĂǀĂƚŝŽŶŵƵƐƚďĞŝŶƐƉĞĐƚĞĚ ĂŶĚƐŝŐŶĞĚŽĨĨ͕ƉĞƌK^,ƌĞƋƵŝƌĞŵĞŶƚƐ͕ĞǀĞƌǇϮϰŚŽƵƌƐ͘<ĞĞƉĚŽĐƵŵĞŶƚĂƚŝŽŶŽĨŝŶƐƉĞĐƚŝŽŶƐ͘ ϯ͘ /ŶƐƚĂůůĂŶĚƵƐĞƐƵŵƉƚŽĚĞǁĂƚĞƌŝŶ ĞǆĐĂǀĂƚŝŽŶ͕ ĂƐŶĞĐĞƐƐĂƌǇ͘ Ă͘ /ŶŝŶƐƚĂŶĐĞƐŽĨĞǆĐĞƐƐŝǀĞŐƌŽƵŶĚǁĂƚĞƌŝŶĨůŽǁ͕ƉƌĞǀŝŽƵƐĞǆĐĂǀĂƚŝŽŶƌĞƉĂŝƌƐŚĂǀĞďĞŶĞĨŝƚĞĚ ĨƌŽŵƉůĂĐŝŶŐĂƐƵŵƉƉƵŵƉŝŶĂŚŽůĞŝŶĨƌŽŶƚŽĨŽƌĂĚũĂĐĞŶƚƚŽǁ Ğůů͘ ϰ͘ ŚĞĐŬƐƵƌĨĂĐĞĐĂƐŝŶŐĐŽŶĚŝƚŝŽŶ͘ Ă͘ ƌŝůůŚŽůĞƐ ďĞůŽǁƚŚĞ ůĂŶĚŝŶŐƌŝŶŐĂŶĚďĞůŽǁƐƵƐƉĞĐƚĞĚůĞĂŬĚĞƉƚŚ ŝŶĐŽŶĚƵĐƚŽƌƚŽĐŚĞĐŬĨŽƌ ĨůƵŝĚƚǇƉĞĂŶĚůĞǀĞůďĞŚŝŶĚƚŚĞĐŽŶĚƵĐƚŽƌǁŝŶĚŽǁĂƌĞĂ͘ ď͘ ǀĂĐƵĂƚĞĨůĂŵŵĂďůĞĨůƵŝĚ͘ Đ͘ ƵƚƚǁŽǁŝŶĚŽǁƐŝŶƚŚĞĐŽŶĚƵĐƚŽƌĂŶĚƉĞƌĨŽƌŵhdŝŶƐƉĞĐƚŝŽŶƐƚŽĞŶƐƵƌĞǁĞůĚĂďůĞ ƐƵƌĨĂĐĞ ĐĂƐŝŶŐ ďĞůŽǁƐƵƐƉĞĐƚĞĚŚŽůĞĚĞƉƚŚƉƌŝŽƌƚŽĐƵƚƚŝŶŐĐŽŶĚƵĐƚŽƌ͘E ŽƚŝĨǇK'ŝŶƐƉĞĐƚŽƌĨŽƌ ŽƉƉŽƌƚƵŶŝƚǇƚŽŝŶƐƉĞĐƚ͘ ŝ͘ hd ƐƵƌĨĂĐĞ ĐĂƐŝŶŐ ĨŽƌ ŝŶƚĞƌŶĂů ĚƌŝůůŝŶŐ ǁĞĂƌ ĂŶĚͬŽƌ ĞǆƚĞƌŶĂůĐŽƌƌŽƐŝŽŶ͘ ;ŝŶƚĞƌŶĂů ĚƌŝůůŝŶŐǁĞĂƌхϱϬйŶŽŵŝŶĂůĐĂƐŝŶŐƚŚŝĐŬŶĞƐƐŽƌĞǆƚĞƌŶĂůĐŽƌƌŽƐŝŽŶхϱϬйŶŽŵŝŶĂů ǁĂůůͿǁŽƵůĚŝŶĚŝĐĂƚĞĂƐƚŽƉƉŽŝŶƚ ĨŽƌĨƵƌƚŚĞƌůŽĂĚĂŶĂůǇƐŝƐ͘ ϱ͘ DŽǀĞŝŶĂŶĚƌŝŐƵƉtĞůů^ƵƉƉŽƌƚ^ƚƌƵĐƚƵƌĞ͘ Ă͘ >ĞǀĞůŐƌĂǀĞů ĨŽƵŶĚĂƚŝŽŶ͘ ď͘ WůĂĐĞ ƐƚƌƵĐƚƵƌĂů ƌŝŐŵĂƚƐ͘ Đ͘ /ŶƐƚĂůůƐŚŝŵƐďĞƚǁĞĞŶŐŝƌĚĞƌĂŶĚĨŽƵŶĚĂƚŝŽŶďĞĂŵƚŽůĞǀĞůƐƚƌ ƵĐƚƵƌĞ;KEKd ƵƐũĂĐŬƐƚŽ ůĞǀĞůƚŚĞƐƚƌƵĐƚƵƌĞͿ͘ Ě͘ :ĂĐŬƐƚŽďĞ>KdKŝŶŽƌĚĞƌƚŽƉƌĞǀĞŶƚƵƐĞ͘ ϲ͘ EŝƉƉůĞĚŽǁŶƉƌŽĚƵĐƚŝŽŶƚƌĞĞĂƚŵĂƐƚĞƌǀĂůǀĞŽƌƚƵďŝŶŐŚĞĂĚĂĚĂƉƚĞƌĂƐŶĞĞĚĞĚƚŽŵĂŬĞƵƉtĞůůŚĞĂĚ ^ƵƉƉŽƌƚ^ƚƌƵĐƚƵƌĞĂĚĂƉƚĞƌĨůĂŶŐĞ͘ ϳ͘ EŝƉƉůĞƵƉtĞůůŚĞĂĚ^ƵƉƉŽƌƚ^ƚƌƵĐƚƵƌĞƵƐŝŶŐƚŚĞĂĚũƵƐƚĂďůĞǀĞƌƚŝĐĂůƉŽƐƚĂŶĚŚĂƵŶĐŚĞƐĨŽƌƉƌŽƉĞƌ ŚĞŝŐŚƚ ƉůĂĐĞŵĞŶƚĂŶĚĐŽŵƉƌĞƐƐŝŽŶůŽĂĚŝŶŐ͘ ϴ͘ KŶĐĞǁĞůůŚĞĂĚŝƐƐƚĂďŝůŝǌĞĚ͕ŝŶƐƚĂůůƐĞĐŽŶĚĂƌǇĐŽŶƚĂŝŶŵĞŶƚĂƌŽƵŶĚůŽǁĞƌĞĚŐĞŽĨĐŽŶĚƵĐƚŽƌ͘ ϵ͘ /ĨƉŽƐƐŝďůĞ͕ĨůƵƐŚĐŽŶĚƵĐƚŽƌǁŝƚŚǁĂƚĞƌĨƌŽŵƚŚĞůĂŶĚŝŶŐƌŝŶŐǁŚŝůĞƚĂŬŝŶŐƌĞƚƵƌŶƐĨƌŽŵƚŚĞůŽǁĞƌ ŝŶƐƉĞĐƚŝŽŶŚŽůĞƐ͘&ůƵƐŚƵŶƚŝů ĐůĞĂŶƌĞƚƵƌŶƐĂƌĞŽďƐĞƌǀĞĚ͘ ϭϬ͘ /ŶƐƚĂůůEϮƉƵƌŐĞĞƋƵŝƉŵĞŶƚ͘ Ă͘ hƐĞŽĨĂEϮĐĂƉͬƉƵƌŐĞǁŝůůďĞĚĞƚĞƌŵŝŶĞĚŽŶƐŝƚĞƉƌŝŽƌƚŽƉƌŽĐĞĞĚŝŶŐ͘ ^ǆĐĂǀĂƚŝŽŶĂŶĚZĞƉĂŝƌ EϯͲϭϭ Wd͗ϭϴϴϬϴϳ ď͘ WƌŝŽƌƚŽĐƵƚƚŝŶŐƚŚĞĐŽŶĚƵĐƚŽƌ͕ŝŶƐƚĂůůĐŽŶƚŝŶƵŽƵƐĨŽƵƌͲǁĂǇŐ ĂƐŵĞƚĞƌĨŽƌ>>͛ƐĂŶĚEϮĨƌŽŵ ƚŚĞĐŽŶĚƵĐƚŽƌ͘ Đ͘ ,Žƚ ǁŽƌŬ ƉĞƌŵŝƚ ƚŽ ŽƵƚůŝŶĞ ŝĨ ĂĚũĂĐĞŶƚ ǁĞůůƐ ǁŝůů ƌĞƋƵŝƌĞ ƐŚƵƚ ŝŶ ĂƐ ƉĂƌƚ ŽĨ ƚŚĞ ƐĂĨĞƚǇ ŵŝƚŝŐĂƚŝŽŶƉůĂŶ͘ ϭϭ͘ ƵƚĂŶĚƌĞŵŽǀĞƚŚĞĐŽŶĚƵĐƚŽƌĨƌŽŵƚŚĞǁŝŶĚŽǁƚŽƚŚĞůĂŶĚŝŶŐƌŝŶŐ͘ Ă͘ WƌŝŵĂƌǇĐƵƚƚŝŶŐŽƉƚŝŽŶŝƐƚŽƵƐĞĂŶĂŝƌĂƌĐƚŽƌĐŚďƵƚƚŚĞ ,ŽƚtŽƌŬWĞƌŵŝƚĨŽƌƚŚŝƐƉŽƌƚŝŽŶŽĨ ƚŚĞũŽďǁŝůůĚŝĐƚĂƚĞŝĨĂŶĂůƚĞƌŶĂƚŝǀĞĐƵƚƚŝŶŐŵĞƚŚŽĚǁŝůůďĞƌĞƋƵŝƌĞĚ͘ ď͘ dǁŽŚŽƌŝǌŽŶƚĂůĐƵƚƐ;ďĞůŽǁƚŚĞůĂŶĚŝŶŐƌŝŶŐĂŶĚŽŶĞĂƚƚŚĞďŽ ƚƚŽŵŽĨƚŚĞĐŽŶĚƵĐƚŽƌƐĞĐƚŝŽŶͿ ĂŶĚƚǁŽǀĞƌƚŝĐĂůĐƵƚƐǁŝůůďĞƌĞƋƵŝƌĞĚƚŽƌĞŵŽǀĞƚŚĞ ĐŽŶĚƵĐƚŽƌ͘ ŝ͘ ůƚĞƌŶĂƚĞůǇ͕ŝĨƚŚĞƌĞŝƐŶŽƚƐƵĨĨŝĐŝĞŶƚƌŽŽŵƚŽĚƌŽƉƚŚĞůĂŶĚŝŶŐƌŝŶŐďĞůŽǁƚŚĞƉĂƚĐŚ ĂƌĞĂ͕ƚŚĞǀĞƌƚŝĐĂůĐƵƚŵĂǇďĞĐĂƌƌŝĞĚĂůůƚŚĞǁĂǇƵƉĂŶĚƚŚƌŽƵŐŚƚŚĞůĂŶĚŝŶŐƌŝŶŐ͘ ϭϮ͘ ŚŝƉĂǁĂǇĞǆĐĞƐƐĐĞŵĞŶƚĨƌŽŵƚŚĞƐƵƌĨĂĐĞĐĂƐŝŶŐ͘ƵĨĨĂŶĚƉƌĞƉĂƌĞƚŚĞƐƵƌĨĂĐĞĐĂƐŝŶŐĨŽƌŝŶƐƉĞĐƚŝŽŶ ĂŶĚǁĞůĚŝŶŐ͘ ϭϯ͘ hdŝŶƐƉĞĐƚŝŽŶŽĨƚŚĞĞǆƉŽƐĞĚƐƵƌĨĂĐĞĐĂƐŝŶŐ͘ Ă͘ /ŶƐƉĞĐƚĨŽƌĂŶǇĂĚĚŝƚŝŽŶĂůŚŽůĞƐďĞůŽǁƚŚĞůĂŶĚŝŶŐƌŝŶŐ͘ ď͘ ^ůĞĞǀĞ ďĂŶĚŝŶŐ ůŽĐĂƚŝŽŶƐƚŽďĞŝĚĞŶƚŝĨŝĞĚ͕ŵĂƌŬĞĚĂŶĚhd͛ĚŽŶĂŐƌŝĚĨŽƌŶŽŵŝŶĂůǁĂůů ƚŚŝĐŬŶĞƐƐǀĞƌŝĨŝĐĂƚŝŽŶ͘ Đ͘ EŽƚŝĨǇK'ŝŶƐƉĞĐƚŽƌĨŽƌŽƉƉŽƌƚƵŶŝƚǇƚŽŝŶƐƉĞĐƚĂŶĚĚŽĐƵŵĞŶƚǁŝƚŚƉŚŽƚŽƐĂƐƉĂƌƚŽĨƚŚĞ ϭϬͲϰϬϰ͘ ϭϰ͘ tĞůĚĐĂƐŝŶŐƐůĞĞǀĞ͘EŽƚŝĨǇK'ŝŶƐƉĞĐƚŽƌĨŽƌŽƉƉŽƌƚƵŶŝƚǇƚŽŝŶƐƉĞĐƚĂŶĚĚŽĐƵŵĞŶƚĂůůƐƚĞƉƐŽĨ ƚŚĞďĞůŽǁǁĞůĚŝŶŐŽƉĞƌĂƚŝŽŶ͘ Ă͘ ůĞĂŶĂƌĞĂƚŽƌĞĐĞŝǀĞĐĂƐŝŶŐƉĂƚĐŚǁĞůĚƚŽƐƵƌĨĂĐĞĐĂƐŝŶŐ͘ ď͘ ƌǇĨŝƚĐĂƐŝŶŐ ƐůĞĞǀĞĂŶĚďĂŶĚŝŶŐ ƚŽĞŶƐƵƌĞĐŽŵƉĂƚŝďŝůŝƚǇ ĂŶĚƉŽ ƐŝƚŝŽŶŝŶŐ͘dŚĞƐůĞĞǀĞǁŝůůďĞ ǁĞůĚĞĚƚŽĂďĂŶĚĂƚƚŚĞďŽƚƚŽŵ ĂŶĚ ůĂŶĚŝŶŐƌŝŶŐŽŶƚŽƉ͘ Đ͘ ůĞĞĚKƉƌĞƐƐƵƌĞƚŽϬƉƐŝ͘ Ě͘ sĞƌŝĨǇĂŝƌŵŽǀĞƌƐͬǀĞŶƚŝůĂƚŝŽŶĂŶĚĞƐƚĂďůŝƐŚĂ ĨŝƌĞǁĂƚĐŚ͘DŽŶŝƚŽƌ>>͛Ɛ͕KϮĂŶĚK͘ Ğ͘ /ŶƐƚĂůůƐůĞĞǀĞŝŶĂĐĐŽƌĚĂŶĐĞǁŝƚŚƐůĞĞǀĞĚĞƐŝŐŶĂŶĚǁĞůĚƉĂĐŬĂŐĞ͕ĐŽŶƚŝŶƵŽƵƐůǇŵŽŶŝƚŽƌŝŶŐ ǁĞůĚƚĞŵƉĞƌĂƚƵƌĞƐ͘ ŝ͘ DĞůƚŝŶŐƐƚŝĐŬƐĂƌĞŶŽƚƉĞƌŵŝƚƚĞĚ͘ Ĩ͘ EǁĞůĚ͘ Ő͘ WŚŽƚŽŐƌĂƉŚǁĞůĚĂƐƉĂƌƚŽĨϭϬͲϰϬϰƌĞƋƵŝƌĞŵĞŶƚƐ͘ ϭϱ͘ ZĞͲŝŶƐƚĂůůĐŽŶĚƵĐƚŽƌ ŽŶƚŽ ƚŚĞƚŽƉŽĨƚŚĞ ĞǆŝƐƚŝŶŐĐŽŶĚƵĐƚŽƌ ŝŶƚ ŚĞŐƌŽƵŶĚ͘ Ă͘ ĞŵĞŶƚƐƵƌĨĂĐĞĐĂƐŝŶŐďǇĐŽŶĚƵĐƚŽƌĂŶŶƵůƵƐ͘ ϭϲ͘ WƵůůƐŚŽƌŝŶŐǁŚŝůĞďĂĐŬĨŝůůŝŶŐĂƌŽƵŶĚƚŚĞĐŽŶĚƵĐƚŽƌ ĂŶĚƌĞͲŝŶƐƚĂůůĐĞůůĂƌĨůŽŽƌ͘ ϭϳ͘ ZŝŐĚŽǁŶƚŚĞtĞůůŚĞĂĚ^ƵƉƉŽƌƚ^ƚƌƵĐƚƵƌĞ͘ ϭϴ͘ EŝƉƉůĞƵƉƚŚĞ ƉƌŽĚƵĐƚŝŽŶƚƌĞĞĂŶĚƉƌĞƐƐƵƌĞƚĞƐƚĂƐƌĞƋƵŝƌĞĚ͘ ϭϵ͘ /ŶƐƚĂůůǁĞůůƐŚĞůƚĞƌ͕ ŝŶƐƚƌƵŵĞŶƚĂƚŝŽŶ͕ ĂŶĚĨůŽǁůŝŶĞ͘ ϮϬ͘ WƵůůWsͬdt͘ ^ůŝĐŬůŝŶĞ ϭ͘ WƵůůƉůƵŐĨƌŽŵϭϮ͕Ϯϲϯ͛ D͘ KƉĞƌĂƚŝŽŶƐ ϭ͘ WKW ǁĞůůhŶĚĞƌǀĂůƵĂƚŝŽŶ ĂŶĚƉĞƌĨŽƌŵĂŶĐĞŵŽŶŝƚŽƌƌĞƉĂŝƌ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ ^ĐŚĞŵĂƚŝĐ ^ǆĐĂǀĂƚŝŽŶĂŶĚZĞƉĂŝƌ EϯͲϭϭ Wd͗ϭϴϴϬϴϳ tĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ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y Meredith Guhl at 11:47 am, Apr 29, 2022 'LJLWDOO\VLJQHGE\7RULQ 5RVFKLQJHU '1FQ 7RULQ5RVFKLQJHU RX 8VHUV 'DWH 7RULQ5RVFKLQJHU ; 0*5$35'/%'65 GWV -/& Jeremy M. Price Digitally signed by Jeremy M. Price Date: 2022.05.02 11:26:25 -08'00' RBDMS SJC 050422 KtĞůůŽĐŬ^ƋƵĞĞǌĞ EϯͲϭϭ Wd͗ϭϴϴϬϴϳ tĞůůEĂŵĞ͗EϯͲϭϭKtĞůůŽĐŬ^YW/EƵŵďĞƌ͗ ϱϬͲϬϮϵͲϮϭϴϰϴͲϬϬͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗^ŚƵƚ/Ŷ ZŝŐ͗ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ϰͬϯϬͬϮϬϮϮ ƐƚŝŵĂƚĞĚƵƌĂƚŝŽŶ ϮĚĂǇƐ WƌŽŐƌĂŵĂƚĞ ϰͬϮϳͬϮϬϮϮ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϴϴϬϴϳ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ĂƌĐŝ,ŽƌŶĞƌ ;ϵϬϳͿ ϳϳϳͲϴϰϬϲ;KͿ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗:ĞƌŝŵŝĂŚ'ĂůůŽǁĂǇ ;ϵϬϳͿ ϱϲϰͲϱϬϬϱ;KͿ ;ϴϮϴͿ ϱϱϯͲϮϱϯϳ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗:ŽůĞĞŶKƐŚŝƌŽ ;ϵϬϳͿ ϳϳϳͲϴϰϴϲ;KͿ ;ϲϱϬͿ ϰϴϯͲϰϳϳϰ;DͿ ǆƉĞĐƚĞĚZĂƚĞƐ ϱϯϭKW͕ϭϬtWĂŶĚϮϱŵŵƐĐĨĚ;ϯϬĂǇ/KZʹϭϴϬͿ &XUUHQW%RWWRP+ROH3UHVVXUHSVL#¶79'.:)aSSJ %DVHGRQ6%+36LQQHDUE\DQDORJXHZHOO$ 0D[$QWLFLSDWHG6XUIDFH3UHVVXUHSVL %DVHGRQSVLIWJDVJUDGLHQW /DVWUHFRUGHGVKXWLQ:+3SVLRQ 6OLFNOLQHGULIWDQGWDJ7,2 ƌŝĞĨtĞůů^ƵŵŵĂƌǇ͗ EϯͲϭϭŝƐĂĂƌƚŝĨŝĐŝĂůůŝĨƚƉƌŽĚƵĐĞƌƚŚĂƚǁĂƐƌĞĐĞŶƚůǇǁŽƌŬĞĚŽǀĞƌ͘/ŶϮϬϬϲƚŚĞϵͲϱͬϴĐĂƐŝŶŐǁĂƐƉƵŶĐŚĞĚ͕ĂŶĚ ƚŚĞKĐĞŵĞŶƚĞĚŝŶĂŶĞĨĨŽƌƚƚŽƌĞƉĂŝƌĂƐƵƌĨĂĐĞĐĂƐŝŶŐůĞĂŬ͘ƵƌŝŶŐĂŶĚĂĨƚĞƌƚŚĞǁŽƌŬŽǀĞƌĂD/dͲdǆ/ĂŶĚ D/dͲ/ďŽƚŚƉĂƐƐĞĚǁŝƚŚĨůƵŝĚ͘KŶĐĞƚŚĞǁĞůůǁĂƐďƌŽƵŐŚƚŽŶůŝŶĞ͕ƚŚĞƐƵƌĨĂĐĞĐĂƐŝŶŐůĞĂŬĂƉƉĞĂƌĞĚƚŽďĞ ƌĞĂĐƚŝǀĂƚĞĚ͘ ƵƌƌĞŶƚůǇ͕ƚŚĞǁĞůůŝƐƐĞĐƵƌĞĚǁŝƚŚĂƉůƵŐĂŶĚĂD/dͲdǆ/ƉĂƐƐĞĚƚŽϮϱϬϬƉƐŝ͘ KďũĞĐƚŝǀĞ͗^ƋƵĞĞǌĞKǁŝƚŚtĞůů>ŽĐŬ;ŽƌƐŝŵŝůĂƌͿƚŽƌĞƉĂŝƌƐƵƌĨĂĐĞĐĂƐŝŶŐůĞĂŬ͘ KƉĞƌĂƚŝŽŶƐ ϭ͘ EŝƉƉůĞĚŽǁŶKŐĂƚĞǀĂůǀĞ͕ŶŝƉƉůĞƵƉK/ŶƚĞŐƌĂů͘/ĨƉŽƐƐŝďůĞ͕ƌŝŐƵƉŝŶƚĞŐƌĂůƐŽŶďŽƚŚƐŝĚĞƐŽĨƚŚĞ ǁĞůůŚĞĂĚ͘ Ϯ͘ tĞůů>ŽĐŬKƐƋƵĞĞǌĞƚŽϮϱϬϬƉƐŝĨŽƌĂƚůĞĂƐƚϲŚŽƵƌƐƉĞƌZWƐ͘hƐĞ>ĂĐĐƵŵƵůĂƚŽƌƚŽŚŽůĚƐƋƵĞĞǌĞ ƉƌĞƐƐƵƌĞĂĨƚĞƌZDK͘ ϯ͘ ĨƚĞƌtĞůů>ŽĐŬƐĂŵƉůĞŝƐƐĞƚƵƉ͕WKWĂŶĚŵŽŶŝƚŽƌKĨŽƌƌĞͲƉƌĞƐƐƵƌŝǌĂƚŝŽŶ͘ ϰ͘ EK/ŶƚĞŐƌĂůƐ͕EhK'ĂƚĞsĂůǀĞƐ͘ ϱ͘ ZĞͲƐƋƵĞĞǌĞKǁŝƚŚtĞůů>ŽĐŬŝĨŶĞĐĞƐƐĂƌǇ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ KtĞůůŽĐŬ^ƋƵĞĞǌĞ EϯͲϭϭ Wd͗ϭϴϴϬϴϳ tĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv ________ Comm ________DUCK IS UNIT SDI 3-11 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 Annular failed closing time. New HYD. Fittings , wrap lines for heat better. Passed re-test. Annular-29sec. Rams-5.5sec. HCR- 1sec. Test Results TEST DATA Rig Rep:Haberthur/BesheaOperator:Hilcorp Alaska, LLC Operator Rep:Dambacher/Menapace Contractor/Rig No.:Hilcorp ASR 1 PTD#:1880870 DATE:2/11/2022 Type Operation:WRKOV Annular: 250/3500Type Test:WKLY Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopAGE220213183104 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 9 MASP: 3100 Sundry No: 321-589 Location Gen.:P Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec.P Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8"P #1 Rams 1 2 7/8 X 5 P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16 P HCR Valves 1 2 1/16 P Kill Line Valves 3 2 1/16 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3050 Pressure After Closure P1550 200 PSI Attained P22 Full Pressure Attained P91 Blind Switch Covers:PAll Stations Nitgn. Bottles (avg):P4 @2175 ACC Misc FP1 NA NATrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA 9 9 9 9 9 9 9 -%5 7HVWFKDUWVDWWDFKHGMEU Annular failed closing time. Passed re-test. Annular-29sec. ACC Misc FP 2/11/2022 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Some people who received this message don't often get email from joleen.oshiro@hilcorp.com. Learn why this is important From:Brooks, Phoebe L (OGC) To:Joleen Oshiro Cc:Regg, James B (OGC) Subject:RE: Sundry 321-589: Endicott Well 3-11 (PTD 188-087) Date:Tuesday, March 1, 2022 12:13:15 PM Attachments:MIT END 3-11 02-15-22 Revised.xlsx Joleen, Attached is a revised report changing the interval to “O”, PTD # format to reflect 1880870 (inspections include a trailing zero with the dash removed), and moving the waived information to the remarks (the AOGCC Rep should include an inspector’s name only if witnessed). Please update your copy. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Joleen Oshiro <Joleen.Oshiro@hilcorp.com> Sent: Tuesday, February 15, 2022 4:23 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: Sundry 321-589: Endicott Well 3-11 (PTD 188-087) All, Please see the attached documentation for the MIT-IA post packer set on Endicott well 3-11 per sundry 321-589 (PTD 188-087). Let me know if there are any questions. Cheers, - 5HJJ 9 (PTD 188-087) revised report Joleen Oshiro Alaska Islands Team Ops Engineer 650-483-4774 joleen.oshiro@hilcorp.com Sent from Yahoo Mail on Android The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Submit to: OOPERATOR: FIEL D / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1880870 Type Inj N Tubing 1650 1650 1650 1650 Type Test P Packer TVD 9,479'BBL Pump 8.0 IA 800 2700 2675 2650 Interval O Test psi 2500 BBL Return 8.0 OA 0 0 0 0 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj N Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec han i c al In t eg r i t y Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Hilcorp Alaska, LLC Endicott, SDI, END 3-11 Steve Dambacher 02/15/22 Notes:MIT-IA post production packer set during ASR workover. Required per sundry 321-589. Waived by A.Earl / G.Cook Notes: Notes: Notes: END 3-11 Form 10-426 (Revised 01/2017)MIT END 3-11 02-15-22 Revised 9 9 9 9 5(9,6(' 9 -5HJJ 02/15/22 MIT-IA post production packer set 5(9,6(' MIT Chart - DIU 3-11 (PTD 1880870) Sundry 321-589 2/15/2022 5HJJ-DPHV%2*& )URP-DPHV/RWW&MORWW#KLOFRUSFRP! 6HQW6XQGD\)HEUXDU\30 7R5HJJ-DPHV%2*&'2$$2*&&3UXGKRH%D\%URRNV3KRHEH/2*&'2$$2*&&3UXGKRH%D\ &F0RQW\0\HUV-RVHSK(QJHO2OLYHU$PHQG& 6XEMHFW+LOFRUS,QQRYDWLRQ5LJ%23(8VH5HSRUW )ROORZ8S)ODJ)ROORZXS )ODJ6WDWXV&RPSOHWHG ůů͕ ĞůŽǁĂƌĞƚŚĞĚĞƚĂŝůƐĨŽƌKWhƐĞ ĂƚĞ͕dŝŵĞŽĨKWhƐĞ͗ ϬϮͬϮϬͬϮϬϮϮ͕Ϭϯ͗ϬϬŚƌƐ tĞůůͬ>ŽĐĂƚŝŽŶͬWdEƵŵďĞƌ͗ WhsͲϮϭϯ͕sͲWĂĚ͕WdϮϮϮͲϬϬϭ ZŝŐEĂŵĞ͗ /ŶŶŽǀĂƚŝŽŶ KƉĞƌĂƚŽƌŽŶƚĂĐƚ͗ :ĂŵĞƐ>Žƚƚ͕ϵϬϳͲϲϳϬͲϯϬϵϰ͕ũůŽƚƚΛŚŝůĐŽƌƉ͘ĐŽŵ >ĂƐƚKWdĞƐƚ͗ϬϮͬϭϮͬϮϮ;ŝŶŝƚŝĂůĨƵůůdĞƐƚͿ;ϬϮͬϭϳͬϮϮdĞƐƚĞĚŶŶƵůĂƌ͕,ZŚŽŬĞ͕,Z<ŝůů͕d/t͕Θ^ƵƉĞƌŚŽŬĞĂĨƚĞƌ tĞůůŽŶƚƌŽůhƐĞͿ KƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ͗ ĨƚĞƌƌŝůůŝŶŐƚŽdŽŶsͲϮϭϯ͕ƉƵŵƉĞĚ^ǁĞĞƉ^ƵƌĨĂĐĞƚŽ^ƵƌĨĂĐĞ͘DĂǆŐĂƐŽŶĐŝƌĐƵůĂƚŝŽŶϴϯƵŶŝƚƐ͘ DŽŶŝƚŽƌǁĞůůŶŽĨůŽǁĂƚƉŽƐƐƵŵĞůůǇ͕^ŚƵƚŝŶDĂŶĂŐĞWƌĞƐƐƵƌĞƌŝůůŝŶŐŚŽŬĞƐĨŽƌϭϬŵŝŶǌĞƌŽWƌĞƐƐďƵŝůĚ͘ ĂĐŬƌĞĂŵŽƵƚŽĨŚŽůĞƚŽŝŶƐŝĚĞĐĂƐŝŶŐtŝŶĚŽǁ͘ dĂƐŝŶŐtŝŶĚŽǁŝƌĐƵůĂƚĞŽƚƚŽŵƐƵƉǆϮ͘ϱ͘DŽŶŝƚŽƌǁĞůůĂƚƚƌŝƉŶŝƉƉůĞ͘tĞůůƐƚĂƚŝĐ͘ WƵŵƉŽƵƚŽĨĐĂƐĞĚŚŽůĞĨͬϯϰϱϬ͛ƚŽϭϯϵϬ͛͘WKK,ŽŶĞůĞǀĂƚŽƌƐƚŽϱϭϬ͛͘ KďƐĞƌǀĞĚϭďďůŐĂŝŶŽŶƉŝƉĞĚŝƐƉůĂĐĞŵĞŶƚ͘DŽŶŝƚŽƌǁĞůůĨŽƌϮϬŵŝŶƐĞĞŝŶŐƐƵƌĨĂĐĞŐĂƐďƌĞĂŬŝŶŐŽƵƚ͘ ^ŚƵƚŝŶǁĞůůĂƚϬϮ͗ϱϴŝŶŝƚŝĂů^/WϮϬƉƐŝƵŝůƚƵƉƚŽϭϵϴƉƐŝ͘ŝƌĐƚŚƌŽƵŐŚĐŚŽŬĞĂŶĚƉŽŽƌďŽǇƚŽĐŝƌĐŽƵƚŐĂƐĐĂƉ͘ ^ŚƵƚĚŽǁŶĂŶĚƐŚƵƚŝŶ͘^/WϮϲϭƉƐŝĂŶĚƌŝƐŝŶŐƚŽŵĂǆϱϴϬƉƐŝ͘ WƌĞƉĂŶĚ^ƚƌŝƉŝŶŚŽůĞĨƌŽŵϱϭϬ͛ƚŽĐĂƐŝŶŐǁŝŶĚŽǁΛϯϰϵϭ͛͘ ŝƌĐƵůĂƚĞ^d^ϯWD͕ŚŽůĚŝŶŐϭϴϬͲϮϬϬW^/ĂĐŬWƌĞƐƐƵƌĞ͘'ĂƐĚŽǁŶĨƌŽŵϳϬϬƵŶŝƚƐƚŽϭϬϲƵŶŝƚƐ͘ŝƌĐƵůĂƚĞĚŽƚƚŽŵƐhƉ ǆϱ͘^ŚƵƚĚŽǁŶ͕ďůĞĞĚĐĂƐŝŶŐƚŽǌĞƌŽ͕ƐŚƵƚŝŶĂŶĚƐĞĞƉƐŝďƵŝůĚĂŶĚůĞǀĞůŽĨĨΛϭϬϴW^/ŝŶϭϬŵŝŶƵƚĞƐ͘>ŽƐƚϭϰďďůƐĚƵƌŝŶŐ ĐŝƌĐƵůĂƚŝŽŶ͘ ƵƌƌĞŶƚůǇǁĞĂƌĞĂƚƚŚĞdŽƉKĨƚŚĞtŝŶĚŽǁǁĞŝŐŚƚŝŶŐƵƉDƵĚƐǇƐƚĞŵ͘ ĐƚŝŽŶdĂŬĞŶƚŽďĞdĂŬĞŶ͗ tĞǁŝůůƚĞƐƚƚŚĞŶŶƵůĂƌ͕ŚŽŬĞ,Z͕<ŝůů,Z͕d/t͕ĂƌƚǀĂůǀĞ͕^ƵƉĞƌŚŽŬĞƚŽϮϱϬͬϯϬϬϬƉƐŝǁŚĞŶǁĞŐĞƚŽƵƚŽĨƚŚĞ ŚŽůĞ͘ &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH 9 9 9 9 9 9 3%89$37' -5HJJ 3%89$37' tĞǁŝůůƉƌŽǀŝĚĞĐŚĂƌƚƐǁŝƚŚZĞƉŽƌƚ͘ :ĂŵĞƐ>Žƚƚ ,/>KZWƌŝůůŝŶŐ&ŽƌĞŵĂŶ ,/>KZW/EEKsd/KEZŝŐ Wh͕EŽƌƚŚ^ůŽƉĞůĂƐŬĂ ϵϬϳͲϲϳϬͲϯϬϵϰ;KĨĨŝĐĞͿ ϵϬϳͲϯϵϴͲϵϬϲϵ;ĞůůͿ ,ĂƌŵŽŶǇϭϬϬϲ ũůŽƚƚΛŚŝůĐŽƌƉ͘ĐŽŵ ũĂŵĞƐůŽƚƚϯϱϮΛǇĂŚŽŽ͘ĐŽŵ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ubmit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1880870 Type Inj N Tubing 800 1250 1250 1250 Type Test P Packer TVD 9,475'BBL Pump 6.8 IA 363 2749 2721 2699 Interval O Test psi 2500 BBL Return2.2OA0000 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj W Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Hilcorp Alaska, LLC END / DIU / SDI Jess Hall / John Houser 02/18/22 Notes:MIT-IA to 2500 post rig work as per Sundry 321-589. Austin McLeod waived his right to witness. Notes: Notes: Notes: 3-11 Form 10-426 (Revised 01/2017)END 3-11 MIT-IA 2-18-2022 post rig Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 188-087 Type Inj N Tubing 1650 1650 1650 1650 Type Test P Packer TVD 9,479'BBL Pump 8.0 IA 800 2700 2675 2650 Interval I Test psi 2500 BBL Return8.0OA0000 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj N Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: Hilcorp Alaska, LLC Endicott, SDI, END 3-11 Waived by A.Earl / G.Cook Steve Dambacher 02/15/22 Notes:MIT-IA post production packer set during ASR workover. Required per sundry 321-589 Notes: Notes: Notes: END 3-11 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Form 10-426 (Revised 01/2017)END 3-11 MIT-IA post production packer set_15 Feb 2022 From:Rixse, Melvin G (OGC) To:Joleen Oshiro Cc:AOGCC Records (CED sponsored) Subject:20220214 1623 PTD188-087 APPROVED Changes Sundry 321-589: Endicott Well 3-11 Date:Monday, February 14, 2022 4:24:15 PM Attachments:END 3-11 AOGCC 10-403 Nov 2021 APPROVAL.pdf Joleen, Your changes to Approved Sundry 321-589 as described below are approved. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. AOGCC Records From: Joleen Oshiro <Joleen.Oshiro@hilcorp.com> Sent: Monday, February 14, 2022 3:35 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Sundry 321-589: Endicott Well 3-11 (PTD 188-087) Hi Mel, Hilcorp proposes the following updates to sundry 321-589 for Endicott well 3-11 (PTD 188-087). Please let me know if you have any objections to the proposed changes or if I can provide any further information. Post Rig Service Coil and Portable Test Separator procedure: Step #4—Use 1% KCl or 8.6 ppg NaCl as working fluid with gel sweeps for milling and fill clean out Post Rig Eline procedure: Step #3—perforating range pending review of pulsed neutron log: 12,700’ – 12,954’ MD Cheers, Joleen Oshiro Alaska Islands Team Ops Engineer 650-483-4774 joleen.oshiro@hilcorp.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20220205 1540 PTD188-087 MIT-IA APPROVED END3-11__9-5/8"casing test 2500psi/30min. Date:Monday, February 7, 2022 8:47:22 AM From: Rixse, Melvin G (OGC) Sent: Saturday, February 5, 2022 3:40 PM To: Steve Dambacher - (C) <Steve.Dambacher@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Joleen Oshiro <Joleen.Oshiro@hilcorp.com>; Sam Menapace - (C) <Sam.Menapace@hilcorp.com> Subject: RE: END3-11__9-5/8"casing test 2500psi/30min. Steve, Hilcorp is approved to proceed. Approved passing MIT on 9-5/8” casing Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Steve Dambacher - (C) <Steve.Dambacher@hilcorp.com> Sent: Saturday, February 5, 2022 1:12 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Joleen Oshiro <Joleen.Oshiro@hilcorp.com>; Sam Menapace - (C) <Sam.Menapace@hilcorp.com> Subject: END3-11__9-5/8"casing test 2500psi/30min. Please reply… Steve Dambacher Hilcorp DSM, ASR #1 Office: 907-685-1266 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Tuesday, February 1, 2022 12:28 PM To: Joleen Oshiro <Joleen.Oshiro@hilcorp.com> Subject: [EXTERNAL] 20220201 1132 (PTD 188-087) APPROVAL REVISION 1Sundry 321-589: Endicott Well 3-11 Joleen, Sundry revision (attached) is approved by AOGCC. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Joleen Oshiro <Joleen.Oshiro@hilcorp.com> Sent: Monday, January 31, 2022 5:34 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Sundry 321-589: Endicott Well 3-11 (PTD 188-087) Hi Mel, Upon further review of our Endicott well 3-11 rig workover and post-rig procedure (sundry 321-589, attached), we are proposing the following updates to the program: Step #10 in Rig Procedure: Use seawater (8.54 ppg) with gel sweeps. Update the “Estimated KWF” noted in objective #1 to 8.54 ppg Step #14 in Rig Procedure: Propose not rigging up slickline to do junk basket run. We are electing to run a junk basket on the rig instead. Freeze Protect in Rig Procedure: Freeze protect post-rig with the tree on. Eline Post-Rig: Propose performing a pulsed neutron log in sigma and c/o modes prior to perforating. Depending on log results, perforations may be re-perforations or add perforations. Please let me know if you have any objections to the proposed updates or if I can provide further information. Cheers, Joleen Oshiro Alaska Islands Team Ops Engineer 650-483-4774 joleen.oshiro@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Sundry 321-589: Endicott Well 3-11 (PTD 188-087) Date:Monday, February 14, 2022 8:45:57 AM No concerns. Approved. Mel Rixse On Feb 12, 2022, at 7:28 AM, Joleen Oshiro <Joleen.Oshiro@hilcorp.com> wrote: Hi Mel, We are proposing to run 6 GLMs for Endicott 3-11’s completion rather than the 4 GLMs noted in the approved sundry. Please let me know if you have any qualms with this or need more information from my end. Cheers, Joleen Oshiro Alaska Islands Team Ops Engineer 650-483-4774 joleen.oshiro@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received thismessage in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 2022-0202_BOP_Hilcorp_ASR1_issues_DIU_3-11_mh.docx Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg DATE:2/4/2022 P. I. Supervisor FROM:Matt Herrera SUBJECT:BOPE Test – Hilcorp ASR1 Petroleum Inspector DIU SDI 3-11 Hilcorp Alaska LLC PTD 1880870; Sundry 321-589 2/2/2022:I traveled to Hilcorp’s Endicott facility for BOPE testing on Hilcorp Rig ASR1 and met up with Company Men Steve Dambacher and Sam Menapace. We went over the Sundry approval and they explained what Hilcorp was intending to do to well SDI 3-11. They expressed major concerns about the limitations of ASR1 and what they were expected to do by Hilcorp Management. To say the rig is going to be pushed beyond its limitations is an understatement. ASR1 was assigned to do this well solely on the basis of saving money to avoid an expensive rig move for the Innovation Rig which is set up to perform this type of workover. It is my belief they, Hilcorp Management, are going to regret this decision. Ambient temperature was right at - 40 degrees F, and ASR1 is not a cold weather rig. The tubing hanger (13-5/8”) required them to change out their normal 11-inch BOP stack with a rented Yellow Jacket Oilfield Equipment BOP Stack – a Cameron BOP stack would not fit. This raised my level of concern because there have been numerous past occasions of Yellow Jacket stacks having persistent failures on the annular preventer and rams. After lining up the BOPE, Hilcorp attempted multiple times to get a shell test at 3500 psi using the annular preventer. It consistently failed to hold pressure, so they pressured up against the blinds to rule out the 2- way check as the leak point. The 2-way check held but was not attempted to 5000 psi (test pressure required for the replacement BOPE stack). Company Man Sam Menapace contacted the Yellow Jacket Rep to request a new sealing element for the annular only to be told one was not available. Upon calling back, the Yellow Jacket representative stated he had a “used” element and could order a new one but was not sure of the delivery date. This was after approximately 8 hours attempting to get a positive test at various accumulator pressures and with 2 test joint sizes. The Company Man and I agreed it would be best to regroup. Hilcorp will get the necessary equipment to proceed and will resubmit for test witness when ready. Testing the gas alarm system was a challenge. ASR 1 relies on Operations Electricians from Milne Point to monitor, calibrate, and repair gas alarms (most rigs have dedicated electricians tied the rig). I am not sure if it’s a communication issue or some other reason, but they need to get on the same page. Overall, the test attempt this date was bust – challenging weather and unreliable equipment Attachments: none 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.02.07 15:43:29 -09'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSub m i t t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:ASR 1 DATE: 2/3/22 Rig Rep.: Rig Phone: 907-685-1266 Operator: Op. Phone:907-685-1266 Rep.: E-Mail Well Name:PTD #11880870 Sundry #321-589 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250-5000 Annular:250-3500 Valves:250-3500 MASP:3100 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1P Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 13 5/8" 5M P Pit Level Indicators PP #1 Rams 1 2 7/8"x5"FP Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 2-1/16 5M P Inside Reel valves 0NA HCR Valves 1 2-1/16 5M P Kill Line Valves 2 2-1/16 5M P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0NA Time/Pressure Test Result System Pressure (psi)3100 P CHOKE MANIFOLD:Pressure After Closure (psi)1700 P Quantity Test Result 200 psi Attained (sec)12 P No. Valves 16 P Full Pressure Attained (sec)110 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 4@2050 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:1 Test Time:6.0 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 2/1/2022 08:30 Waived By Test Start Date/Time:2/3/2022 13:00 (date) (time)Witness Test Finish Date/Time:2/3/2022 19:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Hilcorp Leak on mud cross flange, tightened flange and retest - passed Replaced annular element after unsuccessful intial BOPE test attempt, re-notify AOGCC of Pressure test S. Dambacher / S. Menapace Hilcorp AK M. Beshea / Dusty Shultz DIU SDI 3-11 Test Pressure (psi): steve.dambacher@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0203_BOP_Hilcorp_ASR1_DIU_3-11 9 9 9 9 9 9 -%5 9 9 9 2022-0203_BOP_Hilcorp_ASR1_DIU_3-11 Page 1 of 2 BOPE Test Charts – Hilcorp ASR1 DIU SDI 3-11 (PTD 1880870) 2/3/2022 -%5 2022-0203_BOP_Hilcorp_ASR1_DIU_3-11 Page 2 of 2 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Joleen Oshiro Subject:RE: [EXTERNAL] RE: Sundry 321-589: Endicott Well 3-11 (PTD 188-087) Date:Tuesday, February 1, 2022 3:54:00 PM Joleen, You have approval to proceed with your proposed changes as outlined below. Regards Bryan Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Joleen Oshiro <Joleen.Oshiro@hilcorp.com> Sent: Tuesday, February 1, 2022 2:43 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: Sundry 321-589: Endicott Well 3-11 (PTD 188-087) Hi Bryan, The range of perf depths are 12,695’ MD – 12,947’ MD. Let me know if I can provide more info. Thanks! Cheers, Joleen Oshiro Alaska Islands Team Ops Engineer 650-483-4774 joleen.oshiro@hilcorp.com From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, February 1, 2022 11:48 AM To: Joleen Oshiro <Joleen.Oshiro@hilcorp.com> Subject: [EXTERNAL] RE: Sundry 321-589: Endicott Well 3-11 (PTD 188-087) CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Joleen, Can you provide the range of perf depths you are considering (pending log data) so we can approve perfs within that interval? Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Joleen Oshiro <Joleen.Oshiro@hilcorp.com> Sent: Tuesday, February 1, 2022 11:15 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: FW: Sundry 321-589: Endicott Well 3-11 (PTD 188-087) Hi Bryan, Please let me know if you need any further information to support the requested updates below. Cheers, Joleen From: Joleen Oshiro Sent: Monday, January 31, 2022 4:34 PM To: 'melvin.rixse@alaska.gov' <melvin.rixse@alaska.gov> Subject: Sundry 321-589: Endicott Well 3-11 (PTD 188-087) Hi Mel, Upon further review of our Endicott well 3-11 rig workover and post-rig procedure (sundry 321-589, attached), we are proposing the following updates to the program: Step #10 in Rig Procedure: Use seawater (8.54 ppg) with gel sweeps. Update the “Estimated KWF” noted in objective #1 to 8.54 ppg Step #14 in Rig Procedure: Propose not rigging up slickline to do junk basket run. We are electing to run a junk basket on the rig instead. Freeze Protect in Rig Procedure: Freeze protect post-rig with the tree on. Eline Post-Rig: Propose performing a pulsed neutron log in sigma and c/o modes prior to perforating. Depending on log results, perforations may be re-perforations or add perforations. Please let me know if you have any objections to the proposed updates or if I can provide further information. Cheers, Joleen Oshiro Alaska Islands Team Ops Engineer 650-483-4774 joleen.oshiro@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:Joleen.Oshiro@hilcorp.com Subject:20220201 1132 (PTD 188-087) APPROVAL REVISION 1Sundry 321-589: Endicott Well 3-11 Date:Tuesday, February 1, 2022 12:28:31 PM Attachments:END 3-11 AOGCC 10-403 Nov 2021 APPROVAL.pdf Joleen, Sundry revision (attached) is approved by AOGCC. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Joleen Oshiro <Joleen.Oshiro@hilcorp.com> Sent: Monday, January 31, 2022 5:34 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Sundry 321-589: Endicott Well 3-11 (PTD 188-087) Hi Mel, Upon further review of our Endicott well 3-11 rig workover and post-rig procedure (sundry 321-589, attached), we are proposing the following updates to the program: Step #10 in Rig Procedure: Use seawater (8.54 ppg) with gel sweeps. Update the “Estimated KWF” noted in objective #1 to 8.54 ppg Step #14 in Rig Procedure: Propose not rigging up slickline to do junk basket run. We are electing to run a junk basket on the rig instead. Freeze Protect in Rig Procedure: Freeze protect post-rig with the tree on. Eline Post-Rig: Propose performing a pulsed neutron log in sigma and c/o modes prior to perforating. Depending on log results, perforations may be re-perforations or add perforations. Please let me know if you have any objections to the proposed updates or if I can provide further information. Cheers, Joleen Oshiro Alaska Islands Team Ops Engineer 650-483-4774 joleen.oshiro@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Mill Plugs/Recomplete 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13,533'N/A Casing Collapse Structural Conductor N/A Surface 2,260psi Intermediate 4,760psi Production 5,090psi Liner 8,530psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng See Schematic 2,164' 7" See Schematic 1/4/2021 13,520'1,104' 4-1/2" 10,502' 9-5/8" x 5-1/2" TIW HBBP 12,356' MD / 9,581' TVD 11,220psi 10,537' 2,504' 12,701' Perforation Depth MD (ft): 10,537' 30" 13-3/8" 161' 8,305' 161' 2,504' 9,835'9-5/8" 9-5/8" Length Size 12.6# / 13Cr TVD Burst 12,500' 8,150psi MD 6,870psi N/A 5,020psi 161' 2,504' PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047502 188-087 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21848-00-00 Hilcorp Alaska LLC DUCK IS UNIT SDI 3-11 ENDICOTT / ENDICOTT OIL C.O. 462.007 Tubing Grade: 12.6# / 13Cr Tubing MD (ft): 1,093'Perforation Depth TVD (ft): Tubing Size: 4-1/2" 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Operations Manager Joleen Oshiro Joleen.Oshiro@hilcorp.com 907-777-8486 10,511' 12,605' 9,762' 3,100 1,220' & 12,954' ry Statu Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:53 am, Nov 16, 2021 321-589 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2021.11.16 09:42:26 -09'00' Torin Roschinger (4662) BOPE test to 3500 psi. Variance to 20AAC25.285(c)(2)(B)(i). Approved for 2 ram stack for cleanout and deployment of completion string pending AOGGC receipt of passing charted 30 minute MIT on 9-5/8 casing. SFD 11/16/2021 DSR-11/16/21 3,100 10-404 MGR23NOV2021dts 11/23/2021 11/24/21 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.11.24 07:29:44 -09'00' 3-11 Workover Well: 3-11 PTD: 188-087 API: 50-029-21848-00 Well Name:END 3-11 API Number: 50-029-21848-00 Current Status:Not Operable, SI Rig:NA Estimated Start Date:1/4/21 Estimated Duration:8 days Reg.Approval Req’std? Date Reg. Approval Rec’vd:N/A Regulatory Contact:Darci Horner 777-8406 Permit to Drill Number:188-087 First Call Engineer:Joleen Oshiro 650-483-4774 Second Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Current Bottom Hole Pressure:4,087 psi @ 10,000’ TVD (0.41 psi/ft kill weight fluid) Based on 1/2021 SBHPS in nearby analogue well, 3-23A Max. Anticipated Surface Pressure:3,100 psi (Based on 0.1 psi/ft. gas gradient) Last recorded shut in WHP:T/I/O pressures 0/0/0 (11/12/21) Brief Well Summary: Endicott well 3-11 is a long term shut in producer. It was last online in 2005 and was shut in for a surface casing leak. An OA cement job (6/2006) and conductor top job (8/2010) have mitigated the surface casing leak such that it is no longer an active integrity issue; the well passed a CMIT TxIA to 2500 psi on 11/8/21 (see below “Recent Intervention & Integrity History” for more details). Perforations have a sand plug and ~57’ cement cap over them (top perforation shot 12,700’ MD). Tubing was cut at 12,302’ and pulled; 4.5’’ kill string is in place. There is value in returning Endicott well 3-11 to production. In early 2020, crestal gas injection started at the Satellite Drilling Island (SDI) in well 4-26A, and 3-11 is situated in a prime bottomhole location to reap the benefits of this immiscible gas drive. The 4-26A gas injection has thus far uplifted nearby well 3-23A by ~130 bopd, and we have similar expectations for the response in well 3-11. Recent Intervention & Integrity History (from most recent to older) 11/8/21: Service coil milled hole through cement retainer and plug at 1180’ MD and 1220’ MD respectively. CMIT TxIA to 2500 passed with losses of T/IA= 40/45psi, 23/23psi and 17/17psi (final TIO= 2443/2551/17). RIH and tag TOC at 12,566’ CTMD. 11/3/21: MIT-OA to 1000 psi. OA pressure dropped to 0 psi in under 10 minutes. No visible fluids at surface. 11/13/16: MIT-OA to 500 psi passed with diesel, losses of 14 psi followed by 0 psi (starting TIO=150/480/550, ending TIO=150/480/528) 8/29/10: Cement top job on conductor 9/05/07: Passing MIT-OA with N2 to 500 psi following SC leak remediation. Losses of 30 psi followed by 10 psi (ending TIO= ssv/vac/0) 3/01/06: RWO: Circulate OA with brine then cement to surface through holes. Squeeze at 500 psi. Left killstring. 2/28/06: RWO: Set plug at 1220’. Shot 9-5/8” csg Punch from 1190’1197’. Set EZSV at 1180’. 2/27/06: RWO: Cut and pull tubing from 12302’ 2/18/06: Passing PPPOT-IC and PPPOT-T 2/16/06: Passing CMIT-TxIA against plug set at 12,314’ just above packer. 2/12/06 – 02/14/06: Coil set sand and cement plug across perfs. ~57 ft of cement cap on sand plug. Tag TOC at 12,605’ MD 3-11 Workover Well: 3-11 PTD: 188-087 API: 50-029-21848-00 ***VARIANCE REQUEST***: Requesting a variance to 20AAC25.285(c)(2)(B)(i). This regulation requires at least 4 preventers. Due to height restrictions, we can only RU 3 preventers on the ASR Rig for the 13-5/8” BOPE (rigid rig floor that is at a fixed height that would be exceeded if 4 preventers [3 Rams and 1 Annular] were installed). The 11/8/21 passing CMIT TxIA to 2500 psi demonstrates that the existing perforations are isolated, so the proposed rig operations will only be carried out in cased-hole. Objectives: 1) Mill out shallow 9-5/8’’ cement retainer and plug. Estimated KWF = 8.6 ppg NaCl 2) RIH 4.5’’ completion and set production packer 3) CT mill cement and fill clean out down to cement retainer at 12,954’ MD 4) Re-perforate upper K2B zone Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU crane. Set BPV. ND Tree. Inspect the lift threads on the tubing hanger. 4. NU 13-5/8” BOPE. RD Crane. Rig Procedure: Note: We would like to perform the state-witnessed MIT-IA on the rig; please reach out to state 24 hours in advance of MIT-IA 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines. 2. Check for pressure and if 0 psi pull BPV. 3. Set TWC. 4. Test BOPE to 250 psi Low/ 3,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. ¾Perform Test per ASR 1 BOP Test Procedure ¾Notify AOGCC 24 hours in advance of BOP test. ¾Confirm test pressures per the Sundry Conditions of approval. ¾Test VBR ram on 2-7/8” and 4-1/2” test joints. ¾Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 5. Check for pressure under the TWC. If any pressure is under the TWC, lubricate out the plug. Contact Operations Engineer if you have any pressure. 6. Use landing joint to PU tubing hanger. Contact OE if need to use spear. 7. Recover the tubing hanger. 8. Verify crossover for Safety valve to NSTC connection is on the floor for pulling the 4-1/2” TBG. Re-perforate upper K2B zone 3-11 Workover Well: 3-11 PTD: 188-087 API: 50-029-21848-00 9. Pull and lay down the 4.5’’ kill sting. 10. PU workstring and milling BHA. RIH and establish circulation with 8.6 ppg NaCl (KWF) up the tubing. Record circulation rates and pressures. 11. Mill out cement retainer at 1,180’ MD and HES Fast Drill plug at 1,220’ MD. Chase down to the top of the tubing stub at 12,302’ MD. Circulate bottoms up or until clean returns. POOH 12. CMIT TxIA to 2500 psi for 30 minutes. If fails, establish LLR and contact OE for way forward. ¾If CMIT TxIA to 2500 psi fails, likely way forward is to RIH with 9-5/8’’ test packer and set just above jet cut @ ~12,000’ MD; CMIT TxIA to 2500 psi. If fails again, contact OE; likely way forward is to RDMO ASR and continue diagnostics with slickline or eline. Note that we got a recent CMIT TxIA pass to 2500 psi on 11/8/21. 13. PU the work string and RIH with a 9-5/8” CSG scraper and dress off tool down to the top of jet cut at 12,302’ MD. Objectives are to clean up 9-5/8’’ casing for packer set and to dress off the jet cut in preparation for running the 4.5’’ tubing with overshot. 14. RU slickline. RIH with junk basket to TD. RDMO SL. Note: If we run into obstructions, we will likely make an additional run on the rig to clear obstructions prior to completion run. 15. Install completion as outlined below. Verify crossover for Safety valve to JFE Bear connection is on the floor for running the 4-1/2” completion. Send tally to engineer prior to Install. ¾TBG Over shot ¾1 full Joint 4-1/2” 12.6# 13 Cr80, JFE Bear TBG ¾4-1/2” 9 Cr XN-Profile (RHC Receiver Installed) ¾X# Joints 4-1/2” 12.6# 13 Cr80, JFE Bear TBG ¾9-5/8” x 4-1/2” TNT Packer (estimate set depth +/- 12,200’ MD) ¾X# Joints 4-1/2” 12.6# 13 Cr80, JFE Bear TBG ¾4-1/2” 9 Cr X-Profile ¾X# Joint 4-1/2” 12.6# 13 Cr80, JFE Bear TBG ¾4-1/2” GLM w/Dummy installed set at +/- 10,500’ MD ¾X# Joints 4-1/2” 12.6# 13 Cr80, JFE Bear TBG ¾4-1/2” GLM w/Dummy installed set at +/- 8,500’ MD ¾X# Joints 4-1/2” 12.6# 13 Cr80, JFE Bear TBG ¾4-1/2” GLM w/Dummy installed set at +/- 6,500’ MD ¾X# Joints 4-1/2” 12.6# 13 Cr80, JFE Bear TBG ¾4-1/2” GLM w/Dummy installed set at +/- 4,000’ MD ¾X# Joints 4-1/2” 12.6# 13 Cr80, JFE Bear TBG ¾4-1/2” SSSV and Control line set at +/- 1,400’ MD ¾X# Joints 4-1/2” 12.6# 13 Cr80, JFE Bear TBG ¾4-1/2” Tubing Hanger 16. Circulate and spot corrosion inhibited brine around the overshot and packers. Estimated volume from production packer to top GLM is 440 bbl. Volume may be adjusted based on final packer depths prior to setting the overshot over the TBG stub. Charted 30 minute MIT9-5/8" casing. Results to AOGCC. 3-11 Workover Well: 3-11 PTD: 188-087 API: 50-029-21848-00 17. Run completion in hole over the TBG stub, verify overshot indicators observed to ensure we have swallowed the 4-1/2” TBG cut. 18. Space out and land tubing hanger. RILDS. 19. Drop the ball and rod. Pressure up the TBG to the required pressure to set TNT Packer, est. 3,500 psi setting pressure. Confirm pressures with packer hand onsite. 20. State-witnessed MIT-IA to 2,500 psi (Chart for 30 min). Confirm packer set. If MIT-IA fails, establish LLR and contact OE. 21. Lay down landing joint. Record PU and SO weights on the tally and WellEZ. 22. Set BPV. 23. ND BOPE. 24. Pressure test the tubing hanger void to 500 psig low and 5,000 psi high. 25. Pressure test the tree to 500 psig Low and 5,000 psig High. 26. Pull BPV. 27. RD ASR #1 and all ancillary equipment. Post Rig Procedure: Slickline 1. RU SL unit and pressure test PCE to 250psi low 3,500 psi high. 2. RIH Pull the ball/rod and RHC. 3. Drift to TD with 3.7’’ centralizer. 4. Install live gas lift valves. Service Coil and Portable Test Separator Notes: x Expect ~57’ (2 bbl) cement cap and ~285’ (10.5 bbl) of sand to clean out. x We will need to put the well on gas lift to unload the IA. Please work with field operations to coordinate this. 1. MIRU Coiled Tubing Unit, portable test separator, and spot ancillary equipment. 2. Perform BOP test if one has not been completed in last 7 days. 3. MU motor and 3.7’’ mill with underreamer. RIH to TOC at ~12,566’ CTMD and flag pipe. 4. Establish circulation with 8.6 ppg NaCl up the tubing. Record circulation rates and pressures. 5. Mill through cement. 6. Fill clean out cement and sand(~285’) down to cement retainer at 12,954’ MD. Top shot of first open perforations is at 12,700’ MD; we expect to lose returns at this point. Eline 1. RU EL unit and pressure test to 250psi low 3,500 psi high. 2. RIH and obtain a GR/CCL correlation pass,Contact Joleen Oshiro at (650)-483-4774 to get final perf depths. Tie-in log= GR/CCL, 1993, Western Atlas 3. Perforate with 3-1/8’’ guns per final approved perf depths. 3-11 Workover Well: 3-11 PTD: 188-087 API: 50-029-21848-00 Gun Run # Perf Top Perf Bottom Perf Length 1 ±12,806’ MD ±12,816’ MD 10’ Total 10’ Table 1: END 3-11 Proposed Perf Gun Run Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. ASR BOP Stack 3-11 Workover Well: 3-11 PTD: 188-087 API: 50-029-21848-00 Attachment 1: Current WBS 3-11 Workover Well: 3-11 PTD: 188-087 API: 50-029-21848-00 Attachment 2: Proposed WBS 3-11 Workover Well: 3-11 PTD: 188-087 API: 50-029-21848-00 Attachment 3: ASR BOP Stack 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Mill Plugs/Recomplete 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 13,533'N/A Casing Collapse Structural Conductor N/A Surface 2,260psi Intermediate 4,760psi Production 5,090psi Liner 8,530psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE AOGCC Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng See Schematic 2,164' 7" See Schematic 1/4/2021 13,520'1,104' 4-1/2" 10,502' 9-5/8" x 5-1/2" TIW HBBP 12,356' MD / 9,581' TVD 11,220psi 10,537' 2,504' 12,701' Perforation Depth MD (ft): 10,537' 30" 13-3/8" 161' 8,305' 161' 2,504' 9,835'9-5/8" 9-5/8" Length Size 12.6# / 13Cr TVD Burst 12,500' 8,150psi MD 6,870psi N/A 5,020psi 161' 2,504' PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047502 188-087 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21848-00-00 Hilcorp Alaska LLC DUCK IS UNIT SDI 3-11 ENDICOTT / ENDICOTT OIL C.O. 462.007 Tubing Grade: 12.6# / 13Cr Tubing MD (ft): 1,093'Perforation Depth TVD (ft): Tubing Size: 4-1/2" 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Operations Manager Joleen Oshiro Joleen.Oshiro@hilcorp.com 907-777-8486 10,511' 12,605' 9,762' 3,100 1,220' & 12,954' ry Statu Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:53 am, Nov 16, 2021 321-589 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2021.11.16 09:42:26 -09'00' Torin Roschinger (4662) BOPE test to 3500 psi. Variance to 20AAC25.285(c)(2)(B)(i). Approved for 2 ram stack for cleanout and deployment of completion string pending AOGGC receipt of passing charted 30 minute MIT on 9-5/8 casing. SFD 11/16/2021 DSR-11/16/21 3,100 10-404 MGR23NOV2021dts 11/23/2021 11/24/21 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.11.24 07:29:44 -09'00' RBDMS HEW 11/24/2021 3-11 Workover Well: 3-11 PTD: 188-087 API: 50-029-21848-00 Well Name:END 3-11 API Number: 50-029-21848-00 Current Status:Not Operable, SI Rig:NA Estimated Start Date:1/4/21 Estimated Duration:8 days Reg.Approval Req’std? Date Reg. Approval Rec’vd:N/A Regulatory Contact:Darci Horner 777-8406 Permit to Drill Number:188-087 First Call Engineer:Joleen Oshiro 650-483-4774 Second Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Current Bottom Hole Pressure:4,087 psi @ 10,000’ TVD (0.41 psi/ft kill weight fluid) Based on 1/2021 SBHPS in nearby analogue well, 3-23A Max. Anticipated Surface Pressure:3,100 psi (Based on 0.1 psi/ft. gas gradient) Last recorded shut in WHP:T/I/O pressures 0/0/0 (11/12/21) Brief Well Summary: Endicott well 3-11 is a long term shut in producer. It was last online in 2005 and was shut in for a surface casing leak. An OA cement job (6/2006) and conductor top job (8/2010) have mitigated the surface casing leak such that it is no longer an active integrity issue; the well passed a CMIT TxIA to 2500 psi on 11/8/21 (see below “Recent Intervention & Integrity History” for more details). Perforations have a sand plug and ~57’ cement cap over them (top perforation shot 12,700’ MD). Tubing was cut at 12,302’ and pulled; 4.5’’ kill string is in place. There is value in returning Endicott well 3-11 to production. In early 2020, crestal gas injection started at the Satellite Drilling Island (SDI) in well 4-26A, and 3-11 is situated in a prime bottomhole location to reap the benefits of this immiscible gas drive. The 4-26A gas injection has thus far uplifted nearby well 3-23A by ~130 bopd, and we have similar expectations for the response in well 3-11. Recent Intervention & Integrity History (from most recent to older) 11/8/21: Service coil milled hole through cement retainer and plug at 1180’ MD and 1220’ MD respectively. CMIT TxIA to 2500 passed with losses of T/IA= 40/45psi, 23/23psi and 17/17psi (final TIO= 2443/2551/17). RIH and tag TOC at 12,566’ CTMD. 11/3/21: MIT-OA to 1000 psi. OA pressure dropped to 0 psi in under 10 minutes. No visible fluids at surface. 11/13/16: MIT-OA to 500 psi passed with diesel, losses of 14 psi followed by 0 psi (starting TIO=150/480/550, ending TIO=150/480/528) 8/29/10: Cement top job on conductor 9/05/07: Passing MIT-OA with N2 to 500 psi following SC leak remediation. Losses of 30 psi followed by 10 psi (ending TIO= ssv/vac/0) 3/01/06: RWO: Circulate OA with brine then cement to surface through holes. Squeeze at 500 psi. Left killstring. 2/28/06: RWO: Set plug at 1220’. Shot 9-5/8” csg Punch from 1190’1197’. Set EZSV at 1180’. 2/27/06: RWO: Cut and pull tubing from 12302’ 2/18/06: Passing PPPOT-IC and PPPOT-T 2/16/06: Passing CMIT-TxIA against plug set at 12,314’ just above packer. 2/12/06 – 02/14/06: Coil set sand and cement plug across perfs. ~57 ft of cement cap on sand plug. Tag TOC at 12,605’ MD 3-11 Workover Well: 3-11 PTD: 188-087 API: 50-029-21848-00 ***VARIANCE REQUEST***: Requesting a variance to 20AAC25.285(c)(2)(B)(i). This regulation requires at least 4 preventers. Due to height restrictions, we can only RU 3 preventers on the ASR Rig for the 13-5/8” BOPE (rigid rig floor that is at a fixed height that would be exceeded if 4 preventers [3 Rams and 1 Annular] were installed). The 11/8/21 passing CMIT TxIA to 2500 psi demonstrates that the existing perforations are isolated, so the proposed rig operations will only be carried out in cased-hole. Objectives: 1) Mill out shallow 9-5/8’’ cement retainer and plug. Estimated KWF = 8.6 ppg NaCl 2) RIH 4.5’’ completion and set production packer 3) CT mill cement and fill clean out down to cement retainer at 12,954’ MD 4) Re-perforate upper K2B zone Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU crane. Set BPV. ND Tree. Inspect the lift threads on the tubing hanger. 4. NU 13-5/8” BOPE. RD Crane. Rig Procedure: Note: We would like to perform the state-witnessed MIT-IA on the rig; please reach out to state 24 hours in advance of MIT-IA 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines. 2. Check for pressure and if 0 psi pull BPV. 3. Set TWC. 4. Test BOPE to 250 psi Low/ 3,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. ¾Perform Test per ASR 1 BOP Test Procedure ¾Notify AOGCC 24 hours in advance of BOP test. ¾Confirm test pressures per the Sundry Conditions of approval. ¾Test VBR ram on 2-7/8” and 4-1/2” test joints. ¾Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 5. Check for pressure under the TWC. If any pressure is under the TWC, lubricate out the plug. Contact Operations Engineer if you have any pressure. 6. Use landing joint to PU tubing hanger. Contact OE if need to use spear. 7. Recover the tubing hanger. 8. Verify crossover for Safety valve to NSTC connection is on the floor for pulling the 4-1/2” TBG. Re-perforate upper K2B zone 3-11 Workover Well: 3-11 PTD: 188-087 API: 50-029-21848-00 9. Pull and lay down the 4.5’’ kill sting. 10. PU workstring and milling BHA. RIH and establish circulation with 8.6 ppg NaCl (KWF) up the tubing. Record circulation rates and pressures. 11. Mill out cement retainer at 1,180’ MD and HES Fast Drill plug at 1,220’ MD. Chase down to the top of the tubing stub at 12,302’ MD. Circulate bottoms up or until clean returns. POOH 12. CMIT TxIA to 2500 psi for 30 minutes. If fails, establish LLR and contact OE for way forward. ¾If CMIT TxIA to 2500 psi fails, likely way forward is to RIH with 9-5/8’’ test packer and set just above jet cut @ ~12,000’ MD; CMIT TxIA to 2500 psi. If fails again, contact OE; likely way forward is to RDMO ASR and continue diagnostics with slickline or eline. Note that we got a recent CMIT TxIA pass to 2500 psi on 11/8/21. 13. PU the work string and RIH with a 9-5/8” CSG scraper and dress off tool down to the top of jet cut at 12,302’ MD. Objectives are to clean up 9-5/8’’ casing for packer set and to dress off the jet cut in preparation for running the 4.5’’ tubing with overshot. 14. RU slickline. RIH with junk basket to TD. RDMO SL. Note: If we run into obstructions, we will likely make an additional run on the rig to clear obstructions prior to completion run. 15. Install completion as outlined below. Verify crossover for Safety valve to JFE Bear connection is on the floor for running the 4-1/2” completion. Send tally to engineer prior to Install. ¾TBG Over shot ¾1 full Joint 4-1/2” 12.6# 13 Cr80, JFE Bear TBG ¾4-1/2” 9 Cr XN-Profile (RHC Receiver Installed) ¾X# Joints 4-1/2” 12.6# 13 Cr80, JFE Bear TBG ¾9-5/8” x 4-1/2” TNT Packer (estimate set depth +/- 12,200’ MD) ¾X# Joints 4-1/2” 12.6# 13 Cr80, JFE Bear TBG ¾4-1/2” 9 Cr X-Profile ¾X# Joint 4-1/2” 12.6# 13 Cr80, JFE Bear TBG ¾4-1/2” GLM w/Dummy installed set at +/- 10,500’ MD ¾X# Joints 4-1/2” 12.6# 13 Cr80, JFE Bear TBG ¾4-1/2” GLM w/Dummy installed set at +/- 8,500’ MD ¾X# Joints 4-1/2” 12.6# 13 Cr80, JFE Bear TBG ¾4-1/2” GLM w/Dummy installed set at +/- 6,500’ MD ¾X# Joints 4-1/2” 12.6# 13 Cr80, JFE Bear TBG ¾4-1/2” GLM w/Dummy installed set at +/- 4,000’ MD ¾X# Joints 4-1/2” 12.6# 13 Cr80, JFE Bear TBG ¾4-1/2” SSSV and Control line set at +/- 1,400’ MD ¾X# Joints 4-1/2” 12.6# 13 Cr80, JFE Bear TBG ¾4-1/2” Tubing Hanger 16. Circulate and spot corrosion inhibited brine around the overshot and packers. Estimated volume from production packer to top GLM is 440 bbl. Volume may be adjusted based on final packer depths prior to setting the overshot over the TBG stub. Charted 30 minute MIT9-5/8" casing. Results to AOGCC. 3-11 Workover Well: 3-11 PTD: 188-087 API: 50-029-21848-00 17. Run completion in hole over the TBG stub, verify overshot indicators observed to ensure we have swallowed the 4-1/2” TBG cut. 18. Space out and land tubing hanger. RILDS. 19. Drop the ball and rod. Pressure up the TBG to the required pressure to set TNT Packer, est. 3,500 psi setting pressure. Confirm pressures with packer hand onsite. 20. State-witnessed MIT-IA to 2,500 psi (Chart for 30 min). Confirm packer set. If MIT-IA fails, establish LLR and contact OE. 21. Lay down landing joint. Record PU and SO weights on the tally and WellEZ. 22. Set BPV. 23. ND BOPE. 24. Pressure test the tubing hanger void to 500 psig low and 5,000 psi high. 25. Pressure test the tree to 500 psig Low and 5,000 psig High. 26. Pull BPV. 27. RD ASR #1 and all ancillary equipment. Post Rig Procedure: Slickline 1. RU SL unit and pressure test PCE to 250psi low 3,500 psi high. 2. RIH Pull the ball/rod and RHC. 3. Drift to TD with 3.7’’ centralizer. 4. Install live gas lift valves. Service Coil and Portable Test Separator Notes: x Expect ~57’ (2 bbl) cement cap and ~285’ (10.5 bbl) of sand to clean out. x We will need to put the well on gas lift to unload the IA. Please work with field operations to coordinate this. 1. MIRU Coiled Tubing Unit, portable test separator, and spot ancillary equipment. 2. Perform BOP test if one has not been completed in last 7 days. 3. MU motor and 3.7’’ mill with underreamer. RIH to TOC at ~12,566’ CTMD and flag pipe. 4. Establish circulation with 8.6 ppg NaCl up the tubing. Record circulation rates and pressures. 