The URL can be used to link to this page

Home My WebLink About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y Samantha Carlisle at 7:53 am, Mar 11, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ dh ϭͬϮϭͬϮϮ ϮͬϮϰͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ ^ZhϮϰϭͲϭϲ ϱϬͲϭϯϯͲϮϬϱϰϬͲϬϬͲϬϬ ϮϬϰͲϬϴϴ ϬϮͬϮϬͬϮϬϮϮͲ^ƵŶĚĂǇ Wdt͕:^ǁŝƚŚĐƌĞǁ͘&ŝƌĞĞƋƵŝƉŵĞŶƚ͘^>dhϭƉŽǁĞƌƉĂĐŬĐŽŶƚŝŶƵĞƐƚŽĚŝĞ͘^>ĚŽǁŶƚŝŵĞ͘ŽŝůŐĞŶƐĞƚŶŽƚĂďůĞƚŽŚŽůĚ ĐŚĂƌŐĞŽŶďĂƚƚĞƌǇ͘ůƚĞƌŶĂƚŽƌŝƐŽƵƚ͘&ŝǆĞĚ'ĞŶƐĞƚƚŚĞŶŚĂĚŝƐƐƵĞƐǁŝƚŚ^>ĂĐƋƵŝƐŝƚŝŽŶƐŽĨƚǁĂƌĞŶŽƚďŽŽƚŝŶŐƵƉ͘EŽƚŝĨǇ K'ŽĨKWƚĞƐƚ͘ƉƉƌŽǀĞĚďǇ:ŝŵZĞŐŐ͘tŝƚŶĞƐƐǁĂŝǀĞĚ͘WĞƌĨŽƌŵKWŽŶĂůůƌĂŵƐĂŶĚǀĂůǀĞƐϮϱϬͬϯϱϬϬƉƐŝ͘^ĞĐƵƌĞ ůŽĐĂƚŝŽŶ͘^&E͘WůĂŶĨŽƌǁĂƌĚ͗WŝĐŬƵƉDhYƵĂĚĐŽƵŶĚĞƌƌĞĂŵĞƌŵŝůůŝŶŐĂƐƐĞŵďůǇ͘ ϬϭͬϮϭͬϮϬϮϮͲ&ƌŝĚĂǇ ϬϭͬϮϮͬϮϬϮϮͲ^ĂƚƵƌĚĂǇ &ŽǆŶĞƌŐǇĂƌƌŝǀĞĚĂƚůŽĐĂƚŝŽŶ͘&ŝůůŽƵƚƉĞƌŵŝƚ͘^ƉŽƚĂŶĚƌŝŐƵƉŚĂƌĚůŝŶĞĂŶĚKW͘K'ǁĂƐŶŽƚŝĨŝĞĚŝŶĂĚǀĂŶĐĞŽĨKW Wd͘:ŝŵZĞŐŐǁĂŝǀĞĚK'ǁŝƚŶĞƐƐ͘KWWdůŽǁϮϱϬƉƐŝͬϯϱϬϬƉƐŝ͘'ŽŽĚWd͘&ŝŶŝƐŚƐƉŽƚƚŝŶŐĞƋƵŝƉŵĞŶƚ͘&ŽǆĐƌĞǁŽĨĨ ůŽĐĂƚŝŽŶ͘ ϬϭͬϮϰͬϮϬϮϮͲDŽŶĚĂǇ ƌĞǁĂƌƌŝǀĞĚĂƚůŽĐĂƚŝŽŶ͘d'^D͘ZŝŐƵƉEϮĞƋƵŝƉŵĞŶƚĂŶĚƉƌĞƉĐŽŝůƚŽZ/,ƚŽƚĂŐĐĞŵĞŶƚĂŶĚďůŽǁĚŽǁŶǁĞůů͘Dhd ,Ͳϭ͘ϳϱΗKd͕Ϯ͘ϬΗ&s͕Ϯ͘ϭϯΗǆϱΖƐƚŝŶŐĞƌ͕Ϯ͘ϭϯΗ:^EǁŝƚŚϳǆϭͬϴΗŚŽůĞƐ͘K>Ͳϳ͘ϱΖ͘KƉĞŶĞĚǁĞůůĂŶĚƚŚĞƌĞǁĂƐϬ t,W͘&ůƵŝĚǁĂƐƌŝŐŚƚĂƚƐƵƌĨĂĐĞ͘Z/,ĂŶĚĚƌǇƚĂŐŐĞĚĂƚϯϬϱϲΖ͘WƵůůĞĚϴŬŽǀĞƌWhǁĞŝŐŚƚ͘ĂŵĞŽŶůŝŶĞǁŝƚŚƉƵŵƉƐĂƚϭ͘ϱ ďƉŵĂŶĚǁĂƐŚĞĚĚŽǁŶƚŽϯϬϱϴΖ͘WhǁĞŝŐŚƚƐŐŽƚĐůĞĂŶĞƌďƵƚŶŽƉƌŽŐƌĞƐƐ͘WKK,͘dŚĞƚĂŐŽĨϯϬϱϴΖŝƐΕϭϰϬŚŝŐŚĞƌƚŚĂŶ ĞǆƉĞĐƚĞĚ͘,ŝŐŚƚĂŐƉƌĞǀĞŶƚƐĐƵƌƌĞŶƚůǇƉůĂŶŶĞĚƉĞƌĨĂĚĚ͘^ůŝĐŬůŝŶĞD/Zh͘ZƵŶd>ĂŶĚƐĂŵƉůĞďĂŝůĞƌ͘>ŽĐĂƚĞĚddΛϮϮϴϯΖ ^>D͘dĂŐŐĞĚΛϯϬϲϬΖĂŶĚǁŽƌŬĞĚĚŽǁŶƚŽϯϬϲϯΖ͘ddŝƐůŽĐĂƚĞĚĂƚϮϮϳϴΖ>D͕ƐŽĐŽƌƌĞĐƚĞĚWdсϯϬϱϱΖ>D͘ ŽƚƚŽŵƉůĂŶŶĞĚͲϵƉĞƌĨĂƚϯϬϴϲΖD͘^ĂŵƉůĞďĂŝůĞƌŚĂĚǁĞƚĐŽŶƚĂŵŝŶĂƚĞĚĐĞŵĞŶƚĂŶĚďŽƚƚŽŵŽĨďĂŝůĞƌǁĂƐƉĂĐŬĞĚ ǁŝƚŚŚĂƌĚĞƌĐĞŵĞŶƚ͘ZDK͘tĞůůƐĞĐƵƌĞĚǁŝƚŚƚƌĞĞĐĂƉ͘dĂŶĚEϮƵŶŝƚƐůĞĨƚŽŶůŽĐĂƚŝŽŶƵŶƚŝůƉůĂŶĨŽƌǁĂƌĚŝƐĚĞƚĞƌŵŝŶĞĚ͘ ƌĞǁƐĂƌƌŝǀĞĂƚŽĨĨŝĐĞ͕ŽƌŝĞŶƚĂƚŝŽŶĂŶĚƐĂĨĞƚǇŵĞĞƚŝŶŐ͘ƌŝǀĞƚŽůŽĐĂƚŝŽŶĂŶĚƌŝŐƵƉĐĞŵĞŶƚĞƌƐ͘ƌƌĂŶŐĞĞƋƵŝƉŵĞŶƚƚŽƐƚĂƌƚ &K͘DhĂŶĚZ/,ǁŝƚŚ&K,͕ϮΗ&s͕Ϯ͘ϭϯΗǆϱΖƐƚŝŶŐĞƌ͕:^EǁͬƐĞǀĞŶϭͬϴΗŚŽůĞƐ͘dĂŐĨŝůůĂƚϮϵϭϬΖ͘ůĞĂŶŽƵƚĨŝůůĚŽǁŶƚŽ ϯϯϭϭΖĐƚŵ͘DĂĚĞϮƐŚŽƌƚƚƌŝƉƐƵƉŝŶƚŽϮͲϳͬϴΗƚƵďŝŶŐƚĂŝů͘^ŚƵƚĚŽǁŶƉƵŵƉƐĂŶĚĚƌǇƚĂŐŐĞĚĂƚϯϯϭϬΖ͘WKK,͘Dh ĞŵĞŶƚŝŶŐ,͕ϮΗ&s͕Ϯ͘ϭϯΗǆϱΖƐƚŝŶŐĞƌ͕E͘Z/,͘dĂŐŐĞĚĨŝůůĂƚϯϭϲϮΖ͘tĂƐŚĞĚĚŽǁŶƚŽĐĞŵĞŶƚƚŽƉĂŶĚƚĂŐŐĞĚĂƚ ϯϯϭϰΖdD͘WƌĞƐƐƵƌĞƚĞƐƚĞĚĐĞŵĞŶƚĞƋƵŝƉŵĞŶƚϮϱϬůŽǁͬϰϬϬϬŚŝŐŚ͕ŐŽŽĚƚĞƐƚ͘ĂƚĐŚĞĚĐĞŵĞŶƚĂŶĚůĂŝĚŝŶϰďďůƐŽĨϭϱ͘ϯ ůĂƐƐ'ĐĞŵĞŶƚϭĨŽƌϭĨƌŽŵϯϯϭϰΖĐƚŵƚŽϯϮϬϬΖĐƚŵ͘WKK,ƉƵŵƉŝŶŐƉŝƉĞĚŝƐƉůĂĐĞŵĞŶƚ͘ƚƐƵƌĨĂĐĞ͕WƌĞƐƐƵƌĞƚĞƐƚĞĚEϮ ŚĂƌĚůŝŶĞϮϱϬůŽǁͬϯϱϬϬŚŝŐŚ͕ŐŽŽĚƚĞƐƚ͘ůŽǁĚŽǁŶƌĞĞůƚŽƌĞƚƵƌŶƚĂŶŬ͘ZŝŐĚŽǁŶĐĞŵĞŶƚĞƌƐ͘>ĂǇĚŽǁŶŝŶũĞĐƚŽƌ͘>ĞĂǀĞ ŚŽƚŽŝůƚƌƵĐŬ͕EϮƵŶŝƚĂŶĚdƵŶŝƚƐƌŝŐŐĞĚƵƉŽŶǁĞůů͘dƌĞĞǀĂůǀĞƐĐůŽƐĞĚ͕ŐƌŽƵŶĚǀĂůǀĞƐĐůŽƐĞĚ͘tĂŝƚŝŶŐŽŶĐĞŵĞŶƚĨŽƌϯϲ ŚŽƵƌƐ͘ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ dh ϭͬϮϭͬϮϮ ϮͬϮϰͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ ^ZhϮϰϭͲϭϲ ϱϬͲϭϯϯͲϮϬϱϰϬͲϬϬͲϬϬ ϮϬϰͲϬϴϴ ϬϮͬϮϭͬϮϬϮϮͲDŽŶĚĂǇ Wdt͕:^ǁŝƚŚĐƌĞǁ͘tĂƌŵƵƉĞƋƵŝƉŵĞŶƚ͘WŝĐŬŝŶũĞĐƚŽƌŚĞĂĚĂŶĚϯϬΖŽĨůƵďƌŝĐĂƚŽƌ͘&ůƵŝĚƉĂĐŬƌĞĞů͘ZĞĞůǀŽůƵŵĞϯϰ͘ϲďďůƐ͘ ĂĨƚĞƌϭϴďďůƐƉƵŵƉĞĚĐŽŝůƉƌĞƐƐƵƌĞĚƵƉƚŽϯϰϬϬƉƐŝ͘ŽŝůĨůƵŝĚƉĂĐŬĞĚ͘DĂŬĞƵƉdWƵůůƚĞƐƚƚŽϰϬ<͘DĂŬĞƵƉƚŽŽůƐƚƌŝŶŐ ĚŽǁŶƚŽƚŚĞŝƌĐ^ƵďWƌĞƐƐƵƌĞƚĞƐƚƚŽϯϲϬϬƉƐŝ͘&ŝŶŝƐŚŵĂŬŝŶŐƵƉ,͘ d͘Ϯ͘ϭϮ&sdϳϱϮϴ͘Ϯ͘Ϯϱ,ĂŝůĞǇ:ĂƌƐϭϬϰ͘d:ŝƐĐŽYϬϯϭ͘Ϯ͘ϭϮ^<ϬϵϵϮ͘ƌŽƐƐKǀĞƌy&ϯϮϭϮ͘Ϯ͘ϭϮ,ĂŝůĞǇhZϲΗ ďůĂŶŬůĂĚĞƐϮϭϮϱͲϬϰϬϳ͘ƌŽƐƐKǀĞƌWyW&ϰϬϲϵ͕Ϯ͘ϭϮϯdŝƚĂŶ^dŵŽƚŽƌ<Ϭϲϵϯ͘Ϯ͘Ϯϱ,ĂŝůĞǇhZϲ͘ϮϱƵƉƉĞƌďůĂĚĞϰ͘ϳϱ ůŽǁĞƌϮϮϱKhZͲϬϳϬϵͲϬϬϮ͘ϯďůĂĚĞũƵŶŬŵŝůů&ϯϵϵϬ͘,ůĞŶŐƚŚϮϴ͘ϱϲΖ͘^ƚĂďŽŶǁĞůů͘WdƐƚĂĐŬϮϱϬͬϯϱϬϬƉƐŝ͘KƉĞŶƐǁĂď ǀĂůǀĞ͘ƚƵďŝŶŐϬƉƐŝ͘/ϱϱƉƐŝ͕KϭϮϬƉƐŝ͘ŽŶĨŝƌŵǁĞůůŝƐĨůƵŝĚƉĂĐŬĞĚƚŽƐƵƌĨĂĐĞ͘ůŽƐĞĐŚŽŬĞƐŬŝĚĂŶĚWdƚƵďŝŶŐĂŶĚ ĐĞŵĞŶƚƚŽϭϱϬϬƉƐŝĨŽƌϭϬŵŝŶƵƚĞƐ͘'ŽŽĚƚĞƐƚ͘ůĞĞĚƚŽŽƉĞŶƚŽƉƚĂŶŬĂŶĚZ/,͘WĞƌĨŽƌŵǁĞŝŐŚƚĐŚĞĐŬƐ͘ƌǇƚĂŐϯ͕ϬϰϭΖ dD͘WŝĐŬƵƉǁĞŝŐŚƚϴ<͘KŶůŝŶĞĚŽǁŶϭ͘ϳϱΗĐŽŝůƚĂŬŝŶŐƌĞƚƵƌŶƐƵƉĐŽŝůǆƚƵďŝŶŐĂŶŶƵůƵƐ͘ϭ͘ϲďďůƐͬŵŝŶĂƚϰϴϬϬƉƐŝ͘Z/, ĨƌŽŵϯϬϯϬΖĂŶĚƐƚĂƌƚƐĞĞŝŶŐŵŽƚŽƌǁŽƌŬĂƚϯ͕ϬϰϬΖdD͘ǀĞƌĂŐĞZKW͘ϮͲ͘ϰĨƚͬŵŝŶ͘WƵŵƉϭϬďďůŐĞůƐǁĞĞƉĂƚ͘'ĞůŽƵƚŽĨ ŶŽǌǌůĞďĂĐŬƌĞĂŵƵƉƚŽϯ͕ϬϯϮΖ͘'ĞůĂƚƐƵƌĨĂĐĞƐŚŽǁŝŶŐƐŽůŝĚƐ͘ĂĐŬƚŽďŽƚƚŽŵŵŝůůŝŶŐ͘D/ůůƚŽϯ͕ϬϳϲΖŚĂƐĞϮŶĚŐĞůƐǁĞĞƉ ƵƉƚŽƚƵďŝŶŐƚĂŝů͘ZƵŶďĂĐŬŝŶŚŽůĞĂŶĚĞŶŐĂŐĞĐĞŵĞŶƚ͘'ŽŽĚŵŽƚŽƌǁŽƌŬĂŶĚŐŽŽĚZKW͘DŝůůĚŽǁŶƚŽϯϬϵϯΖdDZKW ĚĞĐƌĞĂƐĞĚ͘DŝůůĞĚƚŽϯϬϵϴ͘ϭ͘ŚĂƐĞϭϬďďůŐĞůƐǁĞĞƚŝŶƚŽƚƵďŝŶŐƚĂŝů͘&ŝŶŝƐŚƉƵŵƉŝŶŐďŽƚƚŽŵƐƵƉ͘^ŚƵƚĚŽǁŶĂŶĚĐůŽƐĞ ĐŚŽŬĞ͘WdƚƵďŝŶŐƚŽϭϱϬϬƉƐŝĂŐĂŝŶ͘'ŽŽĚƚĞƐƚ͘WƵůůĞĚŝŶƚŽt>'ĂŶŶŽǁĞŝŐŚƚďŽďďůĞƐƐĞĞŶ͘ŽŶƚŝŶƵĞKK,͘ůŽƐĞŵĂƐƚĞƌ ĂŶĚƐǁĂďǀĂůǀĞ͘WŽƉŽĨĨǁĞůůƚŽŝŶ͘ĂůůĞĚŽƵƚŶŝŐŚƚĐƌĂŶĞŽƉĞƌĂƚŽƌƚŽŵŽŶŝƚŽƌƚŚĞƌƵǌĐƌĂŶĞ͘/ŶũĞĐƚŽƌ͕ůƵďƌŝĐĂƚŽƌĂŶĚ YƵĂĚĐŽ,ĂƐƐĞŵďůǇ͘ ϬϮͬϮϮͬϮϬϮϮͲdƵĞƐĚĂǇ Wdt͕:^ǁŝƚŚĐƌĞǁƐ͘ZŝŐĚŽǁŶĐŽŝůƚŽŽůƐĂŶĚŝŶũĞĐƚŽƌŚĞĂĚ͘DĂŬĞƌŽŽŵĨŽƌ<ĞͲůŝŶĞ͘Wdt͕:^ǁŝƚŚ<ͲůŝŶĞ͘Z/ŐƵƉ͘Wd ůƵďƌŝĐĂƚŽƌϮϱϬͬϭϱϬϬƉƐŝ͘Z/,͘dĂŐWdĂŶĚ>K'KK,͘dĂŐĚĞƉƚŚϯϭϬϯΖ>D͘ZŝŐĚŽǁŶ<ͲůŝŶĞ͘WŝĐŬƵƉ^>ŝŶũĞĐƚŽƌ ŚĞĂĚ͘^ƚĂďŽŶǁĞůů͘WdůƵďƌŝĐĂƚŽƌϮϱϬͬϯϱϬϬƉƐŝ͘KƉĞŶǁĞůů͘WƌĞƐƐƵƌĞƚĞƐƚƚƵďŝŶŐƚŽϭϱϬϬƉƐŝĨŽƌϭϬŵŝŶƵƚĞƐǁŝƚŚĐŚĂƌƚ͘ 'ŽŽĚWd͘Z/,ǁŝƚŚϭ͘ϳϱΗdĂŶĚďĂůůĚƌŽƉŶŽǌǌůĞ͘ŽŽůĚŽǁŶEϮǁŚŝůĞƌƵŶŶŝŶŐŝŶŚŽůĞ͘dĂŐWdǁŝƚŚĐŽŝůĂƚϯϭϬϬ͘ϳdD͘ WĂƌŬĞĚĂƚϯϭϬϬΖŽŶůŝŶĞǁŝƚŚEϮĂƚϮϱϬϬƐĐĨͬŵŝŶ͘tĞůůŝƐďůŽǁŶĚƌǇ͘WKK,ůĞĂǀĞϭϬϱϬƉƐŝ^/dW͘ϳϳ͕ϴϯϵƐĐĨƉƵŵƉĞĚ͘ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ dh ϭͬϮϭͬϮϮ ϮͬϮϰͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ ^ZhϮϰϭͲϭϲ ϱϬͲϭϯϯͲϮϬϱϰϬͲϬϬͲϬϬ ϮϬϰͲϬϴϴ <ͲůŝŶĞĂƌƌŝǀĞĂƚůŽĐĂƚŝŽŶ͘ ŽŶĚƵĐƚ:^ĂŶĚĂƉƉƌŽǀĞWdt͘ ^ƉŽƚĞƋƵŝƉŵĞŶƚĂŶĚDhϮΗǆϰΖƉĞƌĨŐƵŶ͘ ůĞĞĚĚŽǁŶƚƵďŝŶŐƉƌĞƐƐƵƌĞĨƌŽŵϵϬϬƉƐŝƚŽϴϬϬƉƐŝ͘ ^ƚĂďůƵďƌŝĐĂƚŽƌŽŶƚŽǁĞůů͘ƚƚĞŵƉƚƚŽWd͕ŚĂǀŝŶŐŝƐƐƵĞƐǁŝƚŚƚƌŝͲƉůĞǆ͘ ^ǁĂƉŽƵƚƚƌŝͲƉůĞǆĂŶĚWdůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϭϱϬϬƉƐŝŚŝŐŚ͘KƉĞŶǁĞůůĂŶĚZ/,ǁŝƚŚƉĞƌĨŐƵŶ͘ 'Zͬ>ƚŽƚŽƉƐŚŽƚсϵ͘ϯΖ ^ĞŶĚĐŽƌƌĞůĂƚŝŽŶĚĂƚĂƚŽZͬ'K͘ĚĚϭΖƚŽŐĞƚŽŶĚĞƉƚŚ͘WĞƌĨŽƌĂƚĞϯϬϴϮͲϯϬϴϲΖ;^ƚĞƌůŝŶŐϵͿ /ŶŝƚŝĂůƉƌĞƐƐƵƌĞсϴϬϴƉƐŝ͘ ϱŵŝŶсϴϬϴƉƐŝ͘ ϭϬŵŝŶсϴϬϴƉƐŝ ϭϱŵŝŶсϴϬϳƉƐŝ͘ ŽŶĨŝƌŵĂůůƐŚŽƚƐĨŝƌĞĚ͘'ƵŶŝƐĚƌǇ͘ZDK͘ ϬϮͬϮϰͬϮϬϮϮͲdŚƵƌƐĚĂǇ hƉĚĂƚĞĚďǇZZϬϯͲϭϬͲϮϮ ^,Dd/ ^ZhϮϰϭͲϭϲ Wd͗ϮϬϰͲϬϴϴ W/͗ϱϬͲϭϯϯͲϮϬϱϰϬͲϬϬͲϬϬ ϭ dсϰ͕ϮϲϰΖDͬϯ͕ϲϯϲ͛ds Wdсϯ͕ϭϬϯ͛DͬϮ͕ϱϭϯ͛ds Z<сϯϯϴ͘ϱΖͬ'>сϯϭϴ͘Ϭ͛D^> Z<ƚŽd,&сϮϬ͘ϱ͛ ^/E'd/> ^ŝǌĞtƚ'ƌĂĚĞŽŶŶ/dŽƉƚŵ ϭϲΗϲϴ:ͲϱϱtĞůĚ^ƵƌĨ͘ϲϲ͘ϱΖ ϵͲϱͬϴΗϰϬ>ͲϴϬdϴ͘ϴϯϱΗ^ƵƌĨ͘ϭ͕ϱϱϯΖ ϳϮϲ>ͲϴϬdϲ͘ϮϳϲΗ^ƵƌĨ͘ϰ͕ϮϲϰΖ dh/E'd/> ϮͲϳͬϴΗϲ͘ϰ>ͲϴϬ/dϮ͘ϰϰϭΗ^ƵƌĨϮ͕Ϯϲϳ͛ :t>Zzd/> EŽ͘ĞƉƚŚ//ƚĞŵ ϭϮϱ͛Ϯ͘ϰϰϭΗƌŽƐƐͲKǀĞƌϰͲϭͬϮΗϭϮ͘ϲηǆϮͲϳͬϴΗϲ͘ϰη/dŽǆǆWŝŶ ϮϮ͕Ϯϰϭ͛Ϯ͘ϯϲϬ͟ϳ͟,^W,>WƌŽĚƵĐƚŝŽŶWĂĐŬĞƌ ϯϮ͕ϮϱϬ͛Ϯ͘ϯϭϯ͟yEŝƉƉůĞWƌŽĨŝůĞ ϰϮ͕Ϯϲϳ͛Ϯ͘ϰϰϭΗtŝƌĞ>ŝŶĞŶƚƌǇ'ƵŝĚĞ;Ϯ͕Ϯϳϳ͛>DͿ ϱϯ͕ϭϬϯ͛ Ͳ ĞŵĞŶƚWůƵŐůĂŝĚŝŶǁŝƚŚdŽŶϭͬϮϭͬϮϮ͘dƵŶĚĞƌƌĞĂŵĞĚƚŽĐƵƌƌĞŶƚ ĚĞƉƚŚϮͬϮϭͬϮϮ͘WĂƐƐĞĚĂWdƚŽϭϱϬϬƉƐŝŽŶϮͬϮϮͬϮϮ͘>ƚĂŐŐĞĚĂƚ ϯϭϬϯ͛>DŽŶϮͬϮϮͬϮϮ ϲϯ͕ϯϰϱ͛Ͳ^ƉŝƌĂůddWʹdKΛϯ͕ϯϬϳ͛D;ϭϬͬϮϴͬϮϭͿ ϳϯ͕ϰϱϬ͛Ͳ/WƐĞƚŽŶƌŝŐǁͬϯϱ͛ĐĞŵĞŶƚʹdKΛϯ͕ϰϭϱ͛;ϵͬϯϬͬϮϬͿ ϴϯ͕ϲϭϴ͛Ͳ^ƉŝƌĂůWůƵŐǁͬĐĞŵĞŶƚʹdKΛϯ͕ϱϲϬ͛;ϴͬϳͬϮϬͿ ϵϯ͕ϳϭϱͲ^ƉŝƌĂůWůƵŐǁͬĐĞŵĞŶƚʹdKΛϯ͕ϲϴϬ͛;ϳͬϮϬͬϮϬͿ ϭϬϯ͕ϳϳϮ͛ͲddWůƵŐƐƐĞŵďůǇǁͬΕϮϮ͘ϱ͛ĐĞŵĞŶƚϰͬϮϭͬϭϱ͘dŽĂƚϯϳϳϮ͛D