5. Mill through cement. 6. Fill clean out cement and sand(~285’) down to cement retainer at 12,954’ MD. Top shot of first open perforations is at 12,700’ MD; we expect to lose returns at this point. Eline 1. RU EL unit and pressure test to 250psi low 3,500 psi high. 2. RIH and obtain a GR/CCL correlation pass,Contact Joleen Oshiro at (650)-483-4774 to get final perf depths. Tie-in log= GR/CCL, 1993, Western Atlas 3. Perforate with 3-1/8’’ guns per final approved perf depths. 3-11 Workover Well: 3-11 PTD: 188-087 API: 50-029-21848-00 Gun Run # Perf Top Perf Bottom Perf Length 1 ±12,806’ MD ±12,816’ MD 10’ Total 10’ Table 1: END 3-11 Proposed Perf Gun Run Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. ASR BOP Stack 3-11 Workover Well: 3-11 PTD: 188-087 API: 50-029-21848-00 Attachment 1: Current WBS 3-11 Workover Well: 3-11 PTD: 188-087 API: 50-029-21848-00 Attachment 2: Proposed WBS 3-11 Workover Well: 3-11 PTD: 188-087 API: 50-029-21848-00 Attachment 3: ASR BOP Stack 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Drill Plug/Prep RWO Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13,533'feet 1,220' & 12,954 feet true vertical 10,511'feet N/A feet Effective Depth measured 12,951'feet 12,356 feet true vertical 10,027'feet 9,581 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4-1/2" 12.6# / 13Cr 1,093' 1,093' Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / 13Cr 12,500' 9,685' 9-5/8" x 5-1/2" See Packers and SSSV (type, measured and true vertical depth)TIW HBBP N/A Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Contact Email: Authorized Title:Operations Manager Contact Phone: 4,760psi 5,090psi N/A 5,020psi 6,870psi 8,150psi Burst Collapse N/A 2,260psi 161' 2,504' 8,305' 9,835' 7" 10,537' 12,701' 13,520' 10,502' 9-5/8" measuredPlugs Junk measured N/A Length 161' 2,504' Size Conductor Surface Intermediate 30" 13-3/8" 9-5/8" Production Liner 10,537' 2,164' 1,104' Casing STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 188-087 50-029-21848-00-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0047502 ENDICOTT / ENDICOTT OIL Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: DUCK IS UNIT SDI 3-11 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 0 2500 0 N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 161' 2,504' 250 Structural TVD 321-547 Sr Pet Eng: 8,530psi Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 N/A 11,220psi Joleen Oshiro Joleen.Oshiro@hilcorp.com 907-777-8486 L G Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Samantha Carlisle at 12:14 pm, Nov 15, 2021 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2021.11.13 07:24:12 -09'00' Torin Roschinger (4662) Well Name Rig API Number Well Permit Number Start Date End Date END 3-11 CTU #6 50-029-21848-00-00 188-087 11/3/2021 11/8/2021 11/3/2021 Hilcorp Alaska, LLC Weekly Operations Summary MIT/OA. IA/ 140 psi OA/ 0 psi. OA was fluid packed. Pressure to 1000. The pressure dropped to 0 in under 10 minutes. There was no visible fluid at surface. I/A 140 OA/0. Summary: MIRU CTU. Pump Drift Ball and Perform weekly BOP test. MU pilot hole milling BHA, and stabbed on well. Found a leak at the lubricator, pop off well to troubleshoot. 11/6/2021 Continue pushing lower plug 100' below orginal set depth. Pump final gel sweep and chase into tubing tail. CMIT-TxIA to 2,500psi - pass. RBIH and spin into tubing stub, dry tagged at top of cement cap at 12566' CTMD. POOH. FP well from 1300' to surface. RDMO CTU. 11/7/2021 Summary: Troubleshoot lubricator leak. MU BOT 3.70" pilot hole milling BHA and RIH. Tagged 9-5/8" cement retainer at 11,55.8', corrected depth based on RKB 1,164.72'. Underream cement down to top of the retainer, mill through retainer until underreamer arms contacted top of retainer at 1174' CTMD (1183' MD). POOH. Make up BOT 3.70" milling BHA without UR and additional disconnect. RIH. Spin into pilot hole and mill cement down to 1205 CTMD (1214 MD). Pump gel sweep and pull up into tubing for MIT-TxIA to 2500 psi. RIH and continue milling at 1205'. Mill down to 1215' and started moving lower plug down hole. Push plug 100' down hole and pump final gel sweep. 11/8/2021 Pilot hole milled with CT 11/8/21 50-029-21848-00-00 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Drill Plug/Prep RWO 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 13,533'N/A Casing Collapse Structural Conductor Surface 2,270psi Intermediate 4,760psi Production 5,080psi Liner 8,510psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Joleen Oshiro Contact Email: Contact Phone: 777-8486 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 9-5/8"x5-/2" TIW HBBP 12,356' MD / 9,581 TVD 12,701' 10,537' 2,164' See Schematic 7" 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: DUCK IS UNIT SDI 3-11 C.O. 462.007 10,537' 2,504' 9,833' Authorized Title: 10/18/2021 13,520'1,104' 4-1/2" 10,500' Perforation Depth MD (ft): 161' 2,504' See Schematic 9-5/8" 30" 13-3/8" 161' 9-5/8" 6,870psi 5,020psi 161' 2,504' 8,304' 3,100 1,220' / 12,954' ENDICOTT / ENDICOTT OIL 12.6# / 13Cr TVD Burst 12,500' 8,150psi Hilcorp Alaska LLC Length Size 10,511'12,951'10,027' MD Tubing Size: 4-1/2" PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047502 188-087 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21848-00-00 joleen.oshiro@hilcorp.com AOGCC USE ONLY 11,220psi Tubing Grade: 12.6# / 13Cr Tubing MD (ft): 1,093'Perforation Depth TVD (ft): ory Statu Form 10-403 Revised 10/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 7:40 am, Oct 19, 2021 321-547 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2021.10.18 11:29:17 -08'00' Torin Roschinger (4662) DSR-10/19/21DLB 10/19/2021 X Conditions of approval: 1. Flowline magnets to be installed in return flow stream during milling. 2. Operational updates to AOGCC at 06:00 and 18:00 when milling retainer, cement, and plug. 3,100 MGR28OCT2021 10-404 dts 10/28/2021 JLC 10/29/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.29 09:20:03 -08'00' RBDMS HEW 10/29/2021 Mill through shallow plugs, PT Well: 3-11 PTD: 188-087 API: 50-029-21848-00 Well Name:END 3-11 API Number: 50-029-21848-00 Current Status:Not Operable, SI Rig:NA Estimated Start Date:October 14, 2021 Estimated Duration:2 days Reg.Approval Req’std? Date Reg. Approval Rec’vd: Regulatory Contact:Darci Horner 777-8406 Permit to Drill Number:188-087 First Call Engineer:Joleen Oshiro (907) 777-8486 (O) (650)-483-4774 (M) Second Call Engineer:Oliver Sternicki (907) 564-4891 (O) Current Bottom Hole Pressure:4,087 psi @ 10,000’ TVD (KWF ~7.9ppg) (Based on 1/2021 SBHPS in nearby analogue well, 3-23A) Max. Anticipated Surface Pressure:3100 psi (Based on 0.1 psi/ft. gas gradient) Last recorded shut in WHP:800 psi on 1/28/17 (Slickline drift and tag, TIO = 800/800/50) Brief Well Summary: Endicott well 3-11 has a cement plug & retainer in the production casing from 1,180-1,220’; perforations have a sand plug and cement cap over them (top perforation shot 12,700’ MD). Well had a surface casing leak with crude in the cellar identified in 2005; leak depth unknown but assumed near surface as bubbling in conductor occurred with N2 at only 20 psi. Tubing was cut at 12,302’ and pulled. Holes were shot in the 9-5/8” and the OA was squeezed to surface with cement. The well was left with the plugs and a 4-1/2” kill string was installed to 1093’. Future RWOs were halted due to lack of money. Beyond the now cemented holes shot in the PC, there is no indication of any other PC leaks. There is value in returning Endicott well 3-11 to production as the last time it sustainably produced was early 2005 (at ~300 bopd and competitive GOR and watercut). Since then, we started crestal gas injection in well 4- 26A in 2020, and 3-11 is situated in a prime bottomhole location to reap the benefits of this immiscible gas drive. The 4-26A gas injection has thus far uplifted nearby well 3-23A by ~130 bopd, and we have similar expectations for the response in well 3-11. Recent Integrity & Drift History 4/01/05: Active SC Leak. Crude bubbling in conductor. 4/27/05: CMIT-TxIA failed. 7/12/05: 1 for 1 returns from conductor while pumping on OA. 8/18/05 & 12/30/05: CMIT-TxIA failed at .2 BPM 1/16/06: LDL shows tubing leak at TIW packer. Spin/Temp indicate fluid going down and out the tubing @ TIW then down the backside of the tubing tail. 2/12/06 – 02/14/06: Coil set sand and cement plug across perfs 2/16/06: Passing CMIT-TxIA against plug set at 12,314’ just above packer. 2/18/06: Passing PPOT-IC and PPOT-T 2/27/06: RWO: Cut and pull tubing from 12302’ 2/28/06: RWO: Set plug at 1220’. Shot 9-5/8” csg Punch from 1190’1197’. Set EZSV at 1180’. 3/01/06: RWO: Circulate OA with brine then cement to surface through holes. Squeeze at 500 psi. Left killstring. 9/05/07: Passing MIT-OA with N2 to 500 psi following SC leak remediation. Losses of 30 psi followed by 10 psi (ending TIO= ssv/vac/0) 8/6/10: Crude bubbled out of conductor. 8/29/10: 2.5 bbls crude sucked out of conductor. Cement top job on conductor 11/13/16: MIT-OA to 500 psi passed with diesel, losses of 14 psi followed by 0 psi (starting TIO=150/480/550, ending TIO=150/480/528) -00 DLB -00 DLB Superceded on page 6 Page 2 Mill through shallow plugs, PT Well: 3-11 PTD: 188-087 API: 50-029-21848-00 1/28/17: Slickline drift with 2.5’’ centralizer and 1.75’’ sample bailer; tag TOC @ 1,180’ MD, no restrictions (ending TIO= 800/800/50) Objectives: 1) Pressure test the 9-5/8’’ casing down to packer at 12,356’ MD to 2500 psi to advise scope of potential rig workover Procedure: Service Coil 1. MIRU Coiled Tubing Unit with 2” or 1.75’’ coiled tubing and spot ancillary equipment. 2. Perform BOP test if one has not been completed in last 7 days. 3. MU motor and 3.8’’ mill BHA. 4. RIH with BHA, Tag the cement retainer at 1,180’ MD and flag pipe. 5. Establish circulation with 8.6 ppg NaCl up the tubing. Record circulation rates and pressures. 6. Set down and mill pilot hole through cement retainer from 1,180’ MD to the TOP of the HES Fast Drill plug at 1,220’ MD (do not mill on Fast Drill plug yet). 7. Circulate bottoms up or until clean returns. POOH to 1,100’ MD. CMIT TxIA to 2,500 psi for 30 min. If fails, establish LLR and contact OE to discuss way forward. 8. If CMIT TxIA passes, RIH and drill through the HES Fast Drill plug at 1,220’ MD. Note when coil weight is back to neutral, meaning coil weight is not being stacked down and the mill is through the plug. 9. After milling through the plug, dry drift in hole ~100ft to ensure there are no obstructions below. Perform a CMIT-TxIA to 2500psi. x If the CMIT-TxIA passes, bleed off pressure and dry drift down to cement top at 12,605’md. The motor may need to be kicked on to spin into the 4-1/2” tubing cut at 12,302’md, but attempt to dry drift if possible. After tagging, POOH and when at 1300’md, swap to FP fluid taking returns from tubing to FP well. x If the CMIT-TxIA fails, establish LLR and notify OE. Depending on leak rate, we may need to circulate bottoms up with 8.6 ppg NaCl. 10. RDMO CT. Note shut in TIO pressures. -00 DLB Page 3 Superceded on page 7 Pilot hole to be drilled Proposed -00 DLB Page 4 See page 8 for existing schematic Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 5000#Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head Endicott Coiled Tubing BOPE Page 5 ZĞǀϭ͗DŝůůƚŚƌŽƵŐŚƐŚĂůůŽǁƉůƵŐƐ͕Wd tĞůů͗ϯͲϭϭ Wd͗ϭϴϴͲϬϴϳ W/͗ϱϬͲϬϮϵͲϮϭϴϰϴͲϬϬ tĞůůEĂŵĞ͗EϯͲϭϭW/EƵŵďĞƌ͗ ϱϬͲϬϮϵͲϮϭϴϰϴͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗EŽƚKƉĞƌĂďůĞ͕^/ZŝŐ͗E ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗KĐƚŽďĞƌϭϰ͕ϮϬϮϭƐƚŝŵĂƚĞĚƵƌĂƚŝŽŶ͗ϮĚĂǇƐ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛ƐƚĚ͍ĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ĂƌĐŝ,ŽƌŶĞƌϳϳϳͲϴϰϬϲWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϴϴͲϬϴϳ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗:ŽůĞĞŶKƐŚŝƌŽ ;ϵϬϳͿϳϳϳͲϴϰϴϲ;KͿ ;ϲϱϬͿͲϰϴϯͲϰϳϳϰ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗KůŝǀĞƌ^ƚĞƌŶŝĐŬŝ ;ϵϬϳͿϱϲϰͲϰϴϵϭ;KͿ &XUUHQW%RWWRP+ROH3UHVVXUHSVL#¶79'.:)aSSJ %DVHGRQ6%+36LQQHDUE\DQDORJXHZHOO$ 0D[$QWLFLSDWHG6XUIDFH3UHVVXUHSVL %DVHGRQSVLIWJDVJUDGLHQW /DVWUHFRUGHGVKXWLQ:+3 SVLRQ 6OLFNOLQHGULIWDQGWDJ7,2 ƌŝĞĨtĞůů^ƵŵŵĂƌǇ͗ ŶĚŝĐŽƚƚǁĞůůϯͲϭϭŚĂƐĂ,ĂůůŝďƵƌƚŽŶ^sƌĞƚĂŝŶĞƌĂŶĚ,ĂůůŝďƵƌƚŽŶ&ĂƐƚƌŝůůƉůƵŐŝŶƚŚĞƉƌŽĚƵĐƚŝŽŶĐĂƐŝŶŐĨƌŽŵ ϭ͕ϭϴϬͲϭ͕ϮϮϬ͖͛ƉĞƌĨŽƌĂƚŝŽŶƐŚĂǀĞĂƐĂŶĚƉůƵŐĂŶĚĐĞŵĞŶƚĐĂƉŽǀĞƌƚŚĞŵ;ƚŽƉƉĞƌĨŽƌĂƚŝŽŶƐŚŽƚϭϮ͕ϳϬϬ͛DͿ͘tĞůů ŚĂĚĂƐƵƌĨĂĐĞĐĂƐŝŶŐůĞĂŬǁŝƚŚĐƌƵĚĞŝŶƚŚĞĐĞůůĂƌŝĚĞŶƚŝĨŝĞĚŝŶϮϬϬϱ͖ůĞĂŬĚĞƉƚŚƵŶŬŶŽǁŶďƵƚĂƐƐƵŵĞĚŶĞĂƌ ƐƵƌĨĂĐĞĂƐďƵďďůŝŶŐŝŶĐŽŶĚƵĐƚŽƌŽĐĐƵƌƌĞĚǁŝƚŚEϮĂƚŽŶůǇϮϬƉƐŝ͘dƵďŝŶŐǁĂƐĐƵƚĂƚϭϮ͕ϯϬϮ͛ĂŶĚƉƵůůĞĚ͘,ŽůĞƐ ǁĞƌĞƐŚŽƚŝŶƚŚĞϵͲϱͬϴ͟ĂŶĚƚŚĞKǁĂƐƐƋƵĞĞǌĞĚƚŽƐƵƌĨĂĐĞǁŝƚŚĐĞŵĞŶƚ͘dŚĞǁĞůůǁĂƐůĞĨƚǁŝƚŚƚŚĞƉůƵŐƐĂŶĚ ĂϰͲϭͬϮ͟ŬŝůůƐƚƌŝŶŐǁĂƐŝŶƐƚĂůůĞĚƚŽϭϬϵϯ͛͘&ƵƚƵƌĞZtKƐǁĞƌĞŚĂůƚĞĚĚƵĞƚŽůĂĐŬŽĨŵŽŶĞǇ͘ĞǇŽŶĚƚŚĞŶŽǁ ĐĞŵĞŶƚĞĚŚŽůĞƐƐŚŽƚŝŶƚŚĞW͕ƚŚĞƌĞŝƐŶŽŝŶĚŝĐĂƚŝŽŶŽĨĂŶǇŽƚŚĞƌWůĞĂŬƐ͘ dŚĞƌĞŝƐǀĂůƵĞŝŶƌĞƚƵƌŶŝŶŐŶĚŝĐŽƚƚǁĞůůϯͲϭϭƚŽƉƌŽĚƵĐƚŝŽŶĂƐƚŚĞůĂƐƚƚŝŵĞŝƚƐƵƐƚĂŝŶĂďůǇƉƌŽĚƵĐĞĚǁĂƐĞĂƌůǇ ϮϬϬϱ;ĂƚΕϯϬϬďŽƉĚĂŶĚĐŽŵƉĞƚŝƚŝǀĞ'KZĂŶĚǁĂƚĞƌĐƵƚͿ͘^ŝŶĐĞƚŚĞŶ͕ǁĞƐƚĂƌƚĞĚĐƌĞƐƚĂůŐĂƐŝŶũĞĐƚŝŽŶŝŶǁĞůůϰͲ ϮϲŝŶϮϬϮϬ͕ĂŶĚϯͲϭϭŝƐƐŝƚƵĂƚĞĚŝŶĂƉƌŝŵĞďŽƚƚŽŵŚŽůĞůŽĐĂƚŝŽŶƚŽƌĞĂƉƚŚĞďĞŶĞĨŝƚƐŽĨƚŚŝƐŝŵŵŝƐĐŝďůĞŐĂƐ ĚƌŝǀĞ͘dŚĞϰͲϮϲŐĂƐŝŶũĞĐƚŝŽŶŚĂƐƚŚƵƐĨĂƌƵƉůŝĨƚĞĚŶĞĂƌďǇǁĞůůϯͲϮϯďǇΕϭϯϬďŽƉĚ͕ĂŶĚǁĞŚĂǀĞƐŝŵŝůĂƌ ĞǆƉĞĐƚĂƚŝŽŶƐĨŽƌƚŚĞƌĞƐƉŽŶƐĞŝŶǁĞůůϯͲϭϭ͘ ZĞĐĞŶƚ/ŶƚĞŐƌŝƚǇΘƌŝĨƚ,ŝƐƚŽƌǇ ϰͬϬϭͬϬϱ͗ĐƚŝǀĞ^>ĞĂŬ͘ƌƵĚĞďƵďďůŝŶŐŝŶĐŽŶĚƵĐƚŽƌ͘ ϰͬϮϳͬϬϱ͗D/dͲdǆ/ĨĂŝůĞĚ͘ ϳͬϭϮͬϬϱ͗ϭĨŽƌϭƌĞƚƵƌŶƐĨƌŽŵĐŽŶĚƵĐƚŽƌǁŚŝůĞƉƵŵƉŝŶŐŽŶK͘ ϴͬϭϴͬϬϱΘϭϮͬϯϬͬϬϱ͗D/dͲdǆ/ĨĂŝůĞĚĂƚ͘ϮWD ϭͬϭϲͬϬϲ͗>>ƐŚŽǁƐƚƵďŝŶŐůĞĂŬĂƚd/tƉĂĐŬĞƌ͘^ƉŝŶͬdĞŵƉŝŶĚŝĐĂƚĞĨůƵŝĚŐŽŝŶŐĚŽǁŶĂŶĚŽƵƚƚŚĞƚƵďŝŶŐΛd/tƚŚĞŶĚŽǁŶ ƚŚĞďĂĐŬƐŝĚĞŽĨƚŚĞƚƵďŝŶŐƚĂŝů͘ ϮͬϭϮͬϬϲʹϬϮͬϭϰͬϬϲ͗ŽŝůƐĞƚƐĂŶĚĂŶĚĐĞŵĞŶƚƉůƵŐĂĐƌŽƐƐƉĞƌĨƐ ϮͬϭϲͬϬϲ͗WĂƐƐŝŶŐD/dͲdǆ/ĂŐĂŝŶƐƚƉůƵŐƐĞƚĂƚϭϮ͕ϯϭϰ͛ũƵƐƚĂďŽǀĞƉĂĐŬĞƌ͘ ϮͬϭϴͬϬϲ͗WĂƐƐŝŶŐWWKdͲ/ĂŶĚWWKdͲd ϮͬϮϳͬϬϲ͗ZtK͗ƵƚĂŶĚƉƵůůƚƵďŝŶŐĨƌŽŵϭϮϯϬϮ͛ ϮͬϮϴͬϬϲ͗ZtK͗^ĞƚƉůƵŐĂƚϭϮϮϬ͛͘^ŚŽƚϵͲϱͬϴ͟ĐƐŐWƵŶĐŚĨƌŽŵϭϭϵϬ͛ϭϭϵϳ͛͘^Ğƚ^sĂƚϭϭϴϬ͛͘ ϯͬϬϭͬϬϲ͗ZtK͗ŝƌĐƵůĂƚĞKǁŝƚŚďƌŝŶĞƚŚĞŶĐĞŵĞŶƚƚŽƐƵƌĨĂĐĞƚŚƌŽƵŐŚŚŽůĞƐ͘^ƋƵĞĞǌĞĂƚϱϬϬƉƐŝ͘>ĞĨƚŬŝůůƐƚƌŝŶŐ͘ ϵͬϬϱͬϬϳ͗WĂƐƐŝŶŐD/dͲKǁŝƚŚEϮƚŽϱϬϬƉƐŝĨŽůůŽǁŝŶŐ^ůĞĂŬƌĞŵĞĚŝĂƚŝŽŶ͘>ŽƐƐĞƐŽĨϯϬƉƐŝĨŽůůŽǁĞĚďǇϭϬƉƐŝ;ĞŶĚŝŶŐd/Kс ƐƐǀͬǀĂĐͬϬͿ ϴͬϲͬϭϬ͗ƌƵĚĞďƵďďůĞĚŽƵƚŽĨĐŽŶĚƵĐƚŽƌ͘ ϴͬϮϵͬϭϬ͗Ϯ͘ϱďďůƐĐƌƵĚĞƐƵĐŬĞĚŽƵƚŽĨĐŽŶĚƵĐƚŽƌ͘ĞŵĞŶƚƚŽƉũŽďŽŶĐŽŶĚƵĐƚŽƌ ϭϭͬϭϯͬϭϲ͗D/dͲKƚŽϱϬϬƉƐŝƉĂƐƐĞĚǁŝƚŚĚŝĞƐĞů͕ůŽƐƐĞƐŽĨϭϰƉƐŝĨŽůůŽǁĞĚďǇϬƉƐŝ;ƐƚĂƌƚŝŶŐd/KсϭϱϬͬϰϴϬͬϱϱϬ͕ĞŶĚŝŶŐ d/KсϭϱϬͬϰϴϬͬϱϮϴͿ Page 6 ZĞǀϭ͗DŝůůƚŚƌŽƵŐŚƐŚĂůůŽǁƉůƵŐƐ͕Wd tĞůů͗ϯͲϭϭ Wd͗ϭϴϴͲϬϴϳ W/͗ϱϬͲϬϮϵͲϮϭϴϰϴͲϬϬ ϭͬϮϴͬϭϳ͗^ůŝĐŬůŝŶĞĚƌŝĨƚǁŝƚŚϮ͘ϱ͛͛ĐĞŶƚƌĂůŝǌĞƌĂŶĚϭ͘ϳϱ͛͛ƐĂŵƉůĞďĂŝůĞƌ͖ƚĂŐdKΛϭ͕ϭϴϬ͛D͕ŶŽƌĞƐƚƌŝĐƚŝŽŶƐ;ĞŶĚŝŶŐd/Kс ϴϬϬͬϴϬϬͬϱϬͿ KďũĞĐƚŝǀĞƐ͗ ϭͿ'ĂŝŶĂĐĐĞƐƐďĞůŽǁƚŚĞĞǆŝƐƚŝŶŐƌĞƚĂŝŶĞƌ͕ĐĞŵĞŶƚƉůƵŐƚŽǀĞƌŝĨǇƉƌĞƐƐƵƌĞŝŵŵĞĚŝĂƚĞůǇďĞůŽǁƚŚĞƉůƵŐďǇ ŵŝůůŝŶŐĂƉŝůŽƚŚŽůĞǁŝƚŚĐŽŝůĞĚƚƵďŝŶŐƉƌŝŽƌƚŽƉĞƌĨŽƌŵŝŶŐĂZtK͘ ϮͿWƌĞƐƐƵƌĞƚĞƐƚƚŚĞϵͲϱͬϴ͛͛ĐĂƐŝŶŐĚŽǁŶƚŽƉĂĐŬĞƌĂƚϭϮ͕ϯϱϲ͛DƚŽϮϱϬϬƉƐŝƚŽĂĚǀŝƐĞƐĐŽƉĞŽĨƉŽƚĞŶƚŝĂů ƌŝŐǁŽƌŬŽǀĞƌ͘ WƌŽĐĞĚƵƌĞ͗ ^ĞƌǀŝĐĞŽŝů ϭ͘D/ZhŽŝůĞĚdƵďŝŶŐhŶŝƚǁŝƚŚϮ͟Žƌϭ͘ϳϱ͛͛ĐŽŝůĞĚƚƵďŝŶŐĂŶĚƐƉŽƚĂŶĐŝůůĂƌǇĞƋƵŝƉŵĞŶƚ͘ Ϯ͘WĞƌĨŽƌŵKWƚĞƐƚŝĨŽŶĞŚĂƐŶŽƚďĞĞŶĐŽŵƉůĞƚĞĚŝŶůĂƐƚϳĚĂǇƐ͘ ϯ͘DhŵŽƚŽƌĂŶĚϯ͘ϴ͛͛ũƵŶŬŵŝůů,͘sĞƌŝĨǇƚŚĂƚƚŚĞŵŝůůĚŽĞƐŶŽƚŚĂǀĞĂŶǇƐŝĚĞĐƵƚƚŝŶŐƐƚƌƵĐƚƵƌĞ͕ƚŚŝƐǁŝůů ĞŶƐƵƌĞƚŚĂƚŝƚĐĂŶŶŽƚǁĞĂƌĂǁĂǇƚŚĞĐĂƐŝŶŐĂŶĚƐŝĚĞƚƌĂĐŬŽƵƚŽĨƚŚĞĐĂƐŝŶŐ͘ůƐŽ͕ŝƚ͛ƐƌĞĐŽŵŵĞŶĚĞĚ ƚŚĂƚĂŵŽƌĞĂŐŐƌĞƐƐŝǀĞũƵŶŬŵŝůů͕ƌĞǀĞƌƐĞĐůƵƚĐŚŵŝůů͕ŝƐƵƐĞĚƚŽĞŶƐƵƌĞƚŚĂƚŝĨƚŚĞŵŝůůĚŽĞƐĞŶŐĂŐĞƚŚĞ ĐĂƐŝŶŐǁĂůůŝƚŝŵŵĞĚŝĂƚĞůǇƐƚĂůůƐĂŶĚĚŽĞƐŶŽƚĐƵƚŝŶƚŽƚŚĞĐĂƐŝŶŐ͘ x/ĨŶĞĞĚĞĚ͕ƌƵŶĂŶƵŶĚĞƌƌĞĂŵĞƌƚŽĐĞŶƚƌĂůŝǌĞƚŚĞ,ƚŽŵĂŬĞĂƉŝůŽƚŚŽůĞ͘,ŽǁĞǀĞƌ͕ŝĨĂŶ ƵŶĚĞƌƌĞĂŵĞƌŝƐƌƵŶ͕ƚĂŬĞĂŵĞĂƐƵƌĞŵĞŶƚĨƌŽŵƚŚĞĨĂĐĞŽĨƚŚĞŵŝůůƚŽƚŚĞůŽǁĞƌhZďůĂĚĞƐĂŶĚ ĚŽŶŽƚĂƚƚĞŵƉƚƚŽŵŝůůĚĞĞƉĞƌƚŚĂŶƚŚĂƚďĞĨŽƌĞWKK,ĂŶĚƌĞŵŽǀŝŶŐƚŚĞhZďĞĨŽƌĞĐŽŶƚŝŶƵŝŶŐ ŽŶ͘ ϰ͘Z/,ǁŝƚŚ,͕dĂŐƚŚĞĐĞŵĞŶƚƌĞƚĂŝŶĞƌĂƚϭ͕ϭϴϬ͛DĂŶĚĨůĂŐƉŝƉĞ͘ ϱ͘ƐƚĂďůŝƐŚĐŝƌĐƵůĂƚŝŽŶǁŝƚŚϴ͘ϲƉƉŐEĂůƵƉƚŚĞƚƵďŝŶŐ͘ZĞĐŽƌĚĐŝƌĐƵůĂƚŝŽŶƌĂƚĞƐĂŶĚƉƌĞƐƐƵƌĞƐ͘ ϲ͘^ĞƚĚŽǁŶĂŶĚŵŝůůƉŝůŽƚŚŽůĞƚŚƌŽƵŐŚĐĞŵĞŶƚƌĞƚĂŝŶĞƌĨƌŽŵϭ͕ϭϴϬ͛DƚŽƚŚĞdKWŽĨƚŚĞ,^&ĂƐƚƌŝůů ƉůƵŐĂƚϭ͕ϮϮϬ͛D;ĚŽŶŽƚŵŝůůŽŶ&ĂƐƚƌŝůůƉůƵŐǇĞƚͿ͘ ϳ͘ŝƌĐƵůĂƚĞďŽƚƚŽŵƐƵƉŽƌƵŶƚŝůĐůĞĂŶƌĞƚƵƌŶƐ͘WKK,ƚŽϭ͕ϭϬϬ͛D͘D/ddǆ/ƚŽϮ͕ϱϬϬƉƐŝĨŽƌϯϬŵŝŶ͘/Ĩ ĨĂŝůƐ͕ĞƐƚĂďůŝƐŚ>>ZĂŶĚĐŽŶƚĂĐƚKƚŽĚŝƐĐƵƐƐǁĂǇĨŽƌǁĂƌĚ͘ ϴ͘/ĨD/ddǆ/ƉĂƐƐĞƐ͕Z/,ĂŶĚĚƌŝůůƚŚƌŽƵŐŚƚŚĞ,^&ĂƐƚƌŝůůƉůƵŐĂƚϭ͕ϮϮϬ͛D͘EŽƚĞǁŚĞŶĐŽŝůǁĞŝŐŚƚŝƐ ďĂĐŬƚŽŶĞƵƚƌĂů͕ŵĞĂŶŝŶŐĐŽŝůǁĞŝŐŚƚŝƐŶŽƚďĞŝŶŐƐƚĂĐŬĞĚĚŽǁŶĂŶĚƚŚĞŵŝůůŝƐƚŚƌŽƵŐŚƚŚĞƉůƵŐ͘ ϵ͘ĨƚĞƌŵŝůůŝŶŐƚŚƌŽƵŐŚƚŚĞƉůƵŐ͕ĚƌǇĚƌŝĨƚŝŶŚŽůĞΕϭϬϬĨƚƚŽĞŶƐƵƌĞƚŚĞƌĞĂƌĞŶŽŽďƐƚƌƵĐƚŝŽŶƐďĞůŽǁ͘ WĞƌĨŽƌŵĂD/dͲdǆ/ƚŽϮϱϬϬƉƐŝ͘ x/ĨƚŚĞD/dͲdǆ/ƉĂƐƐĞƐ͕ďůĞĞĚŽĨĨƉƌĞƐƐƵƌĞĂŶĚĚƌǇĚƌŝĨƚĚŽǁŶƚŽĐĞŵĞŶƚƚŽƉĂƚϭϮ͕ϲϬϱ͛ŵĚ͘ dŚĞŵŽƚŽƌŵĂǇŶĞĞĚƚŽďĞŬŝĐŬĞĚŽŶƚŽƐƉŝŶŝŶƚŽƚŚĞϰͲϭͬϮ͟ƚƵďŝŶŐĐƵƚĂƚϭϮ͕ϯϬϮ͛ŵĚ͕ďƵƚ ĂƚƚĞŵƉƚƚŽĚƌǇĚƌŝĨƚŝĨƉŽƐƐŝďůĞ͘ĨƚĞƌƚĂŐŐŝŶŐ͕WKK,ĂŶĚǁŚĞŶĂƚϭϯϬϬ͛ŵĚ͕ƐǁĂƉƚŽ&WĨůƵŝĚ ƚĂŬŝŶŐƌĞƚƵƌŶƐĨƌŽŵƚƵďŝŶŐƚŽ&WǁĞůů͘ x/ĨƚŚĞD/dͲdǆ/ĨĂŝůƐ͕ĞƐƚĂďůŝƐŚ>>ZĂŶĚŶŽƚŝĨǇK͘ĞƉĞŶĚŝŶŐŽŶůĞĂŬƌĂƚĞ͕ǁĞŵĂǇŶĞĞĚƚŽ ĐŝƌĐƵůĂƚĞďŽƚƚŽŵƐƵƉǁŝƚŚϴ͘ϲƉƉŐEĂů͘ ϭϬ͘ZDKd͘EŽƚĞƐŚƵƚŝŶd/KƉƌĞƐƐƵƌĞƐ͘ Email operational updates to AOGCC at 06:00 and 18:00 while milling. Assure flow line magnets in return flow. Page 7 ZĞǀϭ͗DŝůůƚŚƌŽƵŐŚƐŚĂůůŽǁƉůƵŐƐ͕Wd tĞůů͗ϯͲϭϭ Wd͗ϭϴϴͲϬϴϳ W/͗ϱϬͲϬϮϵͲϮϭϴϰϴͲϬϬ Current Status Page 8 mooe Hileorp Alaska, LLC August 26, 2019 Mr. Guy Schwartz Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907/777-8547 a len `ht i_.. L �:F � u.a• AU G 2 ° 201;1 A0 Uw" 4.9 C.l Re: Endicott Conductor Annulus Cement and Corrosion Inhibitor Treatments 8/6/19-8/18/19 Dear Mr. Schwartz, Enclosed please find multiple copies of a spreadsheet with a list of Endicott wells that were treated with cement and corrosion inhibiting casing filler in the surface casing by conductor annulus. The heavier than water "grease -like" filler displaces water to prevent external casing corrosion that could result in a surface casing leak. The attached spreadsheets include the well names, field, API and PTD numbers, treatment dates and volumes. If you have any additional questions, please contact me at 777-8547 or wrivard@hilcorp.com. Sincerely, C' w f" eit.tF Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC Endicott Surface Casing by Conductor Annulus Cement Top lob and Fill Coat Corrosion Inhibitor (CI) Applications Well Field API PTD Initial Top .) Cement ( ft.) Volume of Cement Pumped (bbls) Final Topof Cement (ft.) Cement Pump Date Corrosion Inhibitor Fill Volume (gal) Final Cl Top (ft.) Corrosion Inhibitor Treatment Date 1-61 DIU 50029225200000 1941420 6.5 3.86 1 8/6/2019 23 Flush w/top of conductor 8/18/2019 2-12 DIU 50029223020000 1921170 15 10.18 0.5 8/6/2019 18 Flush w/top of conductor 8/18/2019 3-11 DIU 50029218480000 1880870 9.2 6.11 0.5 8/9/2019 7 Flush w/top of flutes 8/18/2019 3-258 DIU 50029221250200 2030210 12.2 7.87 1 8/9/2019 3 Flush w/top offlutes 8/18/2019 3-41 DIU 50029218780000 1881260 6.4 3.79 1 8/10/2019 5 Flush w/top of flutes 8/18/2019 3-45 DIU 50029218110000 1880510 5.2 2.95 1 8/9/2019 5 Flush w/top of flutes 8/18/2019 3-47 DIU 50029215690000 1860640 2.9 1.33 1 8/9/2019 3 Flush w/top of flutes 8/18/2019 • • I NI RECEIVEDPost Office Box 244027 n Anchorage, AK 99524-4027 Hilcorp Alaska,LLC JUL 3 0 20h 3800 Centerpoint Drive Suite 100 AOGCCAnchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 S`p34*a ��Cy Commissioner Cathy Foerster �� Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ' Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "I" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD# 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp • Orig • New API_WeilNo I • PermitNumberl WellName WellNumber WellNumber 50029224180000 1931730 DUCK IS UNIT MPI 2-24/M12 2-24 50029218150000 1880550 DUCK IS UNIT MPI 2-26/N14 2-26 50029218470000 1880860 DUCK IS UNIT MPI 2-28/P19 2-28 50029218470100 2010180 DUCK IS UNIT MPI 2-28A/O19 2-28A 50029218470200 2030060 DUCK IS UNIT MPI 2-288/019 2-28B 50029222280000 1911400 DUCK IS UNIT MPI 2-30/009 2-30 50029222280100 1981880 DUCK IS UNIT MPI 2-30A/EI-02 2-30A 50029222280200 2081870 DUCK IS UNIT MPI 2-30B/ME-01 2-30B 50029220840000 1901190 DUCK IS UNIT MPI 2-32/SN3 2-32 50029216620000 1861720 DUCK IS UNIT MPI 2-34/P14 2-34 50029220140000 1900240 DUCK IS UNIT MPI 2-36/014 2-36 50029220900000 1901290 DUCK IS UNIT MPI 2-38/SN1 2-38 50029225270000 1941520 DUCK IS UNIT MPI 2-40/S22 2-40 50029218920000 1881450 DUCK IS UNIT MPI 2-42/P13 2-42 50029217670000 1871190 DUCK IS UNIT MPI 2-44/R12 2-44 50029217670100 1970710 DUCK IS UNIT MPI 2-44A/Q11 2-44A 50029219210000 1890230 DUCK IS UNIT MPI 2-46/Q15 2-46 50029219210100 1961810 DUCK IS UNIT MPI 2-46A/R10 2-46A 50029219210200 1971370 DUCK IS UNIT MPI 2-46B/S13 2-46B 50029226120000 1951660 DUCK IS UNIT MPI 2-48/013 2-48 50029223670000 1930670 DUCK IS UNIT MPI 2-50/U08 2-50 50029217500000 1870920 DUCK IS UNIT MPI 2-52/S14 2-52 50029222180000 1911220 DUCK IS UNIT MPI 2-54/Q12 2-54 50029228630000 1980240 DUCK IS UNIT MPI 2-56/EID 2-56 50029228630100 1980580 DUCK IS UNIT MPI 2-56A/EID01 2-56A 50029220410000 1900520 DUCK IS UNIT MPI 2-58/509 2-58 50029223750000 1930830 DUCK IS UNIT MPI 2-60/U13 2-60 50029216480000 1861580 DUCK IS UNIT MPI 2-62/Q17 2-62 50029220550000 1900770 DUCK IS UNIT MPI 2-64/U10 2-64 50029220819500 1901130 DUCK IS UNIT MPI 2-66/U12XX 2-66XX 50029223740000 1930790 DUCK IS UNIT MPI 2-665D12 2-66 50029218580000 1880970 DUCK IS UNIT MPI 2-68/S17 2-68 50029218990000 1881530 DUCK IS UNIT MPI 2-70/U15 2-70 50029205180000 1801200 DUCK IS UNIT MPI 5-01/SD7 5-01 50029206400000 1811180 DUCK IS UNIT MPI 5-02/SD10 5-02 50029206390000 1811170 DUCK IS UNIT MPI 5-03/SD9 5-03 50029216780000 1861900 DUCK IS UNIT SDI 3-01/N29 3-01 50029223060000 1921210 DUCK IS UNIT SDI 3-03/J33 3-03 50029216240000 1861300 DUCK IS UNIT SDI 3-05/029 3-05 50029219110000 1890120 DUCK IS UNIT SDI 3-07/N28 3-07 50029219110100 1981470 DUCK IS UNIT SDI 3-07A/L29 3-07A 50029217800000 1880020 DUCK IS UNIT SDI 3-09/L28 3-09 50029217800100 1950190 DUCK IS UNIT SDI 3-09A/L28 3-09A 50029218480000 1880870 DUCK IS UNIT SDI 3-11/M30 3-11 50029217510000 1870940 DUCK IS UNIT SDI 3-15/K33 3-15 50029219460000 1890530 DUCK IS UNIT SDI 3-17/J30 3-17 50029219460100 1940460 DUCK IS UNIT SDI 3-17A/J30 3-17A 50029219460200 1971080 DUCK IS UNIT SDI 3-17B/M31 3-178 50029219460300 1980210 DUCK IS UNIT SDI 3-17C/M31 3-17C 50029219460400 1982080 DUCK IS UNIT SDI 3-17D/M31 3-17D 50029219460500 2022470 DUCK IS UNIT SDI 3-17E/K30 3-17E 1. Operations Performed: Secure 1 Safe Out Well o Abandon o Suspend o Operation Shutdown o Perforate !HI Other o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. !HI Development o Exploratory 188-087 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21848-00-00 7. KB Elevation (ft): 55.20 9. Well Name and Number: END 3-11/M-30 8. Property Designation: 10. Field 1 Pool(s): ADL 047502 Endicott Field 1 Endicott Pool 11. Present well condition summary Total depth: measured 13533 feet true vertical 10512 feet Plugs (measured) 1180 Effective depth: measured 1180 feet Junk (measured) 12957 true vertical 1180 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 161' 30" 161' 161' Surface 2504' 13-318" 2504' 2504' 5020 2270 Intermediate 10537' 9-5/8" 10537' 8304' 6870 4760 Production 2164' 9-5/8" 10537' - 12701' 8304' - 9833' 8150 5080 Liner 1104' 7" 12416' - 13520' 9623' - 10500' 11220 8510 êCJil~lf~f[.: '" ,--. ,,;..;., Perforation Depth MD (ft): None Perforation Depth TVD (ft): None 4-1/2", 12.6# 13Cr80 1093' Tubing Size (size, grade, and measured depth): 4-1/2", 12.6# 13Cr80 12302' - 12500' Packers and SSSV (type and measured depth): 9-5/8" x 5-1/2" HBBP 12356' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casina Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: !HI Daily Report of Well Operations o Exploratory !HI Development o Service !HI Well Schematic Diagram 16. Well Status after proposed work: !HI 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. I Sundry Number or N/A if C.O. Exempt: Contact John McMullen, 564-4711 306-042 Printed Name Sondra Stewman Title Technical Assistant - ~ 03 {/ a Prepared By Name/Number. Sign're ~ ~ -" ...........;'\ Phone r I/~L LIJJ..r.\-^. 564-4750 Date ~ ~ ßondra Stewman, 564-4750 Form 10-404 Revised 04/2004 F\ R' ¡ I RBDMS BfL MAR 2 8 1006 .~~ Submit Original Only ¡ ¡ -.1 0pú 'I)¡. _J 1/ RECEIVED . STATE OF ALAS~J 0'¿7~ ALASKAaIL AND GAS CONSERVATION C&ISSION MAR 2 4 2006 REPORT OF SUNDRY WELL OPERATIQ~~I&GasCons,commìssjon Anchorage v ¡ G I 1\4 A L TREE: 4-1/16"1 WELLHEAD: 13-M!" 1 RT. ELEV'" 55.2' SF. ELEV '" 16.7' MAX. DEV. '" 53:25 161' 30" Drive Pipe 13- 31 S", 68#1 f t , 2504' NT - 80 0iVE. 9-5/8", 47#/ft, NT80S XO TO NT95HS TOP 7" TOC ~11 ,500' TIW POSITIVE LATCH 9-518" )( 5-1/2" TIW HBSP PACKER PBTD 12,951'ELMD 1/20/96 Cement Retainer PARTIALL YMILLED 7"TIW NOTE: EQUIPMENT DEPTHS ARE DRillER'S PERFORATING DEPTHS E-UNE MEASUREMENTS. PBTD 7", 29 #/ft, SM-110, BTRS- TKC 'X' --IÞ- ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-11/M-30 3-11/M-30 WORKOVER NORDIC CALISTA NORDIC 2 Start: 2/20/2006 Rig Release: 3/212006 Rig Number: Spud Date: 8/711988 End: 312/2006 2/24/2006 11:00 - 14:00 3.00 MOB P PRE Pull off END 1-23. Move to END 3-11. Mob camps and other equipment. Drop out 7-1/16" BOP stack from cellar, mount on skid. 14:00 - 18:00 4.00 MOB P PRE Rig on Stand-By waiting for Veco's crane to move 13-5/8" BOP stack/skid from behind END 1-23 tree to this well. 18:00 - 18:45 0.75 MOB P PRE Rig still on standby waiting on Veco Crane. 18:45 - 00:00 5.25 MOB N WAIT PRE Call dispatch. Crane has been released from Nordic #1, but the crane operator is out of hours for today. The crane will come to location when the operator has had some sleep. ETA 04:00 in the morning. 2/25/2006 00:00 - 05:00 5.00 MOB N WAIT PRE Continue to wait on Veco crane. Got Veco valve crew to move OA valve from back of wellhead to the front to make room for BOP trolly. 05:00 - 05:45 0.75 MOB N PRE Continue to wait for Veco crane. 05:45 - 06:00 0.25 MOB N PRE TL Meeting which included Veco crane operator and riggers. 06:00 - 07:00 1.00 MOB N PRE Make final preps to place BOP stack. Place new tree into cellar area and hang-off. 07:00 - 10:00 3.00 MOB N PRE Hold "Critical Lift" PJSM with Veco crews and Endicott's safety Rep on 1-23 location. Pick BOP stack and place onto waiting lowboy. Move crane and stack to 3-11 location. Hold another PJSM with rig and Veco crews. Spot crane and stack. Pick and place stack/skid behind wellhead. 10:00 - 10:15 0.25 MOB N PRE PJSM will rig crews for moving rig over 3-11 well. Rig off Stand-by at 1000hrs 10:15 - 11 :00 0.75 MOB N PRE Spot rig over well. Rig accepted at 1100 hrs. 11:00 -16:00 5.00 RIGU N PRE Rig up lines to circulate INtbg. Take on 290bbls of 9.6ppg brine. Mix in 2 55gal drums of SafeSurf-O to help clean up tbg prior to pulling. 16:00 - 17:15 1.25 PRE RU lubricator and pull BPV. 17:15-18:00 PRE Circ FP from tbg then IA 18:00 - 20:00 PRE Rig up bleed trailor to OA. Rig up "dipstick" to monitor the crude level between conductor and 13-3/8". 20:00 - 00:00 4.00 BOPSU PRE Circ down the tubing displacing diesel from the IA. Circulate down the lA, taking diesel from the tubing. Circulate down the IA with 290 bbls of detergent wash. Pumping at 6.5 bpm, 1000 psi circ pressure. Circulate detergent wash OOH. Cleaned up toward end of wash. 2/26/2006 00:00 - 00:30 0.50 BOPSU PRE Flow check well. No flow observed from Tor IA. 00:30 - 01 :15 0.75 BOPSU PRE Dry rod in TWC. PT from below to 500 psi. Held solid. 01:15 - 03:35 2.33 BOPSU PRE ND production tree, and lay in pieces behind the rig. 03:35 - 06:00 2.42 BOPSU PRE Lift 13-5/8" BOP stack from trolly cart into cellar and stab onto wellhead. 06:00 - 12:00 6.00 BOPSU PRE NU BOP stack, HCR kill/choke lines, riser and flowline. Crew change. Review ongoing work at changeout. 06:00 - 14:00 8.00 BOPSU PRE Continue NU HCR kill/choke lines. Purge warm water from stack. Flood with cold water. PT body. Leak in kill line Greyloc fitting. Retighened and still leaked. retighten and in the process rig hand suffered a smalllacaration to right thumb while using hammer to strike hammer wrench. With the hammer in his right hand, his thumb area glanced off a bolt on the stack. Rinsed with sterile water applied anticeptic and sterile gauze bandage. Toolpusher drove him to MMC medic. (Endicott medic at airport Printed: 3/612006 12:52:36 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-11 IM-30 3-11/M-30 WORKOVER NORDIC CALISTA NORDIC 2 Start: 2/20/2006 Rig Release: 3/2/2006 Rig Number: Spud Date: 8/711988 End: 312/2006 2/26/2006 I for changeout day.) Took a break. Gathered all hands. Talked about possible frustrations of the stack leaks and reminded everyone that even though the NU is slower than normal we are not in a race to start the test. Hands are a little tired from the short changeout period also. Reviewed the injury and possible causes. The cellar area is crowed at best with a small stack and with the 13-5/8" stack the working room in places is tight. Body position is even more important at these times and we need to stop and access how we are lined up for the task and identify any possible hazards. 14:20 - 15:00 0.67 PRE Blewdown stack and replaced seal ring in Greyloc fitting. Body tested to 3500psi fine. 15:00 - 16:00 1.00 PRE Test BOP's to 250psi low/5min and 3500psi/min high. Witnessing wavied by AOGCC rep Lou Grimaldi. 16:00 - 16:10 0.17 PRE Stop testing. Hold PJSM to changeout Howco spooler with Endicott crane. 16:10 - 16:30 0.33 PRE Changeout Howco spooler for a larger one. 16:30-19:15 2.75 PRE Resume testing BOP·s. 19:15 - 19:30 0.25 DECaMP PJSM with valve crew, Cameron hands, SWS logging crew and rig crew to discuss plan forward. Discuss pulling TWC and pulling tubing into tension for chem cut. We will have another PJSM prior to RU SWS logging eq. 19:30-21:15 1.75 PULL P DECOMP Pick up SWS lubricator to rig up DSM valve crew lubricator to pull TWC. Pick up valve crew lubricator. PT. Pull TWC. 21:15-23:45 2.50 PULL P DECOMP Make up 4-1/2" tubing pups as landing jt. BO LDS. PU on tubing string and pull in tension to 152,000 Ibs. 23:45 - 00:00 0.25 PULL P DECOMP PJSM with SWS eline crew and rig crew. Discuss rig up and explosive's safety. Discuss plan forward for job. 2/27/2006 00:00 - 01 :00 1.00 PULL P DECOMP RU Schlumberger eline crew eq to jet cut tubing. 01 :00 - 04:30 3.50 PULL P DECaMP RIH, log tie in pass. Fire power jet tubing cutter at 12302'. POOH. This is in middle of first full joint above TIW packer. There should be a 20' pipe stub on the bottom of the recovered tubing, and 19' of pipe stub left in the hole. 04:30 - 05:00 0.50 PULL P DECOMP RD Schlumberger eline equipement. 05:00 - 06:00 1.00 PULL P DECOMP Pickup on tubing string. PU wt was 119 klbs. Good indication of cut. Pull tubing hanger to rig floor. Rig up Howco spooling unit. 06:00 - 06:15 0.25 PULL P DECOMP PJSM with oncoming crews after changeout 06:15 - 09:00 2.75 PULL P DECOMP LD landing jts and cut control lines and crimp. LD tbg hanger assembly. Pull 5 jts and well burped some brine. 09:00 - 11 :00 2.00 PULL P DECOMP Reverse circulate 2 tbg volumes. 11 :00 - 13:30 2.50 PULL P DECOMP Continue pulling tbg to SSSV. Recovered 39 SS bands. No bands appeared to be missing or lost downhole during removal. Tbg looks in good condition. Saving first 40 jts for later completion use. Installing thread protectors after drained. 13:30 - 15:50 2.33 PULL P DECOMP Continue pulling tbg. 80 jts total down. 15:55 - 16:10 0.25 PULL P DECOMP Hold PJSM with crews and crane operator to remove Howco control line spool. 16:10 - 16:20 0.17 PULL P DECOMP Remove Howco spooler from rig floor. 16:20 - 17:15 0.92 PULL P DECaMP Continue LD tbg. 17:15 - 18:00 0.75 PULL P DECOMP 14 Endicott Fire Dept hands showed up for rig tour/training. Installed TIW valve. Split in groups and toured the rig. Printed: 3/6/2006 12:52:36 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-11/M-30 3-11/M-30 WORKOVER NORDIC CALISTA NORDIC 2 Start: 2/20/2006 Rig Release: 3/212006 Rig Number: Spud Date: 8/711988 End: 312/2006 2/27/2006 18:00 - 18:30 0.50 PULL P DECOMP Finish rig tour, and crew change. 18:30 - 18:45 0.25 PULL P DECOMP Safety meeting with night tour to discuss tripping pipe safety and plan forward. 18:45 - 00:00 5.25 PULL P DECOMP 90 jts OOH, resume pulling pipe. 200 jts OOH at midnight. 2/28/2006 00:00 - 05:00 5.00 PULL P DECOMP Continue POH with 4-1/2" tubing string. 200 joints OOH at midnight. 05:00 - 06:00 1.00 PULL P DECOMP Continue and finish pulling pipe total of 307-1/2 out of the hole. Take pictures of Jet-Cut. It has a uniform flared cut - 5-1/8" max OD 06:00 - 06:30 0.50 EVAL P DECOMP Spot SWS e-line unit 06:30 - 06:45 0.25 EVAL P DECOMP PJSM with SWS and rig crews. Discuss RU of sheaves, tools logging runs. 06:45 - 12:00 5.25 EVAL P DECOMP RU SWS sheaves and e-line PU tools. Run USIT. E-mail to town. UD tools. 12:00 - 14:30 2.50 EVAL P DECOMP Run JB-Gauge ring to 2500' (8.5" G.R.). Ran to 2500', no problems. Came out of the hole empty. 14:30 - 15:00 0.50 EVAL P DECOMP PJSM with rig crew, cat man, SWS eline crew, BP WSL, SWS coil crew. Discuss plan forward, and hazards of dealing with explosives. Also covered plan to prevent a spill from the OA when we fire our perf guns. 15:00 - 16:00 1.00 EVAL P DECOMP RU, RIH with HES Fastdrill plug on eline setting tool. Set plug with top at 1220'. 16:00 - 17:15 1.25 EVAL P DECOMP PT fastdrill plug to 1000 psi. Held like a rock. Rig up SWS lubricator. Set in the bag. Rig up SWS pressure control eq, and squeeze perf gun. 17:15 - 18:00 0.75 EVAL P DECOMP RIH with 7' tubing puncher gun with high horsepower charges. Shoot charges 1190'-1197'. Good indication of fire, and saw flow on the OA. POOH. 18:00 - 18:30 0.50 EVAL P DECOMP Wait on flow from IA to stop. Well stable. 18:30 - 19:00 0.50 EVAL P DECOMP RD SLB lubricator equipment. 19:00 - 20:00 1.00 EVAL P DECOMP Hold PJSM with SLB and Nordic crews. RU SLB firing head assembly with Halliburton 9-5/8" EZSV. Run in hole. Tie in with CCL. Set top of EZSV at 1180', btm at 1183'. PU and set down to verify plug set. POOH with SLB. 20:00 - 21 :00 1.00 EVAL P DECOMP RD SLB e-line equipment. 21 :00 - 22:30 1.50 REMCM P DECOMP Load pipe shed with 40 jts of 3-1/2" drill pipe. Drift and strap same. 22:30 - 00:00 1.50 REMCM P DECOMP Hold PJSM with crews and Halliburton. Make up EZSV stinger assembly. Run in hole on DP> 3/1/2006 00:00 - 01 :30 1.50 REMCM DECOMP Continue to pick up drill pipe. 01 :30 - 02:15 0.75 REMCM DECOMP Rig up floor to circulate. 5 bpm at 190 psi. 25k# up and dn wt. 02:15 - 03:00 0.75 REMCM DECOMP Pick up drill pipe pups to space out in EZSV 03:00 - 04:15 1.25 REMCM DECOMP Rig up to circulate. Pump 155 bbls 9.6 brine down dp and up 13-3/8 x 9-5/8" annulus. No additional fluid released from conductor in cellar. Blow down out side hardlines. Check rtns at shaker. 04:15 - 05:30 1.25 REMCM DECOMP Rig up SLB cementers. Run hardline to floor. 05:30 - 08:30 3.00 REMCM DECOMP Rig up rig to reverse circulate after cement job. Double check Printed: 3/6/2006 12:52:36 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-11/M-30 3-11 IM-30 WORKOVER NORDIC CALISTA NORDIC 2 Start: 2/20/2006 Rig Release: 3/212006 Rig Number: Spud Date: 8/711988 End: 312/2006 3/1/2006 05:30 - 08:30 3.00 I REMCM DECOMP unusual flow paths, and make a couple of changes so that we i can clean our lines after circulating cement. 08:30 - 09:00 0.50 I REMCM DECOMP Perform injectivity test. Pump down DP, thru perfs, and into I OA. Observe OA pressure, and injectivity rate. Step pressure I up slowly to 500 psi. Got very slow injectivity rate. Pumped a total of 0.25 bbls at 500 psi on the OA. Bled off very slowly. No apparent gain in volume of fluid between conductor and 0.50 I REMCM 13-3/8" . 09:00 - 09:30 DECOMP PJSM with cement crew, rig crew, Tool pusher, BP WSL, SWS TL, Veco vac truck drivers. Discuss unusual cement job in detail. Review proceedure, and unusual valving rig up. Ensure that everyone is comfortable with the job. Discuss hazards. 09:30 - 10:20 0.83 REMCM DECOMP Discussed flowback path in PJSM. Need to make a change to prevent the choke from getting loaded with cement. 10:20 - 11 :20 1.00 REMCM DECOMP SD pumps. Rig up to cementers. Had hands go back to cellar prior to pumping cement. Found fluid level in conductor nearly at the top. It slowly came up over the past 2 hours despite the fact that the pressure was bled off. 11 :20 - 13:20 2.00 REMCM DECOMP On line with fresh water. Pump 4 bbls. SD. PT cementers hardlines to 3000 psi. Held good. On line with 15.8 ppg class G cement with a 4 hour thicking time. BBLS RATE PRESS 0 1.7 80 psi 10 1.7 69 psi 20 2.7 115 psi 30 2.7 137 psi 40 2.7 183 psi 50 2.7 229 psi 60 3.9 613 psi 70 3.9 660 psi 80 2.7 412 psi 90 1.0 150 psi 100 2.0 400 psi 110 1.7 288 psi 120 2.06 385 Calculated cement vol back to surface was 82.2 bbls. Started seeing first cement at 80 bbls away. Caught a sample at 90 bbls away, 14.4 ppg. 95 bbls away 15.0 ppg. 105 bbls away, 15.2 ppg. 115 bbls away, 15.3 ppg. 123 bbls away, pumped 2 bbls water. SI returns and squeezed up to 500 psi. Took 0.4 bbls to get to 500 psi. Held for 45 minutes. Final squeeze pressure was 445 psi. Good squeeze. Took 40 bbls of cement displacement from OA prior to shutting it in. 13:20 - 14:30 1.17 REMCM DECOMP Rig down cementers leaving 500 psi trapped on drill pipe. Pickup drillpipe with blocks and unstung from EZSV. Saw pressure bleed of DPP when we unstung. Break out hose to DP. Lay down 11' pup joint. Make back up to circulate. PU 20' above EZSV. Reverse circulate cement OOH and drillpipe. Pumping at 6 bpm, 300 psi. Expect to get 4 bbls of cement back. Got cement in returns for 14 bbls. Probably 4 bbls of Printed: 3/6/2006 12:52:36 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-11/M-30 3-11/M-30 WORKOVER NORDIC CALISTA NORDIC 2 Start: 2/20/2006 Rig Release: 3/2/2006 Rig Number: Spud Date: 8/711988 End: 312/2006 DECOMP cement mixed with water. Circulate total of 30 bbls. I CIP @ 14:30 hours. Thickening time = 4:07. DECOMP PJSM prior to tripping pipe OOH. DECOMP Trip OOH with 3-1/2" DP. Having motor man monitor conductor fluid level to ensure that it doesn't overflow. No change observed. DECOMP All pipe OOH. Take 3-1/2" drill pipe outside. Take extra 4-1/2" 13Cr80 tubing outside. Take GLM's outside. Checked conductor fluid level. No gain observed. RUNCMP Rig up floor to run tbg. RUNCMP MU 27 jts 12.6# 13Cr tubing w/ cut joint guide shoe. MU hanger. MU landing joint. RUNCMP Set TWC in hanger. RUNCMP Remove tubing annulus valve from well head. ND 13-5/8" BOPs. Set on cart and remove from cellar. RUNCMP Continue to ND BOPs. Complete removal of riser assembly. Remove kill and choke lines. Un bolt and lift stack. RUNCMP Skid BOPs out of cellar. Remove tubing head adapter from old master valve. NU tubing head adapter and tree. Continue NU tree. PT tree to 4000 psi. Pick DSM Valve crew lubricator, and pull TWC. Due to problems at GC-2, all pumping jobs in the field are shut down at this time. The IMT will not let us rig up LRS. Release LRS pumping unit to respond to GC2. Call for a vac truck of diesel, and plan to pump with rig pumps. Standby on Vac truck of diesel. Hopefully they won't need our vac truck too. Vac truck on location. Hook up to rig pumps. Pump 100 bbls of ice cold -25 degf diesel down lA, and take returns from the tubing. Got good diesel returns. SI master and swab. PT IA to 1000 psi, and hold for 30 minutes. 3/1/2006 13:20 - 14:30 1.17 REMCM 14:30 - 14:45 0.25 REMCM 14:45 - 16:30 1.75 REMCM 16:30 - 18:30 2.00 REMCM 18:30 - 19:00 0.50 19:00 - 21 :30 2.50 21 :30 - 21 :45 0.25 BOPSU 21 :45 - 00:00 2.25 BOPSU 3/2/2006 00:00 - 02:00 2.00 BOPSU 02:00 - 03:00 1.00 BOPSU 03:00 - 06:00 3.00 BOPSU 06:00 - 08:00 2.00 BOPSU 08:00 - 08:15 0.25 BOPSU 08:15 - 09:00 0.75 BOPSU 09:00 - 12:15 3.25 RIGD WAIT RUNCMP RUNCMP RUNCMP RUNCMP POST 12:15 - 14:00 1.75 RIGD P POST 14:00 - 15:00 1.00 RIGD P POST 15:00 - 19:30 POST 4.50 RIGD P 19:30 - 20:00 0.50 DEMOB P POST TIME PRESSURE 00:00 1062 psi 15:00 1260 psi 30:00 1475 psi Looks like we got thermal expansion of the diesel as it warmed up. Bled back to 0 psi and rigged down the vac truck and hoses. Well is dead after bleeding off thermal expansion. Open MV and Swb valve. Fluid level stable. Chugger pump out fluid to below tubing hanger profile to leave a void space for expansion. Dry rod in BPV. Disconnect all lines in the cellar. Warm move system. Unhook cables to camps. move everything in front of rig. Finish cleaning sumps with vac truck. Finish cleaning pits. Prepare to move off well. Hold PJSM with DS operator and rig crew. Discuss positions. comms, operations with all. Jack rig to max height of 16". Release rig at 2000 hrs. Printed: 3/6/2006 12:52:36 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-11 IM-30 3-11/M-30 WORKOVER NORDIC CALISTA NORDIC 2 Start: 2/20/2006 Rig Release: 3/212006 Rig Number: Spud Date: 8/7/1988 End: 3/2/2006 Back off well. Spot rig into wind, on side of pad, to prep for scoping and lowering derrick. Printed: 3/612006 12:52:36 PM RECEIVEl) .. STATE OF ALASKA I AlA~ Oil AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Opera!. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 55.2 KB 8. Property Designation: ADL-047502 11. Present Well Condition Summary: Total Depth measured 13533 true vertical 10511.51 Effective Depth measured 12951 true vertical 10027.29 Casing Drive Pipe Surface Production Production Liner Length 122 2466 10500 2164 1104 Size 20" x 30" 13-3/8" 68# NT -80 9-518" 47# NT80S 9-5/8" 47# NT95HS 7" 29# SM-110 Perforation depth: Measured depth: 12700 - 12718 True Vertical depth: 9832.66 - 9846.38 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Contact Sharmaine Vestal Printed Name Sharmaine Vestal Signat Plug Perforations [2] Perforate New Pool D Perforate D 4. Current Well Class: Development ;'] Stratigraphic r MAR 1 7 !UUb on Stimulate D ARSRSraoe WaiverD Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 188-0870 6. API Number: 50-029-21848-00-00 9. Well Name and Number: Exploratory Service 3-11/M-30 10. Field/Pool(s): Endicott Fieldl Endicott Oil Pool feet feet Plugs (measured) 12954 cmt ret, 12605 sandback Junk (measured) None feet feet MD 39 - 161 38 - 2504 37 - 10537 10537 - 12701 12416 - 13520 TVD 39 - 161 38 - 2503.81 37 - 8303.62 8303.62 - 9833.43 9622.56 - 10500.24 12757 - 12777 9876.27 - 9891.71 12782 - 12790 9895.58 - 9901.78 4-1/2" 12.6# 13CR80 5-1/2" TIW HBBP Packer 3-1/2" TIW HBBP Packer Burst Collapse 5020 6870 8150 11220 2270 4760 5080 8510 12806 - 12816 Closed 9914.21 - 9921.99 Closed 36 - 12500 12356 12957 Tubing pressure Service Title Data Mgmt Engr Phone 564-4424 RBDMS BFL MAR 1 6 200~ W DS P L Date 3/14/2006 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure SHUT-IN SHUT-IN 15. Well Class after proposed work: Exploratory Development ;'] 16. Well Status after proposed work: Oil ;'] Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Submit Original Only e e ". 3-11/M-30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 2/12/2006 CTU #5, Sand Back; Road CTU #5 to Endicott SDI, Endicott orientation, spot equipment. Continue job on WSR 2/13/06... 2/13/2006 CTU #5, Sand Back; Continued from WSR 2/12/06 ... Perform weekly BOP test and chain inspection. Load well with 300 bbls of 2% KCL w/40 bbl LubTex lubricant pill. RIH with 2.25" SDN. Attempt to lay in 6550# of 20/40 carbolite (33 bbls slurry). Had trouble pumping sand due to weak gel and were forced to stop short at 24 bbls slurry away. Flushed coil and layed in sand. Alowed time for settling. Tagged sand top at 12734'. Prep to pump second batch. Pumped and layed in an additional 1 0 bbls of slurry. Wait for gel to break. Continued on WSR 2/14/06... 2/14/2006 CTU #5, Sand Back; Continued from WSR 2/13/06 ... Wait for second sand dump to settle. Tag sand top at 12677' ctm. Release Dowell (16 hr. rule). POOH freezing protecting. Work on pump. Wait on cementers. RIH with 2.0" BDN. Found bad spot on pipe at 4720' ctmd. Inspect pipe wall thickness - OK. Dry tag sand top at 12670' ctm. Lay in 2.1 bbls cement on top of sand. Maintain 500 psi on well while POOH. Freeze protect well with 60/40 meth to 2037'. Trap 500 psi on well. Notify well tender. RD. Install tree cap connection on top of pump-in-sub for slickliners. Est. TOC @ 12615'. Move to EN D2-22. *** Job Complete*** 2/15/2006 ***WELL S/I ON ARRIVAL *** SET 3.81 X-LOCK C-SUB @ 12,314' SLM, ATTEMPT TO PULL STA #1 @ 11087' SLM, ***JOB CONTINUED ON 02-16-05 *** 2/16/2006 *** JOB CONTINUED FROM 12-15-06 *** PULLED STA#1 DGLV @ 11077' SLM...CMIT Tx IA TO 3000 PSI..PASSED***LEFT STA#1 OPEN*** DRIFT W/ 3.70 CENT, TEL, & S-BAILER TO 12,605' CORRECTED DEPTH WELL LEFT S/I 2/17/2006 T/I/O=525/700/0 Temp = SI Circ out well w/ 9.6 ppg Brine (Pre RWO) Rd To Location Open Permit Rig Up Pumped 5bbls Meth Spear Down TBG Followed By 372 bbls Of 110* 1 %KCL Followed By 48 bbls Of 55* 9.6 Brine Job In Progress FLUIDS PUMPED BBLS 142 Meth 507 2% KCL 40 Lubetex 20 Clean gel 34 20/40 carbo lite 2.1 cement 39 freshwater 784.1 TOTAL Re: Variance for Endicott 1-23 & 3-11 ) (81-- 037 ) Subject: Re:Variance for Endicott 1-23 & 3-11 From: Winton Aubert <winton_aubert@admin.state.ak.us> Date: Wed, 08 Feb 2006 07:40:30 -0900 T(): ..."vvdrthington,..Ar~s..J"...<Äras.Worthington@bp.com> c.C::9athèrine.PEoers,ter<cathy_foèrsìer@admiJ1.state.ak.us>, Admin AOGCG Prudhoe Bay <aogcc_prudhoe_bay@admin.state.ak;us> Aras, Per 20 AAC 25.285 (h), AQGCChereby approves alternate BOPE for your proposed workovers of Endicott well 1-23 (PTD 194-128, Sundry No. 306-018) and Endicott well 3-11 (PTD 188-087, Sundry No. 306-042). All other approval stipulations apply. Winton Aubert AOGCC 793-1231 Worthington, Aras J wrote: Winton, As per phone conversation regarding Sundry permits for Endicott wells 1-23 (306-018) and Endicott 3-11 (Sundry # not received yet). Nordic 2 plans to move to Endicott for these two tubing workovers towards the end of this week. Currently our 13 5/8" BOP stack includes 3preventers: one pipe ram, one blind ram, and an annular preventer. BP requests a variance from regulation 20 AAC 25.285 which implies that 4 preventers are needed if API 5K equipment is required. Our MASP on End 1-23 is 3200 psi and for End 3-11 it is 3300 psi. It may be possible to rig up (4) 135/8" preventers with this rig but would require significant cost/modified rig equipment andlor additional rig moves onloff the well for these workbvers. The 3·preventer stack will provide sufficient BOPE for these rig-workovers and is consistent with BP internal Policy. Aras Worthington CTD Engineer BP Exploration Alaska Inc. 564-4102 SCI\NNEO F@ (I 7 201:15 1 of 1 2/8/20063:36 PM ) ) FRANK H. MURKOWSKI, GOVERNOR ~SIiA OIL AND GAS CONSERVATION COMltUSSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John McMullen Senior Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Cb7 tð.;Û \t{) Re: Endicott Field, END 3-11/M-30 Sundry Number: 306-042 . ,,.. %) ([\\ Ire. '2ßÜß ~'I. cJ\\ \\': E,b,j) \" t\)ì ~ 5Cí\N"'Q~v \\" Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this 6> day of February, 2006 Enc!. fYl}¿·fJ·()4' WGA-RË'~D ) STATE OF ALASKA) ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 2 2006 APPLICATION FOR SUNDRY APPROVAIt.a Oil & Gas Cons. Commission 20 AAC 25.280 Anchorage 1. Type of Request: 0 Abandon 0 Suspend 0 Operation Shutdown 0 Perforate II Other Secure I Safe Out Well ,,/ o Alter Casing 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: / 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number 188-087 / 6. API Number: /' 50- 029-21848-00-00 9. Well Name and Number: /' END 3-11/M-30 10. Field / Pool(s): 99519-6612 55.20 8. Property Designation: ADL 047502 Endicott Field / Endicott Pool 11. Total Depth MD (ft): 13533 Casing Structural Conductor Surface Intermediate Productior) Liner PRESENTWELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 10512 12951 / 10027 12488 Length Size MD TVD Burst Junk (measured): 12957 Collapse 161' 30" 161' 161' 2504' 13-3/8" 2504' 2504' 5020 2270 10537' 9-5/8" 10537' 8304' 6870 4760 2164' 9-5/8" 10537' - 12701' 8304' - 9833' 8150 5080 1104' 7" 12416' - 13520' 9623' - 10500' 11220 8510 Perforation Depth MD (ft): Perforation Depth TVD (ft): 12700' - 12816' /' 9833' - 9922' Packers and SSSV Type: 9-5/8" x 5-1/2" HBBP SSSV Landing Nipple Tubing Size: 4-1/2",12.6# /~ Tubing Grade: 13Cr80 Packers and SSSV MD (ft): 12356' 1502' Tubing MD (ft): 12500' ,,/ 12. Attachments: 181 Description Summary of Proposal o Detailed Operations Program 14. Estimated Date for Commencing Operations: o BOP Sketch 13. Well Class after proposed work: /' o Exploratory 181 Development 0 Service 15. Well Status after proposed work: 181 Oil D Gas o WAG 0 GINJ o Plugged DWINJ o Abandoned o WDSPL 16. Verbal Approval: Commission Representative: 17. I hereby certify that t foregoin Printed Name Jo I February 10, 2006 I Date: correct to the best of my knowledge. Contact John McMullen Title Senior Production Engineer ~) Prepared By Name/Number: Phone 564-4711 Da~ 2 0 00ndra Stewman, 564-4750 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity rn'Bop Test 0 Mechanical Integrity Test 0 Location Clearance I Sundry Number:,~ - (}!:~~ Subsequent F COMMISSIONER APPROVED BY THE COMMISSION Date~-6-(}Þ Other: "\ -e.S t go e f RBDMS BFL FEB 0 G 2006 Submit In Duplicate ORIGIt\'AL ) ') Endicott 3-11/M-30 Production Well Proposed Ria Assisted Safeout ./ Well Status: Shut-in producer. Shallow 13-3/8" surface casing leak. Freeze protect fluids (crude) will enter and rise up the 13-3/8" x conductor annulus if any pressure builds on the outer (9-5/8" x 13-3/8") annulus. The leak is currently mitigated by keeping on open bleed from the outer annulus to a bleed tank. A tubing tail plug is set, the well is monitored daily, and secondary containment has been installed in the wellhouse. Rig Workover Obiective: Secure/safeout the well. The plans are to just secure the well during the 2006 ice road season and not recomplete the well this year. Future options for the wellbore are being evaluated. As such, approval is requested for the secure steps listed below only. BP understands that future AOGCC Sundry approval is required to plug perfs, abandon, * suspend, re-enter, or otherwise.· ' 1. Pre-rig: Pull tubing tail plug. Using coiled tubing, sand back perfs to 12,650' MO (50' MO above top perf) and spot 50' of cement on top of sand (target TOC = 12,600'). Pressure test cement to 3000 psi. Chemical cut tubing above packer. Load tubing and IA with kill weight fluid. Set BPV. 2. MIRU Nordic 2. Pull BPV; set and test TWC in tubing h~2~ì NO tree and adapter flange. NU BOPE. Test BOPE to 250 psi (Iow)/~psi (high). 3. Circulate hole volume with kill weight fluid (containing corrosion inhibitor). 4. Pull 4-1/2" tubing. 5. Run cement bond log to locate the top and bottom of cement in the 9-5/8" x /' 13-3/8" annulus. 6. Set 9-5/8" retrievablé bridge plug at about 1950' (-1 00' below TOC identified in step 5). Spot sand. on top of bridge plug. 7. Punch holes in' 9-5/8" casing. Circulate well with completion fluid through circ ./ holes, displacing crude out of 13-3/8" annulus. 8. Set cement retainer above circ holes. 9. Cement 9-5/8" x 13-3/8" annulus to surface. WOC. / 10. Pressure test wellbore above retainer to 3000 psi. 11. Run 4-1/2" tubing to about 1500'. Freeze protect wellbore. 12. NO BOPE. NU and test two 4-1/16" 5K tree valves. / . ··CHROME TBG*" 7~~~voy END3-11 MAX. DEV. '" SSSV Nipple I 1502' 13- 3/8" , f t , I NT- 80 CHYE, 161' 30" Drive Pipe Six GLM's 9-5/8", 47#/ft, XOTO NT95HS 10537' -þo.. TIW POSITIVE LATCH 9-5/8" x 5-1/2" TIW HBBP PACKER 12355' 4-112", 12.6#/ft, 13CR80, r Toe -11,500' 12356' TOP OF 7" LINER 12416' 9-5/8", 47ft/ft, NT95HS, 12701' 12,43Z' H4-1I2" HSS X NIP, 10'" 3,813" I H4-1/2" HESXN NIP, ID'" H4-1/2"XXN1TF'(04/15/05) I 12500' r4-1/2" WLEGI PERFORA TION SUMMARY REF lOG: Dll ON 09/33/88 ANGLE AT TOP ?? @ 12700' Note: Refer to Production historic¡¡1 perf d¡¡t¡¡ SIZE SPF INTERVAL DATE 2·7/8" 6 12700 - 12718 0 3-318" 6 12757 - 12777 0 3-3/8" 6 12782 - 12790 0 6 12806 - 12816 0 6 12606 - 12646 S 3-318" 6 12666 - 12878 S 3-3/8" 6 12885· 12900 S 3-3/8" 6 12690 12920 S 5" 5 12920 - 12940 S 5" 5 12970 - 12994 S 5" 5 13016 - 13030 S 5" 5 13040 - 13098 S 5" 5 13106 - 13116 S I == 12,951' ELMD 1120/96 . ~ Halliburton Cement Retainer ~ PARTIALLY MILLED 7" TIW "HB-BP" PKR W/2-7/8" 'X' NIPPLES 12954' -KEY: O==OP/:N/C== NOTE: COMPLETION EQUIPMENT DEPTHS ARE DRILLER'S MEASUREMENTS, PERFORATING DEPTHS ARE E-UNE MEASUREMENTS. 12957' PBTD 7", 29 'It/ft. 8M-110, I BTRS-TKC 13436' I ---þoo- 13520 ~ ÀÀÀ/f vvv"" DATE REV BY COMMENTS 111 ORIGINAL COM PL. TlR JTP SQZ & REPERF DATE REV BY COMMENTS 09/26/05 XXN TIP SET 4115105 ENDICOTI UNIT WELL: 3·11 1 M.30 PERMIT No: '1680870 API No: 50-029-21648-00 SECTNRE TREE: 4-1/16" I 5000 psi WELLHEAD: 13-5/8" I 5 RT. REV:: 55.2' SF. REV:: 16.7' MAX. DEV. :: 53:25 13- 3/8", 68#1 f t , I 2504' I Nr- 80 Œ-IYE, 9-5/8", 47#1ft, I NT80S XO TO 10537' NT95HS I-Þ-- TOP Of 7" LINER 12416' þo 9-5/8", 47#/ft, þo NT95HS, 12701' "* IŒY: 0.. OPm Î c ct.œm Î sœ~m NOTE: COMPLETION EQUiPMENT DEPTHS ARE DRiLLER'S MEASUREMENTS. PERfORATING DEPTHS ARE E-LlNE MEASUREMENTS. PBrD 7", 29#/ft, SM-110, BTRS- TKC 13436' .... 13520 I ~ 3-11 161' 30" Drive Pipe TOC -11,500' 12355' TiW POSITIVE LATCH 9-5/8" x 5-1/2" TIW HBSP PACKER 12356' 12432' 12488' 12500' 12500' PSTD:: 12,951' ELMD 1/20/96 Halliburton Cement 12954' Retainer PARTIALLY MiLLED 7" TIW "HS-BP" PKR WI 2-7/8" 'X' NiPPLES 12957' v v v '" COMMENTS 111 ORIGltoW. COMP!.. RECEIVED '\ STATE OF ALASKA '\ ALA~ -~ OIL AND GAS CONSERVATION COMIV.. ~!310N JAN 2 4 2006 REPORT OF SUNDRY WELL OPERATIONSA1 k O·'~G ". Co . as a I as vvns. mmtasio1 1. Operations Abandon D Repair Well D Plug Perforations [] Stimulate D Other Performed: Alter Casing D Pull Tubing D Perforate New Pool D WaiverD Time Extension ftchoraOt Change Approved Program D Operat. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ß?': Exploratory D 188-0870 3. Address: P.O. Box 196612 Stratigraphic [' Service C' 6. API Number: Anchorage, AK 99519-6612 50-029-21848-00-00 7. KB Elevation (ft): 9. Well Name and Number: 55.2 KB 3-11/M-30 8. Property Designation: ADL-047502 11. Present Well Condition Summary: 10. Field/Pool(s): Endicott Field/ Endicott Oil Pool Total Depth measured 13533 true vertical 10511.51 feet feet Plugs (measured) Junk (measured) 12488 XXN None Effective Depth measured 12951 true vertical 10027.29 feet feet Casing Drive Pipe Surface Production Production Liner Length Size MD TVD Burst Collapse 122 20" x 30" 39 - 161 39 - 161 2466 13-3/8" 68# NT -80 38 - 2504 38 - 2503.81 5020 2270 10500 9-5/8" 47# NT80S 37 - 10537 37 - 8303.62 6870 4760 2164 9-5/8" 47# NT95HS 10537 - 12701 8303.62 - 9833.43 8150 5080 1104 7" 29# SM-11 0 12416 - 13520 9622.56 - 10500.24 11220 8510 Perforation depth: Measured depth: 12700 - 12718 True Vertical depth: 9832.66 - 9846.38 12757 - 12777 9876.27 - 9891.71 12782 - 12790 9895.58 - 9901.78 12806 - 12816 9914.21 - 9921.99 Closed Closed Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 36 - 12500 Packers and SSSV (type and measured depth) 5-1/2" TIW HBBP Packer 3-1/2" TIW HBBP Packer 12356 12957 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~Çl\NNEJ) ~H\N 2; 5 2J)~BDMS 8Ft JAN 252006 Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf I Water-Bbl I Casing Pressure Tubing pressure SHUT-IN SHUT-IN 15. Well Class after croposed work: Exploratory r Development P' Service [' 16. Well Status after proposed work: Oil R' Gas r WAG r GINJ r WINJ r WDSPL r Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x 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 Sharmaine Vestal Printed Name Sharmaine Vestal ,- k. ..... t<:;:/ -,. Signaturk:::::?n.&?'~,¿.~ . . ORIGINAL Title Data Mgmt Engr Phone 564-4424 Date 1/24/2006 Form 10-404 Revised 04/2004 Submit Original Only ) ') 3-11/M-30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 12/26/2005 ***WELL SI ON ARRIVAL *** RIG UP RIH W/ 4.5 GS PULLING TOOL ***CONTINUED ON 12-27-2005 *** 12/27/2005 **** CONT. FROM 12-26-05 WSR **** RAN EQ PRONG TO PLUG AND EQUALIZED PLUG @ 12,456'SLM. ATTEMPT TO PULL 4.5" XN PLUG W/.108 STAINLESS WIRE - UNABLE TO PULL CHANGE OVER TO .125 WIRE. PULLED 4.5" XN PLUG @ 12,433'SLM. (PACKING MISSING) LRS DISPLACED/KILL WELL W/SEA WATER & METH. WHILE SLB DRIFT W/ BRUSH AND 3.75" GAUGE RING. ***CONTINUED ON 12-28-2005 *** 12/27/2005 T/I/O= 1100/250/0 Assist slickline,Pumped 5 bbl meoh, 290 bbl1 % kcl, 5 bbl meoh, and 10 bbl diesel to displace and freeze protect tubing. Final WHP= 1 00/250 12/28/2005 ***CONTINUED FROM 12-27-2005 *** SET 4.5" PXN PLUG IN LOWEST X-NIPPLE @ 12,394'SLM. PRONG 97" LNG W/1.75" FN. FL @ 800', SIP=550#. TEST PLUG - PLUG TESTED GOOD. TURN WELL OVER TO DSO - LEFT WELL SHUT IN. 12/30/2005 T/I/O=400/350/0 CMIT TxlA FAILED @ 3000 psi. Established LLR of 0.2 bpm @ 2000 psi.(RWO screen) Pumped 70 bbls Diesel total. Leak appears to be in IA somewhere (flow from Tbg into IA thru equalizing hose during monitor period). (See pump log for more details) Final WHP's=500/450/0 FLUIDS PUMPED BBLS 10 Diesel 10 MeOH 290 1 % KCL 310 TOTAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _X Add Perfs Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 5. Type of Well: Development _X Explorato~__ Stratigraphic__ Service__ 4. Location of well at surface 2529' FNL, 828' FEL, Sec. 08, T11 N, R17E, UM At top of productive interval 1121' FNL, 1558' FEL, Sec. 05, T11N, R17E, UM At effective depth 966' FNL, 1546' FEL, Sec. 05, T11N, R17E, UM At total depth 647' FNL, 1544' FEL, Sec. 05, T11N, R17E, UM (asp's 270214, 5970971) (asp's 269669, 5977677) (asp's 269685, 5977832) (asp's 269696, 5978152) 12. Present well condition summary Total depth: measured true vertical 13530 feet Plugs (measured) 10509 feet 6. Datum elevation (DF or'KB feet) RKB 55 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-11 / M-30 SDI 9. Permit number / approval number 188-087t~ 10. APl number 50-029-21848-00 11. Field / Pool Endicott Oil Pool Top of Cement Retainer set @ 12954' Effective depth: measured true vertical Casing Length Conductor 122' Surface 2465' Intermediate 12662' Liner 1104' 12951 feet Junk (measured) 10027 feet Partially milled 7" TIW Packer w/2-7/8" 'x' Nipples @ 12957' Size Cemented Measured Depth True Vertical Depth 30" Driven 161' 161' 13-3/8" 3300 c.f. Permafrost 2504' 2504' 9-5/8" 575 c.f. Class 'G' 12701' 9833' 7" 320 c.f. Class 'G' 12416' - 13520' 9622' - 10500' Perforation depth: Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) measured Open Perfs 12700'-12718', 12757'-12777', 12782'-12790', 12806'-12816'; Sqzd Perfs 12816 - 846, 12868 - 940, 12970 - 994, 13016 - 030, 13040 - 098, 13106 - 116 true vertical Open Perfs 9833'-9846', 9876'-9892', 9896'-9902', 9914'-9922', Sqzd Perfs 9922'-9945', Sqzd Perfs 9963'-10019', 10042'-10061', 10078'-10090', 10098'-10144', 10150'-10159' 4-1/2", 12.6#, 13 CR80, NSCT TBG @ 12356' with 4-1/2" tailpipe to 12500'. TIW Positive Latch @ 12355' 9-5/8" x 4-1/2" TIW HBBP PKR @ 12356' RECEIVED 4-1/2" HES 'HXO' (3.813" Min ID) w/SSSV (2" Min ID) @ 1502' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure FEB 1 5 14. Prior to well operation 02/02/2002 Subsequent to operation 02/10/2002 Oil-Bbl 478 Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 450 9350 582 706 10231 Anchora~ Casing Pressure Tubing Pressure 397 399 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is. true and correct to the best of my knowledge. ~~~,¢,~~,~C~-~-~ Title: Technical Ass is tant DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · OR!Gi ' AL Date February 15, 2002 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE 03-11/M-30 Description of Work Completed NRWO OPERATIONS 01/21/2002 PERFORATING: DRIFT/TAG 01/27/2002 PERFORATING: DRIFT/TAG 02/07/2002 PERFORATING: COMBINATION MECHANICAL INTEGRITY TEST; DRIFT/TAG O2/O8/2OO2 PERFORATING: PERFORATING SUMMARY 01/21/02 PULLED 4 1/2" BBE # BB-474. DRIFTED W/3.625 CENTRALIZER TO 12,757' CORRECTED. POP W/LIFT GAS. 01/27/02 TAG EOT @ 12,440' WLM. ELM-12,500'. TAG BOTTOM @ 12874' WLM. CORRECTED DEPTH-12,934'. ESTIMATED RATHOLE-34'. O2/O7/02 RAN 3 3/8" DUMMY GUN, TOOLS FALLING SLOW AFTER 4100', CONT' IN HOLE W/NO PROBLEMS TO 12,800' SLM. DID NOT SET DOWN. WELL PUT ON PRODUCTION. 02/08/02 PERFORATE 12700'-12718' WITH 2-7/8" PJ HSD GUNS - 6SPF. Fluids Pumped BBLS. Description 3 DIESEL FOR SURFACE EQUIP PRESSURE TEST (2 TESTS) 3 TOTAL 02/08/2002 ADD PERFS THE FOLLOWING INTERVAL WERE PERFORMED USING THE 2-7/8" POWERJET, LOADED 6 SPF, RANDOM ORIENTATION. 12700' - 12718' Page I ,.~ I A I I:. uI- ALAS~-'"~IL AND GAS CONSERVATION cOMMISS~~ REPORT SUNDRY WELL OPE. ,ATIONS 1. Operations performed: Operation shutdown ... Stimulate__ Plugging__ Pull tubing Alter casing __ Repair well_ Perforate X Other__ 2. Name of Operator BP Ex/~loration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.~Te, Alaska 99519-6612 4. Location of well at surface 2529' SNL, 828' WEL, Sec. 8, T11N, R17E At top of productive interval 1122'SNL, 1559'WEL, Sec. 5, T11N, R17E At effective depth 694' SNL, 1566' WEL, Sec. 5, T11N, R17E At total depth 647' SNL, 1565' WEL, Sec. 5, T11N, R17E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 55.15 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-11/M-30 SDI 9. Permit number/approval number 88-87/Not recluired 10. APl number 50- OO29-21848 11. Field/Pool Endicott Off Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 13530 feet Plugs (measured) true vertical 10509 BKB feet measured 13436 feet Junk (measured) true vertical 10427 BKB feet Length Size Cemented 122' 30" Driven 2465' 13 3/8" 3300 c.f. Permafrost 12662' 9 5/8" 575 c.f. Class G Top of cement retainer set at 12954' Partially milled 7" TIW Packer w/ 2-7/8" "x" Nipples at 12957' Measured depth True vertical depth BKB BKB 161' 161' 25O4' 2504' 12701' 9833' 1104' 7" 320 c.f. Class G 12416'- 13520' 9622'- 10500' measured 12757'- 12777'; 12782'- 12790~ 12806'- 12816'(Open) 12806'- 12846', 12885'- 12900', 12868'- 12878', 12890'- 12920', 12920'- 12940', 12970'- 12994', 13016'- 13030', 13040' - 13098', 13106'- 13116' (Afl Squeezed) true vertical (Subsea) 9821'- 9837~ 9840'- 9847'; 9859'- 9867' (Open) 9859'- 9890', 9921'- 9932', 9907'- 9915', 9924'- 9948', 9948'- 9963', 9987'- 10006', 10023'- 10034', 10042'- 10089', 10095'- 10103' (All Squeezed) Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 TDS tubing with 2 7/8" tailpipe to 12969' Packers and SSSV (type and measured depth) 9 5/8" Packer at 12397'; 4 1/2" SSSV at 1524' ~ECELVEQ 13. Stimulation or cement squeeze summary Addperfs (1/27/00) Intervals treated (measured) 12757'-12777'; 12782'-12790' (MD) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 696 536 6264 0 1282 13279 6729 0 Tubing Pressure 346 1319 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations × 16. Status of well classification as: Oil X Gas Suspended , Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~~ 1~~ TitleseniorTechnicalAssistantlV562-5234 Form 10-404 Rev 06/15.~8 Date 2/21/00 SUBMIT IN DUPLICAT~~) BPX Endicott Production Engineering Department OPERATIONS REPORT DATE: 1/27/99 WELL N°: 3-11/M-30 TYPE OF OPERATION: BP EXPLORATION REP: Add-perfs Tave Peruzzi SERVICE COMPANY: SWS (Boehme/Kirkby) SUMMARY: Shot two guns in the well. INTERVAL(MWD) FEET SUBZONE 12782-12790 8 3A2 12757-12777 20 3A2 2" Powerjet 6 spf 60 degree phased casing gun. DATE/TIME OPERATIONS SUMMARY 1/27 FWHP: 330#, FWHT=182, choke=FOC, lAP: 1,800 (on GL) OAP: 650 1045 On location. Pre Job safety and operational meeting. 1100 Rig up. Pressure test to 3000 psi with triplex. Good. 1230 RIH 1310 Correlate to 9-3-88 DLL-GR. 1330 Shoot lower gun. 1445 RIH 2® gun 1630 Shoot gun 2 1715 Rig down 1800 Off location. SSSV: OUT RECEIVED Naeka Oil & Gas Cons. Commieabn And~or~e LARRY GPRNT Attn. ALASKA OiL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHOP~.GE AK, 99501. Date: 13 May 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL 2-60/U-13 2-60/U-13 DESCRIPTION ?LS FIi'.[AL BL+RF ~ Run # 1 PLS FINAL BL+RF~'/ Run # 1 PFC/PERF FINAL BL+RF~/~Run # 1 PFC/PERF FINAL BL+RF /Run # 1 ECC No. 4973.01 5723.15 6132.07 6132.08 Please sign and return to: Attn. Rodney D. Paulson Wesnern Atlas Logging Services 5600 B Street Suite 201 ~ Anchorage, AK 99518 \/ / Or FAX to (907) 563-7803 Received by: ~~--.- Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 30 April 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~O ~ I f~-25/M-27 (SDI) ~ DESCR=P=zON ~ :~.~~ Run i 1 GR/CCL FINAL BL & RF~~ Run ~ 1 1 PLS FINAL BL+RF Run # 1 1 GR/CCL FINAL BL+RF--~ Run # 1 1 PFC/PERF FINAL BL+RF~/ Run ~ 1 ECC No. 4205.04 5614.06 5723.14 ReceLved by: Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 . Or FAX to (907) 563-7803 ~~ Date: t996 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well __ Perforate X Other X 2, Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2529'SNL, 828' WEL, Sec. 8, T11N, R17E At top of productive interval 1122' SNL, 1559' WEL, Sec. 5, T11N, R17E At effective depth 694' SNL, 1566' WEL, Sec. 5, T11N, R17E At total depth 647'SNL, 1565' WEL, Sec. 5, T11N, R17E 5. Type of Well: Development Exploratory Stratigraphic Service ORIGINAL 6. Datum elevation (DF or KB) KBE = 55.15 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-11/M-30 SDI 9. Permit number/approval number 88-87/Not required 10. APl number 50- 0029-21848 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical 13530 feet 10509 BKB feet Plugs (measured) Top of cement retainer set at 12954' Effective depth: measured true vertical 13436 feet 10427 BKB feet Junk (measured) Partially milled 7" TIW Packer w/2-7/8" "x" Nipples at 12957' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 122' 30" Driven 161' 161' 2465' 13 3/8" 3300 c.f. Permafrost 2504' 2504' 12662' 9 5/8" 575 c.f. Class G 12701' 9833' Tubing (size, grade, and measured depth) 1104' 7" 320 c.f. Class G 12416'- 13520' 9622'- 10500' measured 12806'- 12816' (Open) 12806'- 12846', 12885'- 12900', 12868'- 12878', 12890'- 12920', 12920'- 12940', 12970'- 12994', 13016'-13030', 13040'-13098', 13106'-13_116'(AIISqueezed) true vertical (Subsea) 9859'- 9867' (Open) 9859'~, 9890', .9,92,1'- ~9,3,2,', 9907'- 991,5/, 9924'- 9948', 9948'- 9963', 9987'-~._~1, 0,,00,..~6.', ,~].00~3~- 10034. 10042 - 10089. 10095'- 10103 (AII Soueezed) ii, i..~ ~.i ..... !I.,.; ~ 4 1/2" 12.6# L-80 TDS tubing with 2 7/8" tailpipe to 12969 .... Packers and SSSV (type and measured depth) 9 5/8" Packer at 12397'; 4 1/2" SSSV at 1524' 13. Stimulation or cement squeeze summary Roped (2/14/96), Add pod (3/10/96), Squeeze (4/14/96) and add pod'(4/l:?/~): ~-':'' .... ~';' '" ~ Intervals treated (measured) 12806'- 12846', 12885'- 12900', 12868'- 12878', 12890'- 12940', 12970'- 12994', 13016'- 13030', 13040'- 13098', 13106'- 13116' Treatment description including volumes used and final pressure 505 Bbls Fresh seawater, 10 Bbls 15% HClJXylene, 20 Bbls effluent water, 12 Bbls cement and 33 Bbls methanol 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3415 1791 5123 0 364 Subsequent to operation 3174 2200 3726 0 336 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ' '~ ~i/~ ~ ....~ Signed ~- ~-t~-,~.~'.~., /.~..-.~-- *:_ Title Senior Technical Assistant II Form 10-4.~,~ev 06/15/88 Date SUBMIT IN DUPLIC'ATE Endicott Production Engineering D, epartment DATE' 2 / 14 / 96 WELL Na: 3-11 / M-30 BP EXPLORATION REP: Re-Perf THOMAS RUT SERVICE COMPANY: ATLAS (WAYNE BARKER, JOHN, LARRY) DATE/TIME OPERATIONS SUMMARY I 2/13 0800 MIRU .ATLAS. 103Q RAISE GUNS TO LUBRICATOR & BOPS TO TREE CAP. WELL FLOWING. FWHP = 350 PSI; lAP = 1700 PSI; CAP = 240 PSI; FWHT = 118 F; CK=176 1040 SHUT WELL IN & PRESSURE TEST LUBRICATOR TO SIWHP. RIH WITH GUN #1 (10 FT WITH 18' OAL). GR MEASURE PT TO TOP SHOT - 2'. SlWHP = 1400 PSI, 1140 ON BOTTOM. OPEN WING AND CHOKE TO 176 BEANS FOR DRAWDOWN TO PERFORATE. 1145 LOG TWO TIE-IN STRIPS UP WITH WELL FLOWING. NOTE: TIED-IN WITH 9/3/88 DLL. MAKE -2 FT CORRECTION TO E-LINE. DROP BACK DOWN. ,,, 1200 LOG UP TO TOP SHOT AT 12836' MD, 1208 FIRE GUN. SAW GOOD CURRENT INDICATION, BUT NO WEIGHT CHANGE. LOG UP TO CONFIRM TIE-IN, CLOSED CHOKE/WING, AND POOH. 1255 AT SURFACE. CLOSE SWAB, BLEED LUBRICATOR, & LOWER GUN. ALL SHOTS FIRED. SlWHP = 1300 PSI. 1315 POP WELL AT 75 BEAN CHOKE. OPERATIONS REQUESTED TO RESTRICT RATE UNTIL PLANT LINES OUT. 1345 RD ATLAS FROM 3-11 TO SWING OVER TO 3-09 FOR FSPL. PERFORATION SUMMARY: GUN DLL DEPTH FEET SUBZONE I 12836' - 12846' 10 2B ALL SHOTS WERE FIRED WITH ATLAS 3-3/8" HSC GUNS LOADED AT 6 SPF AND 60° PHASING. Endicott Production Engineering Department DATE: 3 / 10 / 96 WELL Na: 3-11 / M-30 BP EXPLORATION REP: ADD Perf THOMAS RUT SERVICE COMPANY: ATLAS (KEN BRUNNER, STRUBLE, JOHNNY) DATE/TIME OPERATIONS SUMMARY 3/10 0900 MIRU'ATLAS. 1030 RAISE GUNS TO LUBRICATOR & BOPS TO TREE CAP. WELL FLOWING. FWHP = 410 PSI; lAP = 1750 PSI; OAP = 200 PSI; FWHT = 125 F; CK=176 1040 SHUT WELL IN & PRESSURE TEST LUBRICATOR TO SIWHP. RIH WITH GUN #1 (30 FT WITH 39.5' OAL). GR MEASURE PT TO TOP SHOT = 2'.. SlWHP = 1400 PSI. 1200 ON BOTTOM. OPEN WING AND CHOKE FOR DRAWDOWN TO PERFORATE. 1200-1215 LOG TWO TIE-IN STRIPS UP WITH WELL FLOWING. NOTE: TIED-IN WITH 9/3/88 DLL. MAKE -2 FT CORRECTION TO E-LINE. DROP BACK DOWN. 1215 LOG UP TO TOP SHOT AT 12806' MD. 1217 FIRE GUN. SAW GOOD CURRENT INDICATION & WEIGHT CHANGE. LOG UP TO CONFIRM TIE-IN, FLOW WELL TO CLEAN UP PERFS, CLOSED CHOKE/WING, AND POOH. 1330 AT SURFACE. CLOSE SWAB, BLEED LUBRICATOR, & LOWER GUN. ALL SHOTS FIRED. SIWHP = 1520 PSI. 1400 POP WELL AT 176 BEAN CHOKE. REQUESTED A WELLTEST FOR TONIGHT. 1500 RD ATLAS FROM 3-11. PERFORATION SUMMARY: GUN DLL DEPTH FEET SUBZONE I 12806' - 12836' 30 2B ALL SHOTS WERE FIRED WITH ATLAS 3-3/8" HSC GUNS LOADED AT 6 SPF AND 60° PHASING WITH RANDOM ORIENTATION. Endicott Production Engineering Department DATE: 4 / 17 / 96 WELL Na: 3-11 / M-30 BP EXPLORATION REP: ADD Perf THOMAS RUT SERVICE COMPANY: ATLAS (GEORGE HARPER, DEVOLD, MCBRIDE) DATE/TIME OPERATIONS SUMMARY 4/17 0800 MIRU ATLAS. 0945 RAISE GUNS TO LUBRICATOR & BOPS TO TREE CAP. WELL SI POST SQZ. SlWHP = 1300 PSI; lAP = 750 PSI; OAP = 150 PSI; CHOKE & WING CLOSED. 0955 PRESSURE TEST LUBRICATOR TO SIWHP. RIH WITH GUN #1 (10 FT WITH 23' OAL). CCL MEASURE PT TO TOP SHOT = 2'. OBSERVED FLUID LEVEL AT -2300 FT MD. SlWHP = 1300 PSI. 1045 ON BOTTOM. WELL IS ALREADY UNDERBALANCED FOR PERFORATING - NO NEED TO OPEN CHOKE TO FLOW & RISK GETTING BLOWN UPHOLE. 1055 LOG TWO TIE-IN STRIPS UP. NOTE: TIED-IN WITH 9/3/88 DLL.. MAKE -2 FT CORRECTION TO E-LINE. DROP BACK DOWN. 1100 LOG UP TO TOP SHOT AT 12806' MD. 1105 FIRE GUN. SAW STRONG CAP BREAK & WEIGHT CHANGE. LOG UP TO CONFIRM TIE-IN AND POOH. 1200 AT SURFACE. CLOSE SWAB, BLEED LUBRICATOR, & LOWER GUN. ALL SHOTS FIRED. SIWHP = 1350 PSI. (NO REAL CHANGE AT SURFACE) 1220 REQUESTED TO POP WELL WITH PROD CONTROL, BUT THEY PREFERRED TO WAIT FOR WELL TENDER DUE TO PLANT CONSTRAINTS. RELAYED THAT 10 BBLS HCL/XYLENE WAS PUMPED DURING SQZ. 1300 RD ATLAS FROM 3-11 & MOVE TO 3-25 FOR FULL SUITE PROD L,,O_GS. PERFORATION SUMMARY: GUN DLL DEPTH FEET I 12806' - 12816' 10 ALL SHOTS WERE FIRED WITH ATLAS 3-3/8" HSC GUNS LOADED AT 6 SPF AND 60° PHASING WITH RANDOM ORIENTATION. AFTER PERFORATING & WHILE LOGGING WELL 3-25 FULL SUITE, RU MEOH PUMP TO IA ON WELL 3-11 AND BEGAN UNLOADING AT 1.0 MMSCFPD LIFT GAS. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 8 April 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL , 8~.-~_ 3-11/M-30 (SDI) ~ _[~'{ 3-29/J-32 ~-~ ~-~/~-~ DESCRIPTION 1 PLS FINAL BL+RF i PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF ECC No. Run # I 5723.13 Run # i 5933.05 Run # 1 6146.05 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 .~~~V~O Received by: Date: ~JDR ] 6 1995 ,~ska 0~) & Gs~ Cons. Commi~on Please si~n and ~eturn ~o~ Petrcteehnieal Data Cente~ BP Explocration (Alaska) 900 East Benson Boulevard ~horage, ~mska ~508 Received b~ ..... LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: 3-11/M-30 (SDI) ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: Prints/Films: 1 PFC/PERF FINAL BL+RF Date: 14 March 1996 RE: Transmittal of Data ECC #: 5723.12 Sent by: HAND CARRY Data: PFC/PERF Run # 1 Please sign and return to: Attn. Rodne¥ D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 MAR 20 to (907) 563-7803 Received by: Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 17 February 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 1 PLS FINAL BL+RF 1 PDK FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 CN FINAL BL+RF ECC No. Run # 1 5723.10 Run # 1 5945.02 Run # 1 6185.14 Run # 1 6397.12 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage/ AK 99518 Received by: . I Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 24 January 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 1 PFC/PERF FINAL BL+RF 1 SBT FINAL BL+RF ECC No. Run # 1 5723.09 Run # 1 6569.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Received by: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate _ Plugging .. Pull tubing__ Alter casing ... Repair well . Perforate × Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska)/nc. Development X KBE = 55.15 feet Exploratory 3. Address Stratigraphic __ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service Duck Island Unit/Endicott 4. Location of well at surface 8. Well number 2529' SNL, 828' WEL, Sec. 8, T11N, R17E At top of productive interval 1122' SNL, 1559' WEL, Sec. 5, T11N, R17E At effective depth 694' SNL, 1566'WEL, Sec. 5, T11N, R17E At total depth 647' SNL, 1565' WEL, Sec. 5, T11N, R17E ORIGINAL 3-11/M-30 SD/ 9. Permit number/approval number 88-87/Not required 10. APl number 50- 0029-21848 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical 13530 feet 10509 BKB feet Plugs (measured) Top of cement retainer set at 12954' Effective depth: measured true vertical 13436 feet 10427 BKB feet Junk (measured) Partially milled 7" TIW Packer w/2-7/8" "x" Nipples at 12957' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 122' 2465' 12662' Size 30" 13 3/8" 9 5/8" Cemented Measured depth True vertical depth BKB BKB Driven 161' 161' 3300 c.f. Permafrost 2504' 2504' 575 c.f. Class G 12701' 9833' 1104' 7" 320c. f. Class G 12416'- 13520' 9622'- 10500' measured true vertical 12836' - 12846', 12885' - 12900' (All open) 12868'- 12878', 12890'- 12940', 12970'- 12994', 13016'- 13030', 13040'- 13098', 13106'- 13116' (All Squeezed) (Subs,ea) 988~'- 9890; 9921'- ,99~32' (,~11 Open) ' 9987- 10006, 10022'-10024, 10042-10089', 10095'-10102' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 TDS tubing with 2 7/8" tailpipe to 12969' FEB 0 2 Packers and SSSV (type and measured depth) 9 5/8" Packer at 12397'; 4 1/2" SSSV at 1524' 13. Stimulation or cement squeeze summary Add peris 9/21/95, add peris 1/10/96, water shut off cement sque¢~'~'~'l'~'~-6, reperf 1/20/96 and scale inhibitor treatment 1/28/96. Intervals treated (measured) 12868'- 12878', 12890'- 12940', 12970'- 12994', 13016'- 13030', 13040'- 13098', 13106'- 13116' Scale inhibitor treatment: 12836'- 12846', 12885'- 12900' Treatment description including volumes used and final pressure 981 bbls fresh seawater, 19 bbls 15% HClJXylene, 22 Bbls effluent water, 14 bbls cement and 40 bbls methanol; FWSHP = 2400 psig Scale inhibitor treatment is attached. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1342 1006 12079 0 349 Subsequent to operation 6133 4242 3921 0 488 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X.. 16. Status of well classification as: Oil X Gas Suspended. . , Service 17. I hereby certify that the foregoing, i? true and correct to the best of my knowledge. Si~lned ~_.,~,~/~'~.4" .~,,.~/~ /~/~/~'~'~'~' Title Senior Technical Assistant II Form 17~4 Rev 06/15/88 Date SUBMIT IN DUPIClCATE '"' Endicott Production Engineering Department Additional Perforations DATE: 9/21/95 WELL N=: 3-11 / M-30 BP EXPLORATION REP: SERVICE COMPANY: THOMAS RUT ATLAS (DON BARBA, SAM, JOHN) DATE/TIME OPERATIONS SUMMARY 0800 MIRU AWS. INSTALL SSV FUSIBLE CAP. FWHP = 400 PSI; CHK = 176 BEAN; FWHT = 144 ~F; lAP = 1740 PSI. 0840 SHUT WELL IN. PRESSURE TEST LUBRICATOR TO SIWHP. 0850 RIH WITH GUN #1 (30 FT). SIWHP = 1500 PSI 0930 ON BOTTOM - OPEN WING VALVE AND BLEED WHP TO 412 PSI FOR UNDERBALANCE. 0945 TIE INTO DLL DATED 9/3/88 AND MAKE A +14 FT CORRECTION TO E-LINE. , 1000 DROP DOWN AND TAG PBTD AT 12950' MD. LOG A TIE-IN STRIP UP & CHECK TIE-IN. DROP BACK DOWN AND LOG UP TO TOP SHOT AT 12890' MD. 1005 SHOOT GUN #1 FROM 12890' MD TO 12920' MD. SAW STRONG CURRENT SIGNAL AND 350 LBS WEIGHT LOSS. FLOW WELL FOR 15 MINUTES @ FOC. 1020 SI WELL AND POOH. SIWHP = 1260 PSI. 1100 AT SURFACE. BLEED LUBRICATOR & CONFIRM ALL SHOTS FIRED. 1200 RDMO ATLAS TO 3-29 FOR ADD-PERFS. RETURN WELL 3-11 TO PRODUCTION OPERATIONS & REQUEST POST-PERF WELL TEST. PERFORATION SUMMARY' GUN DLL DEPTH FEET SUBZONE I 12890' - 12920' 30 2B All intervals were shot using 3-3/8" Alpha Jet guns at 6 spf, 21 gram charges, 60 degree phasing and random orientation. Endicott Production Engineering Department OPERATIONS REPORT DATE: 1/10/96 WELL N~: 3-11 / M-30 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: ADD PERFORATIONS POWERS ATLAS (BARBA) DATE/TIME OPERATIONS SUMMARY I 0930 MIRU ATLAS. 1050 SI WELL AND RIH WITH GR/CCL AND 10' GUN. SIP=900, lAP=lB00, OAP=200, WHT=125°F. 1200 OUT OF TUBING. POP WELL @ 60 BEANS. SIP=1350 PSIG. ,,, 1215 TIE-IN TO DLL DATED 9/3/88. ADD 17'. 1230 HANG CCL AT 12866' AND SHOOT GUN #1 FROM 12868-878' MD. LOG OFF. NO INDICATION THAT GUN FIRED. 1245 SI WELL AND POOH. 1330 AT SURFACE. CONFIRM ALL SHOTS FIRED AND RETURN WELL TO PRODUCTION. PERFORATION SUMMARY GUN DEPTH INTERVAL ZONE 1 12868-12878' 1 0 2B 3-3/8" ALPHA JET, 6 SPF, 60° PHASING AND RANDOM ORIENTATION. Endicott Production Engineering Department OPERATIONS REPORT DATE: 1 ~20~96 WELL N-°: 3-11/M-30 TYPE OF OPERATION' BP EXPLORATION REP: SERVICE COMPANY: RE-PERFORATE VARBLE ATLAS (BARKER) DATE/TIME OPERATIONS SUMMARY 0830 MIRU ATLAS. SIP = 1500 IA = 700 OA = 0 0930 SWAB VALVE LEAKING - STAND BY FOR GREASE TRUCK 1030 RIH WITH PFC/CCL/33'GUN -SELECT FIRE - OVERALL LENGTH45' 1147 OUT T.T. - OPEN CHOKE & BLEED SIP DOWN TO 300 PSI (APPROX. 450 LBS. UNDER BALANCED) 11 54 LOG TIE-IN PASS FROM 12900'- 12866' ADD 2'. LOG CONFIRMATION PASS - ON DEPTH. (TIED INTO CRT DATED 07-SEP-88) 1210 LOG INTO PLACE WITH CCL @ 12866' (CCL TO TOP SHOT = 19') SHOOT GUN #lA FROM 12885'- 12900'. GOOD CAP BREAK - LOST 300 PSI & GAINED 200 PSI ON WELL HEAD. LOG OFF 1221 OPEN CHOKE TO 70 BEANS & ATTEMPT TO FLOW WELL. 1231 WILL NOT FLOW - SIP =300 PSI SHUT IN & LOG TIE -IN PASS FROM 12900' TO 12778' - ADD 2' RIH TO 12900' & LOG INTO PLACE@ 12834' (CCL 2' FROM TOP SHOT) 1243 SHOOT GUN # lB FROM 12836' - 12846' GOOD CAP BREAK - LOST 100 LBS. WEIGHT. LOG OFF 1248 POOH 1334 OOH - ALL SHOTS FIRED 1430 RDMO - POP TO TEST SEPERATOR WITH G/L PERFORATION SUMMARY GUN DEPTH INTERVAL ZONE lA 12885'-12900' 15' 2B lB 12836'-12846' 10' 2B 3-3/8" ALPHA JET, 6 SPF, 60° PHASING AND RANDOM ORIENTATION. Endicott Production Engineering Department OPERATIONS REPORT DATE' 1/28/9~, WELL N-°: 3-11 / M-30 TYPE OF OPERATION: SCALE INHIBITOR TREATMENT (BAKER PRODUCTS) BP EXPLORATION REP' THOMAS RUT SERVICE COMPANY: HB&R & APC VACTRUCKS DATE/TIME OPERATIONS SUMMARY 1/28 0800 RENDEZVOUS WITH HB&R & APC AT POL TO LOAD CHEMICAL FROM TOTES. STICK METER ALL CHEMICALS INTO VAC TRUCKS AND 70 BBL DAY TANKS. VAC TRUCKS LOADING SW AT SKID 405. 0945 ARRIVE SDI WITH HB&R TO LOAD 10 BBLS MEOH. 1015 MIRU TO WELL 3-11. HOOK UP VAC TRUCKS TO FILTER SKID AND LAY HARDLINE. SI WELL IN PREP FOR TREATMENT. lAP = 1700 PSI; OAP = 240 PSI; SIWHP = 1400 PSI; CHOKE AND WING CLOSED. 1030 PRESSURE TEST HARDLINES TO 4000 PSI. PUMP TREATMENT AS PER FOLLOWING SCHEDULE: TIME RATE PRESSU RE CUM FLUID / COMMENT 1035 4 2000 0 START MS PRE-FLUSH 1040 4.6 1800 20/0 START SI-4004 IN SW 1055 4.6 1400 40 SI-4004 IN SW 1102 4.6 1350 80 SI-4004 IN SW 1115 4.6 1250 130 SI-4004 IN SW 1118 4.6 1150 162/0 SWITCH TO SW W/NE-118 11 35 4.6 1100 80 SW W/NE-118 1145 4.6 1600 120 SW W/NE-118 1148 4.1 1700 136 REDUCE RATE FOR WHP 1200 2.5 1850 172 SW W/NE-118 1205 2.0 1900 185/0 SWITCH TO TBG DISP 1230 2.0 1950 50 TBG DISPLACEMENT 1245 2.0 1950 80 1300 2.0 1950 108 1315 2.0 1950 140 1330 2.0 1950 172 1 345 2.0 1950 202/0 SWITCH TO MEOH 1 347 2.0 1950 5 207 BBLS TBG AWAY. SD. 347 I SD PUMPS. 430 I RDMO HB&R & APC VAC TRUCKS. SUMMARY: PUMPED 20 BBLS SW WITH 75 GALS SS-5206 MUTUAL SOLVENT (A VALVE BETWEEN THE TANKS LEAKED DURING TRANSPORT & 5 BBLS FLOWED OUT OF SS-5206 MIX TANK INTO MEOH TANK) I~UMPED 162 BBLS S1-4004 AS A 1:8 MIXTURE IN SW PUMPED 185 BBLS SW OVERFLUSH WITH 0.2% NE-118 PUMPED 202 BBLS SW + 5 BBLS MEOH FOR TUBING DISPLACEMENT SD PUMPS AT 1347 ON 1/28. POP WELL AT 0200 HRS ON 1/29 (+12 HRS) LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 16 January 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL D3-35/L-36 (sDi) DESCRIPTION PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF PLS FINAL BL+RF ECC No. Run # 1 5723.08 Run # 1 5921.12 Run # 1 6001.17 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 /~AX to (907) 563-7803 Received by: Date: RECEIVED Alaska Oil & Gas Cons, Commission A~3chora§e LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 13 December 1995 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL 3-11/M-30 SDI~-- 1 GR/C~ FIN~ BL+~ 1 PLS FIN~ BL+~ Run ~ 1 ECC No. 2628.12 ' ' Run ~ 1 5723.07 Run ~ 1 Run # 1 5933.04 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street SUite 201 .. Anchorage, AK 99518 ~ O/~: F~ to (907) 563-7803 Received by: ..,.-- _ ~. Date: STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate Plugging Pull tubing Alter casing Repair well .. Perforate X Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 2529' SNL, 828' WEL, Sec. 8, T11N, R17E ~ At top of productive interval 1122' SNL, 1559' WEL, Sec. 5, T11N, R17E At effective depth 694' SNL, 1566' WEL, Sec. 5, T 11N, R 17E At total depth 647' SNL, 1565' WEL, Sec. 5, T11N, R17E 6. Datum elevation (DF or KB) KBE = 55.15 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-11/M-30 SDI 9. Permit number/approval number 88-87/Not required 10. APl number 50- 0029-21848 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 13530 feet Plugs (measured) 10509 BKB feet 13436 feet Junk (measured) 10427 BKB feet Size Cemented Top of cement retainer set at 12954' Partially milled 7" TIW Packer w/2-7/8" "x" Nipples at 12957' Measured depth True vertical depth BKB BKB 122' 30" Driven 161' 161' 2465' 13 3/8" 3300 c.f. Permafrost 2504' 2504' 12662' 9 5/8" 575 c.f. Class G 12701' 9833' 1104' 7" 320 c.f. Class G 12416'- 13520' 9622'- 10500' measured 12890'- 12940' (Open) 12970'- 12994', 13016'- 13030', 13040'- 13098', 13106'- 13116' (All Squeezed) true vertical (Subsea) 9924'- 9963' (Open) 9987'- 10006', 10023'- 10034', 10042'- 10089', 10095'- 10103' (Afl Squeezed) Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 TDS tubing with 2 7/8" tailpipe to 12969' Packers and SSSV (type and measured depth) 9 5/8" Packer at 12397'; 4 1/2" SSSV at 1524' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 3211 2242 5240 0 3260 2729 6328 0 Tubing Pressure 383 383 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations __ 16. Status of well classification as: Oil X Gas__ Suspended. Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~.,/¢//'/,~...~j, '-'~--,~i~2,~,.~. Title Senior Technical Assistant II Form 10-....~' Rev 06/15/88 Date SUBMIT IN DUISLICA'TI Endicott Production Engineering Department DATE: 9/21/95 WELL N-°: 3-11 / M-30 BP EXPLORATION REP: SERVICE COMPANY: Additional Perforations THOMAS RUT ATLAS (DON BARBA, SAM, JOHN) DATE/TIME OPERATIONS SUMMARY 0800 MIRU AWS. INSTALL SSV FUSIBLE CAP. FWHP = 400 PSI; CHK = 176 BEAN; FWHT = 144 OF; lAP = 1740 PSI. 0840 SHUT WELL IN. PRESSURE TEST LUBRICATOR TO SIWHP. 0850 RIH WITH GUN #1 (30 FT). SIWHP = 1500 PSI 0930 ON BOTTOM - OPEN WING VALVE AND BLEED WHP TO 412 PSI FOR UNDERBALANCE. 0945 TIE INTO DLL DATED 9/3/88 AND MAKE A +14 FT CORRECTION TO E-LINE. ! 1000 DROP DOWN AND TAG PBTD AT 12950' MD. LOG A TIE-IN STRIP UP & CHECK TIE-IN. DROP BACK DOWN AND LOG UP TO TOP SHOT AT 12890' MD. 1005 SHOOT GUN #1 FROM 12890' MD TO 12920' MD. SAW STRONG CURRENT SIGNAL AND 350 LBS WEIGHT LOSS. FLOW WELL FOR 15 MINUTES @ FOC. 1020 SI WELL AND POOH. SIWHP = 1260 PSI. 1100 AT SURFACE. BLEED LUBRICATOR & CONFIRM ALL SHOTS FIRED. 1200 RDMO ATLAS TO 3-29 FOR ADD-PERFS. RETURN WELL 3-11 TO PRODUCTION OPERATIONS & REQUEST POST-PERF WELL TEST. PERFORATION SUMMARY' GUN DLL DEPTH FEET S U BZO N E I 12890' - 12920' 30 2B All intervals were shot using 3-3/8" Alpha Jet guns at 6 spf, 21 gram charges, 60 degree phasing and random orientation. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 29 September 2995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL 1-33/M-23 DESCRIPTION 1 PLS FINAL BL+RF 1 GR/CCL FINAL BL+RF 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL'BL+RF ECC No. Run # 1 2628.09 Run ~ 1 5709.05 Run # 1 Run # 1 5723.06 Run # 1 5933.03 _~ .... ~. . - _. ,.. ...... Run # 1 6483.02 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street R~CEIvED Suite 201 .,, Anchorage, AK 99518 0CI 04 , Received by: Date: a,,h,r~-- LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 18 September 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 3-11/M-30 SDI~'~ 1 PDK FINAL BL+RF ECC No. Run # 1 5723°05 Run # 1 5933.02 Run # 1 6452.08 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services ~~ 5600 B Street Suite 201 ~, ~ ~ Anch°rage' AK 995~83 ~2/~ ~~ /'~/~,~ Or FAX to (907) 5 -7803 Received by: ~ Date: L . ;42~ c,.~. . .~,.y~ J~iease siEnand ?etrot'echnical Data Cente~ JP Exploration (Alaska) 900 East Benson Boulevard AnchoraEe, Alaska 99508 Received by LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 20 September 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: ........................................ WELL ~~0~ # DESCRIPTION ECO No. 3-11/M-30U'~ - ~SDII~i~~ 1 LDWG TAPE+LIS Run 1 5723.05 Run # 1 5933.02 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 ~~,_ Or, to (907) 56~~03~~ Received by: ~ Date: RECEIVED Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ~LASKA OIL AND GAS CONSERVATION COMMI~51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate . . Plugging Perforate Pull tubing Alter casing Repair well Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic . Service . 4. Location of well at surface 2529' SNL, 828' WEL, Sec. 8, T11N, R17E At top of productive interval 1122'SNL, 1559' WEL, Sec. 5, T11N, R17E At effective depth 694'SNL, 1566' WEL, Sec. 5, T11N, R17E At total depth 647'SNL, 1565' WEL, Sec. 5, T11N, R17E 12. Present well condition summary Total depth: measured true vertical 6. Datum elevation (DF or KB) KBE = 55.15 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-11/M-30 SD/ 9. Permit number/approval number 88-87/Not required 10. APl number 50- 0029-21848 , 11. Field/Pool Endicott Oil Pool 13530 feet Plugs (measured) 10509 BKB feet JAN 0 3 1995 Effective depth: measured 13436 feet Junk (measured) true vertical 10427 BKB feet Alaska 0il & Gas Cons. Commission Anclmra ~,~ ~ Casing Length Size Cemented Measured depth True v~Ba depth BKB Structural Conductor 122' 30" Driven 161' 161' Surface 2465' 13 3/8" 3300 c.f. Permafrost 2504' 2504' Intermediate 12662' 9 5/8" 575 c.f. Class G 12701' 9833' Production Liner 1104' 7" 320 c.f. Class G 12416'- 13520' 9622'- 10500' RECEIVED Perforation depth: measured 12920' - 12940' (Open) 12970'- 12994', 13016'- 13030', 13040'- 13098', 13106'- 13116'(AII Squeezed) true vertical (Subsea) 9948'- 9963' (Open) 9987'- 10006', 10023'- 10034', 10042'- 10089', 10095'- 10103' (All Squeezed) Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 TDS tubing with 2 7/8" tailpipe to 12969' Packers and SSSV (type and measured depth) 9 5/8" Packer at 12397'; 7" Packer at 12951'; 4 1/2" SSSV at 1524' 13. Stimulation or cement squeeze summary Scale inhibitor treatment Intervals treated (measured) 12920'- 12940' Treatment description including volumes used and final pressure 63 Bbls diesel/mutual solvent mix, $$ Bbls. eeawater/scale Inhibitor mix, 68 Bbla. seawater/2%surfactant, 195 seawater tubing volume, and 10 Bbls meOH. FSIWHP = 300 peig 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 7670 4954 1461 0 8113 3460 1432 0 Tubing Pressure 370 397 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X . Gas Suspended 17. I hereby certify that the foregoing is~ to the best of my knowledge. Signed <~'~_~~ ~ Title sen/or Technical .4ssistan, II Form 10~ Rev 06/15/68 Service SUBMIT IN DdPLIdATE STATE OF ALASKA ALA ....-t OIL AND GAS CONSERVATION COMMISS,..., REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ' Stimulate Plugging' Perforate Pulltubing x AItercasing .... Repair well . Other ... 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska) Inc. Development X KBE = 55.15 feet Exploratory 3. Address Stratigraphic 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service Duck Island Unit/Endicoff ,, 4. Location of well at surface 8. Well number 2529' SNL, 828' WEL, Sec. $, T11N, R17E ;7-11/M-$0 SD/ At top of productive interval 9. Permit number/approval number 1122' SNL, 1559' WEL, Sec. 5, T11N, R17E 88-87/92-168 At effective depth ~ ~, I 10. APl number 694'SNL, 1566'WEL, Sec. 5, T11N, R17E ~..~.! ! ' ~ i '~ 50- 0029-21848 At total depth 11. Field/Pool 647' SNL, 1565' WEL, Sec. 5, T11N, R17E Endicott Oil Pool 12. Present well condition summary Total depth: measured 13530 feet Plugs (measured) true vertical 10509 BKB feet Effective depth: measured 13436 feet Junk (measured) true vertical 10427 BKB feet Casing Length Size Cemented Measured depth True ve_r~i.c~l depth Structural BKB Conductor 122' 30" Driven 161° 161' Surface 2465' 13 3/8" 3300 c.f. Permafrost 2504' 2504' Intermediate 12662' 9 5/8" 575 c.f. Class G 12701' 9833' Production Liner 1104' 7" 320 c.f. Class G 12416' - 13520' 9622'- 10500' Perforation depth: measured 12920'- 12940', 12970'- 12994', 13016'- 13030', 13040'- 13098', 13106'- 13116' true vertical (Subsea) 9948'-9963', 9987'- 10006', 10023'- 10034', 10042'- 10089', 10095'- 10103' Tubing (size, grade, and measured depth) 4 1/2" 12.6# 13CR80 tubing to 12501°MD Packers and SSSV (type and measured depth) 9 5/8" TIW 'HBBP' Packer at 12356'; 4 1/2" Otis 9CR 'HXO' SVLN @ 1502' MD R E C E IV E L~i 13. Stimulation or cement squeeze summary Intervals treated (measured) ~(~T ii 0 i!~4' .,,,...~,,,. G,~ Con~;. Commissiop, Treatment description including volumes used and final pressure ^nch0r;,~,e 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation '"15.'Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations . Oil X Gas Suspended Service , 17.1 hereby Certify that the.f~ing is true a~d correct to the best of my knowledge. ~ ~./~?~" .~ Signed ;~ ~ :~'~.~ Title Drilling Engineer Supervisor/,~" ~'~~ Date/~ ~/~'~ ~' ~ Form 10'-~.04 Rev 06/15/88 SUBMIT IN DUPLICATE BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: SDI 3-11/M-30 BOROUGH: NORTH SLOPE UNIT: ENDICOTT FIELD: ENDICOTT LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 08/25/94 09:00 SPUD: RELEASE: 09/07/94 12:00 OPERATION: DRLG RIG: WO/C RIG: DOYON 15 08/26/94 ( 1) TD:13520 PB:13436 08/27/94 (2) TD:13520 PB:13436 08/28/94 (3) TD:13520 PB:13436 08/29/94 (4) TD:13520 PB:13436 NU BOPE MW: 9.1 NaCl/Br MOVE IN RU. BERM, HOOK UP LINES T/SLOP TANK. HOOK UP CHOKE & KILL LINES. PULL BPV W/LUBRIC. SICP/350PSI. SHUT-IN TBG PRESS. PUMP 180 BBLS 9.1 BRINE DOWN TBG, TAKE ON OIL & GAS RETURNS T/SLOP TANK. SHUT DOWN. SICP0 300PSI. MIX SALT/TAKE ON BRINE & SHUT DOWN. CHK PRESS. BULLHEAD 134 BBLS DOWN TBG. BULLHEAD 150 BBLS SW & 239 BBLS BRINE DOWN ANNUL. PRESS BUILT T/950 ON ANNUL. SHUT DOWN. PRESS BLED T/100PSI. PUMP 9.1 BRINE DOWN TBG. TAKE RETURNS THRU CHOKE T/PITS. SWITCH T/SLOP TANKS AFTER 136 BBLS. TIL 9.1# RETURNS. SWITCH RETURNS T/PITS TIL 40 BBLS. SHUT DOWN/MONITOR WE;;. STABLE. SET 2-WAY CHECK. ND TREE. CHECK THREADS IN HNGR. N]~ TREE. RIH W/FTA #1 MW: 9.1 NaCl/Br NU BOPE - TEST. RU LUBRICATOR & PULL BPV. MU LANDING JT. FILL TBG & ANNUL PULL HNGR T/FLOOR. CIRCULATE. LOST 76 BBLS/30 MIN. MONITOR WELL. TAKING ON 12 BBLS PER MINUTE. LAY DOWN TBG. RD CL SPOOL UNIT. LD TBG/ 220 JTS 17.65 CUTOFF. MU FTA #1. RIH T/2500. CUT DL. RIH W/FTA #1. POOH W/PBR MW: 8.9 NaCl/Br RIH T/8743. SPEAR INTO FISH. CBU. CUT BRINE WT T/8.9. OBSERVE. POOH SLM. NO CORRECTION. SERV. RIG. RU & LD 91 JTS TBG. 4 GLM, A SLIDING SLEEVE & 2 CUT OFFS. CHANGE GRAPPLE ON SPEAR. RIH T/9269. PU 98 JTS OF 3.5" DP. TAG FISH @12364. SPEAR INTO FISH. SHEAR PBR W/45K. CIRC. LOST 105 BBLS BRINE TIH. LOST 52 BBLS/HR. WHILE CIRC. POOH W/PBR. RIH W/O' SHOT MW: 8.7 NaCl/Br POOH LD 3.5" CUTOFF & 4' OF SEAL ASSY W/3 SETS OF SEALS. RIH T/12387. SPEAR INTO CUTOFF ABOVE PKR. WORK PIPE. PULL PKR FREE W/130K OVER STRING WT. CBU REDUCE BRINE W/T/8.65. POOH SWAB'NG BAD. ACTUAL FILL = 151 BBL. LD SEAL ASSY GUIDE RECEPTICLE, PKR W/3.5" BUTT COLLAR ON BTTM. LD JARS. CHANGE FTA #4. RIH. W/O'SHOT. WELL : SDI 3-11 OPERATION: RIG : DOYON 15 PAGE: 2 08/30/94 (5) TD:13520 PB:13436 NO REPORT TODAY NO REPORT AS OF 10 AM 8-30-94 MW: 8.7 NaCl/Br 08/31/94 (6) TD:13520 PB:13436 09/01/94 (7) TD:13520 PB:13436 09/02/94 ( 8) TD:13520 PB:13436 09/03/94 (9) TD:13520 PB:13436 09/04/94 (10) TD:13520 PB:13436 RIH W/NEW SHOE MW: 8.7 NaCl/Br RIH T/12952. MILL OVER PKR. MADE 2' IN 2 HRS. 800 AMPS TRQ. TRQ FELL T/350 AMPS DURING 3.5 HRS. PUMP DRY JOB. POOH SERV. RIG. CHK TOP DRIVE. POOH CHANGE SHOE, CLEAN BB. CALC. FILL 92 BBLS. ACTUAL=il7. RIH. CUT DL. RIH. WORK ON DWKS BLOWER MOTOR BRACKET. RIH. POOH W/FISH MW: 8.6 NaCl/Br RIH W/MILL SHOE T/12954. MILL ON PKR. POOH T/10000. SERVICE IRON ROUGHNECK. POOH & LD MILL SHOE. NO SIGN OF WEAR ON MILL. PU TAPER TAP ASSY. RIH. SERVICE RIG. RIH. LATCH ONTO FISH W/TAP @12954. ROTATE & RELEASE LATCH ON TOP OF PKR. POOH SLOWLY W/FISH.~ MILL ON 7" PKR MW: 8.6 NaCl/Br POOH & LD TIW FISH. (PACKER LATCH) & FISHING TOOLS. RIH T/2000 W/6" PKR MILL ASSY. CUT DL. PUH T/TOP OF 7" PKR @12951. MILL ON PKR T/12957. POOH STINGER ON BTTM OF MILL HAD BTTM OUT INSIDE OF ID OF PKR. CLEAN BOOT BKTS & PU NEW 6" MILL W/O STINGER. RIH. CON'T MILLING ON PKR @12957. TRIP OUT TOOK 163 BBLS T/FILL. RIH W/CMT RETAINER MW: 8.6 NaCl/Br MILL ON 7" TIW PACKER @ 12957'. SERVICE RIG. POH. L/D MILL & P/U TAPER TAP. RIH TO 3000'. CUT DRILL INE. RIH TO 12957'. ESTABLISH INJECTION RATE @ 5 BPM, 500 PSI, STAB INTO FISH & ESTB RATE@ 5 BPM 900 PSI. SET TAPER TAP IN FISH W/30 K WEIGHT DOWN ON FISH, ROTATE BUT SEEN NO TORQUE. POH (NO FISH) MARKS ON TAP SHOWED HAD FISH & PULL OUT. L/D TOOLS, CLEAR FLOOR. SERVICE RIG. P/U HALLIBURTON CMT RETAINER & RIH ON 3-1/2" DRILL PIPE XO TO 5" DRILL PIPE. RIH W/BIT & SCRAPER MW: 8.6 NaCl/Br RIH W/CMT RETAINER & SET @ 12954'. R/U HALLIBURTON & PUMP CMT, REV OUT EXCESS CMT. P OH TO 12000'_ CIRC TO CLEAR DRILL PIPE OF CMT. SERVICE. POH L/D 3-1/2" DRILL PIPE. L/D 6-3/4" DC'S & HWDP. RIH W/6" BIT & 9-5/8" SCRAPER TO 2500'. CUT DRILL LINE. RIH TO 12954' TOP OF RETAINER (NO FILL). R/U & REVERSE CIRC TO CLEAN 8.6 PPG BRINE. WELL : SDI 3-11 OPERATION: RIG : DOYON 15 PAGE: 3 09/05/94 (11) TD:13520 PB:13436 09/06/94 (12) TD:13520 PB:13436 09/07/94 (13) TD:13520 PB:13436 09/08/94 (14) TD:13520 PB:13436 POH LD DRILL PIPE MW: 8.6 NaC1/Br REVERSE CIRC TO CLEAN 8.6 PPG BRINE. POH TO 5600'. REPAIR CHAIN ON DRAWORKS. CONTINUE POH L/D 3-1/2" DRILL PIPE & COLLARS. CLEAR FLOOR OF SCRAPERS & TOOLS. P/U HALLIBURTON 9-5/8" RTTS. SERVICE RIG. RIH SET RTTS @ 12406' = 10' ABOVE 7" LINER. TEST CSG TO 3500 PSI/30 MIN (OK) UNSET RTTS. POH LD ALL DP FOR MOVE. RIH W/CHROME TBG MW: 8.6 NaCl/Br POH L/D DRILL PIPE. L/D HALLIBURTON RTTS. CUT DRILL LINE. PULL WEAR RING, SERVICE RIG. R/U & RIH W/273 JTS 4-1/2" CHROME TBG. P/U BALL VALVE, TEST CONTROL LINES TO 5000 PSI. RIH W/TBG & CONTROL LINE. FREEZE PROT W/DIESEL MW: 8.6 NaCl/Br RUN 4-1/2" CR 13-80 TBG 310 JTS, MU/HANGER. REVERSE CIRC COREXIT INHIBITOR TO TBG ANNULUS. R/U & TEST CONTROL LINES TO 5000 PSI, LAND TBG, L/D LANDING JT. N/D BO (REMOVE ALL RAMS, BREAK CAP ON HYDRILL, BREAK ALL FLANGES. NU TREE. TEST CONTROL LINE & TREE TO 5000 PSI. R/U DSM & PULL TWC. DROP BALL, SET PACKER & TEST TBG TO 3500 PSI. TEST BACK SIDE TO 3500 PSI. SHEAR RP VALVE @ 2900 PSI, DISPLACING TO DIESEL FOR FREEZE PROT. RIG RELEASED MW: 8.6 NaCl/Br PUMP 103 BBLS DIESEL DOWN TBG ANNULUS. RU & U-TUBE ANNUL. T/TBG. PUMP 20 BBLS DIESEL T/OUTER ANNUL. RD & RELEASE RIG @12:00 HRS ON 9/7. SIGNATURE: (drilling superintendent) DATE: ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 2 September 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 0 SDI 1 CCL/TUBCUT FINAL BL 1 CCL/TUBCUT RF SEPIA Run # 1 Run # 1 ECC No. 5723.04 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Received Date: Please sign and retur~ to: Petrotechnical Data Center BP Exploration (Alaska) Inc 900 East Benson Boulevard Anchorage, Alaska 99~08 ~'ee e ired by '~'te RECEIVED ~AY 1 7 1994 Alas~a Oil & Gas Cons. Commission Anchorage ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHOP~AGE AK, 99501. USA Date: 3 May 1994 RE: Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ DESCRIPTION 1 PLS FINAL BL //~ PLS FINAL RF SEPIA ECC No. 2-62/Q-17 (MPI) Run # ! 4297.04 Run ~ 1 3-11/M-30 SDI 1PLS FINAL BL · Run # 1 6191.00 PLS FINAL RF SEPIA Run # 1 Run # 1 5723.03 Run ~ 1 2-08/K-16 MPI /~1 SPINR/TEMP FINAL BL SPINR/TEMP RF SEPIA Run # 1 6175.01 Run ~ 1 1 PLS FINAL BL 1 PLS FINAL RF SEPIA Run # 1 5764.03 Run # ! 1 PLS/SPNR FINAL BL 1 PLS/SPNR RF SEPIA Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D.. Paulson Received by: Date: Please sign and return to: Sonya Wallace (MB 3-3) Petrotechnical Data Center BP Exploration (Alaska) Inc. 900 East Benson Boulevard Anchorage, Alaska 99508 Received by: Date: ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 16 March 1994 RE: Transmittal of Data ECC #: 5723.02 Data: PL Dear Sir/Madam, Reference: BP o 3-11/M-30 SDI ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 1 Sent by U.S. MAIL PLS LEAKDET.FINAL BL PLS ~LEAKDET~ RF SEP IA Run # 1 Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Date:Received by: ~'~~i C/ ~.~ ~/~~C~~.,/~....~ j~ /~~,. ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 6 December 1993 RE: Transmittal of Data ECC #: 5723.01 Data: PDK-PORO Dear Sir/Madam, Reference: BP 3-11/M-30 SDI ENDICOTT Enclosed, please find the data as described below: Tapes/Diskettes: 1 Sent by U.S. MAIL PDK LDWG TAPE+LISTER Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: RECEIVED DEC 0 ? 1.99~ Alaska Oil & ~as Cons. Cor~,~n/s.~,o, Anchorage This is to acknowledge--receipt of the following p~-'nts and negatives. COMPANY: STATE OF ALASKA ATTENTION: LARRY GRANT FIELD: ENDICOTT WELL - LOG DESCRIPTION PRINTS NEGS. SEPIA 1-51/V-20 ~PERF~PFC CCL ~,, ~%~%o~ 1~ ~L~ 0 1 2-66/SD-12 SBT/GR/CCL ~,, ~5qO~1 ~%~q~ 0 1 3-05/0-29 PLS ~INJECTION~ 5" 1 0 1 3-11/M-30 DDK-100/~%/~U 5" ~%700 L }~6 0 1 · . v ; 1993 " SIGNED . _ j . . DATE Please return one copy of signed transmittal to each of the following: Atlas Wireline Services Pouch 340013 Prudhoe Bay, AK 99734 BP Exploration (Alaska) Inc. Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 FT\RTNCARD1 BLUELINE AND SEPIA INFORMATION TO THE STATE ENDICOTT FIELD ONLY WELL NAME DATE INTERVALS LOG NAME RUN NO COMPANY NAME // 1-35/O-25J'.~-I~q 1 0/1 6/92 1-43/P-26 ~J--Io~ 9/28/92 1-47/Q-21~1) I 1 0/1 3/92 1-67/T-20~-I~ 9/26/92 2-28/P-19~J-~ ~ 10/15/92 ~1-1~ 2-54/Q-12 9/29/92 3-07/N-28~1~ 9/27/92 -~x3-11/a-30~-~ 10/14/92 .)4-04/T-26 ~¢~ 9/28/92 37~ 4-06/Q-32~ 1 0/3/92 4-44/M-44 ~.~ ~ 9/27/92 9/17/92 SAG DELTA NORTH ONLY 2-32/SN-03,%.41~1 9/19/92 12100'-13150' 12900'-14275' 10750'-11200' 11315'-11600' 9650'-10350' 10620'-12063' 13050'-13300' 12800'-13380' 13000'-14030' 10800'-11482' 13600'-14226' 14000'-14225' 12900'-13278' PDK-100 Gamma Ray/CCL (Borax)~-" Injection Profile Survey Production Logging .~ PFC Gamma Ray PDK-100 Gamma Ray/CCL (Borax) Injection Profile Warm Back Injection Profile Survey ~ . prOduction Logging Injection Profile Survey Production Profile - Pump-In-Temperature Survey PFC//Gamma Ray ~ Production Profile Survey Atlas Wireline Camco Atlas Wireline Atlas Wireline Atlas Wireline Camco Camco Atlas Wireline Camco Camco Camco Atlas Wireline Camco " RECEIVED OCT 5 0 1992 Alaska 0il & Gas Cons. C0mmissi0n Anchorage ALA~,,,A OIL AND GAS CONSERVATION COMMISS.,.,. ~ STATE OF ALASKA ORIG L REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown . Stimulate X Plugging Perforate Pull tubing .. AItercasing Repair well Other 5. Type of Well: Development _.~ Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 55.15 feet 7. Unit or Property name Duck Island Unit/Endicott 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 8. 2529' SNL, 828' WEL, Sec. 8, T11N, R17E At top of productive interval 1122'SNL, 1559' WEL, Sec. 5, T11N, R17E At effective depth 694'SNL, 1566' WEL, Sec. 5, T11N, R17E At total depth 647' SNL, 1565' WEL, Sec. 5, T11N, R17E 12".' present well conditi~'~'"s~'r~'mary Total depth: Well number 3-11/M-30 SDI 9. Permit number/approval number 88-87/92-168 10. APl number 50- 0029-21848 11. Field/Pool Endicott 0/I Pool measured 13530feet Plugs (measured) true vertical 10509 BKBfeet measured 13436feet Junk (measured) true vertical 10427 BKBfeet Effective depth: Casing Length Size Cemented Measured depth True ve~¢~ depth BKB Structural Conductor 122' 30" Driven 161' 161' Surface 2465' 13 3/8" 3300 c.f. Permafrost 2504' 2504' Intermediate 12662' 9 5/8" 575 c.f. Class G 12701' 9833' Production Liner 1104' 7" 320c. f. Class G 12416'- 13520' 9622'- 10500' measured 12920'- 12940', 12970'- 12994', 13016'- 13030', 13040'- 13098', 13106'- 13116' true vertical (Subsea) 9948'- 9963', 9987'- 10006', 10023'- 10034', 10042'- 10089', 10095'- 10103' Perforation depth: Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 TDS tubing with 2 7/8" ta/Ip/pe to 12969' Packers and SSSV (type and measured depth) 9 5/8" Packer at 12397? 7" Packer at 12951'; 4 1/2" SSS Vat 1524' 13. Stimulation or cement squeeze summary Scale inhibitor treatment Intervals treated (measured) 12920'- 12940', 12970'- 12994', 13016'- 13030', 13040'- 13098', 13106'- 13116' Anch0ra~d6 Treatment description including volumes used and final pressure 540 Bbls Scale Inhibitor, 100 Bbls seawater pad, 766 BblsCalclum chloride water spacer and 1869 seawater overflush. FSIWHP=350 PSId Prior to well operation Subsequent to operation 14. Representative Daily Average Produ~ion orlnje~ion Data OiI-Bbl Gas-Mcf WateroBbl Casing Pressure Tubing Pressure 3359 2750 5481 0 546 1104 1096 5390 0 379 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Service Date SUBMIT IN DUP[..IC'ATE- 16. Status of well classification as: Oil ...X Gas. Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned ~~ ~. //~~.',~ Title SeniorTechnicalAssistantll Form 10-A'(~' Rev 06/15/88 AL^~,A OIL AND GAS CONSERVATION COMMISS,,~.',J APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair wel~ Plugging __ Time extension __ Stimulate x ~ c' ~ Change approved program ~ Pull tubing_ Variance__ Perforate__ Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X ,. Exploratory __ Stratigraphic __ Service 4. Location of well at surface 2529' SNL, 828' WEL, Sec. 8, T11N, R17E At top of productive interval 1122' SNL, 1559' WEL, Sec. 5, T11N, R17E At effective depth 694' SNL, 1566' WEL, Sec. 5, T11N, R17E At total depth 647' SNL, 1565' WEL, Sec. 5, T11N, R17E 12. Present well condition summary Total depth: measured true vertical RECEIVED JUL - 1 1992 Alas~ 0il .& 6as Cons. C0mmissi0~ ch0rage 13530 feet 10509 BKB feet Plugs (measured) 6. Datum elevation (DF or KB) KBE -- 55.15 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-11/M-30 SDI 9. Permit number 88-87 10. APl number 50- 0029-21848 11. Field/Pool Endicott Oil Pool feet Effective depth: measured 13436 feet true vertical 10427 BKB feet Junk (measured) Casing Length Size Cemented Measured d~?~ Structural Conductor 122' 30" Driven 161' Surface 2465' 13 3/8" 3300 c.f. Permafrost 2504' Intermediate 12662' 9 5/8" 575 c.f. C/ass G 12701' Production Liner 1104' 7" 320 c.f. C/ass G 12416' - 13520' Perforation depth: measured 12920'- 12940'; 13016'- 13030'; 13106'- 13116'; 12970'- 12994'; 13040'- 13098' Tru eBv~ical depth 161' 2504' 9833' 9622'- 10500' true vertical (Subsea) 9948', 9963'; 10023'- 10034°; 10095'- 10103'; 9987'- 10006'; 10042'- 10089' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 TDS tubing with 2 7/8" tailpipe to 12969' Packers and SSSV (type and measured depth) 9 5/8" Packer at 12397'; 7" Packer at 12951'; 4 1/2" SSSV at 1524' 13. Attachments Description summary of proposal X Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation July, 1992 1 ~i' If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas~ Suspended~ Sewice 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signe~.~,~~-~/~ ~,~;~_,,/ Title SeniorTechnicalAssistantll /~ FOR COMMISSION USE ONLY Condit~ns of approval: Notify Commission so representative may witness Plug integrity__ BOP Test~ Location clearance ~ Mechanical Integrity Test Subsequent form required 10- ¥0,~ Approved by order of the Comm~ Form 10-403 Rev 06/15/88 ' -- -- ~-" ~'--~'- J Approval No. Approved ICnpy ?~,~-' Returned Commissioner ? / ' ~ I SUBMIT IN TRIPLICATE ENDICOTT FIELD Well :~-11/M-30 Two of the three wells which were treated with Nalco's 91VM-057 scale inhibitor last year are likely to require retreatments this year, as originally planned. Designs for these retreatments have been prepared by Nalco, and are attached for your reference. Current plans are to arrange with Nalco to prepare and transport 58 drums of Nalco's 91VM-057 inhibitor from their Sugarland, Texas processing facility to Anchorage. The chemical will be stored until the specific retreatment time is finalized. Having this chemical available in Anchorage storage will enable us to respond quickly once Nalco confirms the need for retreatment. The two subject wells are 3-11/M-30 and 3-23/N-32.- Recently analyzed residual returns for well 3-11/M-30 have shown a level of <3 ppm chemical in the production stream for the past two analyses. Cumulative produced water since the squeeze treatment should exceed the design volume within the next two months. The inhibitor volume pumped in 3-23/N-32 last August was limited to 15 drums due to chemical availability, for an estimated treatment life of less than one year. While residual analyses to date have remained at or near the 10 ppm effective level, a retreatment for this well is also likely for this year. The remaining well treated by Nalco, 3-33/K-37, still shows good residual returns, and should not require another treatment until next year. 'Anchorage 2652/DVT Nalco Scale Inhibitor Squeeze Procedure Well 3-11/M-30 Retreatment PRE-TREATMENT OPERATIONS , Please contact J. D. Dyess in Anchorage at 696-4690 for the necessary arrangement to be made for the treatment and flowback analysis. 2. Obtain well test at normal recommended rate prior to treatment. Ensure WC sample is taken. SCALE INHIBITOR TREATMENT 1. Mix or obtain fluids as detailed on attached treatment fluids sheet. . MIRU for bullhead treatment. Pump the following without exceeding frac gradient. Avoid shutting down during the treatment. Evidence indicates that even brief shut-downs of 5-10 min have an adverse affect on the treatment. a. 41 drums Nalco oligomer scale inhibitor in 483 bbls seawater b. 100 bbl SW spacer c. 800 bbl 2% CaCI2o2H20 in SW d.1838 bbl SW ovedlush Displace to within 10 bbls of top perforation (approximately 199 bbls). Consider using SW for displacement and minor diesel freeze protection volume if GLT is available to return well to production. Note: Filter all fluids that are to enter the peals to 3 p, preferably on the fly while pumping the job. 3. RDMO. Leave the well shut in for 24 hours. 4. POP well to test separator for 24 hrs. and arrange with Nalco to monitor returns. Nalco will pull brine samples for inhibitor flowback evaluation, per the following schedule. · Every 2 hrs for 1st 24 hrs · Every 6 hrs for next 24 hrs · Every 12 hrs next 48 hrs · Every 24 hrs next 3 days · Twice weekly for two weeks · Montly thereafter Nalco will mark each sample with date and time pulled and analyze the brine samples at the Endicott production lab. Please note on telex when the well is actually POP'd. . After the last 24 hr sample has been obtained (,,-8th day), set a DH corrosion coupon in the tubing tailpipe or sliding sleeve to monitor scale inhibitor effectiveness. POP at recommended rate and obtain a welltest. Ensure that a watercut sample is pulled during the test. 6. Pull the downhole coupon monthly, as operations permit, and inspect for scale deposition. 2652/DVT RECEIVED J U L - 1 ' 992 Alaska 0il & Gas Cons. C;0mmissioH /~nch0rage NALCO SCALE INHIBITION PROGRAM TREATMENT FLUID SUMMARY Well 3-11/M-30 Retreatment NALCOOLIGOMER. 91VM-057 Volume: 537 bbls Dilute 41 drums (2255 gal) of Nalco's oligomer with 483 bbls of seawater in a clean stainless steel vac truck equipped with mixing paddles. Mix thoroughly. CaCI?2H20 Volume: 800 bbls Add approximately 5712 lbs CaCI2 to seawater to make 800 bbls of a 0.2% solution of CaCI2. Adjust pH with NaOH to ~9. SEAWATER SPA(~ER/OVERFLI. ISH Add non-ionic sudactant to seawater. Volume: 1838 bbls Ser vice Company BJ Halliburton Dowe II/Sch lu mberge r Product Name NE-18 Losurf 300 F-75N Concentration 0.2% 0.2% 0.2% 2652/DVT RL ¢EIV[D d UL - 1 1992 Alaska Oil & Gas Cons. CDmmissio~i Anchorage STATE OF ALASKA ALA~r~A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2529'SNL, 828'WEL, Sec. 8, T11N, R17E At top of productive interval 1122'SNL, 1559' WEL, Sec. 5, T11N, R17E At effective depth 694'SNL, 1566' WEL, Sec. 5, T11N, R17E At total depth 647' SNL, 1565' WEL, Sec. 5, T11N, R17E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 55.15 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-11/M-30 SDI 9. Permit number/approval number 88-87 10. APl number 50- OO29-21848 11. Field/Pool Endicott Oil Pool !2. Present well condition summary Total depth: measured true vertical 13530feet 10509 BKBfeet Effective depth: measured 13436feet true vertical 10427 BKBfeet Plugs (measured) Junk (measured) Casing Length Size Cemented Structural Conductor 122' 30" Driven RECEIVED ,S c P 0 4 P.91 Measu~'dKBdepth Anchorage 161' 161' Surface 2465' 13 3/8" 3300 c.f. Permafrost 2504' 2504' Intermediate 12662' 9 5/8" 575 c.f. C/ass G 12701' 9833' Production Liner 1104' 7" 320 c.f. Class G 12416'- 13520' 9622'- 10500' Perforation depth: measured 12920'- 12940'; 13016'- 13030? 13106'- 131167 12970'- 12994'; 13040'- 13098' true vertical (Subsea) 9948'- 9963~ 10023'- 10034? 10095'- 10103? 9987'- 10006? 10042'- 10089' Tubing (size, grade, and measured depth) 4 1/2" 12.6,~ L-80 TDS tubing with 2 7/8" tailpipe to 12969' Packers and SSSV (type and measured depth) 9 5/8" Packer at 12397'; 7" Packer at 12951'; 4 1/2" SSSV at 1524' 13. Stimulation or cement squeeze summary Scale inhibitor treatment Intervals treated (measured) 12920'- 12940', 13016'- 13030', 13106'- 13116', 12970'- 12994', 13040'- 13098' 14. Treatment description including volumes used and final pressure 249 bbls. scale inhibitor 100 bbls seawater pad w/surfactant, 498 bbls. Calcium chloride water spacer, 571 bbls. seawater overflush w/surfactant. FSAlYHP = 700psi .Representative Daily Average Production or Injection Data. OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3583 2921 2389 0 980 Subsequent to operation 2358 2034 2358 0 905 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~"~"f~'~'-'---~~, Title Endicott Operations and Production Lead Engineer Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE JOHN BOYLE July 10, 1991 Page 2 WELL 1-63/T-22 12100'-13088' STATIC TEMPERATURE SURVEY WELL 2-04/M-19 9800'-10680' TDT SCHWMBERGER WELL 2-08/K-16 11670'-12038 TEMPERATURE SURVEY HRS WELL 3-01/N-29 I I 650'-1 2931' PRODUCTION PROFILE WELL 3-11/M-30 12695'-13395' TDT SCHLUMBERGER WELL 3-21/L-34 12200'-12850' PRODUCTION PROFILE WELL 3-27/M-33 11550'-12070' STATIC TEMPERATURE SURVEY 11500'-12071 ' PRODUCTION PROFILE WELL 3-33/K-37 12100'-13284' PRODUCTION PROFILE 6/1 0/91 RUN Ct~IE 6/29/91 RUN RVE 5/24/91 RUNCNE 6/5/91 RUN ONE '6/30/91 RUNTHREE 6/1 7/91 RUNONE 6/11/91 RUN ONE 6/9/91 RUNONE 6/6/91 RUNONE 2063/JLH/clt June 13, 1991 Alaska Oil and Gas Conservation Commission Page 4 WELL 3-07/N-28 / TEMPERATURE SURVEY V 12500'-13360' 5/21/91 RUN ONE WELL 3-11/M-30 PRODUCTION PROFILE 12700'-13381' WELL 3-21/L-34 COLLAR LOG V 11010'-12575' ATLAS WIRELINE WELL 3-27/M-33v/. Y'~ 11 700'-11850' ATLAS WlRELINE 12195'-12985' SCHLUMBERGER ~ k~ SPINNER ~/ J ~ 12200'-12680' ,/j :,\ 11880-12680' WELL 3-33/K-37 PERFORATING RECORD WELL 3-49/J-40 PUMP IN TEMPERATURE SURVEY V' 14316'-14940' 4/4/91 · RUNONE 5/29/91 RUNONE 5/1 7/91 RUN ONE 5/14/91 RUN ONE 4/9/91 RUN ONE 4/9/91 RUNONE 5/27/91 RUNONE 2013/JLH/clt John Boyle Alaska Oil and Gas Conservation Commission Page Two WELL 2-34/P-14 LEAK DETECTION 9100'-10900' 3/3/91 RUNONE WELL 2-44/R-12 INJ 11 900'-12340' 3/2/91 RUN ONE WELL 3-11/M-30 (~R SURF-1495' 3/28/91 RUN ONE WELL 3-23/N-32 PROD-F 11200'-11660' WELL 3-2g/J-32 HRS 11950'-12700' SPINNER WELL 4-08/P-27 PROD-F 13000'-13710' 3/27/91 RUN ONE 3/22/91 RUN ONE 3/26/91 RUNONE WELL 2-26/N-! 4 *PRODUCTION PROFILE / 11450'-11950' CAMCO 7/16/90 Run No. I WELL 2-:36/C)-14 *PRODUCTION PROFILE 10900'- 11200' CAMCO 7/14/90 Run No. 1 WELL 2-44/R-12 7/18/90 *.INJECTION PROFILE SURVEY 11 300'-1 2708' Run No. 1 CAMCO .-WELL 2-46/Q-15, 7/29/90 / ';PERFORATi~(~ RECORD 10855'-11071' Run No. 1 ATLAS ...--WELL 3-11/M-30 *DUAL BURST TDT LOG 12675'-13400' SCHLUMBERGER 7/29/90 Run No. 1 WELL 3-15/K-33 ~*CCL LOG 11 543'-11885' CAMCO 7/17/90 Run No. 1 WELL 4-26/0-34 *WATER FLOW LOG 10190'-11620' SCHLUMBERGER 8/5/90 Run No. 1 RECEIVED AUG 2 2 1990 Alaslm 0il & Gas uons. Anchorage *OAMMA RAY SURVEY 11600' - 12350' Camco 6/25/90 Run No. 1 *PRODUCTION PROFILE 6/28/90 11700' - 12350' Run No. 1 Camco WELL 3-11/M-30 6/2~)/~0 *DUAL BURST TDT LOG (TDT-P) 12675' - 13395 Run No. 1 Schlumberger WELL 3-21/L-34 7/2/90 *DUAL BURST TDT LOG (TDT-P) 12290' - 12834' Run No 1 Schlumberger WELL 3-27/M-33 5/19/90 *DUAL BURST TDT LOG (TDT-P) 11500' - 12070' Run No. 1 Schlumberger *WATER FLOW LOG SERVICE (TDT-P) 11500' - 12070' Run No. 1 Schlumberger WELL 3-35/L-36 7/1/90 *DUAL BURST TDT LOG (TDT-P) 11980' - 12390' Run No. 1 Schlumberger *WATER FLOW LOG SERVICE (TDT-P) 11980' - 12390' Run No. 1 Schlumberger WELL 3-41/K-39 *TEMPERATURE LOG 12900' - 13650' Camco 5/7-8/90 Run No. 1 5/19/90 7/1/90 *INJECTION PROFILE TEMP WARM BACK 13200' - 13669' Run No. 1 Camco ,, WELL 4-04/T, -26 *RADIO ACTIVE TRACER LOG 13530' - 14027' Run No. 1 Schlumberger 6/12-13/9O A U G -- 2 19~0 Alaska 0il & fias Cons. Con. nission Anchorago BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 December 19, 1989 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Endicott Field - Bottom-Hole Pressure Reports Dear Sirs: Enclosed are Bottom Hole Pressure Reports for the following wells. Well Name Date- ~2-22/L- 14 10/23/89 2-52/S-14 11/24/89 3-05/0-29 11/27/89 3-11/M-30 10/28/89 3-35/L-36 11/11/89 4-14/R-34 10/22/89 5-03/SAG 9 11/24/89 5-03/SAG 9 11/25/89 If there are any questions regarding this data, please contact Dave MacDonald at 564-4697. RECEIVED DEC~ 11989 Alaska Oil & Gas Cons. C0mm'tssiO~ Anchorage BP EXPLORATION BP Exploration (Alaska) Inc, 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 December 4, 1989 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle: Enclosed please find one sepia and one blueline print for the well logs run in the following Endicott wells: WELL 4-04/T-26 *PFC LOG 12950'- 14016' Run No. 1 ATLAS WIRELINE SERVICES WELL 3-11/M-30 *PRODUCTION PROFILE LOG 12800'-13200' Run No. 1 CAMCO WELL 3-45/M-39 SDI *INJECTION PROFILE TEMPERATURE SURVEY 11880'-12700' Run No. 1 CAMCO WELL 1-41/0-23 *PRODUCTION PROFILE 11400' - 11900' CAMCO Run No. 1 DEC - 19tl9 Alaska Oil & Gas Cons. C0mmissi.0_r Anchorage BP EXPLORATION July 28, 1989 BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 End[c~,tt, Fielcl- B0tt0m-H01e Pressure Reports Dear Sirs: Enclosed are Bottom Hole Pressure Reports for the following wells in the Endicott Reservoir: Well Name Date 2-70/U- 15 06-14-89 3-11/M-30 07-09-89 3-33/K-37 07-10-89 3-39/J-39 07-10-89 If there are any questions regarding this data, please contact Dave MacDonald at 564-4697. Sincerely, anne L. Haas JLH/lms cc: File 06.10 1061/JLH WELL 3-11/M-30 *TEMPERATURE SURVEY 12700'-13385' Run 1 CAMCO WELL 5-01/SAG 7 *DUAL BURST TDT LOG (TDT-P) ~ 11750'- 12355' Run 2 ~I~11750'-12357' Run 3 ~CHLUMBERGER WELL 1-29/M-25 *DUAL BURST TDT LOG (TDT-P) 13100'-14087' Run 1 SCHLUMBERGER WELL 3-05/0-29 *DUAL BURST TDT LOG (TDT-P) · 11445'-12566' Run 2 SCHLUMBERGER WELL 1-43/P-26 NI~ *DUAL BURST TDT LOG (TDT-P) 13000'-14263' Run 2 SCHLUMBERGER Sincerely, GND/Ims cc' Fi le 06.10 1092/GND BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 May 23, 1989 Mr. J. Boyle AOGCC 3001 Porcupine Dr. Anchorage, Alaska 99501 Dear Mr. Boyle' Accompanying this letter are reprocessed TDT-P data, including bluelines, sepias, and tapes, for the following wells' Sag Delta 7 ~ N-29 Sag Delta 10 ~ 0-23 J-18 ~ ~O-25 ~J-19 ~O-29 ~K-33 ~ ~ P-17 ~, M-19 '~ P-20 M-25 ~ ~ ~' P-24 M-30 ~ Q-32 N-22 In January of this year, Schlumberger modified their TDT-P software. Previously processed logs then became unsuitable as baselines for fluid monitoring with newly processed logs. Consequently, Schlumberger agreed to reprocess previous TDT-P data with the new software, and we now have a full set of standard format, consistently processed logs for monitoring fluid movements. If any further questions arise over the reprocessing of TDT-P logs in Endicott please contact J.H. Dupree (907) 564-4797 G.W. Geehan Manager Endicott Geoscience GWG/GD/Ims Standard Alaska Production Company 900 East Benson Bouleva~ P.O. Box 196612 ~ Anchorage, Aloska 99519-6612 (907) 561-5111 STANDARD ALASKA P~ODUCTION February 1, 1989 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Endicott Well Log Information - Dear Mr. Boyle: Enclosed please find one L.I.S. (data format) tape and computer read-out sheet for the cased hole mn in the following Endicott wells: 1-39/1>-17 50 029 21827 3-1 l/M-30 50 029 21848 Received By Sincerely, Dat~ Standard Alaska Production Company · 900 East Benson Boulevo~ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 STANDARD ALASKA PRODUCTION January 25, 1989 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Endicott Well Log Information Dear Mr. Boyle: Enclosed please find one sepia and one blueline print for the open hole well logs mn in the following Endicott well: Endicott Well 1-39/P-17 *Dual Burst TDT Log Run Date: 1-23-89 Run No. 1 9795'-10635' Endicott Well 3-1 l/M-30 *Dual Burst TDT Log Run Date: 1-24-89 Run No. 1 12695'-13386' From: Schlumberger ~ ~ Sincerely, EC V · Alaska Oil & Gas Cons. Commission Anchorage Received by: Date A un,t of the anginal Slandard Oil Company Founded ,n Cleveland. Ohio. ,n 1870 P' £CEI VED P£'..q "I 1589 Alaska 0ii &,C~as Con,~ ~nchorage' Standard Alaska Production Company 900 East Benson Bouleva~/~ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907/ 561-5111 STANDARD ALASKA PRODUCTION January 3, 1989 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Endicott Well Log Information Dear Mr. Boyle: Enclosed please find one sepia and one blueline print for the cased hole well l°gs run in the following Endicott well: WELL 2-08/K- 16 *PRODUCTION PROFII~E 11700'-12050' Run No. 1 CAMCO WELL 2-28/P- 19 *PRODUCTION PROFILE 9900'- 10250' Run'No. 1 CAMCO WELL 1-41/O-23 *PRODUCTION PROFILE 11350'-11800' Run No. 1 CAMCO WELL 3-1 l/M-30 *PRODUCTION PROFILE 12700'-13200' Run No. 1 CAMCO Alas~ .Oil.& Gas Cons. Commission ': gn~omqe Da~ /~incerely, ~ llard ~ A unit of the original c, tondard O~1 Company Founded in Cleveland, Ohio, in 1870. Standard Alaska Production Company 900 East Benson Boulevard P.O. Box 196612 · Anchorage, Alaska 995t9-6612 (907) 561-5111 STAI~IDARD ALASKA PRODUCTION October 7, 1988 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Endicott Well Log Information Dear Mr. Boyle: Enclosed please find one L.I.S. (data fore, at) tape and computer read-out sheet for the open hole run in the following Endicott wells: 2-16/M-16 3-11/M-30 2-68/S-17 1-43/P-26 4-28/N-37 4-14/R-34 1-49/P-21 4-26/0-34 1-57/R-23 50 029 21885 50 029 2t,848 50 029 21858 50 029 21864 50 029 21870 50029 21863 50 029 21841 50 029 21835 50 029 21873 Received~, ~/~' o r, ~ .,- ...' .~-, ,., ,., x,~. .".Alaska Dil & I~as Con;. gomml~lott , ,i, gncliorageTM Date Grego~illard A unit o! the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. Standard Alaska Production Company x~,~, 900 East Benson Boulevara PO. Box 196612 Anchorage, Alaska 99519-6612 (907i §61-.5111 November 17, 1988 STANDARD ALASKA PRODUCTION Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Endicott Field - Bottom-Hole Pressure Reports Dear Sirs' Enclosed are Bottom Hole Pressure Reports for the following wells in the Endicott Reservoir: Well Name Date 1-29/M-25 1-35/O-25 3-01/N-29 3-11/M-30 3-11/M-30 3-27/M-33 (Upper) (Lower) 10-23-88 10-24-88 10-23-88 10-02-88 10-02-88 10-02-88 If there are Twyford at JLH any questions regarding this data, please contact Loren 564-4401. Sincerely, A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. Standard Alaska Production Company ~ 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION September 14, 1988 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Endicott Well Log Information Dear Mr. Boyle: Enclosed please find one sepia and one bludline print for the cased hole well logs run in the following Endicott well: Endicott Well 3-1 l/M-30 ~'~ *Dual Laterolog MSFL Run Date: 9-3-88 Run No. 1 12697'- 13533~ Company: Gearhart "M *Spectral Litho-Density Compensated Neutron Log Run Date: 9-3-88 Run No. 1 12697'- 13533' Company: Gearhart '~'~*Formation Tester Run Date: 9-4-88 Run No. 1 Company: Gearhart GND:gr Received by: Sincerely, ~J ·Dillard Date A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. Standard Alaska Production Company ~ 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION September 16, 1988 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Endicott Well Log Information Dear Mr. Boyle: Enclosed please find one sepia and one bludline print for the cased hole well logs run in the following Endicott well: Endicott Well 3-11/M-30 SDI: "~'4*Cement Evaluation Log (CET) 12395'-13435' Schumberger *Cement Bond Log (CBT) 12395'-13414' Schumberger GND/gr , ~n0h0rag~ A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Wi=! ! COMP! ETLON OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SU,?~ENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Standard Alaska Production Company 88-87 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-21848 4. Location of well at surface 9. Unit or Lease Name · '~OCATION$ [- Duck Island Unit 2529'SNL, 828'WEL, SEC. 8, T11N, R17E At Top Producing Interval VERJF~ED ~r 10. Well Number 1122' SNL, 1559' WEL, SEC. 5, T11N R17E !Surf~~ 3-11/M-30 SDI At Total Depth ~' ~ ~ 11. Field and Pool Endicott Field/Endicott Pool 647'SNL, 1565' WEL, SEC. 5, T11N, R17E 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 55.15' I ADL 47502 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if olfshore 116. No. of Completions 08-07-88 09-04-88 09-10-88I N/A feet MSLI One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 13530'MD 10509' TVD 13436'MD 10457' TVD YES [] NO []I 1530 feet MD I 1466 22. Type Electric or Other Logs Run CBT, CET, DLL/MSFL, SLD/CNL, FM TESTER 23. CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SIZE VVT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" Structural Drive Pipe Surface 161' Drive 13-3/8" 68# NT80 Surface 2504' 17-1/2" 3300 cu ft Permafrost 9-5/8" 47# NT80S Surface 10537' 12-1/4" 9-5/8" 47# NT95HS 10537' 12701' 12-1/4" 575 cuft Class G 7" 29# TKC 12416' 13520' 8-1/2" 320 cu ft Class G 24. Periorations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET IMD) Schlumberger5" 5 spf 4-1/2" 12.61/ L-90 12968' 7" HB-BP 12951' MD TVDss w/3-1/2" + 2-7/8" Tailpipe 9-5/8" FHL 12397' 12920'-12940' 10009'-10055' .~6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12970'-12994' 10074'-10095' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13016'-13030' 10081'-10092' 13-3/8"X 9-5/8" Down Squeezed 13-3/8"x 9-5/8" 13040'-13098' 10099'-10144' Annulus with 345 sks Permafrost 13106'13116' 10150'-10158 Cement fo/lowed by 115 bbls Dry Crude. 27. PRODUCTION TEST Date First Pr_odu~tjon IMethod of Operation (Flowing, gas lift, etc.) September, S, ~1~8 I Flowing Date of Test Hours Tested PRODUCTION FOR :DIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I1~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. ..... ,. . Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. GEOLOGIC MARKERS~' 30. :'FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP HRZ 12333' 9564' PUT RIVER 12677' 9815' TOP KEKIKTUK 12698' 9830' 31. LIST OF A'FrACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed {~0~132- ~ Tille Drift/no En~in~erin~ Suc)ervi~or Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 8, 1988 at 0600 hours Rig- PAA #7 Nell' 3-11/M-30 AFE# 717551 API- 50-029-21848 AFE Amount' Current Amount' 0600 Depth- 1890' Day- 1 48-Hour Ftg' 1762' Current Operation' Drilling 17-1/2" hole. Accepted rig @ 0300 hours on 8/7/88. Spud well @ 0900 hours on 8/7/88. Drill & survey 17-1/2" hole to 1890'. Mud Type- Spud NT- 8.9 VIS' 144 PV- 10 YP: 52 FL' 16 SOL' 4.2 Temp' 64°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS STANDARD ALASKA PRODUCTION Rig' PAA //7 Nell- 3-11/H-30 (SDI) Daily Drilling Report -- ENDICOTT August 9, 1988 at 0600 hours AFE# 717551 API' 50-029-21848 AFE Amount' Current Amount' 0600 Depth' 2520' Day' 2 24-Hour Ftg' 630' Current Operation' Nipple up wellhead. Drill 17-1/2" hole to TD @ 2520'. Run & cement 13-3/8" casing with permafrost cement. Bumped plug. M/U speedhead system & starting head. Mud Type' Spud NT' 9.2 VIS' 85 PV' 10 YP' 25 FL: 16.4 SOL' 6.4 Temp' 65°F SURVEY MD ANGLE DIRECTION TVD ,SECTION COORDINATES DLS STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August I0, 1988 at 0600 hrs Rig: PAA #7 Well: 3-1 l/M-30 (SDI) AFE # 717551 API: 50-029-21848 AFE Amount: Current Amount: 0600 Depth: 3207' Day: 3 24- Hour Ftg: 687' Current Operation: Drilling 12-1/4" hole. Test BOP's. Drill cement. Test 13-3/8" casing to 3000 psi - OK. Drill out shoe and 10' of new hole. Perform FIT to 14.4 ppg EMW. Drill to KOP @ 2800'. P/U Dynadrill and drill with motor to 3207'. Mud Type: LSND SURVEY MD 8 2646 9 3040 WT: 9.1 VIS:48 PV: 11 YP: 15 FL: 26.0 Solids: 5.2 Temp: °F ANGLE DIRECTION TVD SECTION COORDINATES DL$ 6 N13.3W 2945 30.80 N28 W25 4.45 10.1 N8.4W 3038 43.91 N41 W28 4.42 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 11, 1988 at 0600 hrs Rig: PAA//7 Well: 3-11/M-30 (SDI) AFE# 717551 API: 50-029-21848 AFE Amount: Current Amount: 0600 Depth: 4425' Day: 4 24- Hour Ftg: 1218' Current Operation: Drilling 12-1/4" hole. Dynadrill and survey 12-1/4" hole to 3394'. Trip for BHA and bit change. Drill to 4334'. Trip for Dynadrill. Dynadrilling at 4425'. Mud Type: LSND ~$URVEy 12 14 18 3319 3715 4259 WT: 9.4 VIS: 39 PV: 6 YP: 8 FL: 16 Solids: 6 Temp: ANGLE DIRECTION ,TVD SECTION COORDINATES 18.1 N125W 3309 111 N107 Will 25.5 N 18.8W 3677 253 N246 W80 40 N16.5W 4114 525 NSll W164 78~F DLS 3.17 2.28 3.2 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 12, 1988 at 0600 hrs Rig: PAA #7 Well: 3-1 l/M-30 (SDI) AFE # 717551 API: 50-029-21848 AFE Amount: Current Amount: 0600 Depth: 5851' Day: 5 24- Hour Ftg: 1426' Current Operation: Tripping. Dynadrill and survey 12-1/4" hole to 4637'. Trip .for BHA change. Drill and survey 12-1/4" hole to 5851'. Trip for bit. Mud TyI~: LSND SURVEY 20 22 24 .,MD 4446 4753 5314 WT: 9.6 VIS: 39 PV: 8 YP: 12 FL: 12 Solids: 9 Temp: 80 °F ANGLE DIRECTION TVD SECTION COORDINATES DL$ 43.4 NI0W 4272 665 N647 W198 3.61 47.5 N6.8W 4486 885 N865 W230 1.32 46.4 N5.9W 4868 1295 N1273 W275 .25 STANDARD ALASKA PRODUCTION Rig: PAA #7 Welt: 3-1 l/M-30 (SDI) Daily Drilling Report -- ENDICOTT August 15, 1988 at 0600 hrs AFE # 717551 API: 50-029-21848 AFE Amount: Current Amount: Current Operation: 0600 Depth: 7929' Day: 8 72- Hour Ftg: 2078' Tripping. Drill and survey 12-1/4" hole to 7929'. POH for bit. M/U BHA and bit and IH. Mud Type: LSND SURVEY 25 27 29 31 32 5785 6267 6734 7295 7491 WT: 10.0 VIS:40 PV:9 YP: 10 FL:7 Solids:9 Temp: ANGLE DIRECTION TVD SECTION COORDINATES 44.8 NT. lW 5198 1632 N1608 W313 48.8 N7.4W 5529 1982 N1955 W361 51.9 N6.SW 5826 2342 N2313 W404 53.6 N5.2W 6t67 2787 N2756 W444 52.9 N4.9W 6284 2944 N2913 W457 90 °F DLS., .39 1.04 .56 .51 .38 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 16, 1988 at 0600 hrs Rig: PAA#7 Well': 3-1 l/M-30 (SDI) AFE # 717551 APl: 50-029-21848 AFE Amount: Current Amount: 0600 Depth: 8490' Day: 9 24- Hour Ftg: 561' Current Operation: Tripping. Drill and survey 12-1/4" hole to 8490'. POH for bit. Mud Type: LSND SIIRVEY MD 34 8037 36 8402 WT: 10.0 VIS: 40 PV: 8 YP: 9 FL: 6.5 ANGLE DIRECTION TVD SECTION 52.5 N3.8W 6615 3379 51 N0.5W 684 ! 3665 Solids: 9 Temp' 90 °F ,COORDINATES DLS, N3245 W495 .47 N3632 W507 .84 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 17, 1988 at 0600 hrs Rig: PAA #7 Well' 3-1 l/M-30 (SDI) AFE # 717551 APl: 50-029-21848 AFE Amount: Current Amount: 0600 Depth: 8893' Day: 10 24- Hour Ftg: 403' Current Operation: Tripping. Drill and survey 12-1/4" hole to 8893'. Mud Type: LSND WT: 10.1 SURVEY MD ANGLE 37 8594 50.3 38 8800 49.8 VIS: 40 PV: 13 DIRECTION N3.7W N4.6W TVD 6962 7095 YP: 12 FL: 5.6 ,SECTION 3813 3971 Solids: 9 Temp: 90 °F COORDINATES DLS N3780 W512 1.34 N3938 W523 .41 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 18, 1988 at 0600 hrs Rig: PAA #7 Well: 3-1 l/M-30 (SDI) AFE # 717551 API: 50-029-21848 AFE Amount: Current Amount: 0600 Depth: 9490' Day: 11 24- Hour Ftg: 597' Current Operation: Drilling 12-1/4" hole. Drill and survey 12-1/4" hole to 9490'. Mud Type: LSND .~URVEY .MD WT: 10.2 VIS:41 PV: 15 ANGLE DIRECTION TVD YP: 12 FL: 4.8 SE~FION Solids: 13 Temp: 90 °F COORDINATES DLS STANDARD ALASKA PRODUCTION Rig: PAA #7 Well: 3-1 l/M-30 (SDI) Daily Drilling Report -- ENDICOTT August 19, 1988 at 0600 hrs AFE # 717551 API: 50-029-21848 AFE Amount: Current Amount: Current Operation: 0600 Depth: 9972' Day: 12 24- Hour Ftg: 482' Drilling 12-1/4" hole. Drill and survey 12-1/4" hole to 9972'. *Corrected total per accounting adjustment. Mud Type: LSND WT: 9.9 SURVEY MD ANGLE. 41 9437 47.5 42 9722 46 VIS: 38 PV: 13 DIRECTION N0.6W N 1.6E TVD 7515 7710 YP: 13 FL: 5.6 SECTION 4449 4655 Solids: 11.4 Temp: 106 °F COORDINATES. DLS, N4416 W551 .75 N4623 W549 .77 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 22, 1988 at 0600 hrs Rig: PAA #7 Well: 3-1 l/M-30 (SDI) AFE # 717551 API: 50-029-21848 AFE Amount: Current Amount: 0600 Depth: 10,494' Day: 15 72- Hour Ftg: 522' Current Operation: Tripping. Drill and survey 12-1/4" hole to 10,112'. POH & P/U motor. Turn well to the left & POH with motor. Drill and survey 12-1/4" hole to 10,494'. Mud Type: LSND SURVEY 43 44 45 9916 10291 10418 WT: 10.0 VIS:37 PV: 12 YP: 12 FL:5.2 ANGLE DIRECTION .TVD SECTION 45.1 N5.6E 7846 4792 44.4 N3.1E 8112 5051 44.4 N2.1W 8203 5140 Solids: 12.4 Temp: COORDINATES_ N4762 W540 N5023 W519 N5114 W518 106 CF DLS 1.54 .40 3.19 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 23, 1988 at 0600 hrs Rig: PAA #7 Well: 3-1 l/M-30 (SDI) AFE# 717551 APl: 50-029-21848 AFE Amount: Current Amount: 0600 Depth: 10,815' Day: 16 24- Hour Ftg: 321' Current Operation: Drilling 12-1/4" hole. Drill & survey 12-1/4" hole to 10,815'. Mud Type: LSND WT: t0.1 ~ _MD. ANGLE 46 10559 44.5 VIS: 38 PV: 14 DIRECTION N4.4W TVD 8303 YP: 15 FL: 6.0 SECTION 5238 Solids: 12.7 Temp: °F COORDINATES DLS N5211 W523 1.15 STANDARD ALASKA PRODUCTION Rig: PAA #7 Well: 3-1 l/M-30 (SDI) Daily Drilling Report -- ENDICOTT August 24, 1988 at 0600 hrs AFE # 717551 API: 50-029-21848 AFE Amount: Current Amount: 0600 Depth: 11,035' Day: 17 24- Hour Ftg: 220' Current Operation: Tripping. Drill & survey 12-1/4" hole to 11,035'. POH for motor. Mud Type: LSND SURVEY MD 48 10938 WT: 10.1 VIS:38 PV: 14 YP: 14 FL:5.6 ANGLE DmE(TFION TVD ~ECTION 45 N2.7W 8572 5506 Solids: 12.7 Temp: 106 °F COORDINATES DLS, N5479 W540 .33 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 25, 1988 at 0600 hrs Rig: PAA #7 Well: 3-1 l/M-30 (SDI) AFE # 717551 API: 50-029-21848 AFE Amount: Current Amount: 0600 Depth: 11,110' Day: 18 24- Hour Ftg: 75' Current Operation: Drilling 12-1/4" hole. Drilling 12-1/4" hole with motor to 11,065'. Motor failed. POH for motor. RIH with new motor & drill to 11,110'. Mud Type: LSND S[JRVEY MD WT: 10.1+ VIS:37 PV: 12 YP: 14 FL: 6.2 ANGLE DIRECTION TVD SECTION Solids: 13.5 Temp: 108 °F COORDINATES DLS STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 26, 1988 at 0600 hrs Rig: PAA #7 Well: 3-11/M-30 (SDI) AFE # 717551 API: 50-029-21848 AFE Amount: Current Amount: 0600 Depth: 11,270' Day: 19 24- Hour Ftg: 160' Current Operation: Drilling 12-1/4" hole. Motor drilling to 11,125'. POH for BHA. RIH & drill to 11,270'. Mud Type: LSND SURVEY MD 49 11115 WT: 10.1 VIS:39 PV:ll YP: 12 FL:6 ANGLE DIRECTION TVD SECFION 43.6 N8.6W 8699 5629 Solids: 13 Temp: 106 fi: COORDINATES DLS N5602 W552 2.46 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 29, 1988 at 0600 hrs Rig: PAA #7 Well: 3-1 l/M-30 (SDI) AFE # 717551 API: 50-029-21848 AFE Amount: Current Amount: 0600 Depth: 12,185' Day: 22 72- Hour Ftg: 915' Current Operation: Tripping. Drill & survey 12-1/4" hole to 12,185'. Mud Type: SURVEY MD 50 11307 52 11658 53 11768 WT: 10.3+ VIS: 38 PV: 12 ANGLE DIRECTION 46.4 N6.2W 46.7 N6.2W 46.4 NS.3W TVD 8834 9075 9151 YP: 10 FL: 6.4 SECTION, 5765 6021 6100 Solids: 13 Temp: COORDINATES N5737 W570 N5991 W577 N6070 W607 98°F DLS 1.71 0.40 0.65 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 30, 1988 at 0600 hfs Rig- PAA #7 Well: 3-1 l/M-30 (SDI) AFE # 717551 APl: 50-029-21848 AFE Amount: Current Amount: 0600 Depth: 12,570' Day: 23 24- Hour Ftg: 385' Current Operation: Drilling 12-1/4" hole. Drill & survey 12-1/4" hole to 12,570'. Mud Type: LSND SURVEY MD 56 12437 WT: 10.4 VIS:39 ANGLE DIRECTION 43.8 N4W PV: 12 9619 YP: 10 FL: 6.1 ~ECTION 6578 Solids: 13 Temp: 98 °F COORDINATES DL$ N6546 W645 1.16 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 31, 1988 at 0600 hrs Rig: PAA #7 Well' 3-1 l/M-30 (SDI) AFE # 717551 API: 50-029-21848 AFE Amount: Current Amount: 0600 Depth: 12,710' Day: 24 24- Hour Ftg: 140' Current Operation: Running 9-5/8" casing. Drilled to 12-1/4" TD of 12,710'. Rigged up & running 9-5/8" casing. Mud Type: LSND SURVEY MD 57 12624 WT: 10.4 VIS:39 PV: 13 YP: 11 FL:6.1 ANGLE DIRECTION TVD SECTION 41.4 N2.6W 9757 6705 Solids: 13 Temp: 98 °F COORDINATES DLS N6673 W653 1.57 STANDARD ALASKA PRODUCTION' Daily Drilling Report -- ENDICOTT September 1, 1988 at 0600 hrs Rig: PAA #7 Well: 3-1 l/M-30 (SDI) AFE # 717551 API: 50-029-21848 AFE Amount: Current Amount: 0600 Depth: 12,710' Day: 25 24- Hour Ftg: Current Operation: Drilling float equipment & cement. Ran & cemented 9-5/8" casing to 12,700' with Class G cement. Install packoff. Test BOP. P/U 8-1/2" BHA & RIH to FC and test casing - OK. Drilling cement. Mud Type: LSND SURVEY MD WT:9.7+ VIS:39 PV: 10 YP: 10 FL:7.4 Solids:9 Temp: ANGLE DIRECTION TVD SECTION ~COORDINATES 86°1: DL$ STANDARD ALASKA PRODUCTION Daily Drilling Report-- ENDICOTT September 2, 1988 at 0600 hrs Rig: PAA #7 Well: 3-11/M-30(SDI) AFE # 717551 Al'I: 50-029-21848 AFE Amount' Current Amount: 0600 Depth: 13,268' Day: 26 24- Hour Ftg: 568' Current Operation: Trip for bit. Drilled cement & float equipment. Test casing to 3000 psi. Drilled 10' and mn FIT, 11.8 EMW. Drilled 8-1/2" hole to 13,268'. POH. Mud Type: LSND WT: 9.7 VIS: 37 PV:10 YP:8 FL: 7.6 Solids:10 Temp: ll0°F SURVEY MD ANGLE DIRECTION TVD SECTION COORD.INATE$ .DL$ STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT September 6, 1988 at 0600 hrs Rig: PAA #7 Well: 3- t l/M-30 (SDI) AFE # 717551 API: 50-029-21848 AFE Amount: Current Amount: 0600 Depth: 13,530' Day: 30 96- Hour Ftg: 262' Current Operation: RIH with 6" bit. Drilled 8-1/2" hole to 13,530'. Made three logging runs. Run and cement 7" liner. Clean out to top of liner. RIH with 6" bit & 7" scraper. Mud Type: LSND SURVEY MD WT:9.7+ VIS:42 PV: 12 ANGLE DIRECTION TVD YP: 10 FL: 8.8 SECTION Solids: 12 Temp: 94 °F COORDINATE~, .DLS Rig: PAA #7 Welt: 3-1 l/M-30 (SDS) Daily Drilling RepOrt-- ENDICOTT September 7, 1988 at 0600 hrs STANDARD ALASKA PRODUCTION AFE # 717551 API:,~ 50-029-21848 AFE Amount: Current Amount: Current Operation: 0600 Depth: Day: 24- Hour Ftg: 31 Rig up for cased hole logs. Clean out 7" liner. Test liner lap - OK. Change over to f'fltered brine. R/U for cased hole logs. Mud Type: Brine SURVEY WT: 9.7 'viS: PV: YP: FL: Solids: Temp: °F ANGLE DIRECTION TVD SECTION COORDINATE/3 .DLS STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT September 8, 1988 at 0600 hrs Rig: PAA #7 Well: 3-1 l/M-30' (SDI) AFE # 717551 APE 50-029-21848 AFE Amount: Current Amount: 0600 Depth: 13,436' Day: 32 24- Hour Ftg: Current Operation: RIH with perf guns. Run cased hole logs. Run gyro. R/U & RIH with perf guns. Mud Type: Brine SURVEY IVID WT: 9.7 ANGLE VIS: DIRECTION PV: YP: SECTION Solids: Temp: °F COORDINATES. DLS STANDARD ALASKA PRODUCTION Daily Drilling ,Report-- ENDICOTT September 9, 1988 at 0600 hrs Rig' PAA #7 Well: 3-1 l/M-30 (SDI) AFE # 717551 APl: 50-029-21848 AFE Amount: Current Amount: 0600 Depth: 13,436' PBTD Day' 33 24- Hour Ftg: Current Operation: R/U to mn 4-1/2" tubing. Perforated & flowed well to surface. Killed well & spotted a 40 bbl bridge sal pill. Rigging up to mn tubing. Mud Type: Brine SURVEY WT: 9.7 VIS: PV: YP: FL: Solids: Temp.'. ANGLE DIRECTIQN TVD SECTION COORDINATES. DL$, STANDARD . ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT September 12, 1988 at 0600 hrs Rig: PAA #7 Well: 3-1 l/M-30 (SD[) AFE # 717551 APl: 50-029-21848 AFE Amount: Current Amount: 0600 Depth: 13,436' PBTD Day: 35 48 - Hour Ftg: Current Operation: Ran 4-t/2" tubing. N/U tree & tested. Set packer & test - OK. Displace tubing to diesel & set BPV. Re}eased rig @- 1900 hrs on 9'- 10-88. Mud Type: Brine SURVEY MD WT: 9.7 VIS: PV: YP: FL: Solids: Temp: °F P, .NGLE DIRECTION TVD SECTION COORDINA~S DLS SUB. SURFACE DIRECTIONAL $URVEY [~ UIDANCE [~]ONTINUOUS [~]OOL Company STANDARD ALASKA PRODUCTION COMPANY I ~ Well Name 3-1!,/,M-~30,,,SDI (2,52,9, SN, L,828' WEL,SEC8i, TllN~R17E) Field/Location ENDI COTT, NOR,,,TH SLOPE~ ,ALASKA Job Reference No. Date 72927 7-SEP-88 Loaaed By: Computed By: MCBRIDE STEVENS GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR STANDARD ALASKA PROD. CO. 3-ll ! M-30 SDI ENDICOTT NORTH SLOPEtAL~SKA SURVEY DATE: OT-SEP-B8 ENGINEER: MCBRIDE METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTiCaL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 5 DEG 59 MIN WEST COMPUTATION DATE: 12-SEP-88 PAC, E I STANDARD aLASKA PROD. :CO. 3-11 / M-30 SOI ENOICOTT NORTH SLOPE,ALASKA DATE OF SURVEY: 07-SEP-88 KELLY BUSHING ELEVATION: 55.15 FT ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SE~ COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 0.00 0.00 -55.15 0 0 N 0 0 E 100.00 100.00 44.85 0 11 N 14 48 W ZOO.D0 ZO0.O0 144.85 0 15 N 40 28 W 300.00 300.00 244.85 0 43 N 56 49 W 400.00 399.98 344.83 0 57 N 57 46 W 500.00 699.97 444.82 0 41 N 50 8 W 600.00 599.97 544.92 0 27 N 45 47 W 700.00 699.97 644.82 0 12 N 33 44 W 800.00 799.96 744.81 0 15 N 28 18 W 900.00 899.96 844.,~1 0 49 N 29 16 W 0.00 0.00 0.00 N 0.00 E 0.26 0.15 0.26 N 0.04 W 0.57 0.14 0.54 N 0.26 W 1.08 0.69 l. Ol N 0.79 W 2.01 0.22 1.79 N 2.17 W 3.01 0.24 2.68 N 3.36 W 3.75 0.29 3.34 N 4.12 W 4.17 0.05 3.72 N 4.45 W 4.52 0.09 4.05 N 4.65 W 5.22 1.41 4.72 N 4.98 W 0.00 N 0 0 E 0.26 N 8 3 W 0.60 N 25 8 W 1.28 N 38 4 W 2.81 N 50 26 W 4.29 N 51 24 ir ~ 5.31 N 50 57 W .- 5.80 N 50 5 W 6.17 N 48 53 W 6.87 N 46 32 W 1000.00 999.93 944.78 1100.00 1099.91 1044.76 1200.00 1199.88 114~. 13 1300.00 1299.87 124~.72 1400.00 1399.86 1344.71 1500.00 1499.83 1444.68 1600.00 1599.82 1544.67 1700.00 1699.82 1544.67 1800.00 1799.82 1744.67 1900.00 18t9.81 1844.66 1 24 N 38 53 W 1 17 N 51 11 W 1 10 N 57 48 W 1 2 N 57 55 W 1 2 N 59 28 W 0 53 N 58 6 W 0 42 N 59 59 W 0 26 N 59 43 W 0 22 N 61 28 W 0 20 N 57 43 W 7.10 0.10 6.48 N 6.22 W 8.94 0.25 8.16 N 7.88 W 10.35 0.24 9.39 N 9.65 W 11.52 0.07 10.41 N 11.25 W 12.62 0.07 11.35 N 12.81 W 13.69 0.37 12.26 N 14.34 W 14.51 0.27 12.96 N 15.54 W 15.10 0.03 13.45 N 16.38 W 15.53 0.21 13.82 N 17.02 W 15.89 0.10 14.13 N 17.54 W 8.98 N 43 48 W 11.35 N 44 0 W 13.46 N 45 46 W 15.32 N 47 13 W 17.11 N 48 27 W 18.86 N 49 ZB W 20.23 N 50 10 W 21.20 N 50 34 W 21.93 N 50 55 W 22.53 N 51 8 W 2000.00 1999.81 1944.66 2100.00 2099.81 2044.66 2200.00 2199.81 2144.66 2300.00 2299.81 2244.6F 2400.00 2399.81 2344.66 2500.00 2499.81 244&.66 2600.00 2599.81 2544.56 2700.00 2699.81 2644.66 2800.00 2799.81 2744.66 2900.00 2899.76 2344.61 0 16 N 53 17 W 0 17 N 61 53 W 0 16 N 68 29 W 0 13 N 73 31 W 0 9 N 78 25 W 0 4 N 62 3 W 0 1 N 1 23 W 0 3 S 22 10 E 015 N 69 6 E 3 28 N 5 59 W 16.24 0.13 14.44 N 18.00 W 16.55 0.06 14.71 N 18.38 W 16.79 0.03 14.91 N 18.83 W 17.00 0.22 15.07 N 19.28 W 17.09 0.05 15.13 N 19.5T W 17.17 0.20 15.19 N 19.80 W 17.22 0.05 15.23 N 19.81 W 17.23 0.38 15.24 N 19.86 W 17.23 0.40 15.27 N 19.60 W 19.26 5.79 17.32 N 19.55 W 23.08 N 51 15 W 23.54 N 51 20 W 24.02 N 51 37 W 24.47 N 51 59 W 24.74 N 52 17 W 24.95 N 52 30 W 24.99 N 52 26 W 25.04 N 52 30 W 24.85 N 52 4 W 26.12 N 48 27 W 3000.00 2999.18 2944.03 8 8 3100.00 3097.63 3042.48 11 36 3ZOO.OD 3195.03 3139.88 14 28 3300.00 3291.17 3236.02 17 19 3400.00 3386.05 3330.90 19 3 3500.00 3480.16 3425.01 20 41 3600.00 3573.05 3517.90 22 49 3700.00 3664.39 3609.24 25 11 3800.00 3753.96 3698.91 27 36 3900.00 3841.54 3786.39 30 11 N 7 41 W N 7 27 W N 11 16 W N 14 35 W N 16 20 W N 17 59 W N 18 27 W N 18 34 W N 18 42 W N 18 38 W 29.71 3.79 27.67 N 47.12 2.66 44.95 N 69.68 3.36 67.26 N 96.88 2.81 93.9Z N 128.08 1.48 124.43 N 161.20 1.89 156.68 N 197.38 2.36 191.83 N 237.08 2.49 230.39 N 280.42 2.48 272.48 N 327.49 2.65 21.03 W 34.75 N 37 13 W 23.13 W 50.55 N 27 13 W Z6.72 W 72.37 N 21 39 W 33.29 W 99.65 N 19 31 W 41.46 W 131.15 N 18 25 W 51.56 W 164.94 N 18 12 W 63.21 W 201.97 N 18 14 W 76.10 W 242.64 N 18 16 W 90.36 W 287.07 N 18 20 W 318.19 N 105.79 W 335.32 N 18 23 W COMPUTATION DATE: 12-SEP-88 PAGE Z STANOARO ALASKA PROD. 3-11 ! M-30 SDI ENDICOTT NORTH SLOPE,ALASKA DATE OF SURVEY: 07-SEP-88 KELLY BUSHING ELEVATIOlq: 55.15 FT ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 10'0 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL OOGL~G RECTANGULAR C30RDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000.00 3926.74 3871.59 32 56 4100.00 4009.23 3954.08 35 49 4200.90 4088.86 4033.71 38 33 4300.00 4165.54 4110.39 41 10 4400.00 4240.09 4184.94 42 19 4500.00 4312.71 4257.56 44 26 4600.00 4382.86 4327.71 46 31 4700.00 4450.84 4395.69 47 4800.00 4518.45 4463.30 47 45 4900.00 4585.97 4530.82 47 12 N 18 54 W N 19 9 W N 19 17 W N 18 55 W N 13 39 W N 10 41 W N 8 9 W N 7 47 W N 7 50 W N 7 52 W 378.55 2.87 433.57 2.93 ,492.45 2.75 55~.91 2.72 620.36 2.72 688.72 2.21 759.85 2.40 833.15 0.96 906.79 0.36 980.5! 0.37 367.76 N 122.62 W 387.66 N 18 26 W 421.15 N 141.08 W 444.15 N 18 31 W 478.26 N 151.00 W 504.63 N 18 36 W 538.84 N 182.15 W 568.80 N 18 40 W 602.65 N 201.19 W 635.35 N 18 27 W 669.90 N 215.43 W 703.68 N 17 49 ~, ) 740.20 N 2Z6.96 W 774.22 N 17 2 W 812.87 N 236.91 W 846.69 N 16 14 W 8:35.$6 N 246.95 W 919.63 N 15 34 W 958.93 N 257.02 W 992.78 N 15 0 W 5000.00 ~654.10 4598.95 47 1 5100.00 4722.34 4667.19 46 49 5200.00 4790.84 4735.59 46 40 5300.00 4859.59 4804.44 46 22 5400.00 4928.80 4873.65 46 3 5500.00 4998.45 4943.30 45 50 5600.00 5068.19 5013.04 45 31 5700.00 5138.58 5083.43 44 59 5800.00 5209.52 5154.37 44 42 5900.00 52~0.56 5225.41 45 0 N 8 I W 1053.58 N 8 5 W 1126.71 N 8 0 W 1199.52 N 7 53 W 1272.09 N 7 55 W 1344.25 N 7 42 W 1415.95 N 7 42 W 1487.59 N 8 3 W 1558.58 N 8 11 W 1629.0! N 8 18 W 1699.34 0.0g 0.99 0.31 0.56 0.47 0.53 0.52 0.52 0.19 0.94 1031.43 N 2,67.18 W 1065.47 N 14 31 W 1103.79 N 277.43 W 1138.12 N 14 6 W 1175.92 N 287.64 W 1210.59 N 13 44 W 1247.84 N 297.68 W 1282.86 N 13 25 W 1319.35 N 307.61 W 1354.73 N 13 7 W 1390.43 N 317.38 W 1426.19 N 12 51 W 1461.45 N 326.95 W 1497.58 N 1Z 36 W 1531.81 lq 336.71 W 1568.38 N 12 23 W 1601.53 N 346.67 W 1638.67 N 1Z 12 W 1671.24 N 356.75 W 1708.89 N 12 2 W 6000.00 5350.65 5295.50 45 55 6100.00 5419.71 5364.56 46 44 6200.00 5487.59 5432.43 47 45 6300.00 5554.01 5498.86 48 54 6400.00 5619.17 5564.02 49 47 6500.00 5693.26 5628.11 50 27 6600.00 5746.23 5691.08 51 18 6700.00 5808.49 5753.34 51 35 6800.00 5870.51 5915.36 51 48 6900.00 5932.60 5877.45 51 52 N 8 16 W 1770.60 N 8 4 W 1842.87 N 7 50 W 1916.27 N 7 58 W 1990.97 N 7 58 W 2066.77 N 7 50 W 2143.50 N 7 29 W 2221.14 N 7 20 W 2299.37 N 7 18 W 2377.80 N 6 53 W 2456.17 0.74 1.07 I .20 0.68 1.03 I .01 0.30 0.31 0.39 1.16 1741.81 N 367.09 W 1780.07 N 11 54 W 1813.39 lq 377.40 W 1852.24 N 11 45 W 18,'36.12 N 387.58 W 1925.53 N 11 36 W 1960.16 N 397.88 W 2000.13 N 11 28 W 2035.27 N 408.41 W 2075.84 N 11 20 W 2111.30 N 419.03 W 2152.48 N 11 13 W 2188.28 N 429.40 W 2230.01 N 11 6 W 2265.88 N 439.47 W 2308.10 N 10 58 W 2343.69 N 449.46 W 2386.40 N 10 51 W 2421.48 N 459.19 W 2464.63 N 10 44 W · 7000.00 5994.05 5938.90 52 15 7100.00 6055.32 6900.17 52 26 7200.00 6115.65 6060.50 53 7 7300.00 6175.31 6120.16 53 25 7400.00 6235.30 6180.15 53 6 7500.00 6295.63 6!40.48 52 39 7600.00 6356.42 6301.27 52 20 7700.00 6417.39 6362.23 52 32 7800.00 647~.46 64~3.3! 52 27 7900.00 6539.24 6484.09 52 40 N 6 32 W 2535.05 N 6 25 W 2614.08 N 6 25 W 2693.83 N 6 6 W 2774.08 N 5 46 W 2854.09 N 6 lO W 2933.$3 N 5 58 W 3013.25 N 5 19 W 3092.51 N 4 29 W 3171.67 N 4 3 W 3251.05 0.22 1.32 0.40 0.56 0.21 0.32 0.80 1.10 0.79 0.35 Z499.83 N 468.36 W 2543.32 N 10 36 W 2578.35 N 477.27 W 2622.15 N 10 29 W 2657.60 N 486.18 W 2701.71 N 10 22 W 2737.38 N 494.92 W 2791.76 N 10 14 W 2816.95 N 503.26 W 2861.56 N 10 7 W 2896.27 N 511.47 W 2941.09 N 10 0 W 2975.23 N 519.97 W 3020.33 N 9 54 W 3054.10 N 527.86 W 3099.38 N 9 48 W 3133.00 N 534.47 W 3178.26 N 9 40 W 3212.19 N 540.39 W 3257.33 N 9 32 W COMPUTATION D~TE: 12-SEP-88 PAGE 3 STANDARD ALASKA PROD. CO. 3-11 / M-30 SDI ENDICOTT NORTH SLOPE,ALASKA DATE OF SURVEY: 07-SEP-88 KELLY BUSHING ELEVATION: 55.15 FT ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH OEPTH DEPTH 9EPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HQRIZ. DEPARTURE SECTION SEVERITY NQRTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET :EET OEG MIN 8000.00 5600.02 6544.87 52 26 8100.00 6661.39 6606.24 51 38 8200.00 6723.73 6668.58 51 25 8300.00 5786.56 6731.¢1 51 6 8400.00 6849.20 6794.05 51 10 8500.00 6912.23 6857.14 50 34 8600.00 5976.03 6920.88 50 9 8700.00 7040.17 6985.02 49 50 8800.00 7105.11 7049.96 49 24 8900.00 7170.12 7114.97 49 35 N 3 25 W 3330.40 N 3 4 W 3409.26 N 2 58 W 3487.34 N 3 5 W 3565.03 N 2 3q- W 3642.87 N 2 58 W 3720.32 N 3 22 W 3797.28 N 3 45 W 3873.93 N 4 5 W 3949.93 N 4 13 W 4025.88 0.90 1.37 ! .43 0.66 0.59 0.83 0.72 I .52 0.64 0.34 3291.43 N 545.69 W 3336.36 N 9 24 W 3370.26 N 550.08 W 3414.86 N 9 16 W 3448.34 N 554.10 W 3492.57 N 9 7 W 3526.02 N 558.29 W 3569.94 N 8 59 W 3603.87 N 552.25 W 3647.46 N 8 52 W 3681.37 N 565.80 W 3724.60 N 8 44 W~ 3758.30 N 570.16 W 3801.30 N 8 37 W~ 3834.89 N 574.84 W 3877.72 N 8 31 W 3910.74 N 580.11 W 3953.53 N 8 26 W 3986.53 N 585.68 W 4029.32 N 8 21 W 9000.00 7235.13 7179.98 49 15 9100.00 7300.71 7245.56 48 46 9200.00 7367.08 7311.93 48 6 9300.00 7434.02 7378.87 47 32 9400.00 7501.85 7446.70 47 3 9500.00 7570.07 7514.92 46 52 9600.00 7638.56 7583.41 46 28 9700.00 ?707.78 7652.53 46 0 9800.00 7777.61 7722.46 45 23 9900.00 7848.13 7792.98 /-+4 51 N 3 57 W 4101.83 N 3 44 W 4177.26 N 3 I W 4251.99 N 2 30 W 4326.14 N 2 34 W 4399.49 N 2 2 W 4472.46 N 0 46 W 4545.10 N 0 47 E 4616.89 N 2 46 E 4687.81 N 4 36 E 4757.69 0.27 0.62 1.01 0.84 0.29 0.87 1.62 I .35 1.53 1.29 4062.32 N 591.16 W 4105.11 N 8 16 W 4137.63 N 596.26 W 4180.37 N 8 12 W 4212.30 N 600.80 W 4254.93 N 8 7 W 4286.50 N 604.21 W 4328.87 N 8 1 W 4359.90 N 607.50 W 4402.02 N 7 55 W 4432.94 N 610.6.1 W 4474.80 N 7 50 W 4505.79 N 612.42 W 4547.22 N 7 4¢ W 4577.96 N 612.51 W 4618.76 N 7 37 W 4649.51 N 610.34 W 4689.40 N 7 28 W 4720.26 N 605.73 W 4758.96 N 7 18 W 10000.00 7919.30 7864.15 ~.4 21 10100.00 7990.91 7935.76 44 18 10200.00 9062.37 8007.22 44 33 10.300. O0 8133.72 8078.57 44 10400.00 8205.14 8149.99 44 30 10500.00 8276.81 8221.66 /+4 0 10600.00 8348.52 8293.37 10700.00 8419.85 8364.70 44 3~ 10800.00 8491.02 8435.87 10900.00 8562.14 8506.99 44 35 N 6 30 E 4826.52 N 8 4 E 4894.39 N 7 17 E 4962.35 N 4 49 E 5030.72 N 0 0 E 5099.93 N 4 40 W 5169.52 N 4 58 W 5239.21 N 4 37 W 5309.28 N 4 20 W 5379.49 N 4 9 W 5449.77 I .64 0.77 0.63 3.48 3.37 2.30 0.59 0.39 0.27 0.15 4790.17 N 599.00 W ~+827.47 N 7 7 W 4859.36 N 589.89 W 4895.03 N 6 55 W 4928.68 N 580.53 W 4962.75 N 6 43 W 4998.27 N 572.46 W 5030.95. N 6 32 W 5068.17 N 569.53 W 5100.07 N 6 24 W 5137.83 N 572.52 W 5169.63 N 6 21 W/ 5207.23 N 578.87 W 5239.31 N 6 20 W 5277.08 N 584.67 W 5309.37 N 6 19 W 5347.10 N 590.16 W 5379.57 N 6 17 W 5417.22 N 595.35 W 5449.83 N 6 16 W 11000.00 8633.46 8578.31 ~+4 18 lllO0.O0 8705.61 8650.46 /+3 19 11200.00 8778.12 8722.97 44 7 11300.00 8848.97 8793.32 45 34 11400.00 8918.27 8863.12 46 36 11500.00 8986.74 8931.59 46 37 11600.00 9055.63 9000.47 46 25 11700.00 9124.68 9069.53 46 22 11800.00 ;~193.78 9138.63 46 14 11900.00 3262.68 9207.53 46 45 N 3 37 W 5519.82 N 6 59 W 5589.03 N 8 45 W 5657.81 N 7 56 W 5728.32 N 7 27 W 5800.38 N 6 58 W 5873.24 N 6 56 W 5945.73 N 6 51 W 6018.05 N 6 33 W 6090.32 N 6 34 W 6162.81 0.73 3.43 1.72 I .29 0.96 0.68 0.31 0.29 0.25 O. 84 5487.15 N 600.15 W 5519.87 N 6 14 W 5556.14 N 605.90 W 5589.08 N 6 13 W 5624.22 N 616.14 W 5657.8'7 N 6 15 W 5694.05 N 626.29 W 5728.39 N 6 16 W 5765.49 N 635.99 W 5800.46 N 6 17 W 5837.79 N 645.09 W 5873.33 N 6 18 W 5909.76 N 653.85 W 5945.83 N 6 18 W 5981.57 N 662.53 W 6018.15 N 6 19 W 6053.35 N 671.02 W &090.43 N 6 19 W 6125.37 N 679.23 W 6162.91 N 6 19 W STANDARD ALASKA PROD. CO. 3-11 / M-30 SDI ENDICOTT NORTH SLDPE,ALASK~ CDMPUTATIgN DATE: 12-SEP-88 PAGE 4 DATE DF SURVEY: 07-SEP-88 KELLY BUSHING ELEVATION: 55.15 FT ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGtJLAR COORDINATES HDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH 6AST/WEST DIST. AZIMUTH FEET DEG/IOO FEET FEET FEET DEG MIN 1ZO00.O0 9330.91 9275.76 46 45 1ZIO0.O0 9400.09 9344.9% 45 51 12700.00 9469.88 9414.72 45 42 12300.00 9539.89 9484.74 45 18 12400.00 9610.81 9555.66 44 17 12500.00 9633.06 9627.91 43 5 12600.00 97'56.94 9701.79 41 40 12700.00 983~.3q 9777.24 40 25 12800.00 9909.27 9854.12 39 1 12900.00 9987.21 9932.06 38 44 N 6 37 W 6235.90 N 6 33 W 6308.11 N 6 19 W 6379.72 N 5 59 W 6451.12 N 5 11 W 6521.62 N 4 20 W 6590.73 N 3 20 W 665~.08 N 2 35 W 6723.60 N 2 23 W 6787.42 N 2 16 W 6849.94 I .19 0.60 0.29 0.67 1.16 I .30 1.42 I .01 1.15 0.21 6197.98 N 687.67 W 6236.01 N 6 19 W 6269.71 N 695.97 W 6308.22 N 6 ZO W 63%0.87 N 704.03 W 6379.84 N 6 ZO W 6411.86 N 711.70 W 6451.24 N 6 20 W 6482.02 N 718.64 W 6521.73 N 6 19 W 6550.91 N 724.31 W 6590.83 N 6 18 Wf 6618.16 N 7ZB.BO W 6658.16 N 6 17 6683.68 N 732.16 ~4 6723.67 N 6 15 W 5747.57 N 734.86 W 6787.47 N 6 12 W 6810.17 N 737.~+3 W 6849.98 N 6 10 W 13000.00 10065.50 10010.35 37 48 13100.00 10145.37 10090.22 36 25 13200.00 10226.22 10171;07 35 18 13300.00 10309.5~ 10254.43 31 34 13400.00 10395.89 10340.74 29 51 13500.00 10482.62 10427.47 29 51 13530.00 10508.63 10453.48 29 51 N I 55 W 6912.02 N 0 32 W 6971.99 N 0 10 E 7030.51 N I 3 E 7085.33 N I 33 E 7135.41 N I 33 E 7184.76 N I 33 ,E 7199.57 1.92 0.84 2.40 3.21 0.00 0.00 0.00 6872.34 N 739.79 W 6912.04 N 6 B W 6932.50 N 741.09 W .5972.00 N 6 6 W 6991.33 N 741.26 W 7030.51 N 6 3 W 7046.52 N 740.55 W 7085.33 N 5 59 W 7097.00 N 739.38 W 7135.41 N 5 56 W 7146.77 N 738.02 W 7184.77 N 5 53 W 7161.70 N 737.62 W 7199.58 N 5 52 W COMPUTATIgN OATS: 12-SEP-88 PAGE 5 STANDARD ALASKA PROD. CO. 3-11 / M-30 SDI ENDICOTT NORTH SLOPEsALASKA DATE OF SURVEY: 07-SEP-88 KELLY BUSHING ELEVATION: 55.15 FT ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED 9EPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH gEOTq DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE SECTION SEVERITY N~RTH/S~U[H EAST/WEST OISTo AZIMUTH FEET OEG/IO0 ~EET FEET FEET DEG MIN 0.00 0.00 -55.t5 0 0 1000.00 999.93 944.78 I 24 2000.00 t999.81 1944.66 0 16 3000.00 2999.18 2944.03 8 8 4000.00 39R6.74 3371.59 32 56 5000.00 4654.10 459q.95 47 1 6000.00 5350.65 5295.50 45 55 7000.00 59?4.05 5}38.90 52 15 8000.00 5600.0Z 6544.~7 52 26 9000.00 7235.13 7179.98 49 15 N 0 0 E 0.00 N 38 53 W 7.10 N 53 17 W 16.24 N 7 41 W 3}9.71 N 18 5~ W 37,~.55 N 8 I W 1053.58 N 8 16 W 1770.60 N 6 32 W 2535.05 N 3 25 W 3330.40 N 3 57 W 4101.83 O.OO 0.10 0.13 3.79 2.87 0.09 0.74 0 0.90 0.27 0.00 N 0.00 E 0.00 N 0 0 E 6.48 N 6.2;) W 8.98 N 43 48 W 14.44 N 18.00 W 23.08 N 51 15 W 27.67 N 21.03 W 34.75 N 37 13 W 367.76 N 122.62 W 387.66 N 18 26 W 1031.43 N 257.18 W 1065.47 N 14 31 W( 1741.81 N 3,57.09 W 1780.07 N 11 54 w, 24=)9.83 N 458.35 W 2.543.32 N 10 36 W 3291.43 N 545.69 W 3336.36 N 9 24 W 4062.32 N 591.16 W 4105.11 N 8 16 W 10000.00 7919.33 7864.15 44 11000.00 8633.46 8578.31 44 18 12000.00 9330.91 9275.76 46 45 13000.00 10065.50 10010.35 37 48 13530.00 10508.63 10453..48 29 51 N 6 30 E 4826.52 N 3 37 W 5519.82 N 6 37 W 6235.90 N 1 55 W 6912.02 N 1 33 E 7199.57 1.64 0.73 1.19 1 0.00 4790.17 N 599.00 W 4827.47 N 7 7 W 5487.15 N 600.15 W 5519.87 N 6 t4 W 5197.98 N 687.67 W 6236.01 N 6 19 W 6872.34 N 739.79 W 6912.04 N 6 8 W 7161.70 N 737.62 W 7199.58 N 5 52 W STANDARD ALASKA PROD. 3-11 ENDICOTT NORTH SLOPE,ALASKA COMPUTATION DATE: 12-SEP-88 PAGE 6 DATE OF SURVEY: 07-SEP-88 KELLY BUSHING ELEVATION: 55.15 FT ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DE~TH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTdRE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 CEET FEET FEET DEG MIN 0.00 0.00 -55.15 0 0 N 0 q E 55.15 55.15 0.00 0 12 N 7 49 W 155.15 155.15 100.00 0 12 N 43 45 W 255.15 25~.15 200.00 0 23 N 48 30 W 355.16 355.15 300.00 0 56 N 61 28 W 455.18 455.15 400.00 0 50 N 52 8 W 555.18 555.15 500.00 0 34 N 48 55 W 655.18 655.15 600.30 0 14 N 39 20 W 755.18 755.15 700.00 0 13 N 30 23 W 855.19 855.15 800.00 0 25 N 25 24 W 0.00 0.00 0.03 N 0.00 0.10 0.27 0.10 N 0.00 0.42 0.11 0.41 N 0.13 0.79 0.45 0.75 N 0.45 1.57 0.14 1.42 N 1.52 2.59 0.45 2.30 N 2.90 3.45 0.21 3.07 N 3.82 4.02 0.18 3.58 N 4.35 4.35 0.06 3.90 N 4.56 4.79 0.60 4.32 N 4.77 0.00 N 0 0 E 0.10 N I 55 W 0.43 N 17 21 W 0.87 N 30 38 W 2.08 N 46 56 W . 3.70 N 51 32 W( 4.90 N 51 12 W 5.64 N 50 31 W 6.00 N 49 28 W 6.44 N 47 52 W 955.20 955.15 900.00 1055.23 1055.15 1000.00 1155.26 1155.15 1100.00 1255.28 1255.15 1200.00 1355.29 1355.15 1300.00 1455.31 1455.15 1400.00 1555.32 1555.15 1500.00 1655.32 1655.15 1600.00 1755.33 1755.15 1700.00 1855.33 1855.15 1800.00 I 17 N 35 27 W I 20 N 45 20 W I 13 N 55 42 W I 4 N 57 38 W I 2 N 58 57 W I 2 N 59 30 W 0 46 N 59 55 W 0 32 N 58 30 W 0 25 N 60 54 W 0 20 N 58 16 W 6.18 0.51 5.63 N 5.56 W 8.18 0.34 7.48 N 7.11 W 9.76 0.22 8.83 N 8.85 W ll.O1 0.10 9.97 N 10.56 ii 12.13 O.OB 10.93 N 12.11 W 13.21 0.34 11.85 ,4 13.69 W 14.16 0.12 12.66 N 15.02 W 14.88 0.37 13.27 N 16.06 W 15.34 0.05 13.67 N 16.74 W 15.72 0.03 13.99 N 17.31 W 7.92 N 44 39 W 10.32 N 43 33 W 12.54 N 44 55 W 14.52 N 46 39 W 16.31 N 47 55 W 18.11 N 49 7 W 19.64 N 49 51 W 20.84 N 50 26 W 21.61 N 50 46 W 22.26 N 51 3 W 1955.33 1955.15 1900.00 2055.34 2055.15 2000.00 2155.34 2155.15 2100.00 2255.34 2255.15 ZZO0.O0 2355.33 2355.15 2300.00 2455.33 2455.15 Z4OO.O0 2555.34 2555.15 2500.00 2655.34 2655.15 2500.00 2755.34 2755.15 2700.00 2855.34 2855.15 2.~00.00 0 18 N 55 44 W 0 16 N 5444W 0 16 N 66 33 W 0 16 N 69 46 W 0 9 N 79 55 W 0 8 N 76 44 W 0 I N 8 23 E 0 3 N 87 30 W 0 10 N ~3 32 E 1 6 N 12 41 E 16.09 0.11 14.31 N 17.81 W 16.42 0.13 14.60 N 18.20 W 16.69 O.OZ 14.83 N 18.63 W 16.92 0.04 15.01 N 19.08 W 17.06 0.06 15.11 N 19.45 W 17.14 0.05 15.17 N 19.71 W 17.20 0.03 15.21 N 19.82 W 17.23 0.10 15.25 fl 19.83 W 17.22 0.20 15.24 N 19.77 W 17.46 4.40 15.52 N 19.39 W 22.85 N 51 13 W 23.33 N 51 15 W 23.81 N 51 29 W 24.28 N 51 49 W 24.63 N 52 B W 24.87 N 52 25 W/ 24.98 N 52 29 W 25.02 N 52 26 W 24.96 N 52 21 W Z¢.B4 N 51 19 W 2955.60 2955.15 2900.00 6 19 3056.71 3055.15 3000.00 10 21 3158.91 3155.14 3099.39 13 22 3262.37 3255.15 3200.00 16 18 3367.34 3355.15 3300.00 18 43 3473.32 3455.15 3600.00 ZO 11 3580.62 3555.15 3500.00 22 22 3689.78 3655.1.5 3600.00 24 56 3801.34 3755.15 3700.00 27 38 3915.82 3855.15 3800.00 30 36 N 8 30 W N 6 50 W N 9 20 W N 14 25 W N 15 16 W N 17 41W N 18 26 W N 18 32 W N 18 42 W N 18 40 W 23.99 4.82 22.01 N 38.76 3.95 36.65 N 59.82 2.71 57.52 N 86.12 2.72 83.39 N 117.65 1.57 114.25 N 152.10 1.97 147.82 N 190.10 2.14 184.75 N 232.82 2.55 226.26 N 281.03 2.49 273.07 N 335.36 2.67 Z0.18 W 29.86 N 42 31 W 22.12 W 42.81 N 31 6 W 24.99 W 62.72 N 23 29 W 30.52 W 88.80 N 20 6 W 38.58 W 120.59 N 18 39 W 48.71 W 155.64 N 18 14 W 60.85 W 194.52 N 18 13 W 74.71 W 238.27 N 18 16 W 90.56 W 287.70 N 18 20 W 325.83 ,ii 108.37 W 343.38 N 18 23 W STANDARD ~LASKA PROD. 3-11 / M-30 SDI ENDICOTT NORTH SLOPE,ALASKa C9. c',r)MPUTATI ON D~TE: 1Z-SEP-B8 KELLY DATE OF SURVEY: BUSHING ELEVATION: ENGINEER: PAGE 7 07-SEP-88 55.15 FT MCBRIDE TRUE MEASURED VERTICAL DEPTH DEPTH INTERPOLATED VALUES FOR SUB-SEA VERTICAL OEPTH COURSE DEVIATION AZIMUTH DEG MIN DEG MIN EVEN 100 FEET OF SUB-SE& DEPTH VERTICAL SECTION FEET DOGLEG RECTANGULAR COORDINATES SEVERITY NORTH/SOUTH EAST/WEST DEG/IO0 FEET FEET HORIZ. DEPARTURE DIST. AZIMUTH FEET DEG MIN 4034.05 3955.15 3900.00 33 56 N 4157.22 4055.15 4000.00 37 25 N 4286.22 4155.15 4100.00 40 54 N 4420.45 4255.15 4200.00 42 45 N 4560.05 4355.15 4300.00 45 39 N 4706.33 4455.15 4400.00 47 10 N 4854.58 ~555.15 4500.90 47 29 N 5001.55 ~655.15 4600.00 47 I N 5147.92 4755.15 4700.00 46 46 N 5293.55 4855.15 4800.00 46 24 N 5437.93 4955.15 5581.38 5055.15 5723.41 5155.15 5864.16 5255.15 6006.48 5355.15 6152.01 5455.15 6301.74 5555.15 6456.03 5655.15 6614.27 5755.15 6775.14 5855.15 4900.00 45 51 N 5000.00 45 36 N 5100.00 44 52 N 5200.00 44 45 N 5300.~0 45 58 N 5400.00 47 17 N 5500.00 48 55 N 5600.00 50 10 N 5700.90 51 21 N 580Q.00 51 45 N 19 1 W 19 14 W 19 9 W 12 55 W 9 2 W 7 48 W 7 50 W 8 1 W 8 3 W 7 53 W 7 51 W 7 40 W 8 5 W 8 14 W 8 16 W 7 5B W 7 5R W 7 56 W 7 27 W 7 1~ W 6936.67 5955.15 5900.00 51 59 N 6 43 W 7099.72 6055.15 6900.00 52 26 N 6 25 W 7266.09 6155.15 6100.00 53 ZB N 6 10 W 7433.07 6255.15 6200.00 53 0 N 5 48 W 7597.93 6355.15 6300.00 52 20 N 5 59 W 7761.88 5455.15 6400.00 52 17 N 4 40 W 7926.28 6555.15 6500.00 52 38 N 3 57 W 808'9.92 6655.15 660D.00 51 45 N 3 6 W 8250.14 6755.15 6700.00 50 57 N 3 5 W 8409.49 6855.15 6800.00 51 9 N 2 34 W 8567.35 6955.15 6900.00 50 19 N 8723.15 7055.15 7000.00 49 33 N 8876.94 7155.15 7100.00 49 :32 N 9030.67 7255.15 7200.00 49 8 N 9182.16 7355.15 7300.00 48 4 N 9331.22 7455.15 7400.00 47 22 N 9478.16 7555.15 7500.00 46 55 N 9624.00 7655.15 7600.00 46 20 N 9768.00 7755.15 7700.00 45 34 N 9909.90 7855.15 7800.00 44 47 N 3 18 W 3 54 W 4 13 W 3 54 W 3 14 W 2 33 W 2 15 W 0 28 W 2 4 E 4 46 E 396.83 2.93 385.50 N 466.81 2.55 453.39 N 546.08 2.52 530.28 N 634.08 3.35 616.13 N 731.10 3.04 711.74 N 837.78 0.80 817.46 N 947.17 1.21 9Z~.B~) N 1054.81 0.08 1032.55 N 1161.61 0.14 1138.36 N 1267.42 0.53 1243.21 N 1371.50 1474.31 1575.10 1674.09 1775.26 1880.91 1992.29 2109.70 2232.28 2358.25 2485.08 2613.86 2746.82 2880.55 3011.62 3141.51 3271.95 3401.35 3526.35 3650.25 3772.21 3891.57 4008.35 4125.04 4238.75 4349.09 4456.56 4562.37 4665.25 4?64.56 0.61 1346.36 N 0.53 1448.29 N 0.43 1548.18 N 0.51 1646.23 N 0.82 1746.41 N 0.92 1851.07 N 0.69 1961.46 N 0.43 2077.80 N 0.39 2199.38 N 0.63 2324.29 N 0.62 2450.18 N 1.32 2578.13 N 0.50 2710.Z7 N 0.72 2843.27 N 0.79 2973.61 N 0.71 3102.92 N 0.71 '32 33.05 N 1.20 3362.35 N 0.70 3437.35 N 0.70 3611.26 N 0.67 3733.25 N 0.94 3852.49 N 0.18 3969.04 N 0.61 4085.49 N 0.82 4199.05 N 0.40 4309.46 N 0.77 4417.02 N 1.10 4523.13 N 1.75 4626.72 N 1.19 4727.22 N 128.73 W 406.43 N 18 27 W 152.30 W 478.29 N 18 34 W 179.18 W 559.74 N 18 40 W 204.33 W 649.12 N 18 20 W 222.71 W 745.77 N 17 22 W 237.54 W 851.27 N I6 lZ Wi 252.47 W 959.68 N 15 15 W' 267.33 W 1066.59 N 14 30 W 282.34 W 1172.86 N 13 55 W 297.04 W 1278.21 N 13 26 W 311.36 W 1381.89 N 13 1 W 325.17 W 1484.34 N 1Z 39 W 339.03 W 1584.86 N 12 21 W 353.12 W 1683.67 N 1Z 6 W 367.76 W 1784.72 N 11 53 W 382.73 W 1890.23 N 11 40 W 398.06 W Z001.44 N 11 28 W 414.38 W 2118.72 N 11 16 W 430.84 W 2241.13 N 11 5 W 446.98 W 2366.88 N 10 53 W 462.60 W 2493.47 N 10 41 W 477.24 W 2621.93 N 10 29 W 492.02 W 2754.57 N 10 17 W 505.93 W 2887.93 N 10 5 W 519.80 W 3018.70 N 9 54 W 532.07 W 3148.21 N 9 43 Wy' 541.86 W 3278.15 N 9 30 W 549.65 W 3406.98 N 9 17 W 556.18 W 3531.43 N 9 3 W 562.60 W 3654.82 N 8 51 W 568.70 W 3776.31 N 8 39 W 576.03 W 3895.32 N 8 30 W 584.38 W 4011.83 N 8 22 W 592.75 W 4128.27 N 8 15 W 600.09 W 4241.72 N 8 7 W 605.22 W 4351.75 N 7 59 W 609.99 W 4458.94 N 7 51 W 612.59 W 4564.43 N ? 42 W 611.32 W 4666.93 N 7 3I W 605.18 W 4765.80 N 7' 17 W STANDARD ALASKA PROD. 3-11 / M-30 SD[ ENDICOTT NORTH SLOPE,ALASKA CO. COMPUTATION TRU MEASURED VERTI DEPTH OEP 10050.05 7955 10189.87 8055 10329.92 8155 10469.90 8255 10609.27 8355 10749.54 8455 10990.19 8555 11030.24 8655 11168.12 8755 11308.82 8855 11453.87 8955 11599.31 9055 11744.17 9155 11889.03 9255 12035.24 9355 12178.90 9455 12321.68 9555 12461.62 9655 12597.60 9755 12729.84 9855 12858.88 9955 12986.91 10055 13112.15 10155 13235.25 10255 13353.05 10355 13530.00 10508 INTERPOLATED VALUES POR E SUB-SE CAL VERTIC TH 9EPT A COURSE AL DEVIATION AZIMUTH H DEG MIN DEG MIN .15 7900. .15 8000. .15 8100. .15 8200. .15 8300. .15 8400. .15 8500. .15 8500. .15 8700. .15 8800. O0 44 14 N 7 32 E O0 44 31 N 7 17 E O0 44 20 N 3 22 E O0 44 4 N 3 27 W O0 44 19 N 4 54 W O0 44 35 N 4 29 W O0 44 36 N 4 10 W O0 44 4 N 4 1 W O0 43 39 N 8 54 W O0 45 41 N 7 54 W .15 8900. .15 9000. .15 9100. .15 9200. .15 9300. .15 9400. .15 9500. .15 9600. .15 9700. .15 9800. O0 46 51 N 7 7 W O0 46 25 N 6 55 W O0 4d 17 N 6 46 W O0 46 41 N 6 32 W O0 46 21 N 6 37 W O0 45 44 N 6 23 W 90 45 8 N 5 52 W 00 43 34 N 4 34 W O0 41 4! N 3 21W O0 40 4 N 2 26 W .15 9900. .15 10000. .15 10100. .15 10Z0O. .15 10300. .63 10453. O0 38 46 N 2 29 W O0 38 2 N 2 3 W O0 36 21 N 0 26 W 00 34 6 N 0 36 F 00 30 7 N 1 23 E 48 29 51 N 1 33 E DATE: 12-SEP-B8 KELLY DATE OF SURVEY: BUSHING ELEVATION: ENGINEER: EVEN 100 VERTICAL SECTION FEET 4860.54 4955.43 5051.27 5148.64 5245.68 5344.03 5441.88 5540.98 5,535.74 5734.61 5839.64 5945.23 6050.01 6154.83 6261.48 6364.62 6466.52 6564.40 6656.48 6742.86 6824.25 6904.02 6979.16 7050.53 7112.26 7199.57 FEET OF SUB-SEA DEPTH DOGLEG SEVERITY DEG/IO0 RECTANGULAR COORDINATES HORIZ. DE NORTH/SOUTH EAST/WEST DIST. AZ FEET FEET FEET DE I .32 0.57 3.43 3.55 0.52 0.65 0.17 2.04 1.24 PAGE 8 07-5EP-88 55.15 FT MCBRIDE 0.37 0.30 0.46 0.74 I .0~+ 0.16 1.00 1.43 1.41 1.48 PARTURE IMUTH G MIN 0.12 1.88 0.76 4.40 2.14 0.00 6784.45 N 736.39 W 6824.30 N 6 11 W 6864.32 N 739.51 W 6904.04 N 6 8 W 6939.71 N 741.15 W 6979.18 N 6 5 W 7011.47 N 741.14 W 7050.53' N 6 2 W 7073.66 N 7~0.00 W 7112.26 N 5 58 W 7161.70 N 737.62 W 7199.58 N 5 52 5804.45 N 640.98 W 5839.73 N 6 18 W 5909.27 N 653.79 W 5945.33 N 6 18 W 6013.31 N 656.34 W 6050.11 N 6 19 W 6117.45 N 678.3,2 d 6154.94 N 6 19 W 6223.39 N 690.61 W 6261.59 N 6 19 W 6325.86 N 702.36 W 6364.73 N 6 ZO W 6427.17 N 713.30 W 6466.63 N 6 19 W 6524.65 N 722.26 W 6564.50 N 6 19 W 6616.56 N 7!8.71 W 6656.57 N 6 17 W 5702.97 N 733.01 W 6742.93 N 6 14 W 4824.~2 N 594.74 W 4861.34 N 7 1 W 4921.63 N 5"31.42 W 4955.85 N 6 44 W 5019.09 N 5?0.96 W 5051.47 N 6 29 W 5116.99 N 570.99 ~ 5148.75 N 6 22 W 5213.68 N 579.43 W 5245.78 N 6 20 W 5311.73 N 587.42 W 5344.12 N 6 18 W( 5410.35 N 594.85 W 5442.95 N 6 16 W 5508.19 N 601.46 W 5540.93 N 6 13 W 5602.38 N 612.71 W 5635.79 N 6 14 W 5700.29 N 6!7.16 W 5734.69 N 6 16 W STANDARD ~LASKA PROD. CD. 3-11 / M-30 SDI ENDICOTT NORTH SLOPE,ALASKA MARKER BEGIN LDG INTERVAL END LOG INTERVAL DRILLERS OEPTH COMPUTATION D6TE: 12-SEP-B8 PAGE 9 D~TE OF SURVEY: 07-SEP-88 KELLY gUSHING ELEVATION: 55.15 FT ENGINEER: MCBRIDE INTERPOLATED VALUES FOR CHOSEN HGRIZOflS MEASURED DEPTH BELOW KB FROM KB ORIGIN= 2529 SNL, 829 TVO SU3-SEA 0.00 0.00 -55.15 13397.00 10393.29 10338.14 13530.00 10508.63 10453.48 SURFACE LOCATION AT WEL SEC Bt TllNt R17E RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 0.00 N 0.00 E 7095.51 N 73g.42 W 7161.70 N 737.62 W STANDARO ALASKA PROD. CO. 3-11 / M-30 SDI ENDICOTT NORTH SLOPEgALASKA CEMPUTATION DATE: 12-SEP-B8 PAGE 10 DATE OF SURVEY: 07-SEP-88 KELLY BUSHING ELEVATION: 55.15 FT ENGINEER: MCBRIOE MARKER DRILLERS DEPTH ~~~ STRATIGRAPHIC MEASURED DEPTH BELOW KB 13530.00 FROM KB 10508.,53 SUMMARY ~~~ SURFACE LOCATION ORIGIN= 2529 SNL, 828 WEL, SEC B, TllN, R17E TVO RECTANGULAR COOROINATES SUB-SEA NORTH/SOUTH EAST/WEST 10453.48 7161.70 N 737.62 W ~INAL WELL LOC~TION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 13530.00 10508.63 10453.4~3 HORIZONTAL DEPARTU2E DISTANCE AZIMUTH FEET DEG MIN 7199.58 N 5 52 W SCHLUMBERGER D l RE C T ~ ONAL SURV E Y COMPANY STANDARD ALASKA PRODUCTION WELL ~-I i / M-BO SD I FIELD END I COTT COUNTRY USA RUN 0 i DATE LOGGED O? - SEP - 88 REFERENCE 72927 WELL' ' 3-Il/M-30 SDI (2529' SNL, 828' WEL iEC 8, TllN, R17E) HORIZONTAL PROJECTION NOR?H IZO00 R~F 7Z927 SCALE : 1 / ZOO0 I N/FT 8000 6000 4000 2000 -ZOO0 -4000 -BO00 WEST -SO00 -4000 -2000 0 -?.--?...?~IT..?..?...? .... 2000 400O 6000 8000 WELL ' (2529' 3-Il/M-30 SDI VERTICAL PROJECTION SNL, 828' WEL,',--SEC 8, TllN, R17E) ~ -4000 -2000 0 0 2000 4000 6000 8000 10000 : i i i i t i i"li'"i'"t"i'l'i'"?~'l'~" i"'i-'!'"!'"tl'~"'~-~-i"'Fi-+--i--!-- --~-.-~...~,~-"!-,-i---!,,.i,--~..-i,-.i..,i---!,--~-.,~-,.!,,.i-,~..~..,!...i..,!.-! -~.,..~,-,~..~..,~,..~,..i,..i.,,~...~...~.,. ~,,..i..,~.,.i...~...~..,!.,,~._ ~..,~,.,i,.,~.,.~...:..- -~.4...~...~... LEi;]]] i ] ~ ] Z ~ ~ ~ ] '] ] ~ ] t ~EE~ ]l] ~; ~ ~; ~"; .... ?7-?J'"?"m ...... ?"?"?'?'r?'??"!'" "i'"~'-?"?"f'+"??'i ...... ~"+'~'"?'t'"f"~"i'"?"k?'~'"?"?T''~'''~'''76't''~'''6'~-~'-~ ....... ~'"~"'~'"~'I'" ~''' ~'' ~i~.~+~4~~4~+~L~tJ~J~L~L~L~]:J~:~:~:~:;:~Z~ ; ~ , · : · .... I .... PROJECTION ON VERT,:Cg, L F',_~,.: 12000 q54. E¢S4. - 174, SCALEF~ I~'J VERTICAL DEPTHS HCRI7 SCALE = 1/2000 I~;,'?l" STANDARD ALASKA PRODUCTION CO. SDI 5-11(31-5-1 I-17) M-30 Controlled Drilling Consultants, Inc. 3334552 · . ,~,~ ;.~ CONTROLLED DRILLING CONSULTANTS, INC. P.O. Box 190560 Anchorage, Alaska 99519-0560 (907) 333-1552 August 30, 1988 Mr. Brian Rose Standard Alaska Production Company Pouch 6-612 Anchorage, AK. 99502 RE: Magnetic Single Shot Survey Job No. A-O888-O07 Well: M-30 3-11(31-5-11-17) Endicott Field North Slope, Alaska Date of Survey 8-7-88 to 8-30-88 Dear Mr. Rose' Please find enclosed the "Original" and six (6) copies of our Magnetic Single Shot Survey on the above well. The method of calculating this survey was Radius of Curvature. The depth of the survey was O' to 12,624'. Thank you for giving us the opportunity to be of service. Yours very truly, Controlled Drilling Consultants, Inc. Cecil Harrington Directional Supervisor ::'-T-~-~ .... : ...... ~--~-~ ~AGNETJC SINGLE*SHOT : ~ , ~ 4 ; , ~ , ' , , ~"~'*:"-~'--"~-r-"~'? 757.. : , ~ ~ ; ~. ~ ~ .~: , ~ - '-F~-'~;.....T_.r._T_.;_: .T_T._.F._~_T...~__~.. :_~_.~.._?__~_ ?:_: .: .':_~L__ :::-. .... . ~ . , : ~ . . : · , ~ , '~ :.-, : , .... STANDARD · SKA PRODUCTION COHPAN¥ MAGNETIC SINGLE SHOT SURVEY RADIUS OF CURVATURE HETHOD OF COHPUTATiON ENGINEER C.'W,HARRINGTON cOHP~TED FOR cDC BY OCEANTECH RECORD OF SURVEY TRUE 'MEAS, DRIFT VERTICAL "~PTH ANGLE DEPTH D M SUB SEA DRIFT DIREC DEG, TOTAL ASSUMED VERTICAL TO 0 0 0 460' t 0 1005 t45 1461 ! 0 t935 0 15 2494 0 I5 2749 0 18 2854 2 0 2946 6 0 3040 10 3t34 12 24 )226 15 i8 3319 18 6 3529 21 24 3715 25 30 3900 30 18 3994 32 54 4184 38 24 4234 40 0 4351 41 4446 43 ,00 459,98 1004,82 t460,68 I934 65 2493 64 2748 64 2853 62 2945 37 3038 43 3130 62 32t9 93 3309 O0 3506 62 3677 22 3840 67 3920 72 4075 06 4ii3 80 Cons. · ~nchorag~ :~ ..... 0 Fl', -55. 15 404,83 949.67 ! 405.53 ~J 879.50 2438.49 2693.49 2798,47 289 O, 22 2983,28 3 075,47 3164,78 3253,85 345t , 47 ~622,07 3785,52 3865,57 4019,91 4 058,65 4147, 15 4217.. !4 N N29 N45 N74 N49 S62 N 1 N~ 3 N 8 N 6 N15 N16 NJ8 Ni7 N~8 N16 .OOE , OOW . OOW , OOW . OOW .60E .OOE , ,40W .?OW ,70ti , OOIj ,80W .20W .40W ,60W .50W .40W .00 S 3.5! N 13,92 N 19.42 N 21.86 N 22,i2 N 21,12 N 22,01 N 28.37 N 4i.29 N 59,47 N 81,05 N ! 06,96 N i75 72 N 246 33 N 328 64 N $75 53 N 48i I0 N 5ii 39 N 585 i 4 N ~47,92 N JO8 NO A0888-007 WELL 3-il/M-30 KB ELEV 55, 15 FT, SURVEY DATE 08/0??88 PROPOSED OtR NOS-54W COORQINATES DOG LEG C L 0 S U R E S SEVER-I-T¥ SECTION DISTANCE ANGLE DEG/IOOFT DISTANCE D ~ S i 95 W 9 79 W t9 i2 23 G3 259! 2591 24 39 25 08 27 55 29 96 34 24 40 75 58 21 80 34 07 08 22 I3 55,42 64,42 84.80 98. ~8 .OO S 90 o O W 4,0i N 29 O OW i7.02 N 35 7 8 W 27,25 N 44 32,19 N 47 13 iO 34,07 N 49 30 33,43 N 50 40 39 W 32,85 N 47 56 2.1 W 37.87 N 4~; '-28 2i W 49,64 N 33 42 50 W 66,59 N 26 44 25 W 87,98 N 22 53 58 W 114.46 N 20 5! i ! W 185,11 N 259 1 0 N 345 64 N 394 89 N 505 58 N 537 17 N 6i3 63 N 6,77, E, 0 N i8 t9. 3'"' W,., I8 3 45 i.~t i8 2 48 W ,., ._ 7 t,.t 17 54 ii b~ !7 i 24 W · O0'O .2i7 , i 64 ,05t .625 ,35i ,365 ,448 ~, 029 ,587 , ~ 04 . '20 t ,656 O0 2I ,28 24,18 24,67 23,67 '- 24,40 ':' :i R 0 43,9i 62,24 84, i4 '10.59 253, '29 337 .~85, 09 494... 5'}~ ~'o 601 04 664 8S SOHIO WELL TRUE i MEAS-~-DR,-tFT VERTICAL i DEPTH ANGLE DEPTH ~753 4?30 4943-47~ 53t4 46 24 ~785 44 48 6073 46 54 62'67 48 4-8 6734 5~ 54 7023 52 24 7295 53 36 749t 52 54 7687 52 54 8037 52 30 8233 51 30 8402 51 O 0594 50 )800 49 9053 49 24 9248 48 0 943747 30 9722 46 9916 45 6 1O291 44 24 104!8 44 24 10558 44 30 t0745 45 6 1O938 45 0 4340.22 4486.41 4868,74 5198,27 5398.86 5529,05 5645,~2 5826,04 6003,37 6167 06 6284 33 6402 5~ 6735 33 6841 11 6962 84 7259.09 7387,79 75t4,87 77~8,~4 7845,99 8112,3t 82 03.05 83 02,99 8435,68 8572,03 :SUB SEA 4285,07 443~ 4559, SE,, 4813,,59 5i43, i2 5343,71 5473,90 559 O. 67 577 O, 89 5948,22 611l ,91 6229, ~ 8 6347.41 6559,5 ! 6680,18 6785.96 6907,69 7039,97 7203,94 7332,64 7459,72 7654,99 7790,84 8057, 16 8147.90 8247,84 838 O, 53 SINGLE SHOT SURVEY ,..IOB NO A0888-007 RECORD OF SURVEY DRIFT TOTAL bOORDiNRTE. C L 0 DtREC DISTANCE DEG. N 9,20W 713,39 N N 6,80~ 865,40 N N 6,20W i004,36 N N 5,90W t27;~,52 N N 7,tOW 1607,85 N N 8,30t,~ i812,62 N N 7,40W ~955,~0 N N 6,70B 209i,03 N N 6,80fJ 23i2,83 N N 4,30W 2539,94 N N 5.20W 2756.42 N N 4,90W 29i2,85 N N 5,80W 3068.50 N N 3,80W 3345,92 N N 2,20t,~ 3500,15 N N , 501.¢ 363i,9i N N 3,70W 3780,26 N N 4,GOW 3937,77 N N 4,40i¢J 4129.84 N N 2,40W 4276,07 N N ,60B 4415,92 N N 1.60E 4623,48 N N 5,60E 4761,66 N N 3,70E 5024,79 N N 2.!0W 5113.60 N N 4,40W 5211.47 N N 3,60[¢ 5342.92 N N 2,70~ 5479,30 N 230,8i 2.46, ~5 275, 17 3t3,27 340,95 360,60 377.41 403,66 425.73 443,'/'I 457,54 472.tl 495.4i 503.49 506,60 512.04 523 47 ,.=38 58 547 27 550 93 549 i 2 540 43 51~ 07 517.79 523,34 532,53 540,04 743,50 895 i O34.20 1302.91 1638.09 184'4,4t 1988,07 2124,82 2347.79 2575,37 27~t ,90 2948,57 3i 04 60 3382 4 O 3536 t 8 3667 07 38~ 4 78 3972 4 4i64 43t 0 95 4450 4655 97 4792 23 505i 52 5139 74 5237 68 =369 39 55 05 85 COMPUTER- 07 SEP 88 KB ELCV s=: FT DOG LEG R E S SEVERITY SECTION ANGLE D-EG/t-OOFT DISTANCE- ,045 ,206 ,200 ,246 · 362 i', 814 .865 55.¢4 ~ 78 .370 377 852 352 t65 ,58~ 66! t34 239 731 , t4 ..... 884 54 i 02-4 · ~,., 1295 163t 54 i-~o ~, '87 ]98i 81--- 2i !8,75- 2342,07 '- ,~ ~ ~ ,~ ~' 2944,46 .... ~i 00,77 3379~ ~ 2 3~,64 , 75 38i2,87 3970 ~¢' 4t63,3~ 43 09,67 4449, ~ 6 4655,4~ 479~ ,99 ~ '~5 ~ 52 ~:37 66 ~369,35 350~ .... .SOHIO {dELL SINGLE SHOT SURVEY TRUE 'MEAS. DRIFT YERTtCAL SUB DEPTH SEA DEPTH ANGLE D M .~t15 43 36 8638,7t 8643.56 ,- 307 46 24 8834,46 8779,31 11486 46 54 8957,33 ~902,t8 t1658 46 42 9075.07 9019.92 t1768 46 24 9t50,72 '~095.57 12090 45 30 9374.60 93t9,45 12249 45 54 9485.65 9430,50 t2437 43 48 9618.93 9563,78 THE FOLLOWING IS EXTRAPOLATED 12624 4t 24 9756,57 9701.42 RECORD OF SURVEY DRIFT D!REC DEG, TOTAL doE, NO ROSSS-O07 COORDINATES C L 0 S U DISTANCE N 6,20W 5736.87 N 7, t OlJ 5'.866. i6 N 6 , 20i~ 5998.78 N 5. ~OkI 6070.I5 N 4,eon 6300,81 N 4.90t~ 64~4.26 H 4,~OW 6546.43 TO TD N 2,60~ 6672,78 N BOTTOM HOLE CLOSURE 6704.62 FEET AT N 5 35 I0 N 552.2i W 5629.4I N 569.69 W 5765.09 N 584.76 W 589'5.23 N 599.28 W 6020.60 N 607.28 N 6t00.45 N 626.04 ~ 633i.84 N 634.87 W 6445,6i N 645.27 W 6578.t6 N 652,67 kt 6704.62 N CONPUTER- 07 :=,EP 8S KB ELEV 55..i5 FT. DOG LEG R E S SEVERITY SECTION ANGLE DE-G?tSOFT DISTANCE 5 40 i5 N ~.599 5765.04 5 4.2 45 N ..301 ~8'2.0.56 5 42 47 ~ .58e 6~00.42 5 40 27 W .347 6331.79 5 39 9 ~ ..... 8~ 6445 55 5 37 45 ~ 1.i35 6578.09 5 35 i O ~. i ,.S.',~t 6784-52 SOHIO WELL 3-11/M-JO SINGLE SHOT o ~URVEY JOB HEASURED DEPTH MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN !00 FEET TRUE VERTICAL SUB MD-TVO DEPTH SEA DIFFERENCE VERTICAL CORRECTION 155 255 355 455 555 655 755 855 955 1 0'55 I155 1255 1355 1455 i 555 1655 1755 1:955 I95& 2 056 2256 2356 2456 2556 2656 2756 2856 2956 3057 31 59 326:3 3368 3474 O, -55 0 0 t55, t00 0 0 255, 200 0 0 355, 300 0 0 455, 408 0 0 555, 500 O 0 655. 600 0 0 755, 700 O 0 855, 8O0 O 0 955, 900 0 0 1055. lO00 0 0 1155, 1100 0 0 t255. 1200 O 0 t355, 1300 0 0 1455, 1400 0 0 i555, 1500 0 1655. I600 0 0 1755, 1700 0 O t855. I800 0 0 1955. 1900 0 0 2055. 2000 0 0 2155, 2100 0 0 2255. 2200 O 2355, 2300 0 0 2455, 2400 0 0 2555. 2500 0 0 2655, 2600 0 0 2755, 2700 0 O 2855. 280O 0 0 2955, 2900 0 0 3055. 3000 ! 1 3155, 3100 4 3255, 3200 7 3355, 3300 t2 5 3455, 3400 NO A0888--007 OF SUB ~ ¥_A DEPTH COMPUTE'R- 07 SEP 88 K8 E~EV 55 iq FT TO'TAL COORDINATES ,45 1,19 3.45 5,04 6.79 8,69 i0,70 12,83 t4.95 i6.67 17,97 i8.87 19.40 i9.90 20,45 2i,00 2i.5~ 2i.92 22,15 22 30 22 36 22 32 22 20 21 94 2i 48 21 11 22 06 29 41 44,30 64.99 90.71 I22,00 i56,72 ,gO ,08 E .34 E ,9i E t.89 E 2.84 W 5.35 W 6,95 tsj i0,88 1~,05 W i5,i6 17.i7 W 20,5~ W 2i,79 22.72 W 23,34 23,70 W 24, ~ W 24,47 24.90 25,34 W 25,75 26,i! 26.18 W o5 8~ 24,39 25,32 27,99 30.73 36.84 t.~i 44,i9 W 52,96 W SOHIO WELL MEASURED DEPTH AND OTHER DATA MEASURED DEPTH TRUE VERTICAL SUB DEPTH SEA 355! 39t7 3855, 4035 3955, 4t59 4055, 4288 4422 4255, 4562 4355, 4707 4455, 4855 4555, 5002 5t49 5294 5439 5582 5724 5866 6 009 6i56 ~07 6620 678t 6944 7108 7275 7443 7608 7774 7939 8265 8424 SINGLE SHOT SURVEY dub NO A0888-007 FOR EVERY EVEN 100 FEET OF SUD SEA DEPTH. HD-TVD VERTICAL DIFFERENCE CORRECTION TOTRL COt~PUTER- O? K8 ELEV 55, ~,5 3500 26 3600 35 9 3700 4'7 3800 6J 14 4000 JO3 23 4200 167 34 4300 207 40 4400 25I 44 4500 299 48 4655, 4600 346 47 4755, 4700 393 47 4855, 4800 439 46 4955, 4900 483 44 5055, 5000 526 43 5155, 5t O0 568 42 5255 , 5200 61 0 42 5355. 5300 654 44 5455, 5400 700 46 5555, 5500 751 51 5655, 5600 806 55 5755, 5700 864 58 5855, 5800 926 62 5955, 5900 988 62 6055, 6000 i053 65 6i55. 6t00 lii9 66 6255, 6200 it87 68 6355. 6300 i253 66 6455, 6400 i318 65 6555. 6500 1383 65 6655. 6600 t448 6755. 6700 t509 6855, 6800 1569 60 6955, 6900 !626 57 ~94,52 236,48 203.42 336.79 397.t8 545,2t 632.~1 728.35 83t,84 t047.50 ~t54.05 1259.3t 1 363.09 ~ 465,04 ~565,21 ~664,46 t766,76 1873,03 1984.85 2~02 20 2224 07 2349 76 2477 69 2607 43 2740 35 2874,29 3006,~1 3~37,58 3268,4~ 3398,27 3525,02 3649,23 COORDINATES N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N 63,74 77.04 92,69 i09,62 i29,25 t50..93 i74.i2 i95.42 2ii,84 226,64 25f 262,69 273,78 284,68 308,00 320.49 334.38 349,56 364.42 378 "'* ~q3 ii 407,93 420.67 430,97 454 2i 4~5 98 478 83 489 89 498 64 504 38 586,8~ 51 ~ ,45 W W W W W W W W W W W- W W W W W W W W W W SOHIO YELL 3-1i?M-30 SINGLE SHOT SURVEY JO8 NO MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN lO0 FEET OF · TRUE VERTICAL SUB MD-TVD DEPTH SEA DIFFERENCE VERTICAL CORRECTION 8?38 8893 9047 9i'99 9348 9496 9643 9?8? 9929 JO070 1035! 10773 I09i4 11055 i~337 ~774 ~2062 ~2205 12348 12487 12622 12624 7055, 7000 1682 56 7~55. 7~00 1737 55 7255. 7200 179t 54 7355, 7300 ~843 52 7455. 7400 ~893 50 7555, 7508 ~94~ 48 7655, 7600 t987 46 7755, 7700 203~ 44 7855, 7800 2073 42 7955, 7900 2~15 42 8055. 8000 2~55 40 8155. 8t00 2;95 40 8255. 8200 2~35 40 8355, 8300 ~276 41 8455, 8400 23~7 41 8555. 8500 2358 4t 8655. 8600 ~399 8755. 8700 2438 39 8855, 8800 248~ 43 8955, 8900 2527 46 9055. 9000 2573 46 9155, 9100 2619 46 9255, 9200 2663 44 9355, 9300 2707 44 9455, 9400 2750 43 9555, 9500 2792 42 9655, 9600 2831 39 9755, 9700 2866 35 9757, 970~ 2867 A0888-007 SUB SEA DEPTH, TOTAL COORDINATES 3890.49 N 4008,39 N 4!25~24 N 4239.64 N 4350,49 N 4459,64 N 4566~t4 N 4669.8~ N 4779,80 N 4870.20 N 4968,79 N 5 066,57 N 5;64.63 N 5262,80 N 5362,40 N 5462,42 N 5560,81 N 5656,56 N 5758,50 N 586~.85 N 5969,63 N 6074,7~ N 6!78.59 N 6281.04 N 6382,96 N 6484,38 N 6580,71 N 667~,5~ N 519,77 529.~-0 538,23 545,59 549,77 55~.22 550.43 547,29 5~9.54 530,53 522,84 515,32 520,~9 527,~5 533.74 539.23 54~.65 559,93 572,87 584.48 596,97 607.7~ 6~6,'76 624 64 632 26 640 6~ 647 6~ 652 6i ~52 67 COMPUTER- 07 SEP 88 KB ELEV 55,!5 FT. INTERPOLATED MEASURED DEPTH ~ O00 ~000 3000 40 O0 5000 6000 ?000 ~000 ~ O00 I 0000 ~}000 12000 12624 VALUES FOR EVEN TRUE VERTICAL DEPTH SINGLE SHOT SURVEY !000 FEE'[,' OF d NO A0888-007 COMPUTER- 07 :~'EP 8-9 KB ELEV 55.15 FT. SUB SEA TOTAL MEASURED DEPTH. O, -55, 1000, 945, 2000, 1944, 22. 2999, 2944, 34. 4654. 4599, J045. 5349, 5294, i760. 5989, 5934, 252~. 6592, 6537. 33t6, 7225, 7i69, 4089, 7905, 7850, 4820. 8616, 8561, 5522, 9312, 9257. 6236. 9757, 9701, 6672. COORDINATES O0 S 03 N 23, 97 N 26. 78 N 424, 63 N 493. 70 N 535. 82 N 534. 86 N 542. 65 N 621, 78 N 652, O0 W 69 W 85 W 47 W 44 W 41 W 48 W 85 W 88 W 67 W Standard Alaska Production Company 900 East Benson ~ouleva~Er,~,,- PO. Box 196612 Anchorage. Alaska 99.519-66t2 9071 561-511t October 20, 1988 STANDARD ALASKA PRODUCTION Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Endicott Field - Bottom-Hole Pressure Reports Dear Sirs' Enclosed are Bottom Hole Pressure Reports for the following wells in the Endicott Reservoir: Well Name Date 1-09/J-18 2-28/P-19 2-44/R-12 3-05/0-29 3-1 l/M-30 3-35/L-36 3-39/J-39 4-02/Q-28 4-26/0-34 10-10-88 09-27-88 08-30-88 10-10-88 09-27-88 10-09-88 09-12-88 07-26-88 09-18-88 If there are any questions regarding this data, please contact Loren Twyford at 564-4401. A unit of th~ anginal Standard Oil Company Founded in Clevelond, ~io, in 1870. Sincerely, Jeanne L. Haas Standard Alaska Production Company ~ 900 East Benson ~ou~evora PO. Box 196012 Anchorage. Alaska 99519-6612 k9071 561-51~1 I'&NI AI I ALASKA PRODUCTION October 7, 1988 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Endicott Well Log Information Dear Mr. Boyle: Enclosed please find one sepia and one blueline print for the cased hole well logs run in the following Endicott well: WELL 3-39/J~39 *Pump-In Temp. Survey Collar Log 13700'-14640' Run No. 1 Camco WELL 2-28/P- 19 *CCL LOG 9200'- 10451' Camco Run No. 1 WELL 3-1 l[Mr30 *CCL LOG 12300'-13403' Camco Run No. 1 Received By Sincerely, Date A unit of the original Standard C~I Company Founded in Cleveland, Ohio, in 1870. M EMORAN DIOM State O'f Alaska ALASKA OIL AND/GAS CONSERVATIOM CO~-~ISSION 'TO: Lonnie C · ~ DATE: August 18, 1988 Commissioner FILE NO: D. BDF. 010 THRU: Michael T. Minder Sr. Petroleum Engineer TELEPHONE NO: SUBJECT: BOP Test SAPC DIU 3-1I/M-30 Endicott Field FROM: Petroleum Inspector Tuesday, August 9~ 1988: The test began at 3:00 p.m. and was com- pleted ~at 6:00 p.m',- "~s" the attached BOP Test report shows there were no failures. In summary, I witnessed the BOP Test on SAPC's 3-11/M-30. Attachment 02-001A (Rev. 8/85) O&G #4 ~W84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date · Location: Sec ~ T~//1/R/~'M.~'J] /~~Casing Set ontrac or - .'C:- Location, General ~1~ Well SignO~ ACCUMULATOR SYSTEM General Housekeepin~~___Rig Reserve Pit Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure Test Results: Failures Full Charge Pressure ~P~? psig. ~re~r~ A~t~r C~o~ur~ /_f~CO p.~ig Pump incr. clos. pres. 200 psig -- min2/ sec. Full Charge Pressure Attained: ~ min~-3.~_sec. Controls: Master -- / RemOte ~~Blinds switch cover Kelly and Floor Safety Valves ' Upper Kelly / Test Pressure Lower Kelly / Test Pressure . ~©~ Ball Type / Test Pressure ~_~.~0~ Inside BOP / Test Pressure Choke Manifold~Test Pressure~DSU-z3 No. Valv?s Adjustable Chokes Hydrauically operated choke Test Time ~ hrs. Repair or Replacement of failed equipment to be made within ~' day~ and Inspector/ Commission office notified. / Distribution orig. - AO&GCC cc - Operator cc - Supervisor August 4, 1988 J G Vidrine Endicott Drlg Eng Supervisor Standard AlaSka Production Company P O Box 196612 Anchorage, AK 99519-6612 Telecopy No. (907) 276-,7542 Duck Island Unit/Endicott 3-11/M-30 SDI Standard Alaska Production Company Permit # 88-87 Surf Loc 2529'SNL, 828"~L, Sec 8, TllN, RITE, ~ Btmhole Loc 558'SNL, 1510'WEL, Sec 5, TI!N, R17E, UM Dear Mr Vidrine: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable ne..a t4o obtain additional permits required by law from other govern- m~m~al agencies prior to commencing operations at the well site. -~-~'~T° aid us in scheduling field work, please notify this ofiice 24 hours prior to commencing installation of the blowout pr.evention equipment so that a representative of the Commission may be present~'to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that 'the Commission may witness testing before drilling below the shoe of the conductor pipe. / / '~ ~,' ,," /_. /: z~_ . .~ ........ ",. ' ,~' ', :' "t: :"' '~ " ," ":' ~''' ........ g- v ¢ at rto'n . Chairman Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION jo Enclosure C: Department of Fish & Game, Habitat Section - w/o encl Department of Environmental Conservation - w/o encl STATE OF ALASKA ,.-.' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill I-Illb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Standard Alaska Production Company BKB=56 feet Endicott Fie/d/Endicott Pool 3. Address 6. Property De/signation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 47502 V 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025 2529' SNL, 828' WEL, SEC 8, T11N, R17E Duck island Unit/Endicott At top of productive interval 8. Well number Number 900' SNL, 1475' WEL, SEC5, T11N, R17E 3-11/M-30 SD/ KOO683449-G-14 At total depth 9. Approximate spud date Amount 558'SNL, 1510' WEL', SEC5, T11N, R17E August6, 1988 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (aD and TVO) property line ADL 212828 900 feet 3-09/L-28 @ 10 feet 2469 13509'MD 10391' TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (sso 20 ^AC 25.035 (o)(2)) Kickott depth 2800 feet Maximum hole angle 48 0 Maximum surfaco 3558 psig At total depth (TVD) 10090' 4870'pslg 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" Struct. Drive Pipe 105 Surface 161' 161' Drive 17-1/2" 13-3/8" 68# NT80 Butt 2444 Surface 2500' 2500' 4185 cu ft Permafrost 12-1/4" 9-5/8" 47# NT80S NSCC 10630 Surface 10686' 8500' 12-1/4" 9-5/8" 47# NT95HS NSCC 1980 10686' 8500' 12666' 9826' 575 cu fl Class G 8-1/2" 7" 29# SMl10 Butt 1094 12415~ 9659' 13509' 10391' 435 cu fl Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Surface Intermediate Production ..,,ii~i !? : ~::' '~ Liner Perforation depth: measured ./ -'.;,~;:;c:, ,,-~, ,., ~.~',,,~:,~, true vertical ' ;:'~;'~:"!~'~"~'~' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify that the fp£egoing is true and correct to the best of my knowledge Signed b~...~' ~)~~,.~~_j Title Endicott Drilling Engineering Supervisor Date ~'/~2¢//~ ///- " Commission Use Only Permit Number ,2' IAPI number IApproval date See cover letter ~-~j7 150-O'i~-~l~l~ Iq~~~'~~s~ for other requirements Conditions of approval Samples required [] Yes I~No Mud Icg re I~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required !~ Yes [] No Required ~~.~ e~/~ working ssurefor 1-12 ; I~3M; ~SM; []10M; I-!15M; Other: by order of Approved by __ _ Commissioner me commission Dar Form 10-401 Submit,/ riplicate PROPOSED DRILLING AND COMPLETION PROGRAM WELL 3-11/M-30 (SDI) Objective Well 3-11/M-30 will be drilled as a production well. Zone 2A is the primary objective. The completion will be run at the time of drilling. Ooeration Execute a rig move from slot 4-26 to slot 3-11 and rig-up. Vertically drill 17-1/2" hole to 2500 ft. and cement 13-3/8" 68#/ft., NT-80 CYHE Buttress casing to surface. Pressure test casing. Install BOPE. Maximum BHP is 4870 psi at 10090 ft. TVDss. Maximum possible surface pressure is 3558 psi based on a full gas column. Drill out casing and 5 ft. of new hole and conduct a formation leak-off test. Vertically drill 12-1/4" hole to 2800 ft. then directionally drill to the intermediate casing point above the Kekiktuk formation. Run and cement 9-5/8" 47g/ft., NT80S and NT95HS, NSCC casing. No abnormal pressures are expected in the 12-1/4" hole section. Pressure test casing. Drill out casing shoe and 5 ft. new hole and conduct a formation leak-off test. Drill 8-1/2" hole to TD. Run open hole logs. Run and cement 7" 29#/ft, SM-110 buttress (TKC) liner to TD with approximately 250 ft. of lap in the 9-5/8" casing. Clean out to float collar. Test casing and lap to 3000 psi. Change over to NaC1 packer fluid. Run CET/ CBT/VDL/GR/CCL in 7" liner and gyroscopic survey from PBTD to surface. Perforate well underbalanced using guns run on drill pipe. Kill well and complete with a simple/straddlepack completion. A sub surface safety valve will be installed below base of permafrost. Nipple down BOPE. Install tree on wellhead and release rig. JWB/7-19-88 ENDICOTT PROP(;)$ED DIAGRAM WELL 3-11/M-30 (SDI) NON-FREEZING FLUID TVD CBKB) MD (_BKB) 30" DRIVE PIPE 161 FT 161 ~ BASE PERMAFROST 1466 FT 1466 FT SSSV 1600 FT 1600 FT TOP OF DOWN SQUFF71:: CEMENT (ESTIMATED) 2000 FT 13-3/8" 68#/FT L-80 BUTT 25O0 FT 25OO FT ~KOP(DIR:N5°47'W; ANGLE: 47.94°) 28OO FT BOTI'OM OF DOWN SQUE~ CEMENT (ESTIMATED) 3000 FT 4-1/2", 12.6#/FT L-80 TDS TUBING W/ 3-1/2" TAILPIPE TOP OF 9-5/8" CEMENT 9-5/8" 47#/FT NT80S NSCC (ESTIMATED) 8969 FT 8500 FT 10686 FT 4-1/2" SLIDING SLEEVE 9-5/8" PACKER 9625 FT 12365 FT 7"LINERTOP 9658 FT 12415 FT 9-5/8" 47#/FT NT95HS NSCC 9826 FT 12666 FT 7" PACKER PLUG BACK TD 13469 FT 7" 29#/FT SM-110 BUTT LINER 10391 FT 13509 FT JWB/7-19-88 B.O.P. STACK CONFIGURATION 13-5/8 IN. TRIPLE RAM STACK 5000 PSI WP DRILLING I I ANNULAR PREVENTER PIPE RAMS Z IN. KILL LINE GATE GATE I I I BLIND RAMS I I DRILLING SPOOL PIPE RAMS .... I I IN. CHOKE LINE HAND HYD. ASST. GATE GATE [ ] ~6 ~.~ ~1 Main Produ¢lio~ t~ 1.12 N. I 5 '4 T.I I N. 12 8 9 ~ ~ ~Satellite Drilling Island(SDI) ~ Howe Ishnd .;,..:.:~:.~. ~;~:;:~;=~:. = ..... --c, "' DRW NO. I1(;- 85 SHEET I of I0 REV. 0 PLAT OF PROPOSED WELL LOCATIONS MPI Wells Located In Sec.56, T. IZN.,R.16E.,Umiot M. SDI Wells Located In Sec. 8,T. IIN.,R.I?E.,Um'~ot M. PREPARED FOR SOHIO ALASKA PETROLEUM CO. PREPAREO BY F.R. BELL ~ ASSO.C. PRUDHOE BAY OFFICE PRUOHOE 8AY, ALASKA DATE: NOV. 13, 1985 SCALE: I""1 MILE DRAWN BY: R~3.T. CHECKED' BY' 8.E. 00000 O0 00000 0 2 4 6 8 I0 12 14 16 113 ~:)22 24 26 00000 0000000 0 Z6 30 :~. (~4 36 ~8 40 42 44 46 4~ ~0 000 0000000'0 0 Indicitii ~ell I k~rbl citify ~at I om Properly regil/e~d and IKiI~ ~r fhe Well num~eri ihown above. i PLAT OF /LOCiT[O INI[C. I. T U~ R LOCiTIoN~ PREp4R[D FOR TROLEuM CO. ~-, -,,o I~:~;~ "'.'.., ~ELL a A OC. . ~ IIL,~ I II I I I III ~J~l I~ I IIIII q~lJ~ ~L.L dbSP Z $ UTi, Jl~ & LATITUDf. LOI~""~,'UD4~ BI! BIB I Y- S417041'&~,47 II- 710il70,15 70c~19' 20, 2409· 147'$1'49,27~9' 233~5.21 B71,OG £- Z70163.10 E- , , 2 Y' ~S970796.40 N' 7801819.43 70°19'18.~B42' 147G51'~,8.610'5' 2703.73 t~.6O X' 270181.57 Es 467547.32 3 ' Y' 5970966.51 N' 7801871.22 70~19'20.254'2' ~ 147~5'~-'48.990'~' ~' 2~.~ i ~6B.14 X- 27017~.75 E- 467544,08 ' ~ - .... ~--I Y- S~709~7.S~ i N- 7~0~71.S9 ' 70r19'20.267~" ~ 147~ ~2'48.7016' 2~2.~8 8~.22 6 Y- ~970798.49 N- 7801B~0.17 70o19'1B.6108· 147o~1'4B.0~21· 2701.02 X- 270201.46 E- 467~5~.37 7 Y" ~970968.&0 N" 7801871.9~ 70019'20.2808' 147°51'48.4124' 2~31.23 848.31 X' 270~93.64 E' 467~0.13 ~ Y' ~970799.~4 N' 7801820.~4 70019'18.6240' 147c~1'47.7429' 2699.67 B25.86 X' 270211.41 E' 467556.39 9 Y' ~970969.&~ N' 7801872.32 70°19'20'2940' 147°~1'48.12~2' 2529.87 138.40 X' 27020~.~8 E' 467~53.16 ~0 Y' 5970800.58 N' 7801820.90 70°19'18.6373' 147°~1'47.4~37' 2698.32 B1~.9~ X' 270221.3~ E' 467~59.42 .. , 11 Y- ~970970.69 N- 7801872.~9 70019'20.3073' 147c~1'47.8~40' 2~28.~2 828.49 X- 2702i3.53 E- 467~6.18 12 Y- ~970801.63 N- 7801821.27 70o19'18.6~06' 147°~1'47.164~' 2696.97 806.04 X- 270231.30 E- 467~62.44 13 Y- ~970971.74 N- 780~87~.06 70o19'20.3206' ~47c51'47.5448' 2~27.17 818.~7 X- ~70223.47 E- 467559.2~ 14 Y- ~970802.67 N- 7801821.64 70o19'18.6639' 147°~1'46.87~4' 269~.62 796.13 X- 27024~.24 E- 467~6~.47 1~ Y- ~970972.79 N- 7801873.4~ 70o19'20.3338' 147°~1'47.25~6' 2~2~.82 808.66 X- 270233.42 E- 467~62.23 ~6 Y- ~970803.72 N- 7801822.01 "70°19'18.6771' 147°51'46.~862' 2694.27 786.21 X- 2702~1.19 E- 467568.49 17 Y- ~970973.8~ N- 780~873.80 70°19 ' 20. 34'71' 147°~1'46.9664' 2~24.47 798.7~ X- 270243.36 E- 46756~.26 18 Y- 5970804.76 N- 7801822.38 70°19'18.6904, 1~°~1'46.2970' 2692.91 776.30 X- 270261.~3 E- 467~71.~2 19 Y- 5970974.88 N- 7801874.16 70019'20.3604. 147°51'46.6772' 2~2~.12 788.83 X- 2702~.3i E- 467~68.28 ~.. , 20 Y- ~97080~.81 N- 7801822.7~ 70c19 '18. 7037' ~47°~1"46.00'7"B' 2691.~6 766.~9 X- 27027~.08 E- 467~74.~4 21 Y- ~97097~.92 N- 7~01i74.~ 70c19 ' 20. 3736· 147°~1'46.~880' 2~21.76 77B.92 X- 270263.2~ E- 46757[.30 i SDI PRO~SEDWELL L~ATION ~ST ~%%~t LOCATED IN SEC. 8 T. IIN R.IT[. UMIAT M 4( ,, ~..~~~ ~ SOHIO ALASKA PETROLEUM CO. ~.~ ~~ J~ DRW. NO, Ile-8~ PREPARED BY D&TE:NOV. I~,I98S e4~+~~/~~,~~__~ SHEE~ e of ,o F.R. BELL & ASSOC. SC,L[' N/, ~_~ss,~~~~. -- PRU DHOE BAY OFFICE ' RG.T. ~~~ REV. O PRUOHOE BAY, ALASKA°"*WN e .~ CHECKED ' 8.E. i F.I II III " II III ~ LI _J I I I i W{LL ~ ZONE I UT~'~"'"'JNE & LATITUDE L~''''~UDE lilT__ IIIT~ , Zl Y- 1970106.15 N- 7101123.11 7~19 '11, 7169' 14~11'4S,7186' 16~.ll 7~.47 2~ Y- 5970976.97 N- 7801874.90 70~19'2~.~869' 147°51'46.0989' 2~20.41 769.01 24 Y- ~970807.90 ~ N- 7801823.48 7 70~19'18. 7302" ~147c~1'4~.4294" ' 2688.86 746.54 X- 270290.97 ' E- 447~80.~ 2~ ~ Y- ~970~78.01-~ N- 780187~ 27 '-~'~-' T'-~" ~970~00:~4"~'N; ~OOle2~.O~ 27 Y- ~70~82,19 N- 780~;-~4--70~"J9-~~3 X- 270322,~2 E- 467~e~.4~ ~'28 Y- ~9708~3,~2 N- 780te2~,32 70o~9'~8,79~· ~47o~t'43.~83~· 2~12, t0 ; ~7,00 X- 270340,6~ E- ~67~.7t ~ 29 Y- ~97~983.24 N- 7801877.11 70~19'20.466~" 147°~'44;'3&37" 2~12.30i 70~.~ X- 2703~2,87 E- 467~92.48 , JO ~- $~081~,1~ ~- ~01~25,$~ X- 270350.64 E- 467~98.74 31 Y- ~970984.28 N- 7801877.48 7~'19'20.479~" ~47~1'44.074~" 2~10.9~ ~ ~99.&2 X- 270342 Bt E- 467~9~ ~0 32 Y- ~97081~,21 N- 7801B26.06 70~9'18.B231" 147°~'43,40~2" 2679.40 ~ E77.17 . X- 270360.38 E- 467601.76 33 Y" ~97098~.33 N" 7B01877.8~ 70~19'20.4931" ~47°~1'43.7~3" 2~09,~0 ~ El9 71 X- 2703~2.76 E- 467~9~,33 34 Y- ~970~16.26 N- 7B0~826.43 70c19'~0.B364" 247°~1'43.1160" 2678.04 ~67.26 X- 270370.~3 E' 467604.79 3~ Y' ~970986.37 N" 7801878.21 70°19'20.~063" 147°~1'43.496[" 2~0B.2~ , X- 270362.70 E- 467601.~ , 36 Y- ~970817.31 N- 7801826.80 70:19 '18. 8496· X- 2703~0.47 E- 467607.81 37 Y- ~970987.42 N- 7801878.~ 70c19'20.~96· 147°51'43.20~9· 2~06.1~ ~69.18 X- 270372,6~ E- 467604.~8 ' 38 Y; ~970818.3~ N- 7801827.1& 70o19'18.8629" 147°~1'42.~37~" ~ 267~.34 647'43 X- 270390.42 E- 4676~0,84 ~ 39 '~- ~970988,46 N- 7B01878.9~ 70o%9"20.~329 x- 270~2.~9 E- e67607.~0 .... 40 Y- ~9708~.'40 ~ N- 780~e27.~ X- 270400.36 E- 4676t3.e6 41 Y- ~9709-8~.~- N- 7B01879.32 70o19'20,~461· ~47o~1'42.'&286· 2504.~9 --42 Y- 970820.44 7,0z,27. 0 ,i i i SDI ~O~SEO WELL L~ATION LIST ~%~ LOCATED IN SEC. I,.T. II N., R. 17E. UMIAT : ~~~ - ~* SOHIO ALASKA PETROLEUMCO. ~ ' ~ ZIII I IITL~..~,I, til 6 LATITIIN L! Till 43 -Y' S970tt0.Si N' 710~179.&9''' 70~19'20.~594' 14~1'42.33t4' 2S02.14 i40,~4 44~ Y' S9701~i.4, N- 710Jl21.27 70Gig'ib.t027' S4~oSl~41~&7~' ' 2,7t'.29 Xm 27042~.2~ E~ 4&76~.91 4~ Y- 597099~.&0 N~ 710JBSG.0& 70~19'20.5727' S47G~I'42.0~02 x- 2704Z2.43 E- 467616.67 ....... ~ ......... 46 Y" 597~822',-53~'Ni'~-B-01~28,64 70: 29' 28, 9~60" 147: 5-~v4~, 3809' ~ 2669,93 607,78 rX" 270430.20 E" 467622 93 .... ~'7--~-Y~;"~eTO992-.6~-~; 780~ee0-:~---~o~-9.20.~e60, ~ 247~.4~.76~0-. 2~00. t4 T 620.32 ~ X- 270422.38 E- 4676t9.70 t 48 Y- ~97082s.~" N- 7eo~e29.0t 70~lg'le.9292,T'~47~t'4~.09~7 x- 270440.~ E- 4~7~2~.9~ ~9 Y- ~7099s.~9 N- 7~0~880.79 70~9'20.~92''~47~5~'42.47t8, 249B.71 ~10.40 x- 2704~2.S2 E- 467~22.72 50 Y- ~970824.&2 N- 7801829.37 70c19'1B.942~' 147°51'40.802~' 2~67.23 ~ ~87.~6- X- 270430.09 E- 4&7~28.9g i i i i SDi ~OPOSED WELL LOCATION LIST ~ / ~ ~.~1~ t~ PREPARED FOR ~c''~'~'~"~'/'~ S~OHIO ALASKA PETROLEUMCO. '~.~. ~.~9~ ./~ DRW. NO. t~e-e~ PREPARED BY OATE'NOV. Ij?e~..~~ ~ F.R. BELL & ASSOC ~'~ESSI~AL~ SHEET ~ of I0 · :SCALE ' N/A ~~~- PRUDHOE BAY OFFICE .. egv. o PRUOHOE BAY, ALASKA , , C,CCKC~: ~.c. ENDICOTT DEVELOPMENT WELL 3-11/M-30 (S.DI) SLOT 3-11 SURFACE LOCATION X = 270,214 FT ;Y -- 5,970,971 FT 2529 FT SNL; 828 FT WEL SEC8, T11N, R17E DEPARTURE TO BHL: 7284 FT 13509 FT MD 10391 FT TVD BKB DEPARTURE TO TARGET: 6940 FT 13046 'FT MD 10081 FT TVD BKB N 5.8° W TRUE NORTH GRID NOTE: THE NEAREST WELL TO 3-11/M-30 IS 3-09/L-28 LOCATED t0 FT WEST AT SLOT 3-09. JWB/7-25-88 Interval ENDICOTT MUD PROGRAM SATELLITE DRILLING ISLAND WELL 3-11/M-30 Mud Weight Viscosity Fluid Loss (ppg)_ (sec/qt) (ml/30min) pH 0-2500 8.8-9.8 100-200 20-15 8.5-9.0 Mud Type/ Components Generic Mud #5 Seawater Fresh water Gel Soda Ash 2,500- 12,666 12,666- 13,509 9.2-10.2 9.6-10.2 Set 13-3/8" casing 40-45 15-16 9.5-10..0 Set 9-5/8" casing 40-45 6-8 9.0-t0..0 Hang 7" Liner Generic Mud #7 Seawater Fresh water Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite Newdrill Generic Mud #7 Seawater Fresh water Gel Caustic Soda Soda Ash Barite Lignosul£onate Drispac [,ignite Newdrill POOL ARCTIC ALASKA RIG NO. 7 MUD AND SOLIDS CONTROL EQUIPMENT Equipment Manufacturer Model Nominal Capacity Shaker B rand t Dual Double I000 gpm Desanders Tri Flow/Pioneer Mann-Design 2 each - TFI-126 screens 4 each - Pioneer 12" Economaster Cones 1000 gpm (each) Mudcleaners Brandt Double 8 each - 4" Cones 400 gpm (each) Centrifuge Oiltools Decanting, Type S-3-0 160 gpm Degasser SWACO Vacuum 1000 gpm Agitators Brandt 7 each - 5 h.p., 32" Impellers Hoppers Geosource 2 each - 1000 gpm S-800 Sidewinders The trip tank and mud tank sections each have one vertical pit level float indicator which are connected to the drilling recorder system that contains visual and audio warning devices located in the driller's console. POOL ARCTIC ALASKA RIG NO. 7 Mud Tank/Trip Tank Monitorin~)-Recordin~ TOTCO, PITOMETER UNIT L-8 (PNEUMATIC) DRILLING RECORDER SYSTEM TOTCO, MODEL DR8WPT (E) RS (2) F DRILLER'S CONSOLE TOTCO "COMMAND" $1$DUA10:[DRAN017]SIM30 CLOSAP SHORT.LIS;2 Search Radius= 200 COURSE LINE For proposed well: 3-11/M-30 [31- 5-11-17] Location = W-E S-N TVD(SB$) Top 270214.00 5970971.00 -56.00 Bottom 269736.25 5978194.58 10295.00 Note: All depths in feet Below Kelly Bushing (BKB) 18-JUL-1988 09:50 --- Closest Approach Analysis --- Date: 18-JUL-88 Time~ 09:50:20 Page 1 Closest Approach WELL IDENT /PROPOSED% /NEARBY% CLOSEST TVD DEPART TVD DEPART DISTANCE A000-0000025 SI-25 A000-0000026 SI-26 A000-0000028 SI-28 A029-2028000 SI-DI1 A029-2028001 SI-DI2 A029-2158600 SI-M33 A029-2162400 SI-O29 A029-2164000 SI-T34 A029-2164001 SI-M35 A029-2164500 SI-N32 A029-2166800 SI-K37 A029-2167800 SI-N29 A029-2169200 SI-P27 A029-2170100 SI-L36 A029-2171400 SI-L34 A029-2172300 SI-Q32 A029-2173100 SI-P38 A029-2175100 SI-K33 A029-2176400 SI-$39 A029-2178000 SI-L28 A029-2178900 SI-Q28 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW 3393.2 78.1 3673.9 1029.6 1143.0 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW 801 0 3311 8 1 9 101 9 300 5 1200 6 1400 7 3296 0 3304 8 300 9 2800 0 2300 9 2854 1 2200 7 2982 0 0.0 58 2 0 0 0 0 0 0 0 0 0 0 54 3 56 5 0 0 0 0 0 0 I 2 0 0 7 6 800.0 3307 4 00 100 0 300 0 1200 0 1400 0 3323 1 3303 3 300 0 2800 1 2300 0 2853 4 2200.0 2981.4 1.9 84 .8 0.0 0.2 0.3 0.6 1.5 116 2 67 7 0 2 48 9 3 1 3 5 7 0 7 3 107.7 18 .9 175.5 175.4 59 .0 138 .1 5O 0 149 7 109 2 49 2 157 8 245 1 15 7 164 4 8 9 0.7 0o0 0.0 0.0 177.9 Vertical Intersection /PROPOSED\ /NEARBY% TVD DEPART TVD DEPART 3421.4 86.3 3341.7 92.4 VERTICAL DISTANCE -79.6 3079.7 17.5 3793.2 20.4 714.1 3685.6 178.2 4582.1 178.9 897.1 SUMMARY $1$DUA10:[DRAN017]SIM30_CLOSAP_$HORT.LIS;2 Ii-JUL-1988 09:50 Page 2 The well which comes closest to the proposed well is: A029-2178000 SI-L28 Closest approach distance = KICK OFF for this run = 8.9 feet 2800.0 feet $1$DUA10:[DRAN017]SIM30 CLOSAP SHORT7.LIS;2 Search Radius= 200 7 DEGREE LEAD LINE For proposed well: 3-11/M-30 [31- 5-11-17] Location = W-E S-N TVD(SBS) Top 270214.00 5970971.00 -56.00 Bottom 268859.48 5978082.52 10295.00 Note: Ail depths in feet Below Kelly Bushing (BKB) 18-JUL-1958 10:02 --- Closest Approach Analysis --- Date: 18-JUL-88 Time: 10:02:24 Page Closest Approach WELL IDENT /PROPOSED% /NEARBY~ CLOSEST TVD DEPART TVD DEPART DISTANCE A000-0000025 SI-25 A000-0000026 SI-26 A000-0000028 SI-28 A029-2028000 SI-DI1 A029-2028001 SI-DI2 A029-2158600 SI-M33 A029-2162400 SI-O29 A029-2164000 SI-T34 A029-2164001 SI-M35 A029-2164500 SI-N32 A029-2166800 SI-K37 A029-2167800 SI-N29 A029-2169200 SI-P27 A029-2170100 SI-L36 A029-2171400 SI-L34 A029-2172300 SI-Q32 A029-2173100 SI-P38 A029-2175100 SI-K33 A029-2176400 SI-J39 A029-2178000 SI-L28 A029-2178900 SI-Q28 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED'SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW 3393.2 78.1 3673.5 1029.5 1141.8 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW 801 0 3339 3 1 9 101 9 300 5 1200 6 1400 7 3393 2 3206 9 300 9 2800 0 2300 9 2800 0 2200 7 2999 6 0.0 64.9 0.0 0 0 0 0 0 0 0 0 78 1 36 6 0 0 0 0 0 0 0 0 0 0 8 7 8O0 0 3334 6 00 100 0 300 0 1200 0 1400 0 3419 6 3204 9 300 0 2800 1 2300 0 2799 2 2200 0 2999 1 1.9 90.7 0.0 0.2 0.3 0.6 1.5 151 1 65 9 0 2 48 9 3 1 3 5 7 0 7 4 107.7 22.2 175.5 175.4 59.0 138.1 50.0 146.1 114.8 49 2 157 8 245 1 15 8 164 4 8 0 0.7 0.0 0.0 0.0 177.9 Vertical Intersection /PROPOSED\ /NEARBY% TVD DEPART TVD DEPART 3496.4 108.5 3405.8 110.1 -90.4 3063.6 15.7 3693.0 17.9 630.0 4692.0 967.6 5641.2 966.7~ 949.9 VERTICAL DISTANCE SUMMARY _$1$DUA10:[DRAN017]SIM30_CLOSAP_SHORT7.LI$;2 18-JUL-1988 10:02 Page 2 The well which comes closest to the proposed well is: A029-2178000 SI-L28 Closest approach distance KICK OFF for this run 8.0 feet 2800.0 feet -'"- j . i i 1 THIS I$ & PIRO PRIE'"r ARY OF P~ USE OF THIS OE~N .~ PER. MIngLE ONLY · UTHO~O IN W~I~ .Y FOR INFORMATION ONLY lin JJ~/ I11 t kJ::f t t' ' = 1-'1 T',I i~.1,.,,1..-1:~i~,.i~ , ~7. o~e - - i: _ _ ISSUED FOR INFORMATION ONLY LJ 1~-5/8" API-~O00~ CONTROL LINE-- WELLHEAD ASSEMBLY,ENDICOTT 5KSI 13-3/8"x 9-5/8"× 4-1/2" SOHIO ALASKA PETROLEUM COMPANY FI6URE I (3) 13-B/8" 9 -5/8" CONTROL LINE -- 4- ~/z:' II. 3. 9-5/8" CASING AND WELLHEAD EQUIPMENT 3.! TESTING B.O.P. STACK 1. After B.O.P.'s are nippled up to split speedhead, make up !3" x 4-I/2 Internal Flush B.O.P. test plug, Accessories Item 7, Part No. 5381!6. 2. Lower plug into head (it will land on lower step). Tighten 4 lockscrews 90° apart. 3. After B.O.P. test, back out lockscrews and retrieve test plug. CAUTION: It is very important not to have the lockscrew$ protruding into the bore of the head while either running or pulling the B.O.P. test plug. Always check them if in doubt. (29) -- SPL I T SPEEDHEAO TEST PLUG lB-B/8" O.D, CASING (3O) ACCESSORIES ITEM 7 I 210 ; ~0: '~E-T FL'J$ FOF< LOWER BOWL (19) II. 4. 4-I/2 TUBING AND WELLHEAD EQUIPMENT 4.1 TESTING B.O.P.'s 1. After 9-5/8" has been set and tested, run in B.O.P. test plug, Accessory Item 6, Part Number 538117, which lands in upper bowl of the split speedhead. Run in 4 lockscrews lightly, 90° apart to keep plug from moving. 2. After test, retract lockscrews and pull plug. 3. Run in short bowl protector, Accessory Item 8, Part Number 538114, using the same running tool, Accessory Item 5, Part Number 538115, that was used for the long protector. 4. After bowl protector is in place, run in 4 lockscrews lightly to hold protector in place. CAUTION: Upper lockscrews must be retracted when the bowl protector or B.O.P. test plug is either run or pulled. (43) -5/8 --TEST PLUG --PACK!NG PORT TEST PORT -- LOCKSCREW CASING HANGER SPLIT SPEEDHEAD ;~ -_'q 1831 -20- A 13~t. 70IA IF FEMALE l'HO. t! II tt t! ACCESSORIES I~TE~ 6 BOP TEST PLUG FOR UPI:~R BOWL (538117) -- 21.0 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2 thru 8) (8) (3) Admin ~ i~/,/~B~ 9. (9 thru 10. ~(~.//~. ~-/- ~ 11. (10 and 13) 12. 13. (4) Casg ~ft<.~.~, ff-3-85 (14 thru 22) (23 thru 28) (29 thru 31) (6) Add: ~W~,~;~ ~-J-~g Geology_: Engineering: WWB _~. LCS BEW 14. 15. Company ..~/~ PC 0 Lease & Well No. ~ dido ~ YES NO Is the permit fee attached .......................................... ~ REMARKS 2. Is well to be located in a defined pool ............................. _~ 3. Is well located proper distance from property line .................. ~ 4. Is well located proper distance from other wells .................... _~ 5. Is sufficient undedicated acreage available in this pool ............ _~ 6. Is well to be deviated and is wellbore plat included ................ ~ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... ~ Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~_ Does the well have a unique name and number ......................... ~ 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ For 29. 30. 31 32. Is a diverter system requi~ed ....................................... ~.,., Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. 4~ Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (May 84) .... f ............. ,,, Is the presence of H2S gas probable ................................. __ exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ......... Are seismic analysis data presented on shallow gas zones ... If an offshore loc., are survey results of seabed conditions Additional requirements ............................................. ... ~v /on ,,, INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ~_2otoo t,7~'u -loll 990 Additional Remarks 1~' ~ I.<-ss ~ ,~s'o, ; Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX~ No special'effort has been made to chronologically organize this category of information. .o * ALASKA COMPUTING CENTER * . ....... SCHLUMBERGER ....... JUL 3 1 1998 ~Jaska Oil & Gas Cons. Commissior~ Anchorage COMPANY NAME : BP EXPLORATION (ALASKA), INC. WELL NAME : 3-11/M-30 FIELD NAME : ENDICOTT BOROUGH : NORTH SLOPE STATE : ALASKA API ArUMBER : 500292184800 REFERENCE NO : 98344 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 14:11 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/07/10 ORIGIN : FLIC REEL NAME : 98344 CONTINUATION # : PREVIOUS REEL : COGENT : BP EXPLORATION, ENDICOTT, 3-11/M-30, API #50-029-21848-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/07/10 ORIGIN : FLIC TAPE NAME : 98344 CONTINUATION # : 1 PREVIOUS TAPE : COM~ENT : BP EXPLORATION, ENDICOTT, 3-11/M-30, API #50-029-21848-00 TAPE HEADER ENDICOTT CASED HOLE WIRELINE LOGS WELL NAME: 3-11/M-30 API NUMBER: 500292184800 OPERATOR: BP Exploration (Alaska), Inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: lO-JUL-98 JOB NUMBER: 98344 LOGGING ENGINEER: D PALMER OPERATOR WITNESS: D VARBLE SURFACE LOCATION SECTI ON: 8 TOWNSHIP: 1 IN RANGE: 17E FNL: 2529 FSL : FEL : 828 FWL : ELEVATION(FT FROM MSL O) KELLY BUSHING: 55.50 DERRICK FLOOR: 54.50 GROUND LEVEL: 14.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) .............................................. 1ST STRING 8. 500 7. 000 13520.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 14:11 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH .............. 88888.0 12909.0 12904.5 12897.5 12886.5 12886.0 12884.5 12880.5 12878.0 12875.5 12874.5 12869.5 12862.0 12861.5 12851.5 12850.0 12844.5 12831.5 12823 5 12822 0 12817 5 12815 0 12803 0 12801 0 12798 0 12797 5 12791 0 12790 0 12786.0 12785.5 12783.5 12783.0 12782.0 12781.5 12780.0 12779.5 12777.5 12776.5 12774.0 12769.5 12764.0 12762.0 12761.5 12755.0 12751.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD 88889.0 88889.0 12905.5 12899.5 12886.0 12883.0 12880.0 12874.5 12870.0 12861.5 12851.5 12845.0 12833.0 12822.5 12817.0 12802.5 12796.5 12789.5 12785.0 12782.5 12781.0 12779.0 12776.0 12773.5 12768.5 12762.5 12760.0 12754.0 12749.5 12910.0 12905.5 12886.0 12880.5 12874.5 12870.0 12862.0 12852.0 12845.0 12822.5 12817.0 12803.5 12796.5 12789.5 12785.0 12782.5 12781.0 12779.0 12776.0 12773.5 12768.5 12762.5 12760.0 12754.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 14:11 12750 5 12747 0 12738 0 12732 0 12723 5 12720 0 12719 0 12715.5 12715.0 12712.5 12711.0 12709.5 12705.0 12703.0 12701.0 12699.5 12699.0 12692.0 12691.5 100.0 $ REMARKS 12744.5 12736.0 12728.0 12719.5 12715.5 12713.0 12707.5 12702.0 12697.0 12694.5 12686.0 94.0 12749.5 12744.5 12736.0 12728.0 12720.0 12715.5 12711.5 12710.0 12707.5 12702.0 12697.0 12686.0 94.5 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE CNTD DATA AQUIRED ON BP EXPLORATION'S 3-11/M-30 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #1 AND THE BASE GAIV~VA RAY, ALSO PASS #1 NPHI AND THE BASE GAMFiA RAY, CARRYING ALL CNTD CURVES WITH THE NPHI SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUMFLARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12908.0 12606.0 CNTD 12920.0 12606.5 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 14:11 PAGE: CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTD R~Vi&RKS: THIS FILE CONTAINS CASED HOLE CNTD PASS #1. NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA THERE ARE ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1189316 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTD PU-S 1189316 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTD 1189316 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTD 1189316 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTD CPS 1189316 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTD CPS 1189316 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 14:11 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CFTC CNTD CPS 1189316 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTD CPS 1189316 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTD GAPI 1189316 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTD LB 1189316 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTD V 1189316 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 12920.000 NPHI.CNTD 26.408 NRAT. CNTD 4.951 CRAT. CNTD NCNT. CNTD 3431.976 FCNT. CNTD 693.255 CFTC. CNTD 654.130 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1715.000 CCL. CNTD 0.000 DEPT. 12606.000 NPHI.CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD 83.921 TENS. CNTD -999.250 CCL.CNTD -999.250 4.598 3356.406 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 14:11 PAGE: FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12903.5 12619.5 CNTD 12920. 0 12621 . 5 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 12907.0 12901.0 12897.5 12894.5 12889.5 12889.0 12887.0 12885.0 12883.0 12881.5 12880.0 12876.0 12871.0 12868.5 12864.0 12861.0 12860.0 12858.0 12851.5 12849.5 12847.0 12845.5 12838.0 12835.5 12831 0 12824 0 12823 5 12821 0 12819 0 12814 0 12804 5 12802 0 12800 5 12797 0 12796 5 12794 0 12791 0 12790 0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD 88886.5 88891.0 1291 O. 0 12899.5 12889.0 12886.0 12883.0 12881.0 12880.0 12875.5 12870.5 12866.0 12860.0 12859.5 12851.0 12847.0 12839.5 12837.0 12833.5 12823.5 12820.5 12818.5 12814.0 12802.5 12796.0 12789.5 12899.5 12894.5 12889.0 12886.0 12875.0 12862.0 12852.0 12848.0 12825.5 12807.0 12803.0 12796.5 12794.0 12789.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 14:11 PAGE: 12786.0 12781.5 12781.0 12779.0 12777.5 12773.0 12768.0 12766.5 12764.0 12763.5 12761.0 12751.0 12750.0 12748.0 12746.5 12743.5 12742.5 12735.0 12732.0 12727.5 12723 0 12719 0 12718 5 12713 0 12711 0 12708 5 12706 5 12705 5 12705.0 12703.5 12700.0 12697.5 12696.0 12692.5 12691.5 12688.5 12687.0 12682.5 12682.0 12679.0 12673.0 12670.0 12668.0 12664.0 12663.0 12658.0 12656.5 12655.5 12651.0 12648.5 12645.0 12643.0 12638.5 12637.5 12636.5 12785.0 12781.0 12776.0 12773.5 12765.5 12762.5 12760.0 12748.5 12746.5 12745.0 12740.5 12733.5 12728.0 12725.0 12719.5 12715.5 12708.0 12704.5 12702.0 12697.0 12694.5 12692.5 12685.5 12682.0 12678.0 12674.0 12668.0 12664.0 12658.5 12656.5 12653.5 12651.5 12649.5 12644.5 12640.0 12638. 0 12634. 0 12631.5 12781.0 12778.5 12768.0 12763. 0 12760. 0 12750. 0 12740.5 12715.5 12711.5 12708.0 12705.0 12703.0 12694.0 12690.5 12682.5 12677.0 12665.5 12656.5 12646.5 12636.5 LIS Tape Verification Listing Schlumberger Alaska Compu ting Center 28-JUL-1998 14:11 PAGE: 12635.5 12634.5 12633.0 100.0 $ 12627.5 94.5 12633. 0 12631. 0 96.5 REMARKS: THIS FILE CONTAINS CASED HOLE CNTD PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1, ALSO NPHI PASS #2 AND NPHI PASS #1, CARRYING ALL CNTD CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1189316 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTD PU-S 1189316 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTD 1189316 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTD 1189316 O0 000 O0 0 2 1 i 4 68 0000000000 NCNT CNTD CPS 1189316 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTD CPS 1189316 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTD CPS 1189316 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTD CPS 1189316 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTD GAPI 1189316 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 14:11 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TENS CNTD LB 1189316 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTD V 1189316 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 12920.000 NPHI.CNTD 25.521 NRAT. CNTD 5.078 CRAT. CNTD NCNT. CNTD 3433.265 FCNT. CNTD 676.171 CFTC. CNTD 638.010 ClTTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1707.000 CCL.ClTTD 0.000 DEPT. 12619.500 NPHI.CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD 81.936 TENS.CNTD -999.250 CCL.CNTD -999.250 4.485 3401.107 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS A~IMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUFmlARY LDWG TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 14:11 PAGE: 10 GRCH 12905.5 12576.5 CNTD 12918.5 12578.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS ~BER: 1 BASELINE DEPTH 88888.0 12911.0 12901.5 12901.0 12889.0 12886.5 12885.5 12880 5 12878 5 12875 5 12873 5 12861 5 12846 5 12846 0 12843 0 12835 5 12831 5 12823 5 12821 5 12817 5 12816.0 12812.5 12802.5 12800.0 12797.5 12797.0 12794.5 12793.0 12791.0 12790.5 12781.5 12780.0 12778.5 12777.5 12774.5 12769.5 12766.0 12763.5 12761.5 12760.0 12754.5 12750.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTD 88886.5 88887.5 12899.5 12889.5 12886.0 12880.0 12874.5 12847.0 12845 0 12837 0 12833 5 12825 0 12821 0 12817 0 12802.5 12796.0 12789.5 12781.0 12779.0 12776.0 12774.0 12768.5 12765.5 12762.5 12760.0 12753.5 12749.5 12910.5 12902.5 12890.0 12885.5 12880.5 12876.0 12862.0 12848.0 12818.5 12815.0 12802.5 12796.5 12794.0 12793.0 12790.0 12779.0 12762.5 12760.0 LIS' Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 14:11 PAGE: 11 12749.0 12746.5 12748.5 12747.5 12746.5 12745.0 12743.0 12740.5 12740.5 12738.0 12738.0 12736.0 12734 . 5 12732.0 12732.0 12728.0 12731 . 5 12729.5 12728.0 12724.5 12719.0 12715.5 12715.5 12714.0 12711 . 5 12710. 5 12708.0 12710. 0 12708.5 12707.5 12705.5 12704.0 12704.5 12702.0 12704.0 12704.5 12700.0 12699.5 12699.5 12697.0 12697.5 12697.0 12694.0 12690.0 12693 . 5 12690.0 12691 . 0 12685.5 12687.0 12681.5 12686.5 12680.0 12685.0 12677.5 12682.5 12675.5 12679.5 12674.0 12675.5 12670.0 12675.0 12668.0 12673 . 5 12667.0 12673.0 12668.5 12671.0 12667.5 12670.5 12664.0 12669.5 12665.0 12667.5 12663.0 12663.0 12657.0 12662.0 12656.5 12658.5 12654.0 12654.0 12657.0 12651.5 12651.5 12653 . 0 12649.5 12650.0 12646.5 12643.0 12638.0 12638.0 12640.0 12634.0 12639.5 12632.5 12637.5 12631.0 12637.0 12631.5 12628.5 12624.0 12624.5 12618.0 12622.5 12619.5 12621.5 12616.5 12616.0 12611.0 12615.5 12611 . 5 12613.0 12607.5 100.0 94.5 96.0 LIS' Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 14:11 PAGE: 12 REMARKS: THIS FILE CONTAINS CASED HOLE CNTD PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #3 AND GRCH PASS #1, ALSO NPHI PASS #3 AND NPHI PASS #1, CARRYING ALL CNTD CURVES WITH THE NPHI SHIFTS $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1189316 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTD PU-S 1189316 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTD 1189316 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTD 1189316 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTD CPS 1189316 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTD CPS 1189316 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTD CPS 1189316 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTD CPS 1189316 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTD GAPI 1189316 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTD LB 1189316 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTD V 1189316 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 14:11 PAGE: 13 ** DATA ** DEPT. 12918. 500 NPHI. CNTD 26. 366 NRAT. CNTD NCNT . CNTD 3498.646 FCNT. CNTD 71 O . 938 CFTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1753.000 CCL.CNTD 4.921 CRAT. CNTD 670.814 CNTC. CNTD 0.000 DEPT. 12576.500 NPHI.CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD 69.738 TENS. CNTD -999.250 CCL.CNTD -999.250 4.593 3362. 114 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS I, 2, 3, CNTD REMARKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF PASSES 1,2, &3. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 14:11 PAGE: 14 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) FT 1189316 O0 000 O0 0 4 1 1 4 68 0000000000 DEPT NPHI CNAV PU-S 1189316 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1189316 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 1189316 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 1189316 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNAV CPS 1189316 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 1189316 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 1189316 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTD GAPI 1189316 O0 000 O0 0 4 1 1 4 68 0000000000 TENS CNTD LB 1189316 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 12920.000 NPHI. CNAV -999.250 NRAT. CNAV -999.250 CRAT. CNAV NCNT. CNAV -999.250 FCNT. CNAV -999.250 CFTC. CNAV -999.250 CNTC. CNAV GRCH. CNTD -999.250 TENS. CNTD 1715.000 DEPT. 12606. 000 NPHI. CNAV -999. 250 NRAT. CNAV -999 . 250 CRAT. CNAV NCNT. CNAV -999.250 FCNT. CNAV -999.250 CFTC. CNAV -999.250 CNTC. CNAV GRCH. CNTD 83.921 TENS. CNTD -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 14:11 PAGE: 15 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMFL~RY VENDOR TOOL CODE START DEPTH STOP DEPTH 12946.5 12582.0 CNTD LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 03 -JUL-98 8Cl -205 1202 03 -JUL-98 12937.0 12936.0 12582.0 12919.0 900.0 TOOL NUMBER ........... LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 14:11 PAGE: 16 GR CNTD $ GAMMA RAY COMPENSATED NEUTRON BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CGRS-A CNT-D 8.500 13520.0 PRODUCED FLUIDS NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 3000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 12000 TOOL STANDOFF (IN) '. REMARKS: DEPTH CORRELATED TO CET OF 07-SEP-1988 2 1/2" CNTD TOOL RAN. WELL SHUT IN 6 HOURS BEFORE LOGGING 3 PASSES MADE AT 900 F/HR THIS FILE CONTAINS THE RAW DATA FOR PASS #1. LIS FORMAT DATA LIS Tape Verification Listing Schlumberger A1 aska Compu ting Cent er 28-JUL-1998 14:11 PAGE: 17 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1189316 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 1189316 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS1 1189316 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA PS1 1189316 O0 000 O0 0 5 1 1 4 68 0000000000 RCNT PSI CPS 1189316 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 1189316 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PSI CPS 1189316 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 1189316 O0 000 O0 0 5 1 1 4 68 0000000000 GR PSI GAPI 1189316 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1189316 O0 000 O0 0 5 1 1 4 68 0000000000 CCLD PS1 V 1189316 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 12946.500 NPHI.PS1 6.729 RTNR.PS1 2.000 TNRA.PS1 RCNT. PS1 1939.394 RCFT. PS1 969.697 CNTC. PS1 1918.450 CFTC. PSi GR.PS1 108.485 TENS.PSI 882.000 CCLD. PS1 -0.010 DEPT. 12582.000 NPHI.PS1 45.865 RTNR.PS1 7.382 TNRA.PS1 RCNT. PS1 2183.299 RCFT. PS1 295.764 CNTC. PS1 2156.552 CFTC. PSI GR.PS1 86.613 TENS.PSi 1593.000 CCLD.PS1 -999.250 1.941 914.970 6.851 279.072 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 14:11 PAGE: 18 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... 12951.0 12596.5 CNTD $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) '. BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 03 -JUL-98 8Cl -205 1202 03 -JUL-98 12937.0 12936.0 12582.0 12919.0 900.0 TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 14:11 PAGE: 19 GR CNTD $ GAI~W_A RAY COMPENSATED NEUTRON BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CGRS-A CNT-D 8.500 13520.0 PRODUCED FLUIDS NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 3000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 12000 TOOL STANDOFF (IN): REMARKS: DEPTH CORRELATED TO CET OF 07-SEP-1988 2 1/2" CNTD TOOL RAN. WELL SHUT IN 6 HOURS BEFORE LOGGING 3 PASSES MADE AT 900 F/HR THIS FILE CONTAINS THE RAW DATA FOR PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 14:11 PAGE: 20 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1189316 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 1189316 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 1189316 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 1189316 O0 000 O0 0 6 1 1 4 68 0000000000 RCNT PS2 CPS 1189316 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 1189316 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 1189316 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 1189316 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1189316 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1189316 O0 000 O0 0 6 1 1 4 68 0000000000 CCLD PS2 V 1189316 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 12951.000 NPHI.PS2 20.973 RTNR.PS2 4.000 TNRA.PS2 RCNT. PS2 3878.788 RCFT. PS2 969.697 CNTC. PS2 3836.900 CFTC. PS2 GR.PS2 0.000 TENS.PS2 594.000 CCLD.PS2 -0.010 DEPT. 12596.500 NPHI.PS2 45.725 RTNR.PS2 6.932 TNRA.PS2 RCNT. PS2 2201.797 RCFT. PS2 317.638 CNTC. PS2 2128.361 CFTC. PS2 GR.PS2 73.869 TENS. PS2 1719.000 CCLD.PS2 -999.250 3.882 914.970 6. 835 299. 712 LIS 'Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 14:11 PAGE: 21 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 98/07/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~BER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 12954.5 12531.0 CNTD $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 03 -JUL-98 8Cl -205 1202 03 -JUL-98 12937.0 12936.0 12582.0 12919.0 900.0 TOOL NUMBER ........... LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 14:11 PAGE: 22 GR CNTD $ GAM~A RAY COMPENSATED NEUTRON BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE '. FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CGRS -A CN T- D 8.500 13520.0 PRODUCED FLUIDS NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SAArDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 3000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 12000 TOOL STANDOFF (IN): REMARKS: DEPTH CORRELATED TO CET OF 07-SEP-1988 2 1/2" CNTD TOOL RAN. WELL SHUT IN 6 HOURS BEFORE LOGGING 3 PASSES MADE AT 900 F/HR THIS FILE CONTAINS THE RAW DATA FOR PASS #3. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 14:11 PAGE: 23 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELb2~ CODE (HEX) DEPT FT 1189316 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 1189316 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 1189316 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 1189316 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PS3 CPS 1189316 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 1189316 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 1189316 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 1189316 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1189316 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS$ LB 1189316 O0 000 O0 0 7 1 1 4 68 0000000000 CCLD PS3 V 1189316 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 12954.500 NPHI.PS3 20.973 RTNR.PS3 4.000 TNRA.PS3 RCNT. PS3 3878.788 RCFT. PS3 969.697 CNTC. PS3 3836.900 CFTC. PS3 GR.PS3 27.121 TENS. PS3 661.000 CCLD.PS3 0.010 DEPT. 12531.000 NPHI.PS3 42.151 RTNR.PS3 7.168 TNRA.PS3 RCNT. PS3 2237.183 RCFT. PS3 314.863 CNTC. PS3 2295.786 CFTC. PS3 GR.PS3 74.716 TENS.PS3 1775.000 CCLD.PS3 -999.250 3.882 914.970 6.426 297.093 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JUL-1998 14:11 PAGE: 24 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/07/10 ORIGIN · FLIC TAPE NAME : 98344 CONTINUATION # : 1 PREVIOUS TAPE : CONk4ENT : BP EXPLORATION, ENDICOTT, 3-11/M-30, API #50-029-21848-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/07/10 ORIGIN : FLIC REEL NAME : 98344 CONTINUATION # : PREVIOUS REEL : COFk4ENT : BP EXPLORATION, ENDICOTT, 3-11/M-30, API #50-029-21848-00 * ALASKA COMPUTING CENTER * . . * ....... SCHLUMBERGER ....... * COMPANY NAME : BP EXPLORATION (ALASKA), INC. WELL NAME : 3 - 11 / M- 30 FIELD NAME : ENDICOTT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-21848-00 REFERENCE NO : 98002 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-i998 14:55 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/01/12 ORIGIN : FLIC REEL NAME : 98002 CONTINUATION # : PREVIOUS REEL : COMFiENT : B.P. EXPLORATION, ENDICOTT, 3-11/M-30, API #50-029-21848-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/01/12 ORIGIN : FLIC TAPE NAME : 98002 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : B.P. EXPLORATION, ENDICOTT, 3-11/M-30, API #50-029-21848-00 TAPE HEADER ENDICOTT CASED HOLE WIRELINE LOGS WELL NAME: 3 - 11 / M- 30 API NUMBER: 500292184800 OPERATOR: BP Exploration (Alaska), Inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 12-JAN-98 JOB NUMBER: 98002 LOGGING ENGINEER: DANIEL PALME OPERATOR WITNESS: CRAIG LOVELA SURFACE LOCATION SECTION: 8 TOWNSHIP: 1 IN RANGE: 17E FNL: 2529 FSL: FEL : 828 FWL : ELEVATION(FT FROM MSL O) KELLY BUSHING: 55.50 DERRICK FLOOR: 54.50 GROUND LEVEL: 14.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 7. 000 13520.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH .............. 88888.0 12908.5 12882.5 12864.0 12859.5 12837.0 12819.0 12808.0 12797.5 12781.0 12764.5 12738.5 12732.0 12701.0 100.0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH ....... 88888.0 12908.5 12882.5 12866.0 12860.0 12835.5 12817.0 12807.0 12796.5 12779.0 12762.5 12735.5 12728.0 12697.0 96.0 REMARKS: The depth adjustments shown above reflect cased hole GR to open hole GR. Ail other CNTD curves were carried with the NPHI shifts. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~F~%RY LDWG TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 PAGE: GRCH 12909.0 12592.0 CNTD 12933.0 12616.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD REMARKS: This file contains CNTD Pass #1. shifts were applied to this data. $ LIS FORMAT DATA No pass to pass ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1023889 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTD PU-S 1023889 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTD 1023889 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 PAGE: 4 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELE~ CODE (HEX) CRAT CNTD 1023889 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTD CPS 1023889 O0 000 O0 0 I 1 1 4 68 0000000000 FCNT CNTD CPS 1023889 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTD CPS 1023889 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTD CPS 1023889 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTD GAPI 1023889 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTD LB 1023889 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTD V 1023889 O0 000 O0 0 1 1 1 4 68 0000000000 ....................................................................................... ** DATA ** DEPT. 12933.000 NPHI.CNTD 22.758 NRAT. CNTD 4.097~ CRAT. CNTD 4.124 NCNT. CNTD 3691.135 FCNT. CNTD 900.985 CFTC. CNTD 930.714 CNTC. CNTD 4158.290 GRCH. CNTD -999.250 TENS. CNTD 2198.000 CCL. CNTD 0.000 DEPT. 12900.000 NPHI.CNTD 26.777 NRAT. CNTD 4.747 CRAT. CNTD 4.645 NCNT. CNTD 3103.890 FCNT. CNTD 653.865 CFTC. CNTD 675.440 CNTC. CNTD 3532.091 GRCH. CNTD 23.391 TENS. CNTD 2239.000 CCL. CNTD 0.000 DEPT. 12600.000 NPHI.CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD -999.250 NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD -999.250 GRCH. CNTD 85.091 TENS.CNTD -999.250 CCL. CNTD -999.250 DEPT. 12588.000 NPHI.CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD -999.250 NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD -999.250 GRCH. CNTD 67.949 TENS. CNTD -999.250 CCL. CNTD -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUF~VL~Y LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 12907.0 12576.0 CNTD 12931.0 12598.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 12918.5 12914.5 1291 O. 5 12894.5 12890.5 12889.5 12877.5 12873.5 12869.5 12866.5 12865.5 12862 5 12861 5 12858 5 12857 5 12854 5 12853 5 12850 5 12849 5 12845 5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GR CH CNTD .............. 88889.0 88889.0 12890.5 12878.5 12874.0 12870.5 12866.0 12862.5 12858.0 12854.5 12849.5 12845.5 12919.5 12915.5 1291 O. 0 12894.0 12891.5 12867.5 12864.0 12859.5 12855.5 12851.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 PAGE: 12841.5 12834.5 12833.5 12830 5 12829 5 12825 5 12814 5 12813 5 12810 5 12809.5 12806.5 12805.5 12802.5 12801.5 12798.5 12794.5 12790.5 12786.5 12782.5 12778.5 12777.5 12774.5 12773.5 12770.5 12769.5 12766.5 12765.5 12762.5 12761.5 12758.5 12757.5 12753.5 12749.5 12738.5 12737.5 12734.5 12733.5 12730.5 12722.5 12718.5 12714.5 12713.5 12710.5 12709.5 12706.5 12705.5 12702.5 12701.5 12698.5 12694.5 12690.5 12689.5 12686.5 12685.5 12682.5 12842.0 12834.0 12831.0 12827.0 12813.5 12809.0 12805.5 12801.0 12777.0 12772.5 12768.5 12765.0 12761.0 12756.5 12752.5 12747.5 12735.5 12730.5 12710.5 12706.0 12702.5 12698.0 12686.0 12682.5 12835.0 12830.0 12813.5 12809.5 12806.0 12801.5 12797.5 12794.0 12790.5 12786.0 12781.5 12778.0 12774.0 12769.0 12765.5 12761.5 12757.0 12737.0 12732.0 12727.5 12719.5 12715.0 12711.0 12707.5 12703.5 12700.0 12696.0 12690.5 12687.0 12683.5 12679.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 PAGE: 12678 5 12674 5 12670 5 12657 5 12654 5 12653 5 12650 5 12646.5 12642.5 100.0 $ 12654.5 12650.0 96.5 12674.0 12671.0 12667.0 12652.0 12647.5 12642.5 12639.5 97.0 REMARKS: This file contains CNTD Pass #2. The depth shifts shown above relect GRCH pass #2 to GRCH pass #1 and NPHI pass #2 to NPHI pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1023889 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTD PU-S 1023889 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTD 1023889 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTD 1023889 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 PA GE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) NCNT CNTD CPS 1023889 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTD CPS 1023889 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTD CPS 1023889 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTD CPS 1023889 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTD GAPI 1023889 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTD LB 1023889 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTD V 1023889 O0 000 O0 0 2 1 I 4 68 0000000000 ** DATA ** DEPT. 12932.000 NPHI. CNTD 25.358 NRAT. CNTD 4.234 CRAT. CNTD NCNT. CNTD 2990.501 FCNT. CNTD 706.365 CFTC. CNTD 729.673 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1979.000 CCL.CNTD 0.000 DEPT. 12900.000 NPHI. CNTD 27.342 NRAT. CNTD 4.722 CRAT. CNTD NCNT. CNTD 3219.713 FCNT. CNTD 681.900 CFTC. CNTD 704.400 CNTC. CNTD GRCH. CNTD 24.352 TENS. CNTD 2232.000 CCL.CNTD 0.000 DEPT. 12600.000 NPHI. CNTD 46.803 NRAT. CNTD 6.973 CRAT. CNTD NCNT. CNTD 1906.242 FCNT. CNTD 273.363 CFTC. CNTD 282.383 CNTC. CNTD GRCH. CNTD 93.995 TENS. CNTD 2166.000 CCL. CNTD 0.000 DEPT. 12572.500 NPHI. CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD 49.939 TENS. CNTD -999.250 CCL.CNTD -999.250 4.464 3408.602 4. 716 3711. 646 6.958 2200.057 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 PAGE: **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMFIARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 12905.0 12594.0 CNTD 12929.0 12614.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 12916.5 12912.5 12904.5 12896.5 12887.5 12879.5 12876.5 12875.5 12872.5 12871.5 12868.5 12867.5 12864.5 12863.5 12860.5 12859.5 12856.5 12855.5 12852.5 12851.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD .............. 88890.0 88887.5 12889.5 12881.5 12878.0 12873.5 12870.0 12865.5 12861.5 12856.5 12852.5 12916.0 12912.5 12904.5 12898.0 12878.0 12874.5 12870.0 12866.5 12862.0 12857.5 12854.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 PAGE: 10 12848. 12847 12843 12840. 12839 12836. 12816. 12815 12812 12811 12808 12804 12800 12796 12792 12791 12788 12787 12783 12776 12775. 12772 12771 12768. 12764. 12760 12759. 12756.5 12755.5 12751.5 12747.5 12743.5 12740.5 12739.5 12736.5 12735.5 12732.5 12728.5 12716.5 12715.5 12712.5 12711.5 12708.5 12707.5 12704.5 12703.5 12700.5 12696.5 12692.5 12691.5 12688.5 12687.5 12684.5 12683.5 12680.5 5 12849.5 · 5 12847.5 · 5 12844.0 5 12841.5 · 5 12839.5 5 12838.0 5 12818.0 · 5 12817.0 5 12812.5 5 12811.5 5 12808.0 5 12804.5 5 12801.0 5 12796.5 5 12793.0 5 12791.5 5 12788.5 5 12788.0 5 12783.5 5 12776.5 5 12775.5 · 5 12773.0 .5 12771.0 5 12768.5 5 12764.0 · 5 12760.0 5 12759.0 12754· 5 12750.0 12746.5 12741.5 12738· 0 12733.0 12713· 0 12708.5 12704.5 12701.0 12689.0 12685.5 12681.0 12755.5 12739· 5 12734.5 12730.0 12725.5 12713.5 12710.0 12705.5 12701.5 12698.5 12694.0 12690.0 12686.5 12682.0 12678.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 PAGE: 11 12676.5 12672.5 12668.5 12660.5 12656.5 12655.5 12652.5 12651.5 12648.5 12647.5 12643.5 12639.5 12631.5 12627.5 100.0 $ 12653.0 12648.5 12644.5 12640.0 12636.5 12628.5 12625.0 97.5 12674.5 12670.5 12666.0 12658.0 12652.5 12649.0 12646.0 97.5 REMARKS: This file contains CNTD Pass #3. The depth shifts shown above relect GRCH pass #3 to GRCH pass #1 and NPHI pass #3 to NPHI pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 66 66 73 66 66 73 65 0 0 44 1 0.5 FT 23 1 2 3 4 5 6 7 8 68 9 65 11 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 .............................. LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 PAGE: 12 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELE~ CODE (HEX) DEPT FT 1023889 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTD PU-S 1023889 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTD 1023889 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTD 1023889 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTD CPS 1023889 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTD CPS 1023889 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTD CPS 1023889 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTD CPS 1023889 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTD GAPI 1023889 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTD LB 1023889 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTD V 1023889 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 12928. 500 NPHI. CNTD 28. 976 NRAT. CNTD 5. 016 CRAT. CNTD NCNT. CNTD 2868.259 FCNT. CNTD 571.854 CFTC. CNTD 590.723 CNTC. CNTD GRCH. CNTD -999. 250 TENS. CNTD 2014. 000 CCL. CNTD 0. 000 DEPT. 12900.000 NPHI.CNTD 26.186 NRAT. CNTD 4.385 CRAT. CNTD NCNT. CNTD 3192.000 FCNT. CNTD 728.063 CFTC. CNTD 752.125 CNTC. CNTD GRCH. CNTD 27.492 TENS. CNTD 2262.375 CCL. CNTD 0.000 DEPT. 12600.000 NPHI. CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD 94.030 TENS. CNTD -999.250 CCL. CNTD -999.250 DEPT. 12591.500 NPHI.CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD 72.926 TENS. CNTD -999.250 CCL. CNTD -999.250 4.919 3308.774 4.570 3660.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 PAGE: 13 **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, CNTD REM-ARKS: The arithmetic average of passes 1,2 & 3 was computed after all depth shifts and clipping was applied. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 PAGE: 14 ** SET TYPE - CMAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) DEPT FT 1023889 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 1023889 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1023889 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 1023889 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 1023889 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNAV CPS 1023889 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 1023889 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 1023889 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTD GAPI 1023889 O0 000 O0 0 4 1 1 4 68 0000000000 TENS CNTD LB 1023889 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 12933.000 NPHI.CNAV -999.250 NRAT. CNAV -999.250 CRAT. CNAV NCNT. CNAV -999.250 FCNT. CNAV -999.250 CFTC. CNAV -999.250 CNTC. CNAV GRCH. CNTD -999.250 TENS. CNTD 2198.000 DEPT. 12900. 000 NPHI. CNAV 26. 766 NRAT. CNAV 4. 617 CRAT. CNAV NCNT. CNAV 3171.550 FCNT. CNAV 687.874 CFTC. CNAV 710.584 CNTC. CNAV GRCH. CNTD 23. 391 TENS. CNTD 2239 . 000 DEPT. 12600.000 NPHI.CNAV -999.250 NRAT. CNAV -999.250 CRAT. CNAV NCNT. CNAV -999.250 FCNT. CNAV -999.250 CFTC. CNAV -999.250 CNTC. CNAV GRCH. CNTD 85.091 TENS. CNTD -999.250 DEPT. 12588.000 NPHI.CNAV -999.250 NRAT. CNAV -999.250 CRAT. CNAV NCNT. CNAV -999.250 FCNT. CNAV -999.250 CFTC. CNAV -999.250 CNTC. CNAV GRCH. CNTD 67.949 TENS. CNTD -999.250 -999.250 -999.250 4.643 3634.299 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 PAGE: 14 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1023889 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 1023889 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1023889 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 1023889 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 1023889 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNAV CPS 1023889 O0 000 O0 0 4 1 i 4 68 0000000000 CFTC CNAV CPS 1023889 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 1023889 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTD GAPI 1023889 O0 000 O0 0 4 1 1 4 68 0000000000 TENS CNTD LB 1023889 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 12933.000 NPHI.CNAV -999.250 NRAT. CNAV NCNT. CNAV -999.250 FCNT. CNAV -999.250 CFTC. CNAV GRCH. CNTD -999.250 TENS. CNTD 2198.000 DEPT. 12900.000 NPHI.CNAV 26.766 NRAT. CNAV NCNT. CNAV 3171.550 FCNT. CNAV 687.874 CFTC. CNAV GRCH. CNTD 23.391 TENS. CNTD 2239.000 DEPT. 12600.000 NPHI.CNAV -999.250 NRAT. CNAV NCNT. CNAV -999.250 FCNT. CNAV -999.250 CFTC. CNAV GRCH. CNTD 85.091 TENS. CNTD -999.250 DEPT. 12588.000 NPHI.CNAV -999.250 NRAT. CNAV NCNT. CNAV -999.250 FCNT. CNAV -999.250 CFTC. CNAV GRCH. CNTD 67.949 TENS. CNTD -999.250 -999.250 CRAT. CNAV -999.250 CNTC. CNAV 4.617 CRAT. CNAV 710.584 CNTC. CNAV -999 . 250 CRAT. CNAV -999 . 250 CNTC. CNAV -999.250 CRAT. CNAV - 999 . 250 CNTC. CNAV - 999. 250 -999.250 4. 643 3634.299 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 PAGE: 15 **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUF~L%RY VENDOR TOOL CODE START DEPTH STOP DEPTH 12933.0 12592.0 CNTD LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CNTD COMP. NEUT. GR GAM~A RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 16-JUL-97 8C0-609 1030 16-JUL-97 12937.0 12936.0 12576.0 12933.0 1800.0 NO TOOL NUMBER CNC-DA 89 CGRS-A 13520.0 PRODUCED FLUIDS 8.33 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 PAGE: 16 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 2500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 12500 TOOL STANDOFF (IN): 0.5 REMARKS: DEPTH CORRELATED TO CEFIENT EVALUATION LOG OF 07-SEP-1988 2 3/4" CNT-D TOOL RAN. WELL SHUT IN AT 05:00 AM, LOGS STARTED AT 10:30 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 PAGE: 17 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ArOFI~ SAMP ELEM CODE (HEX) DEPT FT 1023889 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 1023889 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS1 1023889 O0 000 O0 0 5 1 1 4 68 0000000000 TiVRA PS1 1023889 O0 000 O0 0 5 1 1 4 68 0000000000 RCNT PS1 CPS 1023889 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 1023889 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PS1 CPS 1023889 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 1023889 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1023889 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1023889 O0 000 O0 0 5 1 I 4 68 0000000000 CCLD PS1 V 1023889 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 12961.000 NPHI.PS1 22.498 RTNR.PS1 4.000 TNRA.PS1 RCNT. PS1 3878.788 RCFT. PS1 969.697 CNTC. PS1 4424.102 CFTC. PSI GR.PS1 0.000 TENS.PSI 997.000 CCLD.PS1 0.029 DEPT. 12900.000 NPHI.PS1 26.777 RTNR.PS1 4.747 TNRA.PS1 RCNT. PS1 3103.890 RCFT. PS1 653.865 CNTC. PS1 3532.091 CFTC. PSI GR.PS1 23.391 TENS.PSI 2239.000 CCLD.PS1 0.000 DEPT. 12600.000 NPHI.PS1 48.399 RTNR.PS1 7.018 TNRA.PS1 RCNT. PS1 2018.018 RCFT. PS1 296.296 CNTC. PS1 2236.848 CFTC. PSI GR.PS1 86.618 TENS.PSi 2161.000 CCLD.PS1 0.000 DEPT. 12567.500 NPHI.PS1 48.399 RTNR.PS1 7.018 TNRA.PS1 RCNT. PS1 2018.018 RCFT. PS1 296.296 CNTC. PS1 2236.848 CFTC.PSI GR.PS1 67.949 TENS.PSI 2161.000 CCLD.PS1 -999.250 4.089 1001.693 4.645 675.440 7.141 306.073 7.141 306.073 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 PAGE: 18 **** FILE HEADER **** FILE NA~E : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ND?4BER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUM~ER: 2 DEPTH INCREMENT: 0.5000 FILE SUMFIARY VENDOR TOOL CODE START DEPTH STOP DEPTH 12931.0 12598.0 CNTD LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CNTD COMP. NEUT. GR GAM~A RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 16-JUL-97 8C0- 609 1030 16-JUL-97 12937.0 12936.0 12576.0 12933.0 1800.0 NO TOOL NUMBER CNC-DA 89 CGRS-A 13520.0 PRODUCED FLUIDS 8.33 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 PAGE: 19 FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 2500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 12500 TOOL STANDOFF (IN): 0.5 RE,lARKS: DEPTH CORRELATED TO CEMENT EVALUATION LOG OF 07-SEP-1988 2 3/4" CNT-D TOOL RAN. WELL SHUT IN AT 05:00 AM, LOGS STARTED AT 10:30 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 PAGE: 20 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1023889 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 1023889 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 1023889 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 1023889 O0 000 O0 0 6 1 1 4 68 0000000000 RCNTPS2 CPS 1023889 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 1023889 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 1023889 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 1023889 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1023889 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1023889 O0 000 O0 0 6 1 1 4 68 0000000000 CCLD PS2 V 1023889 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 12941.000 NPHI.PS2 22.498 RTNR.PS2 4.000 TNRA.PS2 RCNT. PS2 3878.788 RCFT. PS2 969.697 CNTC. PS2 4424.102 CFTC.PS2 GR.PS2 0.000 TENS.PS2 1161.000 CCLD. PS2 0.029 DEPT. 12900.000 NPHI.PS2 28.102 RTNR.PS2 4.643 TNRA. PS2 RCNT. PS2 3241.538 RCFT. PS2 698.152 CNTC. PS2 3673.978 CFTC. PS2 GR.PS2 24.205 TENS.PS2 2258.000 CCLD. PS2 -0.004 DEPT. 12600.000 NPHI.PS2 47.237 RTNR.PS2 7.126 TNRA.PS2 RCNT. PS2 1889.539 RCFT. PS2 265.148 CNTC. PS2 2184.984 CFTC. PS2 GR.PS2 82.775 TENS.PS2 2142.000 CCLD.PS2 0.000 DEPT. 12575.000 NPHI.PS2 49.205 RTNR.PS2 7.289 TNRA.PS2 RCNT. PS2 2052.953 RCFT. PS2 293.279 CNTC. PS2 2309.198 CFTC. PS2 GR.PS2 53.646 TENS.PS2 2136.000 CCLD. PS2 -999.250 4.089 1001.693 4.811 721.188 7.008 273.896 7.233 302.956 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 PAGE: 21 **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~BER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMFIARY VENDOR TOOL CODE START DEPTH ........................... CNTD 12929.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CNTD COMP. NEUT. GR GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : STOP DEPTH 12614.0 16-JUL-97 8C0-609 1030 16-JUL-97 12937.0 12936.0 12576.0 12933.0 1800.O NO TOOL NUMBER ........... CNC-DA 89 CGRS-A 13520.0 PRODUCED FLUIDS 8.33 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 PAGE: 22 FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 2500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 12500 TOOL STANDOFF (IN): 0.5 REMARKS: DEPTH CORRELATED TO CEMENT EVALUATION LOG OF 07-SEP-1988 2 3/4" CNT-D TOOL RAN. WELL SHUT IN AT 05:00 AM, LOGS STARTED AT 10:30 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 PAGE: 23 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1023889 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 1023889 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 1023889 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 1023889 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PS3 CPS 1023889 O0 000 O0 0 7 i 1 4 68 0000000000 RCFT PS3 CPS 1023889 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 1023889 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 1023889 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1023889 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1023889 O0 000 O0 0 7 1 1 4 68 0000000000 CCLDPS3 V 1023889 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 12940.000 NPHI.PS3 7.474 RTNR.PS3 2.000 TNRA.PS3 RCNT. PS3 1939.394 RCFT. PS3 969.697 CNTC. PS3 2212.051 CFTC. PS3 GR.PS3 27.121 TENS.PS3 1323.000 CCLD.PS3 0.019 DEPT. 12900.000 NPHI.PS3 25.141 RTNR.PS3 4.248 TNRA.PS3 RCNT. PS3 3273.088 RCFT. PS3 770.415 CNTC. PS3 3701.113 CFTC. PS3 GR.PS3 27.411 TENS.PS3 2232.000 CCLD.PS3 -0.001 DEPT. 12600.000 NPHI.PS3 44.591 RTNR.PS3 6.154 TNRA.PS3 RCNT. PS3 1938.415 RCFT. PS3 298.839 CNTC.PS3 2218.459 CFTC.PS3 GR.PS3 88.936 TENS.PS3 2186.000 CCLD.PS3 0.004 DEPT. 12591.500 NPHI.PS3 44.591 RTNR.PS3 6.154 TNRA.PS3 RCNT. PS3 1938.415 RCFT. PS3 298.839 CNTC. PS3 2218.459 CFTC.PS3 GR.PS3 69.284 TENS.PS3 2186.000 CCLD.PS3 -999.250 2.044 1001.693 4.436 795.835 6.705 308.699 6.705 308.699 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/12 MAX RFC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-JAN-1998 14:55 PAGE: 24 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/01/12 ORIGIN : FLIC TAPE NAME : 98002 CONTINUATION # : 1 PREVIOUS TAPE : COMIW_ENT : B.P. EXPLORATION, ENDICOTT, 3-11/M-30, API #50-029-21848-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/01/12 ORIGIN : FLIC REEL NAME : 98002 CONTINUATION # : PREVIOUS REEL : COGENT : B.P. EXPLORATION, ENDICOTT, 3-11/M-30, API #50-029-21848-00 3 - II/M - 30 ~,~ ENDICOTT Alaska Oil & Gas Cons. Commission Anchorage Run 1' 11 - September - 1995 PDK-1001GR 12680 12942 W~.61'ERN ATLAS Logging Services Tape Subfile 2 is type: LIS TAPE HEADER ENDICOTT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 3 - 11/M- 30 500292184800 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 19-SEP-95 5723.05 L. KOENN J. POWERS 8 liN 17E 2528 828 55.20 55.20 14.50 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 9.625 12701.0 3RD STRING 7.000 13520.0 PRODUCTION STRING 4.500 12500.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: DENS GR 2 1 03-SEP-88 UNKNOWN BASELINE DEPTH 12697.0 12707.5 12715.5 12720.0 12728.5 12733.0 12735.0 12745.5 12746.5 12749.0 12754.5 12757.0 12757.5 GRCH 12701.0 12712.0 12719.5 12723.5 12733.0 12736.5 12738.5 12748.0 12749.0 12751.5 12757.0 12759.0 12759.5 EQUIVALENT UNSHIFTED DEPTH 47.00 29.00 12.60 12758.5 12762.0 12766.0 12767.0 12777.0 12782.0 12782.5 12785.5 12787.0 12792.0 12792.5 12803.0 12805.0 12846.5 12858.5 12872.5 12874.0 12874.5 12878.0 12878.5 12888.5 12902.0 12906.5 12908.5 12910.5 12912.0 $ REMARKS: 12760.0 12763.5 12768.0 12769.5 12778.0 12783.0 12784.0 12787.0 12788.0 12793.0 12794.0 12804.5 12806.0 12847.5 12860.0 12872.5 12874.0 12875.0 12878.5 12879.5 12889.5 12901.5 12905.5 12908.0 12910.5 12912.0 PDK-100/GR LOG TIED INTO CBL DATED 07-SEP-88. WELL LOGGED SHUT IN WITH 1400 LB SURFACE PRESSURE. LOGGING SUITE ORGANIZATION: 1) BACKGROUND PASS (SOURCE OFF) . 2) LOGGED 3 SHUT-IN PASSES A DIFFUSION CORRECTED SGMA CURVE IS INCLUDED FOR ALL THREE PASSES. THE CURVE IS CALLED SGNT AND WAS CORRECTED WITH THE FOLLOWING PARAMETERS: BOREHOLE SIZE = 8.0" CASING SIZE = 7.0" SALINITY = 0.0 PPM. A PDK POROSITY CURVE (PHI) WAS ALSO CREATED FOR ALL THREE PASSES. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS SGMA (PDK) DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT PDK PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS PDK. / ??MATCH1A. OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH 12680.0 12680.0 BASELINE DEPTH SGMA 12697.0 12701.0 12707.5 12712.0 12715.5 12719.5 12719.5 12724.0 12728.5 12733.0 12733.0 12736.5 12735.0 12738.5 12745.5 12748.0 12746.5 12749.0 12749.0 12751.5 12754.0 12755.5 12760.5 12762.0 12762.5 12765.0 12766.0 12768.0 12767.0 12769.5 12776.5 12778.0 12779.0 12780.5 12782.0 12783.0 12782.5 12784.0 12785.5 12787.0 12787.0 12788.0 12792.0 12793.0 12792.5 12794.0 12803.0 12804.5 12805.0 12806.0 12846.5 12847.5 12858.5 12860.0 12872.5 12872.5 12874.0 12874.0 12874.5 12875.0 12878.0 12878.5 12878.5 12879.5 12885.5 12885.5 12888.5 12889.5 12902.0 12901.5 12908.5 12909.0 12912.0 12912.0 $ STOP DEPTH 12930.0 12942.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH REMARKS: PASS 1. ALL PDK CURVES WERE SHIFTED WITH SGMA. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. CN WN FN COUN STAT / ??MATCH1B. OUT $ : BP EXPLORATION : 3 - ll/M - 30 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units 1 GRCH PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 SS PDK 68 1 CPS 8 MSD PDK 68 1 CU 9 RATO PDK 68 1 10 RBOR PDK 68 1 11 RICS PDK 68 1 12 RIN PDK 68 1 13 SGMA PDK 68 1 CU 14 SGMB PDK 68 1 CU 15 SGNT PDK 68 1 CU 16 PHI PDK 68 1 PU-S API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 64 * DATA RECORD (TYPE# 0) Total Data Records: 44 958 BYTES * Tape File Start Depth = 12956.000000 Tape File End Depth = 12652.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 10354 datums Tape Subfile: 2 Minimum record length: Maximum record length: 232 records... 62 bytes 958 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH 12680.0 12680.0 STOP DEPTH 12930.0 12942.0 (MEASURED DEPTH) BASELINE DEPTH GRCH 12680.5 12685.0 12688.5 12694.5 12698.5 12697.0 12701.0 12703.0 12706.0 12707.5 12712.0 12716.0 12720.0 12720.0 12723.5 12724.0 12727.5 12732.5 12746.0 12748.0 12747.0 12750.0 12748.0 12750.5 12756.5 12759.0 12758.5 12760.5 12767.5 12769.5 12769.5 12768.0 12770.5 12768.5 12771.0 12773.0 12775.0 12774.0 12775.5 12776.5 12778.5 12777.5 12779.0 12786.5 12788.0 12787.0 12789.0 12789.0 12791.0 12790.0 12791.5 12792.0 12793.5 12792.5 12794.5 12801.0 12803.0 12802.0 12803.5 12803.0 12804.0 12804.0 12806.0 12852.0 12853.5 12853.0 12854.0 12853.5 12855.0 12859.5 12861.0 12869.0 12869.5 12871.0 12871.5 EQUIVALENT UNSHIFTED DEPTH SGMA 12684.0 12872.0 12875.0 12883.5 12884.5 12888.5 12889.0 12895.0 12895.5 12896.5 12901.0 12903.0 12903.5 12904.0 12908.5 12911.5 12916.5 $ REMARKS: 12873.0 12876.0 12884.5 12885.0 12889.5 12889.5 12895.0 12895.5 12896.0 12900.5 12902.5 12903.5 12904.5 12908.5 12912.0 12917.0 PASS 2. ALL PDK CURVES WERE SHIFTED WITH SGMA. CN WN FN COUN STAT / ? ?MATCH2A. OUT / ? ?MATCH2B. OUT $ : BP EXPLORATION : 3 - ll/M - 30 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 Name Tool Code Samples Units GRCH PDK 68 1 GAPI BIF PDK 68 1 BKL PDK 68 1 CPS BKS PDK 68 1 CPS CSLS PDK 68 1 CU LS PDK 68 1 CPS SS PDK 68 1 CPS MSD PDK 68 1 CU RATO PDK 68 1 RBOR PDK 68 1 RICS PDK 68 1 RIN PDK 68 1 SGMA PDK 68 1 CU SGMB PDK 68 1 CU SGNT PDK 68 1 CU PHI PDK 68 1 PU-S API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 * DATA RECORD (TYPE# 0) Total Data Records: 44 958 BYTES * Tape File Start Depth = 12956.000000 Tape File End Depth = 12652.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 10354 datums Tape Subfile: 3 131 records... Minimum record length: Maximum record length: 62 bytes 958 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate PASS NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH 12680.0 12680.0 BASELINE DEPTH GRCH 12694.5 12697.0 12701.0 12702.0 12705.5 12717.5 12721.0 12720.0 12724.5 12729.0 12728.5 12733.0 12735.5 12738.5 12744.5 12748.0 12747.0 12750.0 12748.0 12750.5 12749.0 12750.0 12754.0 12754.5 12755.5 12758.0 12756.5 12758.5 12759.0 12763.0 12767.5 12769.5 12774.0 12775.0 12776.0 12777.5 12801.5 12802.0 12803.5 12803.0 12804.0 12803.5 12804.0 12851.0 12859.0 12869.0 12871.5 12872.0 12872.5 12876.0 12877.0 12877.0 12877.5 12878.0 12879.0 files. STOP DEPTH 12930.0 12942.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 12698.5 12723.5 12749.0 12751.0 12751.5 12755.5 12756.5 12758.5 12760.5 12765.0 12776.0 12776.5 12803.0 12804.5 12805.5 12852.0 12860.0 12869.0 12871.5 12873.5 12879.0 12879.5 12884.0 12884.5 12886.5 12887.5 12888.0 12895.0 12896.0 12900.5 12903.0 12903.5 12908.0 12910.0 12912.0 12912.5 12915.5 12916.5 12936.0 $ REMARKS: 12884.5 12885.5 12887.0 12887.5 12889.0 12895.0 12895.5 12900.0 12902.5 12903.5 12908.0 12910.0 12912.0 12912.0 12913.0 12916.0 12917.0 12916.5 12936.5 PASS 3. ALL PDK CURVES WERE SHIFTED WITH SGMA. CN WN FN COUN STAT / ? ?MATCH3A. OUT /??MATCH3B.OUT $ : BP EXPLORATION : 3 - ll/M - 30 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod GRCH PDK 68 1 GAPI 4 BIF PDK 68 1 4 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 4 CSLS PDK 68 1 CU 4 LS PDK 68 1 CPS 4 SS PDK 68 1 CPS 4 MSD PDK 68 1 CU 4 RATO PDK 68 1 4 RBOR PDK 68 1 4 RICS PDK 68 1 4 RIN PDK 68 1 4 SGMA PDK 68 1 CU 4 SGMB PDK 68 1 CU 4 SGNT PDK 68 1 CU 4 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 16 PHI PDK 68 1 PU-S 4 4 51 995 99 1 * DATA RECORD (TYPE# 0) Total Data Records: 44 958 BYTES * 64 Tape File Start Depth = 12956.000000 Tape File End Depth = 12652.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 20708 datums Tape Subfile: 4 132 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 EDITED BACKGROUND PASS Pulsed Neutron only: (neutron generator off). PASS NUMBER: 0 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 Depth shifted and clipped curves BASELINE DEPTH GRCH 12697.0 12702.0 12707.5 12712.5 12716.0 12720.5 12720.0 12724.5 12727.5 12733.0 12735.5 12739.5 12753.5 12756.0 12760.0 12763.0 12763.0 12765.0 12778.5 12781.0 12796.0 12798.0 12820.5 12823.0 12858.0 12859.5 12882.5 12883.0 12908.0 12908.0 12910.0 12910.0 12912.0 12912.5 12916.5 12917.0 $ REMARKS: START DEPTH 12680.0 12680.0 STOP DEPTH 12930.0 12942.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BACKGROUND PASS (SOURCE OFF). BKL & BKS WERE SHIFTED WITH GRCH. for background pass / ? ?MATCH4A. OUT $ CN : BP EXPLORATION WN : 3 - ll/M - 30 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 3 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 2 BKL PDK 68 1 CPS 4 3 BKS PDK 68 1 CPS 4 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 12 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 10 Tape File Start Depth = 12956.000000 Tape File End Depth = 12652.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 12791 datums Tape Subfile: 5 62 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: .5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS GRCH PDK $ REMARKS: CN WN FN COUN STAT 1 1, 2, 3 AVERAGED PASS. PASSES 1, 2, & 3 WERE AVERAGED. $ : BP EXPLORATION : 3 - ll/M - 30 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PNAV 68 1 GAPI 4 2 BKL PNAV 68 1 CPS 4 3 BKS PNAV 68 1 CPS 4 4 BIF PNAV 68 1 4 5 CSLS PNAV 68 1 CU 4 6 LS PNAV 68 1 CPS 4 7 SS PNAV 68 1 CPS 4 8 MSD PNAV 68 1 CU 4 9 RATO PNAV 68 1 4 10 RBOR PNAV 68 1 4 11 RICS PNAV 68 1 4 12 RIN PNAV 68 1 4 13 SGMA PNAV 68 1 CU 4 14 SGMB PNAV 68 1 CU 4 15 SGNT PNAV 68 1 CU 4 16 PHI PNAV 68 1 PU-S 4 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 64 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 44 Tape File Start Depth = 12956.000000 Tape File End Depth = 12652.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 31062 datums Tape Subfile: 6 66 records... Minimum record length: Maximum record length: 62 bytes 958 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12667.0 PDK 12679.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB SBAR SINKER BAR SBAR SINKER BAR SBAR SINKER BAR PDK PDK-100 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 12940.5 12952.5 ll-SEP-95 FSYS REV. J001 VER. 1.1 1524 ll-SEP-95 13436.0 12950.0 12680.0 12942.0 900.0 YES TOOL NUMBER 3913NA 2725XA .0OO 13520.0 .0 PRODUCED FLUIDS .00 .0 .0 0 .0 .000 .000 .000 .0 .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): .0 .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS) : 5000 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS) : 80000 TOOL STANDOFF (IN): .0 REMARKS: PASS 1. $ CN WN FN COUN STAT : BP EXPLORATION : 3 - ll/M - 30 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 24 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 GR PDK 68 1 GAPI BKL PDK 68 1 CPS BKS PDK 68 1 CPS BIF PDK 68 1 CCL PDK 68 1 CSLS PDK 68 1 CU CSS PDK 68 1 CPS ISS PDK 68 1 CPS G1 PDK 68 1 CPS G2 PDK 68 1 CPS LS PDK 68 1 CPS SS PDK 68 1 CPS MON PDK 68 1 CPS MSD PDK 68 1 CU RATO PDK 68 1 RBOR PDK 68 1 RICS PDK 68 1 RIN PDK 68 1 SGMA PDK 68 1 CU SGMB PDK 68 1 CU SGNT PDK 68 1 CU PHI PDK 68 1 PU-S SPD PDK 68 1 F/MN TEN PDK 68 1 LB 4 51 310 01 1 4 51 391 51 1 4 51 390 51 1 4 51 995 99 1 4 51 150 01 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 01 1 4 51 995 02 1 4 51 391 99 1 4 51 390 99 1 4 51 430 01 1 4 51 995 99 1 4 51 420 99 1 4 51 420 99 1 4 51 420 99 1 4 51 420 99 1 4 51 400 01 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 636 99 1 4 51 635 99 1 96 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 122 Tape File Start Depth = 12956.000000 Tape File End Depth = 12652.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 43217 datums Tape Subfile: 7 199 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12668.0 PDK 12680.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB SBAR SINKER BAR SBAR SINKER BAR SBAR SINKER BAR PDK PDK-100 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 12940.5 12952.5 ll-SEP-95 FSYS REV. J001 VER. 1.1 1551 ll-SEP-95 13436.0 12950.0 12680.0 12942.0 900.0 YES TOOL NUMBER 3913NA 2725XA 0.000 13520.0 0.0 PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 80000 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2. $ CN WN FN COUN STAT : BP EXPLORATION : 3 - ll/M- 30 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 24 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 GR PDK 68 1 GAPI BKL PDK 68 1 CPS BKS PDK 68 1 CPS BIF PDK 68 1 CCL PDK 68 1 CSLS PDK 68 1 CU CSS PDK 68 1 CPS ISS PDK 68 1 CPS G1 PDK 68 1 CPS G2 PDK 68 1 CPS LS PDK 68 1 CPS SS PDK 68 1 CPS MON PDK 68 1 CPS MSD PDK 68 1 CU RATO PDK 68 1 RBOR PDK 68 1 RICS PDK 68 1 RIN PDK 68 1 SGMA PDK 68 1 CU SGMB PDK 68 1 CU SGNT PDK 68 1 CU PHI PDK 68 1 PU-S SPD PDK 68 1 F/MN TEN PDK 68 1 LB 4 51 310 01 1 4 51 391 51 1 4 51 390 51 1 4 51 995 99 1 4 51 150 01 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 01 1 4 51 995 02 1 4 51 391 99 1 4 51 390 99 1 4 51 430 01 1 4 51 995 99 1 4 51 420 99 1 4 51 420 99 1 4 51 420 99 1 4 51 420 99 1 4 51 400 01 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 636 99 1 4 51 635 99 1 96 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 122 Tape File Start Depth = 12956.000000 Tape File End Depth = 12652.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 61488 datums Tape Subfile: 8 199 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 9 is type: LIS FILE HEADER FILE NUMBER: 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12670.0 PDK 12682.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB SBAR SINKER BAR SBAR SINKER BAR SBAR SINKER BAR PDK PDK-100 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 12942.0 12954.0 ll-SEP-95 FSYS REV. J001 VER. 1.1 1620 ll-SEP-95 13436.0 12950.0 12680.0 12942.0 900.0 YES TOOL NUMBER 3913NA 2725XA 0.000 13520.0 0.0 PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 80000 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 3. $ CN WN FN COUN STAT : BP EXPLORATION : 3 - ll/M - 30 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 24 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 GR PDK 68 1 GAPI 4 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 4 BIF PDK 68 1 4 CCL PDK 68 1 4 CSLS PDK 68 1 CU 4 CSS PDK 68 1 CPS 4 ISS PDK 68 1 CPS 4 G1 PDK 68 1 CPS 4 G2 PDK 68 1 CPS 4 LS PDK 68 1 CPS 4 SS PDK 68 1 CPS 4 MON PDK 68 1 CPS 4 MSD PDK 68 1 CU 4 RATO PDK 68 1 4 RBOR PDK 68 1 4 RICS PDK 68 1 4 RIN PDK 68 1 4 SGMA PDK 68 1 CU 4 SGMB PDK 68 1 CU 4 SGNT PDK 68 1 CU 4 PHI PDK 68 1 PU-S 4 SPD PDK 68 1 F/MN 4 TEN PDK 68 1 LB 4 4 51 310 01 1 4 51 391 51 1 4 51 390 51 1 4 51 995 99 1 4 51 150 01 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 01 1 4 51 995 02 1 4 51 391 99 1 4 51 390 99 1 4 51 430 01 1 4 51 995 99 1 4 51 420 99 1 4 51 420 99 1 4 51 420 99 1 4 51 420 99 1 4 51 400 01 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 636 99 1 4 51 635 99 1 96 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 122 Tape File Start Depth = 12956.000000 Tape File End Depth = 12652.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 73643 datums Tape Subfile: 9 199 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 10 is type: LIS FILE HEADER FILE NUMBER: 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 0 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12666.0 PDK 12678.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB SBAR SINKER BAR SBAR SINKER BAR SBAR SINKER BAR PDK PDK-100 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 12942.0 12954.0 ll-SEP-95 FSYS REV. J001 VER. 1.1 1507 ll-SEP-95 13436.0 12950.0 12680.0 12942.0 1800.0 YES TOOL NUMBER 3913NA 2725XA .000 13520.0 .0 PRODUCED FLUIDS .00 .0 .0 0 .0 .000 .000 .000 .0 .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 80000 TOOL STANDOFF (IN): .0 REMARKS: BACKGROUND PASS (SOURCE OFF). $ CN WN FN COUN STAT : BP EXPLORATION : 3 - ll/M - 30 : ENDICOTT : NORTH SLOPE : ALASKA .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BKL PDK 68 1 CPS 4 3 BKS PDK 68 1 CPS 4 4 CCL PDK 68 1 4 5 SPD PDK 68 1 F/MN 4 6 TEN PDK 68 1 LB 4 4 51 310 01 1 4 51 391 51 1 4 51 390 51 1 4 51 150 01 1 4 51 636 99 1 4 51 635 99 1 24 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 34 Tape File Start Depth = 12957.000000 Tape File End Depth = 12653.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 70008 datums Tape Subfile: 10 110 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 11 is type: LIS 95/ 9/19 01 **** REEL TRAILER **** 95/ 9/20 01 Tape Subfile: 11 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 20 SEP 95 8:58a Elapsed execution time = 2.80 seconds. SYSTEM RETURN CODE = 0 3 - II/M - 30 °~C o? ENDICOTT II I I Run !' 02 - November - 1993 PDK-!00!GR 12700 2955 Tape subfile' 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 3-11 / M-30 (SDI) 500292184800 B.P. EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 03-DEC-93 5723.01 ECK/KOENN M. MARTIN 8 liN 17E 2529 828 55.20 55.20 14.50 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9.625 12701.0 47.00 7.000 13520.0 29.00 4.500 12382.0 12.60 3.500 12951.0 9.20 DLL GR 2 1 03-SEP-88 GEARHART LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH 12702.0 12754.0 12762.0 12779.0 12796.5 12882.5 12946.5 $ SGMA 12704.0 12756.0 12766.0 12782.0 12800.0 12884.5 12948.0 EQUIVALENT UNSHIFTED DEPTH REMARKS: PDK-100/GR Log. LOG TIED INTO CEMENT EVALUATION LOG RUN 07-SEP-88. LOGGING PROGRAM ORGANIZATION: 1. LOGGED BASE GR (SOURCE OFF) WITH WELL SHUT-IN. 2. LOGGED 3 PASSES WITH BRINE IN THE HOLE. A DIFFUSION CORRECTED SGMA CURVE IS INCLUDED FOR EACH PASS. THE CURVE IS NAMED SGNT AND WAS CORRECTED WITH THE FOLLOWING PARAMETERS: BOREHOLE SIZE = 8" CASING SIZE = 7" SALINITY = 25,000 PPM THE GAMMA RAY BACKGROUND IS VERY HIGH. AS A RESULT, THE RECORDED GAMMA RAY DOES NOT MATCH PREVIOUS GAMMA RAY CURVES. WITH CURRENT AVAILABLE TECHNIQUES, A POROSITY CURVE COULD NOT BE CALCULATED DUE TO THE VERY HIGH GAMMA RAY BACKGROUND. THEREFORE, NO POROSITY CURVES ARE INCLUDED ON THIS TAPE. SHIFT PROCEDURE AS FOLLOWS: 1. THE FIRST PASS SGMA WAS DEPTH MATCHED TO PREVIOUS DLL OPEN HOLE GAMMA RAY. ALL THE PDK CURVES, INCLUDING THE GAMMA RAY, WERE SHIFTED WITH SGMA. 2. ALL SUBSEQUENT SGMA PASSES WERE DEPTH MATCHED TO THE "SHIFTED" FIRST PASS SGMA. 3. ALL SUBSEQUENT GAMMA RAY PASSES WERE DEPTH MATCHED TO THE "SHIFTED" FIRST PASS GAMMA RAY. / ? ?MATCH2. OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 12690.0 12943.0 PDK 12702.0 12955.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: SGMA PASS NUMBER: 1 BASELINE DEPTH 12702.0 12754.0 12762.0 12779.0 12796.5 12882.5 12946.5 $ REMARKS: ......... EQUIVALENT UNSHIFTED DEPTH ......... SGMA 12704.0 12756.0 12766.0 12782.0 12800.0 12884.5 12948.0 PASS 1. ALL PDK CURVES WERE SHIFTED WITH SGMA. GRCH WAS SHIFTED WITH SGMAALSO SINCE GRCH COULD NOT BE DEPTH MATCHED TO THE OPEN HOLE GAMMA RAY DUE TO THE HIGH BACKGROUND GAMMA RAY READING. CN WN FN COUN STAT / ? ?MATCH2. OUT $ : B.P. EXPLORATION : 3-11 / M-30 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 15 Curves: Name Tool Code Samples Units GRCH PDK 68 1 GAPI BIF PDK 68 1 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 00 201 24 1 4 4 00 201 24 1 3 BKL PDK 68 I CPS 4 BKS PDK 68 i CPS 5 CSLS PDK 68 i CU 6 LS PDK 68 i CPS 7 MSD PDK 68 i CU 8 RATO PDK 68 1 9 RBOR PDK 68 1 10 RICS PDK 68 1 11 RIN PDK 68 1 12 SGMA PDK 68 i CU 13 SGMB PDK 68 i CU 14 SS PDK 68 I CPS 15 SGNT PDK 68 i CU * DATA RECORD (TYPE~ 0) Total Data Records: 39 4 4 4 4 4 4 4 4 4 4 4 4 4 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 966 BYTES * Tape File Start Depth = 12960.000000 Tape File End Depth = 12670.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 9297 datums Tape Subfile: 2 174 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: SGMA PASS NUMBER: 1 START DEPTH 12673.0 12685.0 STOP DEPTH 12943.0 12955.0 (MEASURED DEPTH) BASELINE DEPTH 12693.0 12701.0 12701.5 12708.0 12717.5 12718.0 12719.0 12722.5 12752.0 12752.5 12753.5 12757.0 12757.5 12762.5 12779.5 12797.0 12818.5 12858.0 12859.0 12872.5 12874.0 12875.0 12876.0 12877.0 12882.5 12888.5 12889.5 12891.0 12892.0 12895.5 12896.5 12934.0 12936.0 12945.5 12946.0 12949.0 12949.5 GRCH 12696.0 12704.0 12705.0 12755.5 12756.5 12761.0 12762.0 12862.5 12863.0 12880.0 12880.5 12894.5 12896.0 12899.5 12900.0 12937.5 12938.0 12947.5 12948.5 12951.5 12952.0 in separate files. EQUIVALENT UNSHIFTED DEPTH SGMA 12704.5 12712.0 12721.0 12721.5 12722.0 12725.5 12758.0 12767.5 12784.0 12802.0 12823.0 12876.5 12878.0 12878.5 12885.5 12892.0 12892.5 12950.0 12950.5 $ REHARKS: PASS 2. ALL PDK CURVES WERE SHIFTED WITH SGMA. CN WN FN COUN STAT / ??MATCH3A. OUT /??MATCH3B. OUT $ : B.P. EXPLORATION : 3-11 / M-30 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 15 Curves: Name Tool Code Samples Units 1 GRCH PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 MSD PDK 68 1 CU 8 RATO PDK 68 1 9 RBOR PDK 68 1 10 RICS PDK 68 1 11 RIN PDK 68 1 12 SGMA PDK 68 1 CU 13 SGMB PDK 68 1 CU 14 SS PDK 68 1 CPS 15 SGNT PDK 68 1 CU API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 60 * DATA RECORD (TYPE# 0) Total Data Records: 39 966 BYTES * Tape File Start Depth = 12960.000000 Tape File End Depth = 12670.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 9297 datums Tape Subfile: 3 110 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: SGMA PASS NUMBER: 1 START DEPTH 12688.0 12700.0 STOP DEPTH 12943.0 12955.0 (MEASURED DEPTH) BASELINE DEPTH GRCH 12681.5 12684.5 12693.0 12702.5 12704.0 12706.0 12707.0 12707.5 12720.0 12721.0 12724.0 12752.0 12755.0 12752.5 12756.0 12754.0 12757.5 12761.0 12758.0 12762.0 12760.0 12764.0 12760.5 12765.0 12762.0 12769.0 12773.0 12785.0 12786.0 12801.5 12802.5 12807.0 12803.5 12807.5 12806.5 12810.5 12809.5 12814.0 12815.0 12819.5 12817.5 12821.5 12843.5 12847.5 12844.5 12848.0 12866.0 12869.5 12867.0 12870.0 12873.0 12874.5 12875.5 12878.5 in separate files. EQUIVALENT UNSHIFTED DEPTH SGMA 12696.5 12706.0 12706.5 12708.5 12709.0 12710.5 12723.0 12723.5 12726.5 12758.5 12767.5 12773.5 12777.0 12789.0 12790.5 12806.0 12806.5 12807.5 12876.0 12877.5 12878.0 12881.0 12879.0 12882.5 12886.5 12887.0 12887.5 12888.0 12889.0 12906.5 12925.5 12926.0 12936.0 12945.5 12946.0 12946.5 12947.5 12949.0 12949.5 $ REMARKS: 12882.0 12885.0 12889.5 12889.5 12890.5 12890.0 12891.5 12892.0 12909.0 12928.5 12929.0 12938.0 12947.5 12949.0 12949.5 12950.0 12951.5 12950.0 12952.0 12950.5 PASS 3. ALL PDK CURVES WERE SHIFTED WITH SGMA. CN WN FN COUN STAT / ? ?MATCH4A. OUT /??MATCH4B. OUT $ : B.P. EXPLORATION : 3-11 / M-30 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 15 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Name Tool Code Samples Units GRCH PDK 68 1 GAPI BIF PDK 68 1 BKL PDK 68 1 CPS BKS PDK 68 I CPS CSLS PDK 68 1 CU LS PDK 68 1 CPS MSD PDK 68 1 CU RATO PDK 68 1 RBOR PDK 68 RICS PDK 68 1 RIN PDK 68 1 SGMA PDK 68 1 CU SGMB PDK 68 1 CU SS PDK 68 1 CPS SGNT PDK 68 1 CU API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 * DATA RECORD (TYPE# 0) Total Data Records: 39 966 BYTES * mmmmmmm 60 Tape File Start Depth = 12960.000000 Tape File End Depth = 12670.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 18594 datums Tape Subfile-. 4 127 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS PDK GRCH $ REMARKS: CN WN FN COUN STAT 1, 2, 3 1 AVERAGED PASS. PASSES 1, 2, & 3 WERE AVERAGED. $ : B.P. EXPLORATION : 3-11 / M-30 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 15 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PNAV 68 1 GAPI 4 2 BKL PNAV 68 1 CPS 4 3 BKS PNAV 68 1 CPS 4 4 BIF PNAV 68 1 CPS 4 5 CSLS PNAV 68 1 CU 4 6 LS PNAV 68 1 CPS 4 7 MSD PNAV 68 1 CU 4 8 RATO PNAV 68 1 4 9 RBOR PNAV 68 1 4 10 RICS PNAV 68 i 4 11 RIN PNAV 68 1 4 12 SGMA PNAV 68 1 CU 4 13 SGMB PNAV 68 1 CU 4 14 SS PNAV 68 1 CPS 4 15 SGNT PNAV 68 i CU 4 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 6O * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 39 Tape File Start Depth = 12960.000000 Tape File End Depth = 12670.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 18594 datums Tape Subfile: 5 61 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 0 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 12696.0 12708.0 BASELINE DEPTH GRCH 12698.0 12700.5 12702.0 12704.5 12702.5 12705.5 12709.0 12712.0 12710.0 12712.5 12722.0 12724.5 12722.5 12725.5 12723.5 12726.5 12724.5 12727.0 12725.5 12728.0 12726.0 12729.0 12726.5 12729.5 12727.5 12730.0 12745.0 12747.5 12748.0 12751.0 12749.5 12752.5 12750.5 12753.0 12751.0 12754.0 12755.0 12758.0 12756.0 12759.5 12847.0 12850.5 12848.0 12851.0 12877.0 12880.0 12878.0 12880.5 12898.0 12900.5 12899.0 12901.0 12907.0 12909.0 12908.0 12910.5 12915.0 12917.5 12916.0 12918.0 12920.5 12922.5 12921.0 12923.0 $ STOP DEPTH 12930.0 12942.0 (MEASURED DEPTH) REMARKS: in separate files. EQUIVALENT UNSHIFTED DEPTH ......... BASE GR PASS. NO PDK SOURCE ACTIVATION. BKL & BKS WERE SHIFTED WITH GRCH. CN WN FN COUN STAT / ? ?MATCH1. OUT $ : B.P. EXPLORATION : 3-11 / M-30 : ENDICOTT : NORTH SLOPE : ALASKA FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 3 Curves: Name Tool Code Samples Units API AP1 API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 2 BKL PDK 68 1 CPS 3 BKS PDK 68 1 CPS 4 4 06 511 09 0 4 4 39 705 61 6 4 4 74 169 61 6 12 * DATA RECORD (TYPE# O) 1014 BYTES * Total Data Records: 10 Tape File Start Depth = 12960.000000 Tape File End Depth = 12670.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decOding summary: Rep Code: 68 20919 datums Tape Subfile: 6 75 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12689.0 PDK 12701.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR SBAR SINKER BAR PDK PDK-100 $ STOP DEPTH 12956.0 12968.0 02-NOV-93 FSYS REV. J001 VER. 1.1 1312 02-NOV-93 12963.0 12963.0 12700.0 12955.0 900.0 YES TOOL NUMBER 2725XA BOREHOLEAND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 13520.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): BRINE 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 3900 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 1. $ CN WN FN COUN STAT : B.P. EXPLORATION : 3-11 / M-30 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 23 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 GElS PDK 68 1 CPS 4 11 ISS PDK 68 1 CPS 4 12 LS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 RATO PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 i 4 19 SGMA PDK 68 1 CU 4 20 SGMB PDK 68 1 CU 4 21 SPD PDK 68 1 F/MN 4 22 SS PDK 68 1 CPS 4 23 SGNT PDK 68 i CU 4 4 06 511 09 4 00 201 24 4 39 705 61 4 74 169 61 4 92 630 79 4 00 201 24 4 00 201 24 4 35 975 96 4 36 631 32 4 74 169 61 4 00 201 24 4 71 162 89 4 32 125 68 4 00 201 24 4 23 260 40 4 23 260 40 4 23 260 40 4 23 260 40 4 96 761 61 4 00 201 24 4 52 386 28 4 05 626 89 4 00 201 24 0 1 6 6 6 1 1 1 1 6 1 6 0 1 0 0 0 0 6 1 5 6 1 92 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 112 Tape File Start Depth = 12968.000000 Tape File End Depth = 12689.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 45403 datums Tape Subfile: 7 187 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12672.0 PDK 12684.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 12958.0 12970.0 02-NOV-93 FSYS REV. J001 VER. 1.1 1341 02-NOV-93 12963.0 12963.0 12700.0 12955.0 900.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR SBAR SINKER BAR PDK PDK-100 $ TOOL NUMBER 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 13520.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): BRINE 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BAsE NORMALIZING WINDOW (FT): 0.0 BLuELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 3900 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2. $ CN WN FN COUN STAT : B.P. EXPLORATION : 3-11 / M-30 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 23 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 GElS PDK 68 1 CPS 4 11 ISS PDK 68 1 CPS 4 12 LS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 RATO PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 1 4 19 SGMA PDK 68 1 CU 4 20 SGMB PDK 68 1 CU 4 21 SPD PDK 68 1 F/MN 4 22 SS PDK 68 1 CPS 4 23 SGNT PDK 68 1 CU 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 32 125 68 0 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 52 386 28 5 4 05 626 89 6 4 00 201 24 92 * DATA RECORD (TYPE# 0) Total Data Records: 120 966 BYTES * Tape File Start Depth = 12970.000000 Tape File End Depth = 12672.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 49552 datums Tape Subfile: 8 195 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 9 is type: LIS FILE HEADER FILE NUMBER: 8 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12687.0 PDK 12699.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR SBAR SINKER BAR PDK PDK-100 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 12957.0 12969.0 02-NOV-93 FSYS REV. J001 VER. 1.1 1426 02-NOV-93 12963.0 12963.0 12700.0 12955.0 900.0 YES TOOL NUMBER 2725XA 0.000 13520.0 0.0 BRINE 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 3900 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 3. $ CN WN FN COUN STAT : B.P. EXPLORATION : 3-11 / M-30 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 23 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 $ G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 GElS PDK 68 1 CPS 4 11 ISS PDK 68 1 CPS 4 12 LS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 RATO PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 1 4 19 SGMA PDK 68 1 CU 4 20 SGMB PDK 68 1 CU 4 21 SPD PDK 68 1 F/MN 4 22 SS PDK 68 1 CPS 4 23 SGNT PDK 68 1 CU 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 32 125 68 0 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 52 386 28 5 4 05 626 89 6 4 00 201 24 1 92 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 113 Tape File Start Depth = 12969.000000 Tape File End Depth = 12687.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 72500 datums Tape Subfile: 9 188 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 10 is type: LIS FILE HEADER FILE NUMBER: 9 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 0 DEPTH INCREMENT: 0. 2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12695.0 PDK 12707.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 12957.0 12969.0 02-NOV-93 FSYS REV. J001 VER. 1.1 1245 02-NOV-93 12963.0 12963.0 12700.0 12955.0 1200.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL, TYPE SBAR SINKER BAR SBAR SINKER BAR PDK PDK-100 $ TOOL NUMBER 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 13520.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): BRINE 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): 0.0 REMARKS: BASE GR PASS. NO PDK SOURCE ACTIVATION. $ CN WN FN COUN STAT : B.P. EXPLORATION : 3-11 / M-30 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPES 64 ) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 2 BKL PDK 68 1 CPS 3 BKS PDK 68 1 CPS 4 CCL PDK 68 1 5 SPD PDK 68 1 F/MN 4 4 06 511 09 0 4 4 39 705 61 6 4 4 74 169 61 6 4 4 92 630 79 6 4 4 05 626 89 6 _~_t___ 20 * DATA RECORD (TYPES 0) 1014 BYTES * Total Data Records: 27 Tape File Start Depth = 12969.000000 Tape File End Depth = 12695.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 56135 datums Tape Subfile: 10 101 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 11 is type: LIS 93/12/ 4 01 **** REEL TRAILER **** 93/12/ 4 O1 Tape Subfile: 11 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Sat 4 DEC 93 l:17p Elapsed execution time = 19.55 seconds. SYSTEM RETURN CODE = 0 RECEIVED DEC 1 ~ 1988 ?1 & 8as Cons. Comm~lon DIRECT DIGITAL LOGGING COMPUTER PROCESSED ANALYSIS Comp.any STANDARD ALASKA PRODUCTIOH CO. Well o--!t..-'M-~O SD! APl NUM: 50-029-21848 Field ENDICOTT DATE LO.~;~ED: 09.-0~-8~ Counts.'. NORTH SLOPE State ALASKA · . U._A Country,, .~ CLIENT FORMAT DATA TAPE LOG I NFORMAT I ON STANDARD FORMAT ( L. I, S, ) Field: ENDICOTT DATE LOGGEC,; 09-0::3-88 WED. L I I, $. TAPE RECORDS HEADER RE~ORD'' S6r. vice.: name: EGSFOt Date: 88/09/07 Origin R~I name: Comm~nt~: Cont. inuation ~: 01 F'r~vious tap~: Date:o,.,,.."'° "09/ O,.'-' Origin Comments: Tape name: ,7,92276 Continuation +:** EOF *;** Maximum length: 1.024 HEADER RECORD Film tppe: LO Prmvious ~itm: Dmtm: Page M N E M CH WN FN COUH STAT CTRY AP IN LATI LONG SECT 'T' :3 (8 H RANG E:KB EDF EGL. PD LHF Df'IF RUH TiME DATE LOC L U N FL LUL ENG i I.~ I T N DD DL TL~ ~L~ TCS TLA8 MRT MT MSS HViS RHF biFST MFSS RbiC biCST MCSS CS I NFORMAT I'ON RECORDS CONTENTS STANDARD RLR~,Kr4 PRODUCTION CO ............ · ..":~- t t ..,'i.4-.. -;:,;,.~] SD I AP l NIJi,1: 5 O-0~""':':¢ ENDICOTT OATE LOGGED: 09-03-88 ~" '" St OPE ,tuRTH .......................... ALASKA ................................ .... ., .:.,, O 0 ')" L ~:g 0 [:,e.g 0 Min 0 0 Smc ,.,.,,1~0,.. ......... 0,000 ........... i4 ..500 ........... DiS .............. i<B .............. KE; ............... .¢..., ° 000 ~,.:: 9/88 .......... .".~0 HOP, TH SL. OP ' ',:: , ; HO 'rH PRES~LE" ZARN[:,T .................................... i S5-S0, OOO ................................. ~ 35;.?~, OOO ................................. i 2~97, OOO ................................... i fi :30'0 '' ........... . I I 20 ,SOO .................................................. i92, OOO ............................................. i92. OuO .......................................... LiGNOSULF ......................................... C ~ 19 F': U LA'f'ED ........................................ .~;, 000 ................... 2,120 2, igo ........... 66, O00 .......... ME~S ........... 2,¥70 ........... 7 ::.'., 000 ........... HERS ............................. 8.500 .................................................. UNIT TYPE CATG CODE 0 0 40 65 0 0 40 65 0 0 40 65 0 0 '" 0 0 0 2O 65 0 0 4 68 0 0 34 "~ 0 0 2]4 65 0 0 2 0 0 7, 65 O O '~] · .. ~.."., w F T O ..% 4 68 F T 0 ~ 4 b,:.' '" FT 0 ~ 4 r:,o'"" 0 .3 2 65 0 ..:* 2 '" =' 0 0 '2 79 0 O 4 68 0 0 8 0 0 2 79 0 0 iO 65 0 0 i0 0 0 20 65 0 O 20 (.5 0 0 20 65 0 0 20 65 FT 0 3 4 68 FT 0 ~ 4 69 FT 0 ~ 4 68 F T 0 :~ 4 6, 8 fir 8 2 4 68 HR 0 4 4 DEGF 0 1 4 68 DEGF 0 t 4 68 0 2 20 65 0 2 20 65 CP 0 '~'.-. 4 68 0 H i'l M 0 2 4 68 OHMH 0 2 4 68 DEGF 0 2 4 68 0 2 i '2 65 0 H bi H 0 '2 4 6 8 D E G F 0 '2 4 68 0 2 i .:, -' ~ 0 .S 4 68 0 ,~ -4. 68 Page t,,te t 1 Well Location Commmnt i: Location Commant 2: Loca'tion Comment ~: Location Commant 4: SURFACE: C 0 M M E N T 2529' FNL & 828" FEL RECORDS COMMENT RECORD'~. Welt F'it~ Comment 1: NEUTRON POROSITY CORRECTED FOR TEMPERATURE, PRESSURE AND Well File Comment 2: H~E SIZE. SLD CALIPER USED FOR HOLE ~I~E,. CORR~P~ .... TION ~N~ Ymll Film Comment ~: .gS~ USED FOR NEUTRON TOOL CONSTANT. Yell Film Com~mnt 4: Page COMMENT RECORDS LIS t. mpm ~,rittcn by: ANCHORAGE COMPUTING CENTER mm All curve and tool mnmmonics usmd arm thosm which most closmlp match ~m Gmmrhart curvm and :tool mnmmonic~, ~m GEARHART TO SCHLUMBERGER TOP BOTTOM MN_M SERV ICE UNIT MNEH ;~ERVICE UNIT DEPTH FEET DEPT FEET TEN DLLMoF LBS TEN DLLHSF LBS SP DLLMSF MV SP DLLMSF MY GF,' DLLMSF AP ! GR DLLMSF AP I _.RLI C LLM.~F IN CALI DLLMSF iN LLD ~ LLMSF OHMH LLD DLLMSF OHMM LL.S DLLMSF OHMH LLS DLLMSF OHMM MSFL. DLL~'ISF OHMM MSFL DLLMSF OHMM TEN ~ SLDCNS LBS TEN SLDCNS LBS GR ~ SLDCNS API GR SLDCNS API CAL. I I SLDCHS IN CALI SLDCNS IN RH08~ SLDCNS G/C3 RHO8 ~L[,CNS DRHOI SLDCNS G/C~ DEHO SLDCNS ~ ~'' FCNLi SLDCNS CPS FCNL SLDCNS CPS HC:HL1 SLDC:NS CPS NC:NL SLDCNS CPS LS[:,F' i SLDCNS CHAH LSDP 'SLDCHS CHAN C:UPEi ~LD ~H~ CPS CUPE ~LDC:NS CPS SSDPi SLDCHS CHAN SSDP SLD[:NS CHAN DEPTH DEPTH 12296,00 12680.0'0 12680,00 12680.00 2680 O0 2680 O0 2680 O0 2680 O0 2680 O0 2680 O0 2680 O0 2680 OO 2680 O0 2680 00 2680 O0 2680 O0 2680 00 2680 O0 3572 O0 3572 O0 :3572 00 3572 O0 3.572 O0 .3572 00 3572 O0 3572 O 0 3572 O0 3572 O0 3572. 00 ,3572 O0 3572 00 3572 O0 3572 0 0 3572 O0 3572 OO 3572, O0 Page NSLDi LPC T ~, LCCT~, SCCT i PEF? F,'AT ] DPH!~ hiPSSi SLI~r.:HS SLDCNS SLDCHS SLDCNS SLDOHS SLDr.:NS SLDCNS SLDCNS SLDCNS SLDCNS CPS CPS CPS CPS CPS 8?EL CPS PU SSPU QUAL FSLD NSLD LPCT LCCT SCCT PEF RAT DPHI NPSS SLDCNS SLDCNS SLDCNS SLDCNS SLDCNS SLDCNS SLDCNS SLDCNS SLDCNS SL. DCNS CPS CPS CPS CPS CPS 8?EL CPS PU SSPU 12680,00 t2680,00 12680,00 12680.00 t2680,00 12G80,00 t2680,00 12680,00 12680,00 12680,00 .3572.00 .3572,00 · ~572, O0 .3572 O0 .3572 O0 3572 O0 · 3572 O0 7,572 O0 .7,572 O0 .3572 O0 DATA TYPE DESCRIPTION 0 T,~rminator ,:'. r~c, mor.~ ~.ntri,z~.=~ ) FORIdAT TYPE SiZE oPECIFICATIONS (,].ODE 66 G~ FORMAT oPEc I F I I OHS DATUM SF'ECiFICATION BLOCKS MNEM SERVICE SER.VICE APl AP1 AP1 APl FILE tD OR[:,ER ~ UNiT LOG TYPE CLASS MOD ~ DEPT 2276 TEN DLLidSF 2276 SP DLLMSF' 2276 ~76 DLLMSF ~"~ CALl DLLMSF 227G L~D DLLNSF' ~76 L. LS DLL. HSF 227~ MSFL DLLMSF 22?6 TEN SLDCNS 2276 GR SLDCHS 22?6 CALl SLDCNS 2276 RHOB SLDCNS 2276 DRHO SLDCNS 2276 FCNL SLDCNS 227'6 NCNL SLDCNS 227~ LSDP 9LDCNS 2276 CUPE 9LDCNS 2276 ~SDP SLDCNS 2276 QUAL SLDCNS 2276 FSLD SLDCNS 22?6 NSLD SLDCNS 22?6 LPCT SLDCNS 2276 LCCT ~i...LUN~ 227G SCCT SLDCNS 2276 PEF SLDCNS 2276 RAT SLDCNS 227G DPHi SLDCNS 2276 NPSS SLDCNS 2276 FEET 0 0 LBS 94 MV 94 APl 94 IN 94 280 OHMM 94 220 OHMH 94 220 OHHH 94 2?O LBS 94 APl 94 iN 94 28-0 G?C~ 94 ~50 G?C3 94 CPS 94 CPS 94 3~4 CHAN 94 0 CPS 94 0 CHAN 94 0 94 0 CPS 94 0 CPS 94 :0 CPS 94 0 CPS 94 0 CPS 94 0 B/EL 94 0 :uP.. 94 420 PU 94 890 SSPU 94 890 0 0 0 0 0 0 I 0 0 i 0 0 2 0 0 i 0 0 0 9 :0 0 4 0 0 0 0 0 J 0 0 2 0 0 I 0 0 I 0 0 ~0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 :0 0 J 0 0 i 2 0 0 J', 0 0 PRC ~ SIZE LVL SMPL RC 4 0 '1 68 4 0 1 G8 4 0 I 68 4 0 i ~8 4 0 i 68 4 0 1 68 4 0 1 "~ 4 0 I 68 4 0 'i 68 4 0 I 68 4 0 i 68 4 0 i G8 4 0 I GO 4 0 1 68 4 0 i 68 4 0 I 68 4 0 i 68 4 0 i 68 4 0 1 68 4 0 1 68 4 0 I 68 4 0 i 68 4 0 1 68 4 0 i 68 4 0 I 68 4 0 1 68 4 0 I 68 4 0 I 68 PROCESS INDICATORS 000000 0'00000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 0~0000.0 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O0000O 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 =000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 ,00000'0 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 Page ¸DA TA RECORDS DEPT TEN SP GR CALl LLD LLS MSFL TEN GR CALl RHO8 DRHO FCNL NCNL LSDP CUPE SSDP QUAL FSLD NSLD LPCT LCCT SCCT PEF RAT DPHI NPSS Pagm 1.3572 '000 4274 '000 -999 250 "'-' · . , -¥.-¢~ 250 -999 '250 -999 250 -999 "-' ~50 -~' ' .... --~ .~. 250 4274,000 0,000 7,380 2,'"S ~ . .... ' ' e~ .... .~0~; 0 000 0 000 liO ,9~9 ill 480 1 0130 7~70 ~" ~ .... .. , . .4~,~ 23823. i :::7 ~ ~ TM 000 z~88.000 i 8~._ 0.000 3, i 8:0 -999. 250 -~, 0~9 -4255. ~0~ 13472, '000 6182. '000 79,3,00 6173,000 t20,300 8,440 4 , t 87 i lO. 920 .950 1 770 2 '"'~': '~ , , '~,-..:~ .- 3 ,,-,774 1 05. 400 8 . 760 45,709 56,494 I O. 000 2,096 ,062 9i .iO0 260.000 ii0,270 988,96~ 263 02,707 5583. 000 i i 040. 000 20603. 000 57. -093 i 3372, 'OOO 6024 ,'000 64,600 58, 'OOI.1 8,060 27,925 28. 642 26,363 6241,000 57,700 8,400 2.453 ,026 272.200 421 .lO0 1~0.440 1,335 Jtl.iSO 1.090 7906,792 i7701.086 14i5,000 2i94,000 i3207.000 I ,99'0 1 ,462 11.672 18, 160 i3272.000 6178,000 65,400 62~t,008 68,800 8.700 2,86i iii,290 .860 1,650 2,7i3 49,544 62,500 42461,922 47.099 8. 340 155,596 190. 1 08 13i 5. 225 -. 038 77,700 2i2,200 i i 0.8i 0 27~42,254 6978,000 2.3733. OOO '2i ~.38, OOO DATA RECORD DEPT TEN SP GR CALl LLD LLS MSFL TEN GR CALl RH08 DRHO FCNL NCNL LSDP CUPE SSDP QUAL FSLD NSLD LPCT LCCT SCCT PEF 'RAT DPHI NPSS P~ge 1i 13172,008 5822,000 93,100 5646.000 t25,608 8,350 1,95J 110,970 i.000 2,590 1.943 9,30t 88,0'00 2,492 12302,693 30,1'1t 8,3:30 ,081 20370,414 34,754 230,000 2218,000 29,512 413,30:0 35¢..3,000 61.944 ii0,5i0 i5495,000 13072,000 5703,000 100,200 562i,000 86,800 8,S60 ~.946 tit,140 t.060 !.900 1.778 t6.657 116,500 2,37i 12502,584 25.379 8,170 ,030 20183.652 38,904 282,200 2245,000 48,195 448.800 3599.000 23.823 110.350 15184.000 12972,000 5617.000 It2,600 68,t00 8.110 29,5t2 31.JJ7 24,434 584~.'000 86,500 8,360 2.556 ,028 200.000 352.200 t10.290 ,6i6 i10,950 1.070 4446,309 i54i7,0i4 616,000 i266,000 11421,000 2,280 i.761 5.4!0 24,234 !2872,000 5464.000 98,900 5,$60: 000 1 9. 400 8,600 1 ,960 1i0.900 i,080 I , 8i 0 i . 79'," 25. 957 18.700 2.2~8 12133,879 24.788 8,000 · 020 i9860,918 353,183 220.000 2133.000 328.85i 406,608 3354.000 t9.634 ii0.6.40 14826.000 DEPT TEN CUPE PEF T'Ef,I GR SSDP RAT SP CALl QUAL DPHi DA GR FSLD NPSS TA RECORDS CALl DRHO NSLD LLD FCNL LPCT LLS NCNL LCCT MSFL LSDP SCCT Page i2 12772,000 5407,'000 i,790 1,920 5573,000 ~i .400 ii0.960 10. ? 00 8,610 1,060 23.587 37,600 2,257 t2274,381 ~6,764 8,000 20558,906 i88,365 288.800 i944.000 i 74. 582 428.80.0 3446,000 12,823 I10,400 1560i,000 12688,000 -999.25:0 -999,250 -999,250 -999,25 0 -999,250 2,849 149.100 -999,250 -999,250 -999,250 5~.5,000 -999,250 -999,250 -999,250 -999,250 -999,250 2,i04 -999,250 -999,250 ,i20 -999,250 -999,250 ,798 -999,250 -999.250 File .name: ~G.SF01,001 Maximum length: 1:024 TRA I LER RECORD~ Version Next ¢iI~: EOF *:~* ~:.~::~m FI LE HEADER File name: ,0'02 Maximum length: 1024 HEADER RECORDS Servic~ name: Film t~pe: LO './er '_-: i on ~$: Page t4 MNEM CN WN FN bL, UN CTRY APIN LAT! LONG SECT TOWN RANG EKB EDF EGL PD LMF DMF RUN TIHE DATE LCC LUN FL LUL ENG i WITN DD DL TLi BL.I TLA8 BHT MRT MT MV i S RM RMF MFST M F ~ S RMC MCST M C: S S I.NFOR.MAT I ON RECORD C 0 N T E N T S · o T AN DA R D A L ASK A PR OD ij C T i 0 N C 0 ........ 3 ..... I i/t"i-~O ~' o.t.. I APl NLIM: 50-029-21848 , ENDICOTT DATE LOGQED: 09.-03-88 ...... NORTH SL. OPE ...................... A{ "' '-" 'K" _R;,~ ,i.,l: , , .... , .... , , , . , , ...... , . , . USA '2184~,006 0 Deg, 0 Mir, O Bag, 0 Min 0. 0 SInE W . , , == 150 0~000 14,500 MS, KB ~6,000 ~,." 9/88 SO 76 i i ........., , , , NORTH~LUkE"' 0-' ....... NORTH SLOPE ~RNET i~5SO, 000 i ~5~ , 000 i 2697, O00 ....................................... i S5~0. 000 ....................................... iO , ~00 ~'0-' LiGNOSULF CIRCULATED ..................................... 38, O00 2,1~0 ...................... 2,190 66, ~00 ..................... MEAS '2,37~ 72, ~00 MEAS 9,625 8,500 ........................... i · UN I T TYPE CATG olZE Pag.m 0 0 40 65 0 0 40 65 O 0 40 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 4 ~'~ 0 0 34 65 0 0 ~,4 6,5 0 0 2 65 O O 3 65 O 0 '~ FT 0 ~ 4 68 FT 0 ~ 4 68 FT 0 3 4 68 O S 2 65 0 S 2 65 0 ~ ~ o65 O '0 2 79 0 0 4 68 0 0 8 65 0 0 2 79 0 O i0 65 0 0 10 65 0 0 20 65 0 O 20 65 0 0 ~0 65 0 0 20 65 FT 0 S 4 68 FT 0 ~ 4 68 FT O S 4 68 FT O 3 4 68 HR 0 '2 4 68 HR 0 4 4 68 DEGF O 1 4 68 DEGF 0 1 4 68 0 2 20 65 0 2 20 '~ CP 0 2 4 68 OHMM 0 2 4 68 OHMM 0 2 4 68 DEGF 0 2 4 68 0 2 i2 65 OHMM 0 '2 4 68 DEGF 0 2 4 68 0 2 i2 65 0 S 4 68 0 S 4 68 i5 I. Jel I Well &}e i I t. del 1 Location Comment ~: Location Comment 2: Location Comment 3: Location Comment 4: SURF'AC:E: COMMENT RECORDS Page COMMENT RE~SORD~ (~il File Comment i: HEUTRON POROSITY CORRECTED FOR TEMPERATURE, PRESSURE AND ~l~ll Fil~ Comment 2~ HOLE SIZE. SLD CALIPER USED FOR HOLE SIZE CORRECTION AND ~iI File Comment S: .983 USED FOR NEUTRON TOOL CONSTANT. ~ell File Comment 4: P~ge COMMENT RECORDS LiS tape .writt~r, by: ANCHORAGE COHPUTING CENTER Ail curve and tool mnemonics used are those which most closelp match G~arhart curvm and tool mnmmonics. GEARHART TO SCHLUMBERGER TOP 80TTOM MNER SERVICE UNIT MNEM SERVICE UNIT DEPTH FEET DEPT FEET TEN~ DLLMSF LBS TEN DLLMSF LBS SP2 DLLMSF MV SP DLLMSF MV GR2 DLLMSF APl GR DLLHSF AP1 CALI2 DLLMSF IN CALl DLLMSF IN LLD2 DLLMSF OHMM LLD DLLMSF OHMM LLS2 DLLMSF OHMM LLS DLLMSF OHMM MSFL2 DLLMSF OHMM MSFL DLLMSF OHMM TENJ SLDCNS LBS TEN SLDCNS LBS CALiJ SLDCNS IN CALI SLDCNS IN RHOB3 SLDCNS G/CS RHOB SLDCNS G/CS DRHO3 SLDCNS G/CS DRHO SLDCNS G/CS NPSSS SLDCHS SSPU NPSS SLDCNS SSPU NCNLS SLDCNS CPS NCNL SLDCNS CPS LSDP3 SLDCNS CHAN LSDP SLDCHS CHAN CUPES SLDCNS CPS CUPE SLDCNS CPS SSDP3 SLDCNS CHAN SSDP SLDCNS CHAN QtJAi..S SLDCNS .... QUAL SLDCNS DEPTH 12296,00 12681,50 12681.50 12681 50 12681 50 12681 50 12681 50 i268i 50 12681 50 12681 50 12681 50 12681 50 1268i 50 12681 50 12681 50 12681,50 12681.50 12681,50 DE.PTH 1~572.00 13257.00 13257,00 I~257.00 13257.00 13257.00 1~257,00 13257,00 13257,00 13257,00 13257.00 13257,00 i3257,00 13257,00 13257,00 13257.00 13257.00 t~2~,.·. ~ o~ O0 Page II NSLD$ L P C: T L~ LCC T'~ SCCTS PEK3 FCNL3 RAT~ DPHi 3 GRS SLDCNS SLDCNS SLDCNS SLDCNS SLDCNS SLDCNS SLDCNS SLDCNS SLDCNS SLDCNS CPS CPS CPS CPS CPS B/EL CPS CPS PU APl FSLD NSLD LPCT LCCT SCCT PEF FCNL RAT DPHI GR SLDCNS SLDCNS SLDCNS SLDCNS SLDCNS SLDCNS SLDCNS SLDCNS SLDCNS CPS CPS CPS CPS CPS 8/EL CPS CPS PU APl '12681.58 1268t,50 12681,58 12681,50 12681.58 12681.50 12681,58 '12681,50 12681.50 13257.00 13257.00 i3257.00 1~257.00 i~257.00 13257.00 13257,00 13257.00 i~257,00 1~257.00 DATA FORMAT TYPE SiZE SPECIFICATIONS CODE G6 Pag~ :,.~:m:e EI'.!TRY BLOCK LEGEND m:~:~: T"/PE DESCRIPTION · 0 Tmr. mir~m'tor < no more mntrims ) DATA FORMAT SPEC I F I CAT IONS MNEM SERVICE SERVICE AP1 AP1 AP1 APl FILE iD ORDER ~ UNIT LOG TYPE CLASS MOD DEPT ~276 TEN DLLHSF 2276 SP DLL. MSF ~276 :GR DLLMSF 2276 C~Li DLL. HSF 2276 ,LLD DLLMSF 2276 LLS DLLHSF 2276 HSFL DLLHSF 2276 TEN SLOC,NS 2276 CALl SI. DCNS 2276 RHO8 SLDCNS 2276 DRHO SLDCNS 2276 NPSS SLDCNS 2276 NCNL SLDCNS 2276 LSDP SLDCNS 2276 CUPE SL. DCHS 2276 SSDP SL. DCNS 2276 QLJ ¢~t,. SLDCNS 2276 FSLD SLDCNS 2276 NSLD SL~CNS ~Z~ LPCT Si..DCNS 2276 LCCT SLDCNS 2276 SCCT SLDCNS 2276 PEF SLDCNS 2276 FCNL SLDCNS 2276 RAT SLDCHS 2276 DPHI SL~CNS 2276 GR SLDCNS 2276 FEET 0 0 LBS 94 635 MV 94 iO APl 94 318 tN 94 280 OHMH 94 220 OHMM 94 228 OHMM 94 270 LBS 94 IN 94 280 G/C3 94 350 G/C3 94 356 SSPU 94 898 CPS 94 CHAN 94 CPS 94 0 CHAN 94 O .... 94 0 CPS 94 0 CPS 94 CPS 94 0 CPS 94 O CPS 94 0 B/EL 94 0 CPS 94 CPS 94 420 PU 94 890 AP1 94 0 0 0 0 0 i i :0 i i O i 2 0 i JO 0 9 0 i 4 0 i 2 0 i i 0 i i O 3 0 i ~ 0 · 0 0 :0 i 0 0 0 0 0 0 0 -0 0 0 0 0 I 0 :0 I 0 :0 i 31 O I 1 ,0 1 12 O i i .O i PRC ¢ SIZE LYL SMPL RC 4 0 i 68 4 0 I 68 4 0 i 68 4 0 I 68 4 0 1 68 4 O 1 68 4 O i 68 4 O t 68 4 0 i 68 4 0 I 68 4 0 1 68 4 0 I 68 4 0 i 68 4 0 i 68 4 O i 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 I 68 4 0 1 68 4 0 1 68 4 0 I 68 4 0 1 68 4 0 1 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 I 68 PROCESS INDICATORS 000000 000000 O000OO 000000 000000 000000 000000 0:00000 000000 000000 000000 000000 000000 000000 OOOO00 000000 000000 OOOO00 O000OO 000.000 OOOO00 O000OO 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 OOOO00 OOOOOO 000000 000000 O00000 000000 OOO000 OOOOOO O00000 000000 000000 000000 000000 O0000O 000000 000000 000000 000000 000000 OOOOOO OOOOOO 000000 000'000 000000 000000 000000 000000 000000 O00OOO 000000 000000 000000 O00OO0 O000OO 000000 OOOO00 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DATA RECoRDs, DEPT TEN SP GR CALl LLD LLS MSFL 'TEN CALl RHO8 DRHO NPSS NCNL LSDP CUPE SSDP QUAL FSLD NSLD LPCT LCCT SCCT PEF FCNL RAT DPHI GR Page 2i 13i57,500 5673,000 80,000 20,700 7.990 440.555 33!.i31 23,823 .-999.250 -999,250 -999,250 -999,250 -999,250 --999.250 -999.250 -999.250 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,258 -999,250 -999,258 -999,250 -999,250 1J057,5:00 573J,080 78.600 21,'100 7,990 501,187 4i2,097 18,535 · -999,25'0 -99.9,250 -999,250 -999,258 -999,250 -999,250 -999,258 -999,250 -999.250 -999,250 -999,250 -999.,250 -999,250 -999,250 -999.258 -999,250 --999,250 -999,250 -999,250 -999,250 12957,508 575,.3,088 122,700 84,980 8,iSO 34.':'994 3i ,046 5924, OOO 8,070 2,5i i ,002 2S. 527 382. 200 11 O, 05.9 i i 0,880 i ,090 5508.074 i7458,195 981 ,000 i 630. 000 12922,000 202,200 1 ,750 8,t46 99,700 ._-46,98.3 2,.320 12857,500 5486,'000 !05.900 24.300 7,970 237,137 200.447 5416,000 8,490 2,200 ,005 26.i04 389.100 ilO,4iO ii0,920 1,070 i4157.947 20558.906 2463,000 4096,000 15675,008 2t8.800 1,851 27,052 30,000 18. t97 2.202 i .750 DEPT TEN SSDP FCNL TEN CALl QUAL RAT SP RHOB FSLD DPHi DA GR DRHO NSLD GR TA RECORDS CALl NPSS LPCT LLD NCNL LCCT LLS LSDP SCCT MSFL CUPE PEF Page 2~ 12757.500 5870,000 iiO,800 2i5,500 5745,000 8,540 1.090 1.540 65.000 2,409 849i,795 14,347 57.600 ,020 18238,922 66.i00 8.020 i9.242 t4S7,000 t53.815 23i1,000 i48,252 110,320 1~6i8,000 I, :320 I ,850 FiLE TRAILER Film name: &GSFO~.002 Maximum length: 1824 TRAILER RECORDS S~r. vi ~¢ name: ~r~ion Film type: LO N~:xt f'i Pag~ EOF *** Fi lm nmmm: Maximum i~ngth: ~1024 HEADER RECORDS Film 'typ~: LO Version Datm: Prmvious ?Jim: Page 2'-.1 MNEM CN WN COUN STAT CTRY APiN LATi LONG SECT TOWN RANG EK8 EDF EGL LMF DMF RUN TIME DATE LCC SON LUN FL LUL. ENGi WITN DL TLi BLI TCS TLA8 BHT MRT MT MSS M¥iS RM MFST MFSS RMC HCST MCSS CS 8S I NFORMAT I ON RECORD" CONTENTS STANDARD ALASKA 3-1i?M-3'g SOl ENDICOTT DATE LOGGED NORTH SLOPE .... .... ALASKA .............. USA .............. 2184~':000 ' 0 D~g 0 Min, 0 D~g 0 Min, 55,~50 0,'0.00 ~4,500 MS . , KB , , KB , 22 . 39 . , NO , . NO , , PR , , ZA , , lO , , 20 , , i9 , , 19 LI CI ~8 2, PRODUCTION CO ........................... APl NUM: 50-029-21848 ...... 09-03-88 ............ 6.000 . ? 9/88. 2276, , . RTH SLOPE ~TH SLOPE oL.E'~ , , , 53;0, 000,, 533, O(,O·, ~,~7,008, , .:,..~0, OOO, . . ~00 ...... , L'; 00 ...... Uu 0 ..... 21000 ......... GNOSULF ....... RCULATED .................................. , 0'00, , ,, ,,~, ,, , , , , , , , , , , ~ , , ~ , , , , , , ,, ,~,~ ,, , , , ~,, ~ , 120 ................................................. .,, 2,i90 ................................................... 66, OOO MEAS ................................................... 2.3,70 ................................................... -~1'~.,'-1 0011 MEAS 9,625 ................................................... 8,500 ................................................... UNIT TYPE CATG CODE 0 0 40 0 0 40 65 0 0 40 6,5 0 0 20 0 0 20 65 0 0 20 65 0 0 4 GE: 0 0 34 65 0 0 3'4 65 O 0 2 65 O 0 S 65 0 0 3 6,5 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 0 3 2 65 O S o 65 0 3 2 65 0 0 '2 79 0 0 ,4 68 0 0 8 65 0 0 2 79 0 0 i0 65 0 0 10 65 0 0 20 65 0 O 20 65 0 0 2 0 6..; 0 O 20 65 FT 0 .~ ,4 68 FT 0 3 4 68 FT 0 ..'3_', 4 68 FT O 3 4 6~'" HR 0 :' -~ 4 68 HR 0 4 4 68 DEGF 0 i 4 bo"'-' DEGF 0 i 4 68 0 '2 '20 65 0 2 20 65 CP 0 2 4 68 OHMM 0 2 4 68 OHMM 0 2 4 68 DEGF O 2 4 68 0 2 i2 65 0 H M M 0 2 4 6 8 DEGF 0 2. 4 68 0 2 i2 65 O 3 4 68 0 3 4 68 Page Wel 1 Wei 1 Wml 1 Location Comment l: Location Comment 2: Lo.cation Comment 3: L. ocation Co~mn~ 4~ SURFACE: COMMENT 2529' FNL & 828" FEL RECORDS 2~ COMMENT RECORDS Well Film Comment i: NEUTRON POROSITY CORRECTED FOR TEMPERATURE, PRESSURE AND I.~.I.~.,ll Film Co~ml.r~t 2: HOLE SIZE, SLD CALIPER USED FOR HOLE SIZE CORRECTION AND &lmll Film Com~.?.n+.. :-~: ,98~ USeD FOR NEUTRON TOOl. CONSTANT, &imll Film Co~mnt 4: COMMENT RECORD ,*m LIS tape written by: mN..HORAt;E COMPUTING CENTER mm Ali curve and tool mnmmonic~ u~md are tho~m which most closel~ ~atch ** Gear. hart curve and tool mnemonics. GEARHART TO SCHLUMBERGER TOP 80TTOM MNEM SERVICE UNIT MNEH SERVICE UNIT DEPTH DEPTH DEPTH FEET DEPT FEET 12296.00 t~== .... TEN4 SLDCNS LBS TEN SLDCNS LBS 12296.50 1273'0.00 ~R4 SLDCNS AP1 GR ~LDCN,~ APl 12296 .~0 127~0 .OO Pagm 28 DATA ENTRY F 0 R M A T TYPE SIZE SPEC CODE 0 'i 66 IFICATIONS 29 ~.mm ENTRY BLOCK LEGEND TYPE DESCRIPTION O Te.r. minator ( no mor. m mntrims ) D A T A F 0 R M A T MNEM SERVi'CE SERVICE i D ORDER ~ API API API API FILE UNIT LOG TYPE DEPT TEH 2276 SLDCNS 227,G S L I.'~ ~... t..i'.5 22 FEE T :0 ~3 0 ~0 ,0 LBS 94 6:3,5 0 0 2 AP i 94 3'1 0 1 0 2 SPECIFICATIONS PRC ~ SIZE LVL SMPL RC 4 0 i 68 4 0 i 68 4 0 i 68 PROCESS INDi..RTuRo 000000 0'00000 000000 000000 000000 000000 000000 O0000O 000000 Pag~ 3O D E P T T E N .G R DATA RECORDS Page: ,~.~z,,_ 0 OOO 2580 , 'OOO 5465,000 1t2.400 ~.0 '000 ~,~o7.000 500 ~':']~0~..,. ,000 ~250~ ,000 li6,200 OEP}" TEN GR DATA RECORD'-~ Page ~2 Maximum t~ngth ~ ~!4 TRAILER RECORD~ Fit~ t~pm: LO Vep$ion ~: N~xt ~i Date: Pag~ EOF ~,m TAPE TRAILER S~_rvic¢ nar, m: Next tape: Date: 88?09/0? Commmntz: TRAILER Origin: RECORDS Tape nmm¢: F'agm Cont. inuet, ion ~: .34 REEL TRAILER name: &GSFOi N~sxt reel 88/09/0? Comm~nt~: Origin: Rmcl namm: Continuation ~: Oi PROI]UCTISN C']. IS TAP5 V~RIFiC~.T ~'oN LTSYINS ~ -'.~-':~ ~'- T SERVICE N~ME : ES!T D ~ T iF. " ORIGIN : $L'~C TAPE N~qE : 7?09? CONT~NU~TIOH PREVIOUS 'TAOE FILE NAME : · ~,.J 2 ,I, SERViC=_ '~ =LT, C V E R S I 0 N OAT~ : ~9101/2~ MAX qEC SIZE : 1096 FILE TY ~= LAST FIL~ C E :,~ T E R ZS-JAN-!939 12:58 EHP, ICOTT, B-!l/M,-30 SD'l, ~PI. ~ 50-0 29-21848 E~OiCOTT, ~-'tl/M-30 SO1, ~91 ~50--ozg.-g1848 Dm 3DUC. ? I ~N... C g. LJC =Tz:~ : 32~' = S:CTI-~':~ ~, ~'rWNS~IP:.., '~I'~ ,. ._ 28-jAN-:989 12'55 O =: 5a.! GL: 14.5 C N F 13 39 ~. · C ~,S IN5 1: CaSZNG TU~ZNG 2" 519" ~7~ D D?~LL~ D-P~H O: 0 TO 12'701 FIB" ;~ nRILL:~ DEPTH D= ~2695 TO ~2q5~ TYP;: ~LUIn IN ~'!gL=: P~ODUrmE,' "'LUIDS Z'~TC C~3 !152 TNC P 9i T'NG P 90 1153 INT~ [;,LL nF gB-SGP-R° .'../ WELL E~r~3 = ..... F'DR'TSD NIPPLE ~T 12;394 !Nq BL~ST JOZNTS AT !2~g6 - !294~;. S~=CO~D o~ICKER ~T 12951 ~'ITH LIS TAPE 2~-,~a.N-1999 12:58 TABLE- TYPE : C~NS T ,J N Z CN FN WN N ST~T COUN FL SECT T OWN RAN~' LaTZ L g N :5 k NGI S 3 N APIN NCBR'IOE 73097 50-02'9-21848 ~L~SK~ SD Z PRODUCTION CO 8?8' CO~1P&NY 'FIELD N~ME WELL NAME N~,TZON ST;~T~ np PROVINC ,COUNTY FIELD LOC&T[ON SECT !ON TOWNSHIP R~NGE L~T!TUDF L 0 N G Z T U O = aNGIHEER' S :SERVICE ORDER AFl :SER[~.L NUM3E~ TA~L~ DEPT SIGF T-_-N S S RN,r. RN5 R NE R N9 RNIO RN11 RNIZ RNIJ TY 0 ': F I SI TE SI NS w w '4 P~GE" · ~i RN15 RAw ~:~i.~F ]5TH R~NI~ R~N NE~° I~=H R~FI RAW ~.fiR 'IST G~TE RFZ RAW FAR, ~N'~:_. .~ GATE R~F7 R~W F~R 7T~ ,, RF9 ~flW F~'R 3'TH G~TE R~iO R~W ~A'R 10TH R=ll RAW F~R ll~H RFI2 ~R,~W P~,R 12TH G:T R~14 RAW Ffl~ 14'TH G~TE R~15 R~W FAq 15TN G~'T~ RFi5 RAW ~$R !6TN GAT: STDT S'TflTUS g~ TOT : Hz TD~ on2o~ITY ISHU TOT SHUNT CURR~NT S=FD~ :SI~A~.~. =nP~q&Tln~.]~ , . ,.., - 'r"~R.. 9FT~CTDo- , ~., (~'~O~P) ~. SFND SZSNA 'FD~,1T~ON - NEAR DETSC~O:~ (TOT`m) 5BHF S!G~"A 9~5HOL~- F~R DET~CT~R SBHN SZSY:~ 3C:~'EHgLS - FTDT =AR "TC, T~ COUNT NTOT 'FlEeR T'DT~,~ COUNT ABFD ~NPLIIU~S ~JP~E'HgLF--:~fiq 9ETFCTOP (TCTP) AFND AM'PLIT'..JD~ =CR~'~TID~I- qE~R D~TECTDR (TOTP) ABNO A~mLZTUD~ ~OREHOL~ -- H~.~R O~T~CTOg (TDTm) SIGC SiSF' CDR~CT SI~H BCRENGLF SiGqA (CGRRECTED) -- TDTP T~AT TOT ~flC. K ~,~'CKGRjUNO, NE~ GATES F~C ~Ae ~iCKGRgUND TC~N f O' ~. L~. C gtJ N T S- ~ ~,t ~ L v. , ~F~_ ~. - x~CAR,. ~,~-T =r TO R~ { TOT P) TrAc TOT~' CrU~T~ ~N~LYiF~' . . ,"~TnP (tDTp~ TCND TnT~L cDU~'TS ~,,z A o TCFU TgT~L COUNTS - ~R CETECTOR (TOT~) TSCN S~LSCTEO G.~T'~S CDU~ R~Tc. - ~,!~R OSTECT~R (TOTm) TSC= SEL~TCD S~S C~]ttNT R~T - ~ ~ETFCTOR (TCTP) - 'T:' - Nr~ Dz~C~O~ (TDTP) INN~ IN=~ ~ST~L COIINTTNG R~ ~ - iN~O INEL ~c~tc ,-n, , cAP O~CrT~P (TDTO) , .., ~ = ~ .~,Llt',:TTHG m..,.~T = - , _ ~ ... , TTEC TDT-p T~L~'~TRv ~RD~ ~O~JX~T_ NV ~S~C S~TC STATUS CF .~TC CrL~ CrL~ ~"~L[TUO~. ~ .. ! ............................. IS TAPE V~.R'~FZC,~[O~,~ L]STZNG CHLUPBEPGER ~L~SKA C~PUTI~,}:S CE~,~ER 2~-J,aN-'!93.9 12:f8 ~:,,-"' O A T A V~LUE O 1 =T 3 ! ~"' S'r.-T T'YPF - CHAt'.~ "'-'- N~ SE;~V UNIT SERV:C7 IO ':IRS,r_'e, ':~. LOG TYP SZG~ HL~ CU T~NS PSi L'~: OS O0 SZG~ ~Srl CU O0 O0 RN1 PS1 CoS O0 O0 RNZ PSt CPS 99 O0 RN3 PS1 C~S O0 OO RN4 PS! C°S O0 90 ~N5 ~S1 C°S OO O0 RN6 PSt CPS CS O0 R N 7 P S I C o S 0 O 3 0 RNB oSl CPS 09 gO RN9 'PS! C~S OS RNI9 PSi CPS Og O0 RNll oS! C°S OO RN1~ oS1 r~S~ 00. OC RNI3 PSi CoS OO RN14 PS1 C°S 09 gO ~N15 PSI C°S RFi PSI CPS O0 O0 R=Z ~S! C°S R=3 PS1 CoS OO OO Re4 PS' CPS : ~°I ~P'I =ILE .NUN',3 NUMB E CLASS MDg NU~qB S~Mo :_LEM 0 Rf~PR CrjD~ 0 1 ! 1 ~ 68 PROCE:SS CHEX) O000OOOO00 O900OO00OO OOOOOCOOOO OOOO00OO00 0090009000 OO90OO~]O00 O00000OO00 OO30OOOOO0 OOOO00OO00 OOgOOgOOOO 0000009990 0000003000 OOOOOOgOOO 0090009000 O000OO30OO OOOggoooog 0090909000 OOOOOCOOOO O000OOOOOC 0000000090 ~OO90OnOOO 90OOOO00OO .IS TAPE] VER~FIC~TZ~N LISTING ;CHLUN~,EqGER ALfiSK ~ COMPUTING CFNT:R NAME SERV UNIT SE2VTCE ~PI ~P~ RF5 PS1 CPS R ~F 6 g S ~ C o S 0 R~7 ~S1 ~ ~S R F~ PS t C oS C 0 gO O 0 O R~9 PS! CoS O0 COO OO R~lO PS1 C~S RFII PS1 CgS O0 OgO OO RS12 PS1 CPS O0 O,~g O RFI3 PSI CPS R~14 PS1 CPS R~15 OSl Cm~ STDT mS.1 O0 gOO O0 T P H I e S 1 P U 00 O ISHU PSI V SFFg oS1 CU O0 000 SFN'D PSI CU SBH~ PS! Cd Og gOO go SBHN ~PSI CU gO goo O F T g T P S 1 C g S N T g T P S 1 C P S A~F2 PS I C°S A'~FD ~S! C'oS O0 000 O0 A=ND oSt C']S OO 900 ~'~ND PS1 COS OO gOO SIGC PSI CU O0 90~ SIBH PS1 CU gO OOO MN~OF oS1 03 OOO T R~T PSI 09 SOSI PS1 CU B.~CK PS! C~S ~$C PS! C~S O0 gOO OO T Cfi N ~ S I TC~~ oS 1 ICND ~SI C°S TCFD PSi CmS gO TSCN ~S1 C ~S 0~) JO0 OO T S C: P S i C m S · ~ . ,,. ~ .. T T E C P S i C: HV ~S ~ V S ~ T C ~ S l CCL ~'SI CO 003 0:3 FILE NtJM? NUMB SIZE REPR PRGCE'SS NUM~ SfiN~ ELEM CODE (~EX) 6 8 68 68 68 6, .3 6~ 6,8 68 68 68 6 3 68 68 68 68 68 6 ~] 6 8 68 6 8 6 ~ 69 6 8 68 63 6:8 68 6 B 68 6 9 6 ~ 6 3 63 69 OCO000ogo0 OO900OOOOO O00OOO0000 0000000090 OOOO00OO00 O00000OO00 OO90OOOOOO O000000000 OOgO00OOOO O0000000OO O000OOOOOO OOOOOOOOO0 O0000000OO O00000OO00 O000000000 OOOO00OO00 O000OO0000 0090000000 OOOO00OO00 OOOO00OOOO OOOOOOOOOO O00000OOO0 0090009000 OOOOOO0000 OOOOOOO000 OOOOOO9000 O0000000OO OOOOOOOO00 O00000OOOO 3000OO90OO 90900000:0~ OOOOOO3000 O00O909OOO O0000OOOOO OOOOgO3000 O0003OOOgO O000OO<)OOO 0000903000 ~ ~00~ OOqOSO~ O000gOOO90 OOOgO000OO OOgOgO90OO SOOOOO90OO OOOC30OOOO ~N!.~S~I -9~ ..~_~0 c,,,.N2.PSI RNS.PSI -99g.250 q ¢~FI. 751 -999.2 50 RF ~. PS 1 ,-S 9 ?, 2 50 RF 10, PS 1 RF1~ PSi -9:~9 250 oF'Z4 PS ~ , , - ....... p ?41. P S ! N'TDT.PS~ -9~9,7=0., ~BNO.~St -999.~50 S!GC.PS! T:~r PSI -e99 250 ' ' ' -' - TC~' PS~ -~9° 250 'T'SCN'°S~ c~9~ 2=0 TS~= PSI TT=C.PS1 -99q.250 HV GR.~SI -999.2 ~0 O EFT. 134 90 · 000 Si :3M. HL~ RNI.9S! 959. 535 R!'.12..PS1 RN'5. PS I 12 '~4.0 70 e"~6. PSI RNg.°S1 1554 .503 qNIO.PS1 RNIJ.OS! 1644.6~! ~N!4.PSI RFI.PS'! 32n.833 RF5.~SI 406. 250 Pc6.PS1 RPg. Ps! 599. ~ ;~3 PFIO. PS1 R~13.PSI 743.750 q9!a. PSI S'TD r. PSI 66. 000 TPHI. SFND. PSt 24. 104 SFH=.pS1 NTDT.PS1 15.7;~]0 ABN3. PS !. 4 =8. ! 52 SI GC. F S1 TR~~. PS ! !. Z 97 SDS'I,. P TC~N. PS I 2'~0 ~7.1 t 3 rC&~. PS 1 TSCN PSI 2975-4~ ~S T TEC. PS I O. O00 HV GR ~S~ !~.I02 O EP'r. ] 330o. 000 S iSM. HL R,NI.~Si 9no 3'~'~ c,~,~ oS1 RN 5. PS'I 1. 050. C 90 FN6 .P ON9 ~Si i~'.090 ,, ~ , , RNI~ PS1 2TM 557 ~'l~ FS' RFI. oS ! 306.2 ~0 R=2. P SI ~FS. oS t ~ ~ n ~ RF 9.P51 4~.7,590 R=13-~31 9~0 P~ ~=~4 FS~ NTCT.~St, .~n,. · 0'..'_ · AqND. :>Si 4~".''~ ~AT.PS~ . . 1 .~79 S~S!.PS! TC~q. PS i cg: ~ ! · I ,~ ! TC ~ ~. P SI TSC~.PSi 51 3?. x31 ~SC~.F .28-J~N-ig~9 12'55 33. '~63 TENS. PS1 -'~9 250 P~"'~ PSI -999.250 RN7. P SI, -999. 250 ~NIi. PSi -999.253 RNIS.PSI -99g. Z=O R:~7. P SI -9q9-250 PF!5.PS! -999. ZSO 5B~N.P51, -999. ZSO -999.2~0 5I~P.P51 -999. ~59 '3ACK.PS1 -999.Z~3 TCND.PSI -99~.250 iNND.PSI -999.259 5ATC.~S1 -999. 250 - 9c. 9. Z., = 0 -999. ? 50 - 9 ~ 9.2 ~ n -99 9.2F 0 -999.250 -g99.ZSO -999.250 -99 9. 250 -999.250 -999. 250 -999.250 · -99 9.250 -999.250 24.09~+ 'r~Ns. PS1 1989.000 150.933 RN3, P SI 154 4. 471 !03~.654 RNT.PS1 723.I57 1 37 2. !., 95 RN 1 I. P S 1 179 O. 865 1329.112 ~NIS.PS1 85'7.372 ~ ~. 171 R ~3. P S 1 429.167 359. 333 RFT.PS1 266.667 516.667 RF!I.PS1 725.000 q~3 3~ R~~ ~.PS'I ..... 3c 8 3~3 22.~7~ ~SHU.PSI 92. 692 S8~N.PSI O6.3'76 92.97~ ~B=D.~S1 131.261 0.191 SISH.PS1 147.721 0.399 ~CK.PS1 159.162 151~2.'~07 TCNO.PS1 16~75.9~4 I=53.$96 INND.PSI 2?53.752 !35. ~50 5~C.PS! 1.000 19.14I TENS.PSI 1720.000 945 RN3. PS] 1270. 933 7FO RNT.PSi 754.167 l'~2Z.~? ~NII.PS1 1~3.333 ' A7 qNl= P~I ~ 060 41~ '~0 ~ ~, PS~ ~ 75. 000 167 ~=7.PS] Z~O.41 7 ~17 ~FI~ .PSI ~33.333 q7~.917 RF'!5.mSI 547.917 2~.09~ IS~U.PS! 16.~22 $55 5I¢',N.PSl I&9.642 Sv~ r~C' PS~ =~ 38 33Z S IGM. PS I RN4.PS1 :~, N 8. P S 1 R N1 Z. RNtS.PS1 PF4.PS1 RF3.DS1 R,mlZ,PSI R:=16,oSl SFFD.oS1 FTCT.PS1 AFND.PS1 MMO=.PS] FB~C.oSt TCFg.mS1 INr-O.PSl CCL.PS1 o~GE · .i '-999.250 -999.250 -9'99.2rm -999.250 -999.250 -999.250 -999.250 -999.250 -999. ?-50 -'999.250 -999.250 -999.250 --9'99 . -99'9.2,50 -999.2 '5 O -999.250 -999.250 22.744 1612.580 1021.635 ! 70 B. 734 675.080 472.917 379.167 72'7.093 191. 667 23.302 7.9,55 373.106 3B .339 60'7!. 755 49~.013 0.000 !5.8'78 1341. 657 985.417 1952.9~3 554.167 379.1~_7 377.083 ~02.0B3 Z"O 8~ I~, .cO& 9.607 393.700 ~..¢ $ 70~'3,9~9 500.210 TT EC. ~S.t O. 0 O0 ~V,, P S 1 D~_PT. 13090. OOO SIGM.HLA RNI.OS I ~0. OqO PN2. ~'S1 ~NS. PS I l:~gE. ~ 3~ RN6. PS! --', .... ~ !0 PSI RNI 3. oS! 3~ ~7. $ 90 R~! ~. PSi RF 5. PS 1 520, .~ 33 E~ =6 · ~ SI RFg. PS! ~] 2. F'~ ~FI O. PS1 R~i3. PS I I ~ 94. I ~'7 :~' F 14. r SI STCT.~SI E~.O0O TP~i.oS1 S=NO ~Si . =,...07~ NTDT. 0SI 4~, 57~ A~ =C~. PS! ~BND.PSi 5=9. =20 Si:SC.FSI I q~T- PS1 ! .67~ SDSi .PSI 2~-JAN-1989 12'58 ,~.~, ~ ~ ~ 19.844. T=NS~. .FSI 167,5. .OOO I17.206 RN3.PSI t!~1.667 1095. ~33 RN7. P S 1 ~2'?. 083 1397.917 R~$.! 1, PSl 190~,167 ! ?gg..~a3 RNIS.PS1 1225.000 23.22'0 RF3.PS! 287.500 '~41,667 R=7.PS1 277.083 4~3. B33 RF!!.PS! 668.750 T20. ~33 RF15.PSI 443.750 40.686 ISHU,PS1 73. I 2.6 SBHN. P SI 85.9 gO a~ 4.21 &B=D.~S! 92.769 0. I1 B S I 5H. P S 1 13 9. 197 O. 2~6 ~CK..FS! 119.995 17917.727 TCND.PSI 17549.504 1 ~73.999 ZNNg..PSI 2637.923 2 ~ 5. 750 S ~'TC, PS1 !. O00 !2,688 TENS.PSI I 700.000 '176.914 RN3.PSI 14=2,, .083 1659. ? 33 RNT. PS 1 1927. 083 206B,7~0 ~N.iI,PS1 2739,583 2312,500 RN15.PS1 1460,417 ~9,010 P~?,PSI. 441,667 554.167 R~'7. PSI &O ~. 33B 725.900 RFll.PSI 1004.!67 !9~7.500 RFtS.PS! 839.583 25.~932 ISHU.PS1 22.563 59.7B3 S~HN.PSI !07.'7!3 AB=D.PS1 150.553 O. 59! SI'BM.mS1 95.295 0.~14 :~ACK.PSI 158.284 24625.~36 TCN~.PSI 24835.12,5 2557.169 INND.oS1 3240.7~P 17.625 TENS.PS! 135. 450 RN3. PSl 2175.417 RNT.PS1 243].]~3 eNll. PSI 2 6~D. ,q..~3 R~,I15.PSI lO. ~69 RF~. PSI 64 7.917 q :7. P S1 q29,167 RFII.PS1 ?q~, 7~0 RF15,PS! ~4.~P9 ZSqU.PS1 ~a,976 S~HN.PS1 3. 517 SIBH.PSI O. ~ 75 ~ aCK. P S ! 1720.000 ! 22 9. '3 ~. 3 14.:2.083 3589.583 !377.500 350.~17 a52.9~3 1189.583 ~33 3~. 7~ !62.697 161.2C3 CCL. PSt SIGM.PSI ~N4.oS1 RN1Z.PS1 RN15.oS! PF8.oS! RFI£.PSI PF15.PS1 S=FP.~SI =TDT.?S1 PAGE: 0,000 20,04,1. 1247.917 2122.917 600.000 339.583 354.167 716,6.67 197.9t. 7 7.758 ~ t 9.745 ! .258 22.656 5576.348 416. 577 O.OOO 17.715 1879.157 1029.167 2687.500 868,750 562.500 385,4!7 lOZ~.OOO 456.250 1t8.229 10.256 477,495 1.2~8 69.718 ~414.975 5!0.55~ O.OOO !8.1q2 1735,417 3777,083 787,500 462.500 402,C33 1312.500 222.917 21.~13 !5.~9! 64~.550 1.144 ~7.9~7 TCAN. PS 1 7 T048.0 63 TC ~F. P SI TTEC. PS 1 O. 000 HV. P SI GR. P:S 1 ST. ~ ?I DEPT. t 2900. O O0 SI G~ ,HL~ RNi. DS1 920.~33 RN5. DS I 1 ~'i 8. ? 50 ?N6. ~Si RN 9. PS 1 1877.917 RN I O. P S ! RN13. PS 1 3697.9'1.7 ~N14.. PS1 RF 1. PS ! 327.0 8~ RFZ. P SI PP: PS1 ~q! ZEn RF6 P~I RF'9. PS1 5 70. ~: 33 '~F ~0. P S1 RF13, PS 1 1.452,0 F~ B STDT. PS1 66.0 PO TPHI. PS1 SFND.PSt !0~I~1, NTDT. PSI 2~. 895 ABND..PS! a 23.017 SiGC. PS! IR A T, PS 1 1. ~ 31 S'[; SI. p S1 TCAN.PS1 107673.750 TCAF,DS1 TSCN.PS1 ~....~ 03..~, 3~ 'SCF~ .PS! l T'EC. PS 1 0 · O O0 HV .PSI GR. oS 1 ! ~. Z 66 DEPT. t 2800.0 O0 SI'SM. HLB RN'I.PS! g~3.333 RN2,.PSi RNE.PS! !'72:5.000 ~H6.PS1, RNg. PS! 20 ~9. F :53 ~NIO. PSI RNIB.PS1 476a.583 RN!4. ~F 5. ~S i 6 g4.9 6~ R =6.P S1 R~13.PS1 2197. ~16 S'TDT, PS 1 ~6, O O O TPHT SFND, PSI 10,200 S~SF,mS1 NTD~,OS1 ~5,~ ~2 ~m:D ~S1 A'BND,PS1 521, 036 SISC,°S~ qAT, ~51 1 · ~ q! S~ S l. P'S1 TC~N,PS! 1~2~.44. 344 rC&F,PSI TSCN, PS i I S6 ~7. '~2~ TSC~, oS1 TTEC.~S! C.O00 HV.PS1 Ge. PS1 DEPT· ! !700. DOC SI S~.HLa RN1. ~S t 950.4!7 P~J2 .PS! eNS. PS I 16 ~.~! 7 P~:C. PS! RNg.os ! 2112. ~ !7 RN13. PS1 36 !6.6S7 ~.~ I ¢. PSI RF1.PS1 ~ ~7. 917 R~g.PSI RF:.PSI 57~.~17 P=6.PS! PF9. PS i 7g?. ~ = O q = 10. PS 1 R:i~.°SI !~!0.417 e:1i.oS1 rOT.PS1 66.OqO TP~T.PS1 =NC. PS t i7.9 2~ S? NTDT.DS1 ~3.668 ~F=O.PSI 2~-.JAN-1989 IZ: 58 F.IBO T~MS.DS1 1720.009 15 ?. 011 RN3. P SI t 14 3.'750 1672.917 RNT.PS1 1325.000 !:~BT.qO0 RNil. PSI 2700.000 3877.083 RN!S.PS1 3383.3B3 36.~65 R=B,PS1 295.833 ~81.250 RF7.PS! 464.583 502. O 83 RF 11. P S 1 ~ 6 ~. 750 133T. riO0 RFtE.PS1 1637.500 25,414 ISHU.PS1 23.435 47.B19 SSHN.PS1 57.657 101.459 ~=O.Pl51 99.308 0.522 SIBH.PS1 72.560 O, t61 :BACK.~S1 174.516 ~7~B2.359 TCND.PS! 28624.30! 4:~9~.~F4 INNO,PSI 236.625 S~TC,PS1 l. O00 1~.336 TENS.PS! 1710.000 203. t. 75 RN 3. PS 1 1243.75 O 2922.:'~!7 RN7.PSi 1635.417 2!60.417 RNt!.DS1 '3193.7~0 5052.083 RN1S.PS1 4612.500 42. 917 R~. PS1 460. 737 777. 244 RFT. P S1 70 1.122 ~!~.46~ ~:!I.PS1 IB78.205 254'~.077 RFI~.PS1 248B.974 ! ¢. 5 ! 5 !S~U. P S ! Z 2. ~53 =g 3gl S~,HN PS! :52 ~,3 !71.17 S :AB =D. P SI 1 B A. 990 0.3~4 SZ~H.PS1 59.917 0.11~ ~ACK.PS1 Z01.399 3598~. ~2:3 TCNC.PSI 38~60.6~8 873~.V8'~ INND.PS] 3~33.~1~ 236.52S SATC.PS1 1.000 23.35~ TENS.PSi 17!9.00~ !95.~35 RN3.PSi 1177.083 19 ~ 5. 417 R:~7. PS 1 1 ~04. 167 2!27.0~3 ~Nii. PS1 30g3.750 RMIS.~S1 Z15:5.3=3 3q.383 D~3.PSI 739.583 641.667 Rc7.PSI 4~3.337 B62.500 2FII.PS1 !2P5.417 !416.667 RFiS.PSI ?~ lO: ~S~U PS 37.5~9 SSHN.PS] 47.841 131.756 aB=D.PS1 155. 267 T C F O. P S ! I N F O. D S ! ~ ,~ L. P S ! !0506.Z07 5~1.738 8.573 1568.750 1000.000 3172.917 1966.667 33~.583 329.167 I0~3.333 962.500 9.851 457.792 36.024 95B0,186 396.316 0.000 9.214 1662.500 !039.5~3 3902.0B3 256a.5~3 596.939 494.792 1674.679 1478.365 ~.618 I~.492 6&5.2~7 1.2~5 40.126 17212.883 694.259 0.000 15.100 1627.0~ 1002.0~3 ~404.167 1243.750 520.~33 1343.750 510.417 !6.&ll 1~.I08 6!9.B79 DEPT. ! 26 9z~. 5 O0 Si'5~~ .HLA RNI.PS1 -909.250 RN2. PS1 RN5. PS 1 -S 99. 259 ~N~f,. PS! RNO. PS I -9 99.250 RN ].O. PSI RN13. PS ! -999. Z 50 ~N 14. P S1 R'Fi. PSI -999. lEO P=Z,PS! aF 5. o S1 -9:99.250 R F 6. PS ! RF 9. PS 1 -999 :. 25 C q: 10. F' S! RFI3.PSI -~99. 250 STDT.oSi -999.25C TP:~.PSI S~FNO.PS1 -99~. 250 S~F.PS1 NTDT. PS1 -999.2 ~0 ~FF[]. PSI ABNU. ;'S1 -999. lEO SIGC.FS1 TRAT. ~S! -999. g ~O SCS I.PS1 TC ~K. ~ S I -999.2 ~ 0 TC ~. ~ 51 TSCN.PSt -999.2~0 TSCF. PS1 TTEC. PS ! -999. Z 50 HV. P SI GR.PSI -999.Z50 t .O9B SI:~M., PS 1 52.752 O. Z47 B~.CK. P S1. 223.907 375.69. 'I0'~ TCND. P'S! 19608.484 3 qO 7.058 INND. P S1 3 381 .'708 2~6. 875 SATC.PS] t.000 0.000 TENS.PS1 -999. 250 RN3. PSI -999. 250 RN7. PSI -":~99. 250 RNll .PS1 -999.Z59 RN15.PS1 -999.g50 R~3.PSI -999.759 RFT.PS1 -'q99.2fiO RFII .PS1 - :)~9. ~50 RF15.PSt -999.250 ISHU.PS1 -999.250 SBH~.PS1 -999. ZSO ,~BFD.PS1 - 9 ~.2~g ~I ~:H.pS1 -999.259 ~,CK.PSI -~99. ZSO TC~'~C. PS! -9~9. 250 INND. PSI -999.250 SATC,.PSI -999. 250 -999. 250 -999.250 -:999. l 50 -999.250 -999.250 -999.350 -999.250 -g99.250 - 99 9. Z 50 -999.250 -999.250 -99 9.250 -999.250 -999. 250 - 999.250 999 '~ 0 '~MO:.PS1 F3&C. PS 1 "'r C =D ps~ 'i'"~':n P~S 1 C~-,r' L. P-~" 1 1.145 45.085 10807.988 604.925 0.000 -999.250 -999.250 -999.250 -999.250 -9'99.250 -999.250 -999.2~0 -999.250 -9~9.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2~0 10 SERVICE : =tIC VERSION : 901~92 DATE : ~9/01/2~, P~X FEC S!Z': : F IL~ TYPE : tn - L~ST 9ILt 23-J,~N-!989 Il: S8 <SE'= ~IL*: ED*T O0~ =~R ~SS ~3 g~T~.> "' S"~L~J'"~cRGF;* ~ g~;S INC:) UOE:.~ WITH THIS :~!L C,U~L ?,UDS~,..* TOT, LOS- ~,SS, g'Z., (.PS2)_ ..,- FIRST T~ L~ST' REAnr~.~G' 1~'386' TO IZ~?5 11 TABLE I'YP!:- : CONS TUNr V~LU CEFI CN FN W N N A T I STAT COUN FL S EC'T 'T OWN R~NG LATI LONG E.r,~G ~ SON STANDARD ,~L~S~A P'~OD!JCTION CO CC'4PANY ~A~E EN.r,'!COTT FIEI. O NAME ]-1!/~-30 SDI USa a, L a S K ~ NORTH SLOPE :~F2'~' FNL F, 8~'8' FEL 17E 73097 50-029-21 ~LL NA~ E NATi']N 'STAT~= :~q P~OVINCE C OUN'TY F~LD :LOC~T!ON S E C T I g N TOWNSHIP RANGE L~ T I'TU']F L. ONG~UD~~, . =~'-IN~=R'.,,,:~ c S NAM= SERVICE ORDER NUMBER ~PZ SEPI~L N~JM~ER TABLE TYPE : CUqV -- T ENO c., TO. R N1 R NZ RN3 R N4 R H5 R N6 28-J~N-1989 12:58 1 2 DE~! R N 7 R .a W R N 8 'R a, W RN9 RAN R N I 1 R -;t '1,4 R N 1 2 R A RNI3 RN!~ 'R~W R N 15 q :~ W R N 1 6 ? ~ W RF1 ~W R ~ Z :R i W RF3 E~4 RF7 R F 8 R ~ ~ RF!I R F I 3 R ~ W R = 14 R ~ ~ RF15 RF16 S T D T S T ~ T T~ TOT iSMU 'rOT SFF9 S MN g S I SBH= SI S~HN FTCT N T C T '.~ E AFFO A F N g ~ ~¢ A~ND S I G C S I SI2H 30 TP~T TE SOSI ST B&CK FB~C TCAM T~T~ T'.~A~ TuT~ TCND TCF~ T~T~ TSCN SELE T SC~ SEL~ INN9 ZN~L SHUNT ..... ~ ....... ( TOTP ) Gv~ :rJRV&T~N - ~,]~.. gcT~Cr":~.., . ~, , (TqTC)., 3vA ~g~EMr)LE - F~R DSTEC~: CTOTD) iq TnT'~ rD' N~ q ~LZTUD9 SOPEHgL5 --':~ ]ETFCTOR (TDTP) PL!T'JS= FOP~.T~ON - ME.a,R DzT=cIOe (TOTP) ,iITR.]N,vq_9c ,~,~N ~TO~ pArIS (TOT~-) r ~Ti3 FKG~gL:',,JU, ,, ,- 'L L r~UNTS ~q.ALYZc. .... . L CSUNTS ~,.;~D DETECT.., . CT~m C~= .~tt~T R~T -~ ~'CTUCTSO (TDTD) 13 OETECT:gR (TDTP) TY°~ RSPR CODE VaLUE S~RV U*:IT S~RV'TC= ~;-'I a,P'! a.~l ¢,Pl =!LE NUMn ]~~E'R' '~ LOG TYPE CL.~SS '400 NU'qB SAMP ELEI~ S!Z~ REPR PROCESS (H=X) D~P~ T E N S SiG¥ RNi RNZ RN3 RN4 RN6 RN7 R N8 R NS RNIO PS," PSZ PSZ PSZ oSZ PSZ PSZ PSZ ~SZ PSZ PSZ 4 4 4 4 4 4 4 58 68 68 68 O0000000OO OOOO000000 0000000090 0000000090 0090003000 0090000000 0000003090 0000009000 909090)090 OOOO000000 0000000000 9000003090 0000003000 P~GE' PROCESS (HEX) RN!I PSZ CPS O0 000 O0 0 2 I RN12 :PSZ C~'S O0 gO0 O0 0 2 1 1 RNI3 PSZ C~S CO 300 O0 RNI~ ~SZ C9S CO 000 O0 0 Z RN15 P:S2 C°S OO O0:S Og 0 2 ! ~. 4 68 RNi~ PSZ CPS O0 OOO R~I PS 2 C PS 0 O 90 g 00 0 Z I I 4 68 R FZ ~S Z C ~S O0 OOO 0 RF3 PSZ CPS O0 OOO O0 0 2 R ~4 PS Z r ~ O 0 O00 0 R F5 PSZ C PS gO OOg 0 RF7 PS Z CPS 00 900 RF8 PSZ C~S O0 OOO O0 RFg PSZ CPS O0 000 O0 0 Z ~ ~ ~ ~,~ R~IO PSZ CPS O0 000 0 R ~ 1'1. ~SZ CPS O~ 000 O0 0 RFIZ PS2 CPS O0 000 RFI~ PSZ CPS O0 000 OO O 2 'I 1 4 6 R~I5 PS2 CoS O0 00~ O0 0 Z S'TDT PS2 OO 000 O0 0 2 1 1 4 IPHI PSZ PU O0 000 IS~U P~2 V 0~} 000 O0 0 ~ I % 4 68 SmFD PS2 CU O0 000 SBHF ~S2 CU DO gO0 SBHN P.SZ CU O0 000 O0 FTDT PS2 C°S O0 000 A~FD PSZ C~S O0 goo ~.5FO ~SZ C~S OO 000 A:=ND PS" C~ ~ ,. , ~ : ~ 0'~ 00~ 09 ABND PSZ CoS CO 900 O0 0 2 SIGC PSZ CU OS 000 S!Bu PS2 CU O0 OOO Oq 0 2 ! 1 4 ~ ~ ~ TR&T o~ ,qq 00n 0 Sr~S ~ r,S~ CU .. ~ - . . Og 009 OS n Z B~CK PSZ CPS 09 000 O0 0 Z 1 1 ~ 66 F~C PSZ CPS O0 000 OO 0 Z 1 T C &',,~ DSZ OO OOO O0 0 Z I TCAF PS2 OO 000 OD O Z TCND PS~ Co~ nO OOO . ~ ~. '~ O0~ On n 2 1 I 4 6,~ TSC~.: ~SZ CPS C'3 00:3 O0 0 Z ! ! 4 63 TSC~ ~S~ CcS 0~,. ~C'~. ... O~ 0 Z ,' I ¢ 58 1'4N~ PSZ CPS O0 300 0 - ~ O 2 I I ~ 6B O00000OO00 0000009000 0000900000 0000000000 0000000090 ' O0000OO000 9000000000 0000000000 O0000OO000 OOOO0000OO O000OOOO00 0090000000 OOOO00OO00 0000000000 0000000000 0000000000 OOOOOCOOOO 9000000000 OOOO000000 OO90OOgOOO O000000OOO 0000900000 OO900CO000 O0000OOOOO OOO0000000 OOg900OOOO 0000900000 0000009000 O00OOOOOO0 OOOOOO00OO O00OO000OO OOOOOO0000 O00000OO00 O00OO00000 O000OOOO00 0000909000 SO000OC~OO~ go 9 O OC 90 OO 9009900000 OOOOOggOOO OOSO000000 OOOO00OO00 0000000000 00'S0309000 0090909000 0090090000 OOOOOgOOgO O00C900OOC OOgOOOOOOO 28-J~N-1989 12:58 N~P,E SERV UNIT SERVTC5 . : ~.iL.= NUM~ MU ~ Sr- TYP~ Ct~,SS f4Og NttM:~ S~MP ?.--.L~ C~gE PROCESS (HSX) £ I I z+ 2 ! I z+ 68 2 ! i ~ 6 8 2 1 ' ~ 6.~ 00OOOOOOgO gO000OOOOO OOOOOOgOgO O00gOOOO00 D E P T. 134 0 O. 00,9 T~ MS. P ~N,Z.PS ~ 7v~o4~0 oNR o RNS.PS2 ],.4'~ 5.7]9 PNT.D RNlO. PS2 1444.1 29 RNII. P Rql4. PSI 47~. 7~7 ~.~ 1 ~ .P RFZ.'~S 2 67. 090 R=3. P RF 5. oS 2 5'5~. ! ? 2 P =7. P R F!O. oS Z 60 !. 3 2:~. ~ II,. P RF~ ~.PS~ v24.4 ~1~ OF1r p T PHI. oS Z 57. Z! 1 !SWU. P S'~HF. PSZ 55.3 Z 5 5DHN. P ~ FF O. ~S Z ! 30. '714 ~e ~g. P SIGC.PSZ O. P72 'SiBH.P SDS I.~SZ I. 225 B~CK. P l C ~ ~. P52 i.I 7 91. ? ~ 7 TC ND. P I SC~= . PS Z 625.1 49 IN ND. g' NV. PSZ 205. 250 S: TC.P D:EPT. 13300.000 RN2. PS Z Z '~I. 0 46 RNa. PS Z !2 §2 · O1 9 R N1 g. l.,S ', RN14. °S 2 ,~ ~'52.033 R~2. PS2 56. I I 5 RF 6. PS 2 &04. I 67 R=IU ~S" ~7 Rtl ~. PSI !! qS. 4!7 TPHi-PS2 ~ ~F D. gS Z '~ 7.13 ! SZGC-°SZ 0.103 SDS~.PS-~ - ~ 0.212 TCA=. ~S Z ~O1 'Rg. 129 T SC~. '~q ~ '5r~'7~ O q~ D:PT. ],3700.~ O-'"n.: ~ RNZ.PSZ 234.411 RNS.?SZ 1275.00C RNiO-oSZ 1477.093 R,Ni4.P$2 23~7, 500 RFZ.PSZ a&.T]0 SE $2 S? S 2 SZ SZ S2 S2 SZ S2 S2 S2 S2 SZ S Z S2 SE 1 300. gOD 136B. 371 1396.7~0 2 3l,¢. 81 1 4285.037 ~:3:0, q7! 58 7.1 Z 1 990. !.51 2 220.5a4 Zl. 85.lgZ 135.381 222. 645 18727.3~9 3VTa.~59 1 ql 5. 426 1027.644 2g~9.311 1987.179 ~Z.083 {9~ .417 !8.655 9~. IPg. 14~.079 248. ~15 20a3,6. 746 Ba~O. 561 I. O00 1740.009 1718.759 197'9.187 2 ]IZ. 500 1 747.917 ":~ 29.3 C ! SIGM. PS2 38.57.3 RN4. PS2 1581.439 RNg. P'S2 1013. Z 57 RNI2. P S2 30] 9.77Z RN16. P S Z 2 ~5 9..~48 RF~..PSZ ~87.689 PF8. PS2 37 8.788 RF! Z. P 52 I Z6~. 204 RF16.PS2 1~15.719 SFFD. PS2 39.959 =TOT. P Si 5.496 ,aFND.PS2 580.524 h~MOF.PS2 i.163 =8 ~C. P S2 ~ 9. 063 TCFD. P S2 51~ 8. 890 ZN=D.PSZ 59~.919 CCL.PSZ 0.000 SIGM.PS2 15.738 RN4.PS2 1550.481 RNS.PS2 1003.605 RN12. PS2 2331.7.30 RN16. PS2 123 3. 974 R,=4.PS2 ~77.083 RFS.PS2 427. 093 ~'! 2. P S2 lO12. 500 RF!6.PS2 ~66.657 SFcD.PSZ 15.843 =T9 T. P S2 1 9.712 ~=ND.PS2 429.545 MMqF. P S 2 1.267 :E~C.PS2 50.623 TC~P.PSZ 8006.197 ZNFC. oSZ f42. 733 CgL.PS2 SIGM.PS2 20.584 RN4.PS2 1750.000 R?!8 .PS2 964. 583 RN12. PS2 2.387. 509 m~Jl6.. .PSZ Ii~5.~17_, Pc4.Pq2 ~c4.~0~ RN!.,oS2 RNS.~mS2 RNg.~SZ RN!3.PS2 RFI..~S Z RFS.PS2 R F 9. P S 2 Rtl 3. oS2 ETDT. oS 2 SFND.PS2 NT2 T. P S Z A~ND.PS2 TRAT.PS2 TCAN.PS2 T :S C N. o S 2 TTEC. PS.Z ~N!.~S2 PNE.oS2 PNg. PS2 RNI3.PSZ R~I.~S2 :F5.=S2 9732.765 1259.469 1624.053 4000.947 336.174 ~59.280 553.977 :1799.242 56.000 ~0.420 17.372 520.125 1.599 33107.992 O.OOO 172.500 965 :4~ 1280.048 1568.510 2678.285 ?,~+5. ~ 33 404.167 618.750 t200.000 56.090 17.393 22.2~6 482.289 1.4~5 ~720a 977 5823.621 O.OOO 62.344 900.000 1187.500 1552.500 2625.000 314.180 320.931 ES T~,,gE V~RI ~.TC~TIGN L~ST~N~ qF 6, P S Z 3 5 t. i 42 ~ =7. P S2 RFI O, ~$ 2 467,070 REll. PS3 R~l&,PS2 7!~.g~+6 ~FiS. 5 BM:=. PS Z 76. 343 S~ HN. ~ 52 A ~FD. PS 2 94. 990 ~.~ FO, P S2 SiGC, PS 2 O. goo .S!gH, P %2 SOSI PSZ 0 3TM ~CK P~2 TC~F PS2 1~'9:~ 7~9 TC~j~ oS2 TSC~ PS~ ~.~ 90~ "~Ng PS2 HV. ~:S 2 2 ~. 750 S~TC. PS2 D=-P'T. !3!00.000 TE!~,IS.PS2 RN2. PS 2 299. 794 RN3.PS2 RN6 oS~ 167c 167 RN7 PS2 RNI4,PS2 Z422,9!7 qNtS.~S2 RFS. ~S 2 ~ 76. 923 R FT. P S 2 R F1 C. PS 2 8g!. t O 6 P~: ! I. P'S2 R ~1 ~. ~S Z 1077,. T 2~ RF !5.PS2 'T ~I. PS 2 19. ~ 60 ISHU. PS2 S 5H~. ~$2 58. ! !g SBHN. P.S2 ~ FFD.°S 2 10!. ~ 2 ~E:=D. PS2 S'ZGC. ~SZ 0. 566 SI eH. PS2 S DS'I. ~S 2 0.3 ] 5 ~ CK. PS2 TCAF. oS2 240~9. 672 TCND. PS2 TSC~. PS 2 24 50. 442 ~NND. PS2 HV. PS 2 238.375 S,&TC. P S2 D.~P r. ! 3000. D O0 TE NS. P S2 RN2.'PS 2 23 O. 2 ~-5 e~43. PS2 2N8 ~S:~ '~Z..q. 1 66v ~'q7 PS2 RN1U.PS2 2~35.417 ~Ni~ .PS2 RN14. PSi 35~. 8 ~3 RN R F 2. PS 2 ~0.86B P ~3. P 52 RF~.PS 2 677.0~3 P=7,~52 R~IO. mS 2 ~Sa. 167 ~11. PS2 R;I~-~S2 !I~ ~= ~ oS2 TPMi-~ ~= ~ IS~dU PS2 S8~. ~S I 35. 597 S~HN. P S2 S IGC. ~S Z 3 · C ~4 Si ~N. P $2 SOSI.PS2 O.~C 3&CK .PS2 TCaF.PS~ 320~9. 840 T SC=. PS Z 3~ ] 1.5c 8 !NqD. oS 2 NV,[~SZ 2:~ =2~ S~,TM .PS2 28-JAN-1989 tZ: ~8 Z 7 Z. 25. 97, 142, Z ? 6, 2 O0 ~. I, 17!0. 1472. llZg, 2697, 1777. 23. 67. 145. Z6O, 2971. !. 1!72. 1. 71 Z. '-~ ~.04, =6A 512. 131!. 693. 25. 15B. 41. ~I. 33010. I 76 5. 1!~7. ! '~75. 3 O3 5. 3~Oq. !77 RFC.PS2 484 ~F1Z.PS2 26 9 RFt6. PS2 t"72 SF=D.PSZ 4. 3 9 ~TOT. P 52 236 ~FND.PS2 279 ,M~OF. P S2 837 FB,~C.PS2 2~2 TCFD.PSZ ! ~9 ~NFO. PS2 000 CCL.PS2 000 SIGN.PS2 q17 RN4.PS2 833 RNS.PSZ 917 RNI2.PS2 083 RN16.PS2 689 RF4.PS2 689 R;g. PS2 525 RF12. PS2 349 ~:18.PS2 359 iFFD.PS2 675 :TDT. P.S2 28 5 &FND. P SZ ! 18 :~POF. PS2 71~ FBAC.PS2 175 TCFO.PS2 ~42 INFO.PS2 009 CCL.PS2 361. 223 754.38~ ~ ~ 5 457 ~;,. ,..., . 20,777 7.707 ~3~.777 !. 250 4 8.25,5 5~72 0:5 458,~69 0.000 ! 7.2¢7 1864.583 94 3. 750 26!4.58 3 124 5.82, 3 54¢.872 37 6.603 947. 516 5~.B62 10.009 473.37 (, 1,203 87.083 8141,0~9 483.089 0. O 0 O 300 SIG~.mS2 13.162 917 RN4.PS2 1,731.250 500 RMS. PS2 "~ R 3. 333 167 RN!2.~S2 4216.666 ~!7 RNI6.PS2 1214.583 667 ~. ':Z,, PS2 493,759 qOO R;8. PS2 391,66'7 SOO RF!2.PS2 1433.333 75 g RF 16. P S 2 34 5..~33 172 SFFO.PS2 21.514 OO~ =TOT.PS2 15.771 PO2 .~NS'. PS2 543 q~OF.P52 1.140 719 =E~C.PS2 54.60Z ~05. ~C=D, , .PS2 10556.~05 ~2! INFO.PS2 523.0~g OOO CCL. F S2 O. goo SIGM.FS2 8.425 Ol ? Rq4. P SZ 155 Z. O 83 900 RNS.PS2 391.667 4!7 2NI2.PS2 3389.583 2~0 RN!6.PS2 23~7.509 13'~ R;4. PS2 ~2 5. 347 472 ~;8. PS2 36 2. 413 RFg. °S 2 RF1 3.PS2 ST2T. :mS 2 S:NO.PS2 NTDT. P S 2 ASNO.vS2 'T R A T. P S .2 T C A N. :P S Z TSCN.mS2 TTEC.gS2 GR.~S2 RNi. PSZ RNS.PS2 RNg.~S2 RNI?.oS2 ~F 1. PS 2 RFS.~S2 R~:3.DS2 Rci~.PS2 S T g T. p S 2 S~Ng. PS2 NTCT. PS 2 ~,~ND.PS2 TRAT.PS2 TCAN.~SZ T SCN. PS 2 TTEC.PS2 GR. PS 2 4~5.551 823.253 66.000 Z0.584 Zl .349 401.655 1 . 969 47346,078 4713 -7' 33 0.000 57.281 9t8.750 17 68.750 20'75. DO0 2620. 833 340.5,45 570.913 74T.195 I'!03.766 56.000 19.078 lB. 592, 542,674 1,651 55028.367 · 56g0. 423 0.000 .~ 0. 000 979.167 1918.750 23~2.09~ 4~04.156 354,!67 527.08~ 8~5.417 1418,750 Z~ .218 45.B31 553. 731 i .795 :~8~4.. . 55~_ 8601.~56 O.OOO 56.6~B 954,t~.7 1650.000 1985.417 4035.417 316,~4C 427.517 644.5~! 16 DEPT. 12800. OO 0 'TENS. PS2 RNZ. oS2 !4]. S75 PN3. P S2 RN6.PSZ 1951.1 3~ RNT.PS2 RNIO.OS2 2] ~7,.420 RNI!,PS2 RN1 ~. PS 2 ~? 99.839 RN ! ~. ~52 RFZ.PS2 43. 651 R=3. PS2 R;!O PS2 ~77 0~3 :~n!l.P~C2 RFi4. PS2 25'33.333 RF'I 5, PS2 T P~ l. PS 2 ! 3 .~ 90 IS ~tU. P S 2 5 5HP. PS2 ~1.1 ~9 S~.H~, PS2 APED. PS 2 ! 69.0 ID ~ ~O. PS2 S'ZGC. mS Z O. 3~ SI 5H, PS2 SDSI.PSZ O. 126 SACK.PS2 TC~. PS Z 95g g4. P4.4 'TC ND. PS2 TSC~F, PS2 ;? 721,670 INND. P S2 ~V. PS Z Z 36.6,25 SATC. PS 2 D'E P'T o t 2700.000 TENS. PS2 RNZ.PqZ. 2~!.~5 p~!~ RN6. PS 2 lO 09.215 R~.~7. p S2 RNIO. ?52 21 S7, ~ O0 RNI 1. PS2 N14 PSZ ~24 = l°P qNl'g PS~ RF2. PSZ 57.497 R~3 · PS2 RPS,~S2 .~.;2.0 ~3 Rc7.PS2 R~iO ~52 ~7 500 R=' ! P~2 RF14.PSZ 'I~16.6~7 qFIS.PS2 TP~I.PSZ 21 ~ ~ IS~U FPO. oS Z 134. ~ 94 ~ cD. P S2 SiGS.PSZ O. 89~ SIiH.PS2 SDSI.PSZ 0,250 9~,CK.PS2 ICA= P~Z -~¢~ 7c0 TE"4Q Pq2 SC ~. °S Z 39 35.7 F ~ .:t'~ ND. P S 2 NV. ~SZ 276.62S S~ rC. 2:~-JAN-1989 !2::8 '989. 583 PFt2.PS2 168'g.368 RF!6.PS2 27.750 SFFD.PSZ 55.73'9 FTDT.PS2 !!!o16~ ~FND.DS2 6~.660 ,'."! M O F. P S 2 247.932 ~R~AC.PS2 30392.671 TCFD.PS2 2935.T91 ZNFD.PS2 1. 009 CCL. PS2 1725.000 SIGM.PS2 I 272.035 RN4.PS2 ! 618. 590 RNB. PS2 m~4! 186 RN12 PS2 ~393.028 RN16.PS2 702.083 RFS.PS2 13~5.833 RF!Z.PS2 2~45.~33 RF16~.P52 2~,313 SF=D.PS2 5 2.181 FI OT. P S2 !75.I92 :~FNC,PS2 59.~68 MMOF.PS2 ]7!5'9. 164 TCFD.PS2 3231.582 INFO.PS2 1.000 CCL.PS2 1720.0C0 SIGM.PS2 I !.79. 888 RNa. PS2 4 3 . I 74. 5q RN8 PS2 3249.,t 99 RNI 2. PSZ 2.¢23.'~79 RN16.PS2 ~6~ 7=0 PF4 oS2 49! .667 !168.750 RF12.PS2 ! ~. 417 P~I6.PS2 25. 172 SF~D.~S2 &9. ~! ~ ~TOT,OS2 !55.600 AFND.PS2 55. 281 '4~40~. O S2 255.7~B =B~C.PS2 29g23. 277 TC~D.PS2 B ~0 . 926 1.000 CCL.P52 1:197.917 107 ]. '..559 9. 081 ~96.645 1.!40 51.45~ !0176.723 4~1. 092 O.O00 9.186 1,068.670 98 5. 577 3 374.198 2596.154 581.259 487.500 1489.583 9 18.192 ..~0.7ZZ 1.185 52.683 17005. ,;309 55 '7,527 O. 000 15.491 160 B. 573 1927.544 350'7,6.!.2 1546.474 466.56'7 468.759 1379.!67 531.250 !6.&87 14.495 627.737 1.191 5 6.3_'39 10985.213 617.957 3.000 37. ,572 1029.647 1~1~ a07 log 9. 615 ~ 10. & 17 44!.g67 6 ? 2.917 RN!. PS2 RN 5. PS Z 2 N 9. P S 2 qN13.PS2 RFS.PSZ RFg. PS 2 ~=13.PS.2 STDT.PS2 SFNO,PSZ N'TDT, PS 2 ~NO.oS2 TROT.PS2 TCAN.PS2 T S C N. P S ,2 TTEC.PS2 q N I. o S 2 :RN5. PSZ RN~. oS2 RN13.PSZ R~I.PS2 RFS.PS2 R~9.~S2 ~F1~.oS2 ST8T,oS2 S~-ND.OS2 NTDT. PS Z A~Ng. PS.2 TRAT.PS2 T SCN, oS 2 T T EC. O S 2 G,l.oSZ 1~82.205 66.000 10.278 26.943 457 1.878 114170.000 11914.004 O.OOO ~7.625 98T. 5'~0 1698.71R Z 05 ?. 292 4605.368 4)3.3'~3 6 ] !. Z 5 0 864.583 2199.593 66.000 10.175 ]3.918 ~0B.733 I .440 147666.125 15150.8~6 48.969 957.532 17~+2.785 2t~+1.426 3719.952 395.833 529.167 8~5,B33 1541.6,57 66. 000 17. ~23 33.31 1 505.994 1.57Z 825~2.625 8494.629 O.OOO 5~+.906 933.574 1630.609 1931.0~0 3~7.500 6 ZO. 833 445.833 17 18 ,56.000 ¢0.63] 1c 9~8 510.84,3 I .506 ~55!0.t, 30 17 ~ 8.4 ! 4 O.OgO 72.375 ~iLF- N~.~v~' · r_niT 002 SERVIC = ' aL.It V E R S T~ L] N~ - n~., n~ I_ ~ O ~ O~TE : SS/OIl.Z? M,~X RiC SiZE "1096 ~ILE TYPE "LS L~ST FiL:E NA:~'~:E : ;=CTT SERVICE : =!_lC V ERsIrJN : OO !a'32 D~,TE ': :3910 t',~,× R(C $]Z5' : 1096 DI.L~ TYOE : LO L.~ST ,=ILE "' g: g-' X: "' '"' X-' "' '"' ::: ~': ;'F -'-... ...... .., .,. ;1: ~. .. ~. ::: ~:.. -,- ;,,.. ;,,: -,- .,. .~ ~ ..~ ~,,:. .o: .... ~- <Sr=.. Fit,--_ EDT*. ,. .nOl., * <SE= =ICE EUIT.qCZ '4-' ~ :,': ;'.:'~'-,- :': ;'F -,-"' "'-: X: ~: ~: ~: f: ~ '~ "f' 1.4 t ' 4 " -- -.- s-. ~,-U.'.5'..:~3'r''> ...... ~ C"3~ ~,,ICLU:7..'r-? WFTU_ Tq'S.. = LE <=CTT.003>:_ .-"' ~ :JU~L ~,U~'ST TO* LOG - P~SS .,.'" .,... :}:... ............. ... .,. .,. ¢' '" "' ;:-' g: ;? :',.'. 28-JfiN-19~9 12:58 !9 T4E!~LE TY?'C : CONS CN N ~Ti ST~T CCUN SE-CT TOWN L AT 'l L 0 N g EqGI TAPE V~RrFTC~T~N. ..~ tlqTIN<. ~.,~ ~LUNO, ERG~R ~L~SY,~ COM?!jT'Zt,~7 C~NT'ER 2~-J~N-i989 12:59 2O RFll R=I2 RFI 3 R!FI& RF!5 R STDT lpg! ISH'J FT~T N-T ~ T A FF :3 AFND A~NO S IGC M~OF TROT 505I TC~,N TCA~ T CND TCFD T S C N T SC = INND INFO TTEC S ~'TC CCL .. ~ . . . ,..~,~T c ~$N ~=A2 !ITH g~.l R~W ~ 12TN G~Tc R~N ~fiR !3TH GaT~ TOT °C~C'SiTY TO'T SHU~T CU~)~ENT 5I:~?.~ ~gq~A'TiQN- ~=.~g O~TECT~R (TOTP) SIS~'~ 9O~E~Ot~- N'~.a~ C~TECT:3R (TDT~) FI~ T~T~ C~UqT ~PLITIJDE: $Co~.~Tlgq-- F~R g~TECTC~ (TOTP) A~LiT1JD~ ~OR~'TZ(~N- NE~R D~'T~C~D~ (TDT°) ANiPL-!I'UD~ %gP~HCL~ -- H~R g~T{ECTgP (TgTP) 'S I G~ COF~CT '~EHOL~- SinM~ (rr~C~:O) -- TD~P T D T R ~ T I 9 ~CKgRGUND., ',]E&R G6. TES FAR ~ACKGRE]U ND TUTAL CrJUN'TS fi~ALVZ'E~- K;~AR ~ETCCTOR (TDTP) TOTAL FC"N~S - N' 'TDT°) TST~L CCUNTS -- F.~q gET=CTOR SELgCTED G~TSS C1]U~.~T P~TE - M~P FjPT~CT~ S~LECTED G~TES C']UHT R~TE - =,~q ~3~TECTOR (TDTP) ]~FLAS, TIC CC'U~,:'~HG pAT:... - ~4'F.~p O~T:CT~ (TDTP) INELASTIC ~C, UNTIqG RAT~ - Sfi~ 9ETSCTSO (TDTP) TOT-g T~I_~'4~TPY ~P~g~ CC. UNT HE&C VgtTa'~F CCL 28- 1AN-1989 'T¥°E R:EPP rr, g~ V ~L~IF TENS SISM RN1 R NZ R,~tf RNlZ R N 1 4 RNI5 Re4 SFRV_ UHIT, S=qVIC~. E A'p~, .,. ap ~ pROC:p .~ Lng 'rvp FT OO PS3 CU O0 O0 F'S 3 C P S 0 O PS3 CPS O0 O0 PS3 C~S O0 O0 DS3 CPS O0 O0 PS 3 C PS C 9 PS3 CoS PS3 CPS 09 90 =S7 CoS O0 O0 PS3 CPS OO ~S~ fPS P S 3 C~S O ~S~ CPS OO O0 PS~ CPS O0 ~3 C~S ~S~ C~S O0 O0 ~S} C~S 03 O0 P S ~ C o S 0 0 '* n ~ S3 r oS I ~oI 5Pl =ILE NUMB ""~ Sr , 5 CLASS MOD NUi~B Sfi~~ EL~E~ CODE PqOCESS CHEX) 009090.9000 O0000CO000 O0 O0 COO0 O0 3000009000 0090909000 OOOOOO0000 0090009000 0090000000 OOOO000000 OOOO009OOC 0000309000 0000009000 OOOOOO0000 0000003000 OOOOOO007O OOOO0000OO 0030900000 O0']O00OOOO O0000OOOO0 9000909030 900000900C. OOOO0090OO 00-30003000 O00000OO00 'gl 2~-,J~q-ig~9 I2:58 Z 2 RFB ?S3 CPS RF9 ~$3 CPS gO gOO R ~:: 1 O P~3 CPS ..... 0 O R:~ll PS3 CPS O0 NFl2 P33 CPS OO OC'O ~m13 PS3 C~S gO gOO R~I~ PS3 C~S OD go0 RFI5 ~'S3 C~S STDT P'S3 OO gOO TPHI PS3 PU I S Ht.J PS? V 09 OOg S = F g ~ S 3 C~~ ..... ~ 09 SFN3 PS3 CU S[~H~ PS5 Cd 09 000 55H;4 PS3 CU OO O0~ FTO~ PS3 CPS O0 gOD NTDT :oS3 CPS OO ~=FO 0S3 CPS OO gOO ~=~O PS3 CPS OO ~,SNO PS3 CPS O0 SZGC PS~ CU OS OmO SiBH PS3 CU OS 009 M~4gF PS3 O0 OOO T~T PS3 O0 SDSi PS3 CU gO OOO B~CK P53 C'PS gO gOO FB~C ~S~ C°S OO goo TC~F PSI OO 000 TCNO PSI C°S O? goo TCFD PS] C~S 09 00~ TSCN PS3 CPS O0 009 TSC~ PS~ CPS INND ~53 C~S gO 009 INFD PS] CaS OS OOO TTEC PS3 gO OOO HV ~53 V 09 909 S&TC PS3 CCL PS; O0 GR PS3 5LP~ OO gO0 P~QCCESS (~SX') OOOO00OO00 OOgOOOOO00 OOOO00OOO0 O00O0OO00O O0000OOOOO O00000OO00 OOOO00OOOO O00OOOOO00 ogo000OOOO O000OOOO90 OOOO00OO00 OOOOOOOOOO O000OOOO00 O00090OO00 OOOOgO0000 OOOOOO9000 0000000000 OOOO00OO00 0090009000 OOO00OOOOO OOO000OO00 OOOOOOgOOO OOOOOOOOOO O00OOOO000 go00000000 0000000000 O000300OO0 0000900000 0000009000 OOOO00OO00 OOCO0000OO OOOOOOOOOO 0090300000 OOOOOOOO90 OO90000OO0 0090009000 OOOOOO90OO 0090309000 0000003000 O00OO00OO0 9090009000 OO~OOOOO00 DEPT. 134. ;5.0?0 TE'.IS.PS~ - 79o. ?50 S!O,',,I.oS3 -999.250 RNi.~S3 ~NZ.=S~_, -~99, .~50~ R~.}3.PS~ -9~,.~9_., RNa.oS3 -q99.25n~ ~NS,, .~S3 ~N~.PS~ -99o. Z50 ~;7.PS? -)99.250 R~,~8. PS~ -99~.250 qNg.oS~ RqlO.°53 -999.Z~0 q~'J!l.PS~ -999.259 o~!2.P53 -999.250 Rb]i3.PS3 -999.250 -999.250 -999.Z5C -999.250 TA?E V~E. RZ~ZCCTZgN LT'STIN'3 RN1 q.. °S ]3 -9~99.2 FO °,N15. PS :3 - RF2. PS 3 -9~9.2 5~ ~3. PS3 -99 ~F6. PS 3 -999,2 50 P =7. P S3 -99 RF!O.PS3 -999.25~ RF!C.P53 -99 RFI ~. PS 3 -9~9.2~0 q~ 1 ~. PS3 - 99 T PHI.'PS ~ -999. ~ ~.~0 ISHU. P S3 -99 S~H~.oS3 -999. 250 S~HM.PS3 -99 ~F'FD. PS3 -999.2 ~0 .~SFD. o S3 -99 SiGC. PS 3 -~99.2 qO SZ L~H. P S3 - 99 'TCAF. PS3 -999.2 SO TCND. PS3 -99 ISCF. PS3 -999.2 SO INN2. PS3 -99 HV, ~S 3 -999.2 50 'S~?C, PS3 -99 DE PT. 13400,000 TE~,~S. P S 3 RNZ.PS3 .~'.4~.. 430 RN3 . P':S , RN~'.°S] 1'3~ ~A6 RN7 Pc3 R N1 O. PS 3 1 ~ ~6 · 314 :RN t.:i. P S3 R N14. PS 3 3397.4 3:e, RF6. P S 3 4'75. O O0 ~ =7. P $3 RFIO. PS3 539 · :C 8~ RF'II · R F1 ~+. PS3 1577. O :~:~ ~ I 5. PS3 T~HT-mS~ ~2 7~2 ~SMU S~H= °S3 ~I 7~ ~n~N PS3 S iGC. ~ S 3 ~. 0 55 S I BM. P S3 SOSI PS3 0 t4~ TgAF PS~ ~61 ~2~ TCND PS~ T SCF. PS 3 ~3 Z2.914 ~N ND . P S~ HV. PS3 236.3 15 S~ TC-. PS3 I 6 ? !~,-3 221 9 12 14 33 2374 3 !g 28-JhN-t989 12:58 !72 ig, 6 199 !36 52 2 9 !! 17 3 ~6 9.250 ~NI6-PS? 9. 250 DF4. PS3 9. 250 P FS. o S3 9.Z50 RF12.PS~ 9. 250 RF16.P'S3 9. 253 SFFD. PS? 9,250 FTOT.PS3 9.250 9. 259 ~OF.PS3 9.250 FBAC.PS3 9.250 TC~D.PS3 9.250 IN~:D.PS3 9.250 CCL-PS3 0.000 S!G~.oS3 B. 301 ~ Na. P S3 6.010 PNS.PS3 5. ~4'4 RN12.PS3 0.7 ~ '5 ~ N 1 ~'.. P S .3 6.667 RFA.PS] 6.250 RF 8. PS? · 08~ ~4 PS3 2.563 SFFD.PS3 ~q. 76,5 =TOT.PS3 0.~05 ~FND.PS3 2.29l MMO~. P S3 9.49~ FBAC.PS3 ~ ~93 T~:D PS= 6.05'5 IN~O.PS3 !,.909 CCL.PS3 0.000 6.567 RN4.PS3 1.250 RN8.PS3 5.~33 RNI2.PS3 0.417 RN!6.PS3 9.'~83 R~4.PS3 ~ 300 R=8 9.!67 7.98B ~FIB.PS3 3 ~=~ ~.~30 CTDT.PS3 !.9~ F~hC.PS] 4.g26 o. ~g6 ~N~C. 1.009 CCL.PS3 -999. 250 -999.250 -999.250 '-g99.ZSO -999.250 -999 2c3 . -999. -999.250 -'q99. 250 -99 9.250 -999.250 -999.250 - 99 ~. Z 5 O 12,596 1510.417 101 9.63 i 2 634,214 1909.054 43g.583 3,58.750 1095.833 RZ 0. 1 2.680 12.060 1.263 8 8.183 9391.150 0.000 1 9.8 ! '9 !637.500 1012.500 2062.500 119'7. 917 a20.~33 z+O$. 333 715,567 285.~.!7 19. 570 7.~62 ~0 7.39 6 1.29g 55.5~4 6823.217 510.~70 O.O00 20.161 1350.160 943.510 2S41,747 1 21 3. '942 RNI.°S3 RNS.PS3 RNg.~S3 R ~,1! 3. PS .3 RFI.PS3 RFS.0S3 P,F'9. PS3 R ~:13. PS 3 STDT.PS3 S ~FND. NTBT. PS3 ~BND.PS3 TRAT,PS3 TCAN.PS3 TSCN. PS~ TTEC.PS3 GR.PS3 RNI.~oS3 RN5. oS 3 ~Ng. PS3 RNI3.0S3 RFI.PS3 PFS.~S3 RF9.OS3 RF13.PS3 ST~T.mS3 S~N3.°S3 NT~T.:~S? A~ND.PS3 TRAT.PS3 TC~q. PS3 TSCNoPS3 TTEC.OS3 GR.oS3 ~N'!. RNS.PS3 RNg. Ps3 ? t413. °S3 RFI.mS} P~GE: -999.250 -999.250 -999.250 -999.250 -9~9.250 -999.250 -999.250 -999.250 --999.2,50 -999,250 -999.250 -999.250 81.875 931 ,. 4'90 !247.997 t558.:493 3295.272 306,2.50 393,750 591 .667 1412.5'00 13.527 25.984 ~'~5.156 1.615 85648.791 ,,,87:30.133 0.000 29¢, 750 9a7.9t7 12B7.500 1631.250 2060.~17 327.033 335.417 514.5~3 T~I.250 56,090 20,916 lq. Z11 4A5.43~ 1.685 40538.523 4174.488 0.000 8~!.410 1155.849 1526.442 2550.080 312,500 23 RFZ. PS 3 46.4~0 F :3. PS3 RF5 ?33 ~,70 ~'~3 PF7 R Fl9. PS 3 ~'79. 167 ~ 11..PS3 R=I4. PS 3 7 ~! . Z 50 P~ ! 5. PS3 I PH !. PS 3 ¢3. E !0 iS HU.p 53 5 ~H~=. PS 3 77. T 52 S[~ HN. P S ? A FF'O. PS 3 92 . ,~ 35 ~E.'~D. PS3 SIGC.PS3 0,053 51~H.PS3 SDSI.~S5 0.357 ~:ACK .PS3 TCAF.PS3 I 7756.328 TCNO.PS] T'SC=- PSR ~ ~7~.I~I .I ~, mn D'=_PT. 13190.000 TE NS. PS3 RNE. PS 3 252.'! 93 RN3 RN6.P$3 1723.76& PNI.PS3 RN14. P S 3 353$. ~ ~:~ RN 15. P S 3 RFZ.PS3 '79 ~75 R ~3.pS3 RF6 ~S'~ 5~2 %00 RF7 R=!0.PS 3 '7~5.417 ~1 1. PS3 RFI~.PS3 IF70,833 RF~ ~.PS3 TPHI.PS3 Z~ ~m7 [SHU PSTM S 5H'F. PS 3 55.5~I S~N:. PS g A. FFO. PS 3 1 O1.99.3 ~ =D. PS 3 SZGC.mS~ O. 510 SISH. P:S3 SDSZ.PS~ 0.I S'7 TCAF. PS ] 3 7312. 516 rC~:g. PS3 TSC~ PS3 ~'~3 ~n5 INND PS~ HV. ~53 236.625 S,~TC. PS3 DEFT. 13000.09P TE'fiS., PSB 'qNZ 053 259.2q~ R~.'~ pS~ RN6. o53 ZZO¢. !. 57 PN7. RNIO.~S~. ?~:,: ,~n,,, ~.,~-~1, ..PS~ RN!~.PS] 3500.000 Ft:IS.~S3 RFZ-r~S3 51.920 R=~.PS3 RF6. PS3 662. 500 R=IO ~S3 m~O ~:.: q~l~ P~ I . ..~ · ~ .. T PH I. PS 3 ~ ~. ~;'70 IS HU. ~ 53 S 3H=. P S 3 37. ! 8~ 'S~ HN, r 53 A=Fq. PSTM ~'=0.~ S iGC. PS~ = · 2:6 SDS~ PS3 ~ ~ 34 TC~F ~5~ '~:334 1~ TC~C i , .,' - o , · - i TSC:. PS~ 3e 76. 394 DV.RS~ 23~. ~ 7: S&~C.PS3 2:~-J ~N-I 9'B9 !2:.F8 ~,:l.Z=0 304.1~7 R=8.PS3 $81.250 R~=IZ.PS3 547.917 RF!6oPS~ 26.906 SFFO.PS3 ~3. 120 97,725 ,~FND.PS3 !~6.091 M~SF.PS3 268. 569 FBAC.PS3 1E309.789 'TCFD.PS3 2 ~70.252 ZN~D. P S3 1.000 CCL.PS3 1730. O0 O S I G~,. PS3 .,. ,-05 RNa. PS? 137~,. 205 RNS.PS3 2~36.538 RNI2.PS3 2 924. 579 RNI6. PS3 ~Tg. 167 R~.P'S3 497.917 RFS. ~S3 191'5.567 eF12.PS3 142~.9B3 2F!5.mS3 26.469 S~=D.PS3 65.029 :TOT.PS3 164.907 ~FNO.PS3 87. 791 M"OF. PS3 279.~!3 tEAC.PS3 Z8086. 3ZO TC:FD. PS3 3971.383 INFD.P53 1.003 CgL.PS3 1 73~.000 S:ISM. PS3 I !.93.759 R N4. P S3 1629.167 RNS.PS3 '~658 3~3 ~Ni2 ~tq3 7:0 RN I ~:. 3~7.91.7 R~4.PS3 ~27. 983 RF~. PS3 !]25.003 ~F12.PS3 29.203 S~D.PS3 ~ 300 :T~~ PS3 I~'~.573 ~FND.PS3 47 t 80 M~SF 32509.773 TCFD.FS~ ~9~5.365 1.00O CCL.PS3 ! 7AS. 300 SI S~,~. PS3 !905.~09 RNA.PS.% t 209. ~36 217!. '-. '? ~ 3317. 30~ 9Nib. PS3 210.4!, 7 R :&. P S3 356.~0 '797,917 285.4!7 !9.680 7.9!6 1.265 52.562 576 ;¢. 698 461.349 11.316 1760.817 ,a ~ 5. 577 3058.~94 1883.91,3 531.250 383.333 1147.917 833.333 12.30! 10.5B 8 ~1.826 99,390 9863.gTB 48 Y. ~ 74 0.000 1689. 1002.083 1.293.750 5!2.500 435.417 1433.333 ~ ~ ?. 083 2,3.404 16.505 505.6~i 1.192 57.389 110~6.5~3 557.611 O.000 905.449 2542.0,,:.7 RN!.~S3 RNS. oS? RNg.mS3 RN13.PS3 RF1. PS3 R=$.PS3 R F :~. P S 3 RF1,3.oS3 STOT.PS3 S:ND.PS3 NTDT.PS3 TRAT .PS3 TCAN.PS3 T S C N. P S '3 TTEC .PS'3 GR. PS.3 PN!.PS3 qkS.PS3 RN 9. ~S 3 RN!3.PS3 RFI.PS3 ~ fi C; 5 ' Z 4 318.750 '~18. 750 8~1,.667 66.000 20.434 21 · 5:16 395.427 1.870 4 :~ 1.555 47:~5.661 O.OOO 68.750 955.529 1679.6B6 :209~ 3~3 34'99,599 325.000 = 52 500 7~5.833 56. 000 13.202 24.986 cZ4., . 357 1.724 828,82.531 8601.893 0.000 76. 500 920.833 1852.0~3 2295. 833 4256.250 354.583, 575.000 891.667 16~Z.9~7 66.000 Z3. ~.47 544.617 1.67'7 83231.719 3659.959 O.O00 105.938 8]'7.420 !137.820 1470 3 3253.295 212 ·SO0 398.3~3 RF6. PS 3 ]277.0 ~3 R ~?. PS3 RFiO. PS 3 4.08. 333 PP!~, .PS3 RFI4,PS3 1435,4!7 RFI5 .PS3 TPHZ. PS3 g 9.0 6~ IS HU. P S 3 SBHF. ~S 3 52. ~ 86 S~N. PS3 S IGC. PS ] O. 5 lO SZ3~ .~S~ SgSI oS3 0 ~ 6= 3~:~ PS~ TCA~. °S 3 4'3~ 44.9~:~ TCtqD. P53 TSC~.°S~ ~1TM 718 ~NNn PS3 Hr. PS 3 237. O O0 S~TC. P S3 DEPT. 1210O.OOD "rFNs. PS3 RN2. PS 3 Z q _q. 315 PtJ3. PS3 RN6. PS 3 1854, ! 67 R"IV. P S3 RNIO.PS3 199g, 593 PN14,PS3 17!6. 667 RFZ.oS3 ~. 6'51 'R=3.PS3 RF6. PS 3 S ~4,904 RF7 NFl4. P53 6~5,016 IPHI.PS~ B2.79- IS~U.oS~, S IGC.PSI ]. 152 SICH.P S3 SDS I. PS3 O. 85B ~C,K. TC~.DS~ !~.320. 861 TCND.PS3 TSC~.~S3 16~:9,001 HV ~53 '~6 750 S~C PS 27-JAN-1989 !2: 59 427,983 R~8,PS3 685, '~' I'7 ?F 12. P S3 i ~41,667 RFI6,P53 ~ I. 2 = O SF=D. ~'S3 67,444 FTOT.PS3 73.339 ~FND.PS3 95,~5'1 MMDF.PS3 ~g.144 ~BA~.PS3 24543.652 TC~D.PS3 Z73!.~51 INFD.PS3 l. O00 CCh. PS3 256.250 981 98 3 . '.'!, 3 3 8 638 7.92'3 ~,Z5.186 1. Z 16 52.990 7943.3?0 339.63i O.O00 1710.000 SIGM.PS3 11.14'9 :1291.66'7 RN4.PS3 1768.750 1604,167 RN8.PS3 1008.333 3~35.417 RNt2.PS3 3943.750 3797.917 RN16.PS3 2179,167 4~6.250 R=4,PS~ 587,500 662. 500 R=8. P 53 .&72. 917 !c+60.417 R~Ig.PS~ !'7BI.250 2!04.167 RF16.P53 t195.8~3 25.594 SFFO.PS3 !1.597 56.411 :TDv. PS3 17.586 174,546 ~FND,.PS3 609,771 66, 54! ~MOF,PS3 1,ILO 273.650 ~B~&.C, PS 3 60,848 34~92,~44 TCFD,PS3 152!9,648 3359.Z99 IN=D.PS3 661,676 1,000 CCL.PS3 0,000 1715.900 SIGN.PS3 1202.083 PN4.PS3 1214.583 RN8. P 53 29!4. 583 RN!2.PS3 1!.60,417 RN16.PS3 343.'558 R~4.PS? 1033.65~ RF!2.PS3 ~41.5~3 RFI6.PS3 24.297 SF=D.oS3 C0.~93 ~TDT.PS3 146.420 60.7B5 '~q~. P S3 ~?113.922 TC=D.P5~ 3312.292 INFO.PS3 1.000 CCL.PS3 26,99.4 !~00,000 1014,583 2758,333 1145,333 500.801 ~3'~.?02 955.529 256.¢10 27,476 10.090 568.995 1.!29 60.873 7543.402 588.686 O.OCO -999.250 SIG~.PS3 -999.250 -999.2_ 50 RNa. PS3 -99 ~. 250 -999. 250 RN8.oS3 -)99.2~0 -~99.250 PN!2.PS3 -999.250 -~q9. 250 ~N16.PS3 -999.259 -999. 259 P=&.PS~ -999. -~-~g. !50 ~8.PS? -999. PNI.PS3 PN3.oS3 RN9.oS3 R~!3 P~gS: Z5 414.583 1162.500 66.000 10.168 ZZ.4Zg ~60.811 Z.O00 97196.609 100,25,402 O.OOO 78.750 993,750 1779.157 2154,~67 4452.083 629.167 9~1.250 ZI~!,667 66,000 12,376 33.466 518.738 1.423 ]..20081,01~:. 11Z~9,727 O,OOO 71.750 950,000 17.~3.750 Z077.083 Z350.000 37~.606 506.~11 755.224 8~5.353 -56,000 29.302 26.301 493.667 1,533 ~079,648 O.OOO 97.875 -999.250 -999.250 -999.250 -9'g9.ZSO -999.250 -99g.250 -999.250 Fi0.953 .-9'~9. 250 RFII.P$3 -999.253 RF12.PS3 -:)99°250 RFi3.PS3 'PHI,PSI -999.250 ISHU.PS3 -999.250 SFFD,PS3 -999.~50 S=NO.PS3 ~:,H~ :PS:3 q~q Z~O SFj, HN.PS?, 999 259 ~'TDT.PS3 999 25'~ NT~T PS3 '~,D.oS~ -9q9 Z~O ~=r,~ PS3, -99~ ~5n:., AFND.PS~ -999.Z50 ~:ND~ .pS~,, ~ZGC.PS~ -995 250 q.:~H PS~ -9~9.~0 ~MOF P~ -9Q9 2,~0 TR~'T PS'~ , ~ ~ -~ , . ~ ~ . ~ ~ , ~ ~ ~ ~ ~ ~ , , ~ . ~ TSC:=.~S3 -999.2~0 :NND.PS3 -999.!50 INFD.PS3 -999.250 TTE~C.~SB H¥.PS3 -99g. 2FO S~'TC.PS3 -999.2~0 CCL.PS3 -~99..2 FO G.P.PS3 -999,2.50 -999,250 -999,Z50 -999,250 -999,250 -999,250 -999.25.0 .-999.250 -999.250 -999.Z50 FILE, N~I~,E SERVZC~ V:RSION MAX R~C S FILE TYPE L~ST FILE :G r.] 1'1' =tic :: O 0 1 a 'l e 96 ORIGIN C ONT I q~J AT ! G h~ PR~V~SUS Bg/o t./2 _R =tiC T 3 O 9 'B 5 I',.: 9T. C O. T T, ~50-029-218~8 '-. I'.. DIC OTT , ~50-0 29-21 848