ϭϭϯ͕ϴϱϬ͛ͲĞŵĞŶƚ;ϱďďůƐŽĨϭϱ͘ϴη>ydĞŵĞŶƚͿ͗dŽϯϴϱϬ͛D ϭϭϯ͕ϵϱϱ͛Ͳ&ĂŝůĞĚWŽƐŝƐĞƚWůƵŐ;ƉƵƐŚĞĚĚŽǁŶŚŽůĞǁͬĐŽŝůϱͬϯϬͬϬϴͿ ϭϮhŶŬŶŽǁŶͲ&ĂŝůĞĚdd^hŵďƌĞůůĂWůƵŐ;ĚŝĚŶŽƚƚĂŐĂƚϰ͕ϬϯϬ͛ϱͬϮϵͬϬϳͿ WZ&KZd/KEd/> ĂƚĞŽŶĞdŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ ŵƚ'ƵŶ^ŝǌĞŽŵŵĞŶƚƐ ϮͬϮϰͬϮϮͲϵϯ͕ϬϴϮ͛ϯ͕Ϭϴϲ͛Ϯ͕ϰϵϰ͛Ϯ͕ϰϵϴ͛ϰ͛Ϯ͟KƉĞŶ ϭϬͬϯϭͬϮϭͲϭϭhϯ͕Ϯϲϵ͛ϯ͕Ϯϳϰ͛Ϯ͕ϲϲϯ͛Ϯ͕ϱϱϴ͛ϱ͛Ϯ͟/ƐŽůĂƚĞĚ;ϭͬϮϮͬϮϮͿ ϯͬϯϬͬϮϭͲϭϭ>ϯ͕ϯϲϳ͛ϯ͕ϯϲϵ͛Ϯ͕ϳϱϱ͛Ϯ͕ϳϱϲ͛Ϯ͛ϭ͘ϳϱ͟/ƐŽůĂƚĞĚ;ϭϬͬϮϴͬϮϭͿ ϭϬͬϭϯͬϮϬͲϭϮϯ͕ϯϳϴ͛ϯ͕ϯϴϳ͛Ϯ͕ϳϲϱ͛Ϯ͕ϳϳϯϵ͛ϭ͘ϳϱ͟/ƐŽůĂƚĞĚ;ϭϬͬϮϴͬϮϭͿ ϴͬϭϭͬϮϬͲϭϰϯ͕ϰϲϴ͛ϯ͕ϰϳϲ͛Ϯ͕ϴϰϴ͛Ϯ͕ϴϵϰ͛ϴ͛ϭ͘ϳϱ͟/ƐŽůĂƚĞĚ ϳͬϮϬͬϮϬͲϮϯ͕ϲϲϳ͛ϯ͕ϲϳϮ͛ϯ͕Ϭϰϯ͛ϯ͕Ϭϰϴ͛ϱ͛ϭ͘ϳϱ͟/ƐŽůĂƚĞĚ ϲͬϮϰͬϮϬͲϯϯ͕ϳϮϴ͛ϯ͕ϳϯϯ͛ϯ͕ϭϬϯ͛ϯ͕ϭϬϴ͛ϱ͛ϭ͘ϳϱ͟/ƐŽůĂƚĞĚ ϰͬϮϲͬϭϱϰ>ϯ͕ϳϲϱ͛ϯ͕ϳϳϬ͛ϯ͕ϭϯϵ͛ϯ͕ϭϰϰ͛ϱ͛Ϯ͟/ƐŽůĂƚĞĚ ϰͬϭϭͬϭϮͲϰϯ͕ϴϬϯ͛ϯ͕ϴϭϬ͛ϯ͕ϭϳϳ͛ϯ͕ϭϴϰ͛ϱ͛ϭͲϭϭͬϭϲ͟/ƐŽůĂƚĞĚ ϲͬϬϲͬϬϴͲϰϯ͕ϴϬϱ͛ϯ͕ϴϭϬ͛ϯ͕ϭϳϵ͛ϯ͕ϭϴϰ͛ϱ͛ϭͲϭϭͬϭϲ͟/ƐŽůĂƚĞĚ ϵͬϭϲͬϬϰͲϲϰ͕ϬϮϳ͛ϰ͕ϬϯϮ͛ϯ͕ϰϬϬ͛ϯ͕ϰϬϰ͛ϱ͛Ϯ͘Ϭ͟/ƐŽůĂƚĞĚ ϵͬϭϲͬϬϰͲϲϰ͕Ϭϯϯ͛ϰ͕Ϭϯϳ͛ϯ͕ϰϬϱ͛ϯ͕ϰϬϵ͛ϰ͛Ϯ͘Ϭ͟/ƐŽůĂƚĞĚ ϵͬϭϱͬϬϰͲϲϰ͕ϬϮϳ͛ϰ͕ϬϯϮ͛ϯ͕ϰϬϬ͛ϯ͕ϰϬϰ͛ϱ͛Ϯ͘Ϭ͟/ƐŽůĂƚĞĚ Ͳϲ ϯͬϰ Ϯ Ͳϰ ; ϭϬ ϭϭͬ ϭϮ ϭϲ͟ ϵͲϱͬϴ͟ ϳ͟ Ͳϰ> dKΛϮ͕ϭϳϬ͛ ϭϰ Ϯ ϯ ϵ ϴ ϭϭ>ͬ ϭϮ ϳ ϲ ϭϭh dKΛϯ͕ϰϭϱ͛ dKΛϯ͕ϱϲϬ͛ dKΛϯ͕ϲϴϬ͛ dKΛϯ͕ϳϳϮ͛ dKΛϯ͕ϴϱϬ͛ ϱ Ͳϵ Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 3/08/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SRU 241-16 (PTD 204-088) TAG 2/22/2022 PERF 2/24/2022 Please include current contact information if different from above. 204-088 T36410 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.08 14:08:15 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Ryan Rupert Cc:Donna Ambruz; Dan Marlowe Subject:RE: SRU 241-16 (PTD#204-088) Date:Friday, February 4, 2022 4:15:00 PM Ryan, You have approval to proceed as outlined in your email below. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Friday, February 4, 2022 11:36 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: SRU 241-16 (PTD#204-088) Bryan- Per our conversation, this is just a heads up work completed, and path forward for SRU 241-16. thanks CT FCO completed down to PBTD = 3307’ MD CT laid in 4 bbls cement (~100’) to isolate the open A-11U perfs After WoC, ToC was found much higher than anticipated at 3055’ MD Hilcorp plans to bring CT back in and test BOP’s to 250/3500 CT then to underream cement to at least 3100’ MD (possibly deeper) to regain access to the A-9 interval (behind pipe currently) Hilcorp will then perforate per the approved sundry. Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 1/12/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SRU 241-16 (PTD 204-088) GPT-PLUG-PERF 10/28/2021 Please include current contact information if different from above. 37' (6HW eceived By: 01/12/2022 By Abby Bell at 10:50 am, Jan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a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y Samantha Carlisle at 8:27 am, Dec 15, 2021 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH 6)' ; %-0 &7 '65 &7 %23 WHVW WR SVL dts 12/27/2921 Jeremy Price Digitally signed by Jeremy Price Date: 2021.12.27 09:25:44 -09'00' RBDMS HEW 12/28/2021 tĞůů͗^ZhϮϰϭͲϭϲ tĞůůEĂŵĞ͗^ZhϮϰϭͲϭϲ W/EƵŵďĞƌ͗ϱϬͲϭϯϯͲϮϬϱϬϰͲϬϬͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗'ĂƐWƌŽĚƵĐĞƌ >ĞŐ͗Eͬ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ŽŶŶĂŵďƌƵǌϳϳϳͲϴϯϬϱ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϬϰͲϬϴϴ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ZǇĂŶZƵƉĞƌƚ ;ϵϬϳͿϳϳϳͲϴϱϬϯ;KͿ ;ϵϬϳͿϯϬϭͲϭϳϯϲ;Ϳ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗:ĂŬĞ&ůŽƌĂ ;ϳϮϬͿϵϴϴͲϱϯϳϱ;Ϳ DĂǆ͘ǆƉĞĐƚĞĚ,W͗Εϭ͕ϭϲϳƉƐŝΛϮ͕ϱϴϴ͛ds ĂƐĞĚŽŶϬ͘ϰϱƉƐŝͬĨƚƚŽͲϭϭƵƉĞƌĨƐ DĂǆ͘WŽƚĞŶƚŝĂů^ƵƌĨĂĐĞWƌĞƐƐƵƌĞ ΕϵϬϲƉƐŝ ĂƐĞĚŽŶϬ͘ϭƉƐŝͬĨƚƚŽƐƵƌĨĂĐĞ tĞůů^ƵŵŵĂƌǇ ^ZhϮϰϭͲϭϲǁĂƐƌĞĐĞŶƚůǇƉůƵŐŐĞĚďĂĐŬĂŶĚƉĞƌĨ͛ĚŝŶƚŚĞͲϭϭƵ͘dŚĞǁĞůůĐĂŵĞŽŶĂƚΕϴϬϬŵĐĨĚ͕ďƵƚŽŶůǇůĂƐƚĞĚ ΕϭϬĚĂǇƐ͘^ƵďƐĞƋƵĞŶƚ^>ƚĂŐƐĨŽƵŶĚĨŝůůĂƚϮϬϬϬ͛͘DƵůƚŝƉůĞĚĂǇƐŽĨ^>ďĂŝůŝŶŐǁĞƌĞƵŶĂďůĞƚŽŐĞƚĚŽǁŶƉĂƐƚƚŚĞ ƚƵďŝŶŐƚĂŝů͘'ŝǀĞŶƚŚŝƐƐĂŶĚƉƌŽĚƵĐƚŝŽŶ͕ĂŶĚƉŽƚĞŶƚŝĂůƵƉŚŽůĞ,ŝůĐŽƌƉƉƌŽƉŽƐĞƐƚŽƉůƵŐďĂĐŬĂŶĚŐŽĂĨƚĞƌ ĂĚĚŝƚŝŽŶĂůŚŝŐŚĞƌƐƚĞƌůŝŶŐƐĂŶĚƐŝŶƚŚŝƐǁĞůů͘ dŚĞŐŽĂůŽĨƚŚŝƐƉƌŽũĞĐƚŝƐĐůĞĂŶŽƵƚƚŚĞǁĞůůďŽƌĞ͕ŝƐŽůĂƚĞĞǆŝƐƚŝŶŐƉĞƌĨƐ͕ĂŶĚƌĞĐŽŵƉůĞƚĞŝŶƚŚĞƵƉƉĞƌ^ƚĞƌůŝŶŐ;Ăůů ǁŝƚŚŝŶƚŚĞ^ƚĞƌůŝŶŐͬhƉƉĞƌĞůƵŐĂWŽŽůĂŶĚWͿ ,ŝůĐŽƌƉŝƐƐĞĞŬŝŶŐĂ>DǀĂƌŝĂŶĐĞƚŽĂďĂŶĚŽŶƚŚĞĞǆŝƐƚŝŶŐƉĞƌĨƐǁŝƚŚĂϯϱ͛ĐĞŵĞŶƚĐŽůƵŵŶŽŶƚŽƉŽĨĞǆŝƐƚŝŶŐ Ĩŝůů͘dŚŝƐǁŝůůƌĞĚƵĐĞƌŝƐŬĚƵƌŝŶŐƚŚĞ&KďǇŶŽƚƵŶĐŽǀĞƌŝŶŐƚŚĞƉĞƌĨƐĂƐĂƉŽƚĞŶƚŝĂůƐŽůŝĚƐŝŶĨůƵǆͬůŽƐƚĐŝƌĐƵůĂƚŝŽŶ ǌŽŶĞ͕ǁŚŝůĞĂůƐŽƉƌĞƐĞƌǀŝŶŐŵĂǆŝŵƵŵƌĂƚŚŽůĞĨŽƌƵƉŚŽůĞ^ƚĞƌůŝŶŐƐĂŶĚĚĞǀĞůŽƉŵĞŶƚ͘,ŝůĐŽƌƉĂůƐŽƌĞƋƵĞƐƚƐƚŚĂƚ ƚŚŝƐĐĞŵĞŶƚƉůƵŐ;ŽƌĐŽŶƚŝŶŐĞŶĐǇddWͿďĞƐĞƚфϱϬ͛ĂďŽǀĞĞǆŝƐƚŝŶŐƉĞƌĨƐ͘ EŽƚĞƐZĞŐĂƌĚŝŶŐtĞůůďŽƌĞŽŶĚŝƚŝŽŶ x DŝŶ/сϮ͘ϯϭϯ͟ĂƚϮ͕ϮϱϬ͛D;ϮͲϳͬϴ͟yͲŶŝƉƉůĞͿ x /ŶĐůŝŶĂƚŝŽŶ o DĂǆсϱϮĚĞŐƌĞĞƐĂƚϭϴϱϬ͛D o /ŶĐůŝŶĂƚŝŽŶĨƌŽŵϯϮϬϬʹϯϯϬϬ͛D͗ϮϱͲϯϬĚĞŐƌĞĞƐ x ZĞĐĞŶƚŚŝƐƚŽƌǇ o ϭϬͬϭϬͬϮϭ͗ dƐƵĐĐĞƐƐĨƵůůǇƉĞƌĨŽƌŵĞĚ&KĨƌŽŵϯϭϴϳ͛ʹϯϯϱϰ͛ ϭ͘ϳϱ͟:^E, 'Žƚϭ͗ϭƌĞƚƵƌŶƐǁŝƚŚǁĂƚĞƌŚŽůĚŝŶŐϴϬϬƉƐŝŽŶǁĞůů o ϭϬͬϯϭͬϮϭ͗ >ƐƵĐĐĞƐƐĨƵůůǇƉĞƌĨ͛ĚǁŝƚŚĂϮ͟ŐƵŶĚŽǁŶƚŽϯϮϳϰ͛D o ϭϭͬϭϰͬϮϭ ^>ďĂŝůĞĚͬĐŚŝƐĞůĞĚĨŝůůĨŽƌϰĚĂǇƐ DĂĚĞŝƚĚŽǁŶƚŽϮϭϮϬ͛^>D ĐůĞĂŶŽƵƚƚŚĞǁĞůůďŽƌĞ͕ŝƐŽůĂƚĞĞǆŝƐƚŝŶŐƉĞƌĨƐ͕ĂŶĚƌĞĐŽŵƉůĞƚĞŝŶƚŚĞƵƉƉĞƌ^ƚĞƌůŝŶŐ tĞůů͗^ZhϮϰϭͲϭϲ d&K ϭ͘ D/Zhd Ϯ͘ WdKW͛ƐƚŽϮϱϬůŽǁͬϯϱϬϬŚŝŐŚ ϯ͘ DhĂŶĚZ/,ǁŝƚŚ:^E ϰ͘ KďƚĂŝŶĚƌǇƚĂŐ;ĞǆƉĞĐƚĞĚΕϮϭϬϬ͛DͿ ϱ͘ WĞƌĨŽƌŵ&KƵƐŝŶŐƉƌŽĚƵĐĞĚŽƌƐŽƵƌĐĞǁĂƚĞƌĂŶĚŶŝƚƌŽŐĞŶ͕ŝĨŶĞĞĚĞĚ ϲ͘ ůĞĂŶŽƵƚƚŽϯϮϱϬ͛D͘dŚĞƌĞ͛ƐŶŽŶĞĞĚƚŽƵŶĐŽǀĞƌƚŚĞĞǆŝƐƚŝŶŐƉĞƌĨƐ ϳ͘ WƵůůƵƉŚŽůĞĂŶĚŽďƚĂŝŶĚƌǇƚĂŐ ϴ͘ WKK,ĨůƵŝĚƉĂĐŬŝŶŐǁĞůůďŽƌĞ͘ůĞĞĚŽĨĨĂŶǇǁĞůůŚĞĂĚƉƌĞƐƐƵƌĞ;ǁĂŶƚƐƚĂƚŝĐĨŽƌĐĞŵĞŶƚŝŶŐͿ ϵ͘ DhĂŶĚZ/,ǁŝƚŚĐĞŵĞŶƚŝŶŐŶŽǌǌůĞ ϭϬ͘ KďƚĂŝŶĚƌǇƚĂŐ ϭϭ͘ >ĂǇŝŶĐĞŵĞŶƚƉůƵŐ Ă͘ WƵŵƉϯϱ͛ŽĨĐĞŵĞŶƚŝŶϳ͟;ϭ͘ϯďďůƐͬϱϯŐĂůͿ ď͘ tĂŶƚdŽŶŽŚŝŐŚĞƌƚŚĂŶϯϭϴϬ͛D͕ƉƌĞĨĞƌĂďůǇůŽǁĞƌ ϭϮ͘ WKK,ĂŶĚtŽ ϭϯ͘ ůŽǁǁĞůůĚƌǇǁŝƚŚŶŝƚƌŽŐĞŶ ϭϰ͘ dƌĂƉEϮƉƌĞƐƐƵƌĞŽŶǁĞůůƉĞƌK ϭϱ͘ ZDKd >WůƵŐŽŶƚŝŶŐĞŶĐǇ͗/ĨĞǆŝƐƚŝŶŐƉĞƌĨƐĂƌĞŶ͛ƚŝƐŽůĂƚĞĚǀŝĂĐĞŵĞŶƚŽŶdƌŝŐƵƉ ϭ͘ D/Zh>ĞƋƵŝƉŵĞŶƚ Ϯ͘ WdKW͛ƐƚŽϮϱϬůŽǁͬϭϱϬϬŚŝŐŚ ϯ͘ Z/,ĂŶĚƐĞƚĞǆƉĂŶĚĂďůĞddWďĞƚǁĞĞŶцϯϮϭϵ͚ʹцϯϮϱϬ͛D;ƚŚĞĚĞĞƉĞƌƚŚĞďĞƚƚĞƌͿ ϰ͘ ƵŵƉďĂŝůϯϱ͛ŽĨĐĞŵĞŶƚŽŶƚŽƉŽĨƉůƵŐ tĞůů͗^ZhϮϰϭͲϭϲ Ͳ>ŝŶĞWĞƌĨ ϭ͘ D/Zh>ĞƋƵŝƉŵĞŶƚ Ϯ͘ WdKW͛ƐƚŽϮϱϬůŽǁͬϭϱϬϬŚŝŐŚ ϯ͘ WĞƌĨŽƌĂƚĞƚŚĞƐĂŶĚƐůŝƐƚĞĚŝŶƚŚĞƚĂďůĞďĞůŽǁ͕ƉĞƌ'ĞŽͬZ͘;ĂůůǁŝƚŚŝŶ^ƚĞƌůŝŶŐͬhƉƉĞƌĞůƵŐĂWŽŽů ĂŶĚWͿ ^ĂŶĚ WĞƌĨŽƌĂƚŝŽŶ dŽƉ;DͿ WĞƌĨŽƌĂƚŝŽŶ ŽƚƚŽŵ;DͿ WĞƌĨŽƌĂƚŝŽŶdŽƉ ;dsͿ WĞƌĨŽƌĂƚŝŽŶ ŽƚƚŽŵ;dsͿ dŽƚĂů&ŽŽƚĂŐĞ ;DͿ ^ƚĞƌůŝŶŐϵ цϯ͕Ϭϱϲ͛ цϯ͕ϭϮϮ͛ цϮ͕ϰϳϮ цϮ͕ϱϯϬ цϲϲ͛ ^ƚĞƌůŝŶŐϭϬ цϯ͕ϭϯϬ͛ цϯ͕ϭϳϬ͛ цϮ͕ϱϯϳ цϮ͕ϱϳϯ цϰϬ͛ ϰ͘ ZͲ>ŝŶĞhŶŝƚĂŶĚƚƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ͘ ŽŶƚŝŶŐĞŶĐǇ>WůƵŐ͗/ĨĂƐĂŶĚŝƐĨŽƵŶĚƚŽŵĂŬĞƐŽůŝĚƐͬǁĂƚĞƌ ϭ͘ D/ZhͲůŝŶĞ͕WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϭ͕ϱϬϬƉƐŝŚŝŐŚ Ϯ͘ Z/,tͬ'WdƚŽŽůĂŶĚĨŝŶĚĨůƵŝĚůĞǀĞů ϯ͘ Z/,ĂŶĚƐĞƚǆƉĂŶĚĂďůĞddWƉůƵŐƉĞƌK͗tŝůůŶĞĞĚƚŽďĞцϱϬ͛ĂďŽǀĞƚŽƉƉĞƌĨ͕ĂŶĚĐĂƉƉĞĚǁŝƚŚϯϱ͛ ĐĞŵĞŶƚ͕ƵŶůĞƐƐĂǀĂƌŝĂŶĐĞŝƐŽďƚĂŝŶĞĚƚŚƌŽƵŐŚ>D͘ ϰ͘ ZͲ>ŝŶĞhŶŝƚĂŶĚƚƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƵƌƌĞŶƚƐĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ dKW^ĐŚĞŵĂƚŝĐ ϰ͘ EϮƉƌŽĐĞĚƵƌĞ hƉĚĂƚĞĚďǇDϭϮͲϭϬͲϮϭ ^,Dd/ ^ZhϮϰϭͲϭϲ Wd͗ϮϬϰͲϬϴϴ W/͗ϱϬͲϭϯϯͲϮϬϱϰϬͲϬϬͲϬϬ ϭ dсϰ͕ϮϲϰΖDͬϯ͕ϲϯϲ͛ds Wdсϯ͕ϯϬϳ͛DͬϮ͕ϲϵϵ͛ds DĂǆŚŽůĞĂŶŐůĞсϱϭ͘ϱqΛϭ͕ϴϮϮ͛ Z<сϯϯϴ͘ϱΖͬ'>сϯϭϴ͘Ϭ͛D^> Z<ƚŽd,&сϮϬ͘ϱ͛ ^/E'd/> ^ŝǌĞtƚ'ƌĂĚĞŽŶŶ/dŽƉƚŵ ϭϲΗϲϴ:ͲϱϱtĞůĚ^ƵƌĨ͘ϲϲ͘ϱΖ ϵͲϱͬϴΗϰϬ>ͲϴϬdϴ͘ϴϯϱΗ^ƵƌĨ͘ϭ͕ϱϱϯΖ ϳϮϲ>ͲϴϬdϲ͘ϮϳϲΗ^ƵƌĨ͘ϰ͕ϮϲϰΖ dh/E'd/> ϮͲϳͬϴΗϲ͘ϰ>ͲϴϬ/dϮ͘ϰϰϭΗ^ƵƌĨϮ͕Ϯϲϳ͛ :t>Zzd/> EŽ͘ĞƉƚŚ//ƚĞŵ ϭϮϱ͛Ϯ͘ϰϰϭΗƌŽƐƐͲKǀĞƌϰͲϭͬϮΗϭϮ͘ϲηǆϮͲϳͬϴΗϲ͘ϰη/dŽǆǆWŝŶ ϮϮ͕Ϯϰϭ͛Ϯ͘ϯϲϬ͟ϳ͟,^W,>WƌŽĚƵĐƚŝŽŶWĂĐŬĞƌ ϯϮ͕ϮϱϬ͛Ϯ͘ϯϭϯ͟yEŝƉƉůĞWƌŽĨŝůĞ ϰϮ͕Ϯϲϳ͛Ϯ͘ϰϰϭΗtŝƌĞ>ŝŶĞŶƚƌǇ'ƵŝĚĞ ϱϯ͕ϯϰϱ͛Ͳ^ƉŝƌĂůddWʹdKΛϯ͕ϯϬϳ͛D;ϭϬͬϮϴͬϮϭͿ ϲϯ͕ϰϱϬ͛Ͳ/WƐĞƚŽŶƌŝŐǁͬϯϱ͛ĐĞŵĞŶƚʹdKΛϯ͕ϰϭϱ͛;ϵͬϯϬͬϮϬͿ ϳϯ͕ϲϭϴ͛Ͳ^ƉŝƌĂůWůƵŐǁͬĐĞŵĞŶƚʹdKΛϯ͕ϱϲϬ͛;ϴͬϳͬϮϬͿ ϴϯ͕ϳϭϱͲ^ƉŝƌĂůWůƵŐǁͬĐĞŵĞŶƚʹdKΛϯ͕ϲϴϬ͛;ϳͬϮϬͬϮϬͿ ϵϯ͕ϳϳϮ͛ͲddWůƵŐƐƐĞŵďůǇǁͬΕϮϮ͘ϱ͛ĐĞŵĞŶƚϰͬϮϭͬϭϱ͘dŽĂƚϯϳϳϮ͛D ϭϬϯ͕ϴϱϬ͛ͲĞŵĞŶƚ;ϱďďůƐŽĨϭϱ͘ϴη>ydĞŵĞŶƚͿ͗dŽϯϴϱϬ͛D ϭϬϯ͕ϵϱϱ͛Ͳ&ĂŝůĞĚWŽƐŝƐĞƚWůƵŐ;ƉƵƐŚĞĚĚŽǁŶŚŽůĞǁͬĐŽŝůϱͬϯϬͬϬϴͿ ϭϭhŶŬŶŽǁŶͲ&ĂŝůĞĚdd^hŵďƌĞůůĂWůƵŐ;ĚŝĚŶŽƚƚĂŐĂƚϰ͕ϬϯϬ͛ϱͬϮϵͬϬϳͿ WZ&KZd/KEd/> ĂƚĞŽŶĞdŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ ŵƚ'ƵŶ^ŝǌĞŽŵŵĞŶƚƐ ϭϬͬϯϭͬϮϭͲϭϭhϯ͕Ϯϲϵ͛ϯ͕Ϯϳϰ͛Ϯ͕ϲϲϯ͛Ϯ͕ϱϱϴ͛ϱ͛Ϯ͟KƉĞŶ ϯͬϯϬͬϮϭͲϭϭ>ϯ͕ϯϲϳ͛ϯ͕ϯϲϵ͛Ϯ͕ϳϱϱ͛Ϯ͕ϳϱϲ͛Ϯ͛ϭ͘ϳϱ͟/ƐŽůĂƚĞĚ;ϭϬͬϮϴͬϮϭͿ ϭϬͬϭϯͬϮϬͲϭϮϯ͕ϯϳϴ͛ϯ͕ϯϴϳ͛Ϯ͕ϳϲϱ͛Ϯ͕ϳϳϯϵ͛ϭ͘ϳϱ͟/ƐŽůĂƚĞĚ;ϭϬͬϮϴͬϮϭͿ ϴͬϭϭͬϮϬͲϭϰϯ͕ϰϲϴ͛ϯ͕ϰϳϲ͛Ϯ͕ϴϰϴ͛Ϯ͕ϴϵϰ͛ϴ͛ϭ͘ϳϱ͟/ƐŽůĂƚĞĚ ϳͬϮϬͬϮϬͲϮϯ͕ϲϲϳ͛ϯ͕ϲϳϮ͛ϯ͕Ϭϰϯ͛ϯ͕Ϭϰϴ͛ϱ͛ϭ͘ϳϱ͟/ƐŽůĂƚĞĚ ϲͬϮϰͬϮϬͲϯϯ͕ϳϮϴ͛ϯ͕ϳϯϯ͛ϯ͕ϭϬϯ͛ϯ͕ϭϬϴ͛ϱ͛ϭ͘ϳϱ͟/ƐŽůĂƚĞĚ ϰͬϮϲͬϭϱϰ>ϯ͕ϳϲϱ͛ϯ͕ϳϳϬ͛ϯ͕ϭϯϵ͛ϯ͕ϭϰϰ͛ϱ͛Ϯ͟/ƐŽůĂƚĞĚ ϰͬϭϭͬϭϮͲϰϯ͕ϴϬϯ͛ϯ͕ϴϭϬ͛ϯ͕ϭϳϳ͛ϯ͕ϭϴϰ͛ϱ͛ϭͲϭϭͬϭϲ͟/ƐŽůĂƚĞĚ ϲͬϬϲͬϬϴͲϰϯ͕ϴϬϱ͛ϯ͕ϴϭϬ͛ϯ͕ϭϳϵ͛ϯ͕ϭϴϰ͛ϱ͛ϭͲϭϭͬϭϲ͟/ƐŽůĂƚĞĚ ϵͬϭϲͬϬϰͲϲϰ͕ϬϮϳ͛ϰ͕ϬϯϮ͛ϯ͕ϰϬϬ͛ϯ͕ϰϬϰ͛ϱ͛Ϯ͘Ϭ͟/ƐŽůĂƚĞĚ ϵͬϭϲͬϬϰͲϲϰ͕Ϭϯϯ͛ϰ͕Ϭϯϳ͛ϯ͕ϰϬϱ͛ϯ͕ϰϬϵ͛ϰ͛Ϯ͘Ϭ͟/ƐŽůĂƚĞĚ ϵͬϭϱͬϬϰͲϲϰ͕ϬϮϳ͛ϰ͕ϬϯϮ͛ϯ͕ϰϬϬ͛ϯ͕ϰϬϰ͛ϱ͛Ϯ͘Ϭ͟/ƐŽůĂƚĞĚ Ͳϲ ϯ Ϯ Ͳϰ ; ϰ ϵ ϭϬͬ ϭϭ ϭϲ͟ ϵͲϱͬϴ͟ ϳ͟ Ͳϰ> dKΛϮ͕ϭϳϬ͛ ϭϰ Ϯ ϯ ϴ ϳ ϭϭ>ͬ ϭϮ ϲ ϱ ϭϭhdKΛϯ͕ϯϬϳ͛ dKΛϯ͕ϰϭϱ͛ dKΛϯ͕ϱϲϬ͛ dKΛϯ͕ϲϴϬ͛ dKΛϯ͕ϳϳϮ͛ dKΛϯ͕ϴϱϬ͛ hƉĚĂƚĞĚďǇZZϭϮͲϭϭͲϮϭ WZKWK^^,Dd/ ^ZhϮϰϭͲϭϲ Wd͗ϮϬϰͲϬϴϴ W/͗ϱϬͲϭϯϯͲϮϬϱϰϬͲϬϬͲϬϬ ϭ dсϰ͕ϮϲϰΖDͬϯ͕ϲϯϲ͛ds Wdсϯ͕ϯϬϳ͛DͬϮ͕ϲϵϵ͛ds DĂǆŚŽůĞĂŶŐůĞсϱϭ͘ϱq Λϭ͕ϴϮϮ͛ Z<сϯϯϴ͘ϱΖͬ'>сϯϭϴ͘Ϭ͛D^> Z<ƚŽd,&сϮϬ͘ϱ͛ ^/E'd/> ^ŝǌĞ tƚ 'ƌĂĚĞ ŽŶŶ / dŽƉ ƚŵ ϭϲΗ ϲϴ :Ͳϱϱ tĞůĚ ^ƵƌĨ͘ ϲϲ͘ϱΖ ϵͲϱͬϴΗ ϰϬ >ͲϴϬ d ϴ͘ϴϯϱΗ ^ƵƌĨ͘ ϭ͕ϱϱϯΖ ϳ Ϯϲ >ͲϴϬ d ϲ͘ϮϳϲΗ ^ƵƌĨ͘ ϰ͕ϮϲϰΖ dh/E'd/> ϮͲϳͬϴΗ ϲ͘ϰ >ͲϴϬ /d Ϯ͘ϰϰϭΗ ^ƵƌĨ Ϯ͕Ϯϲϳ͛ :t>Zzd/> EŽ͘ ĞƉƚŚ / /ƚĞŵ ϭ Ϯϱ͛ Ϯ͘ϰϰϭΗ ƌŽƐƐͲKǀĞƌϰͲϭͬϮΗϭϮ͘ϲηǆϮͲϳͬϴΗϲ͘ϰη/dŽǆǆWŝŶ Ϯ Ϯ͕Ϯϰϭ͛ Ϯ͘ϯϲϬ͟ ϳ͟,^W,>WƌŽĚƵĐƚŝŽŶWĂĐŬĞƌ ϯ Ϯ͕ϮϱϬ͛ Ϯ͘ϯϭϯ͟ yEŝƉƉůĞWƌŽĨŝůĞ ϰ Ϯ͕Ϯϲϳ͛ Ϯ͘ϰϰϭΗ tŝƌĞ>ŝŶĞŶƚƌǇ'ƵŝĚĞ ϱ ϯ͕ϯϰϱ͛ Ͳ ^ƉŝƌĂůddWʹdKΛϯ͕ϯϬϳ͛D;ϭϬͬϮϴͬϮϭͿ ϲ ϯ͕ϰϱϬ͛ Ͳ /WƐĞƚŽŶƌŝŐǁͬϯϱ͛ĐĞŵĞŶƚʹdKΛϯ͕ϰϭϱ͛;ϵͬϯϬͬϮϬͿ ϳ ϯ͕ϲϭϴ͛ Ͳ ^ƉŝƌĂůWůƵŐǁͬĐĞŵĞŶƚʹdKΛϯ͕ϱϲϬ͛;ϴͬϳͬϮϬͿ ϴ ϯ͕ϳϭϱ Ͳ ^ƉŝƌĂůWůƵŐǁͬĐĞŵĞŶƚʹdKΛϯ͕ϲϴϬ͛;ϳͬϮϬͬϮϬͿ ϵ ϯ͕ϳϳϮ͛ Ͳ ddWůƵŐƐƐĞŵďůǇǁͬΕϮϮ͘ϱ͛ĐĞŵĞŶƚϰͬϮϭͬϭϱ͘dŽĂƚϯϳϳϮ͛D ϭϬ ϯ͕ϴϱϬ͛ Ͳ ĞŵĞŶƚ;ϱďďůƐŽĨϭϱ͘ϴη>ydĞŵĞŶƚͿ͗dŽϯϴϱϬ͛D ϭϬ ϯ͕ϵϱϱ͛ Ͳ &ĂŝůĞĚWŽƐŝƐĞƚWůƵŐ;ƉƵƐŚĞĚĚŽǁŶŚŽůĞǁͬĐŽŝůϱͬϯϬͬϬϴͿ ϭϭ hŶŬŶŽǁŶ Ͳ &ĂŝůĞĚdd^hŵďƌĞůůĂWůƵŐ;ĚŝĚŶŽƚƚĂŐĂƚϰ͕ϬϯϬ͛ϱͬϮϵͬϬϳͿ WZ&KZd/KEd/> ĂƚĞ ŽŶĞ dŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ ŵƚ 'ƵŶ^ŝǌĞ ŽŵŵĞŶƚƐ WƌŽƉŽƐĞĚƉĞƌĨƐƉĞƌƐƵŶĚƌǇ ϭϬͬϯϭͬϮϭ Ͳϭϭh ϯ͕Ϯϲϵ͛ϯ͕Ϯϳϰ͛Ϯ͕ϲϲϯ͛Ϯ͕ϱϱϴ͛ϱ͛Ϯ͟dŽďĞŝƐŽůĂƚĞĚ ϯͬϯϬͬϮϭ Ͳϭϭ>ϯ͕ϯϲϳ͛ϯ͕ϯϲϵ͛Ϯ͕ϳϱϱ͛Ϯ͕ϳϱϲ͛Ϯ͛ϭ͘ϳϱ͟/ƐŽůĂƚĞĚ;ϭϬͬϮϴͬϮϭͿ ϭϬͬϭϯͬϮϬ ͲϭϮ ϯ͕ϯϳϴ͛ϯ͕ϯϴϳ͛Ϯ͕ϳϲϱ͛Ϯ͕ϳϳϯ ϵ͛ϭ͘ϳϱ͟/ƐŽůĂƚĞĚ;ϭϬͬϮϴͬϮϭͿ ϴͬϭϭͬϮϬ Ͳϭϰ ϯ͕ϰϲϴ͛ϯ͕ϰϳϲ͛Ϯ͕ϴϰϴ͛Ϯ͕ϴϵϰ͛ϴ͛ϭ͘ϳϱ͟/ƐŽůĂƚĞĚ ϳͬϮϬͬϮϬ ͲϮ ϯ͕ϲϲϳ͛ϯ͕ϲϳϮ͛ϯ͕Ϭϰϯ͛ϯ͕Ϭϰϴ͛ϱ͛ϭ͘ϳϱ͟/ƐŽůĂƚĞĚ ϲͬϮϰͬϮϬ Ͳϯ ϯ͕ϳϮϴ͛ϯ͕ϳϯϯ͛ϯ͕ϭϬϯ͛ϯ͕ϭϬϴ͛ϱ͛ϭ͘ϳϱ͟/ƐŽůĂƚĞĚ ϰͬϮϲͬϭϱ ϰ>ϯ͕ϳϲϱ͛ϯ͕ϳϳϬ͛ϯ͕ϭϯϵ͛ϯ͕ϭϰϰ͛ϱ͛Ϯ͟/ƐŽůĂƚĞĚ ϰͬϭϭͬϭϮ Ͳϰϯ͕ϴϬϯ͛ϯ͕ϴϭϬ͛ϯ͕ϭϳϳ͛ϯ͕ϭϴϰ͛ϱ͛ϭͲϭϭͬϭϲ͟/ƐŽůĂƚĞĚ ϲͬϬϲͬϬϴ Ͳϰϯ͕ϴϬϱ͛ϯ͕ϴϭϬ͛ϯ͕ϭϳϵ͛ϯ͕ϭϴϰ͛ϱ͛ϭͲϭϭͬϭϲ͟/ƐŽůĂƚĞĚ ϵͬϭϲͬϬϰ Ͳϲ ϰ͕ϬϮϳ͛ϰ͕ϬϯϮ͛ϯ͕ϰϬϬ͛ϯ͕ϰϬϰ͛ϱ͛Ϯ͘Ϭ͟/ƐŽůĂƚĞĚ ϵͬϭϲͬϬϰ Ͳϲ ϰ͕Ϭϯϯ͛ϰ͕Ϭϯϳ͛ϯ͕ϰϬϱ͛ϯ͕ϰϬϵ͛ϰ͛Ϯ͘Ϭ͟/ƐŽůĂƚĞĚ ϵͬϭϱͬϬϰ Ͳϲ ϰ͕ϬϮϳ͛ϰ͕ϬϯϮ͛ϯ͕ϰϬϬ͛ϯ͕ϰϬϰ͛ϱ͛Ϯ͘Ϭ͟/ƐŽůĂƚĞĚ Ͳϲ ϯ Ϯ Ͳϰ ; ϰ ϵ ϭϬͬ ϭϭ ϭϲ͟ ϵͲϱͬϴ͟ ϳ͟ Ͳϰ> dKΛϮ͕ϭϳϬ͛ ϭϰ Ϯ ϯ ϴ ϳ ϭϭ>ͬ ϭϮ ϲ ϱ ϭϭhdKΛϯ͕ϯϬϳ͛ dKΛϯ͕ϰϭϱ͛ dKΛϯ͕ϱϲϬ͛ dKΛ ϯ͕ϲϴϬ͛ dKΛϯ͕ϳϳϮ͛ dKΛϯ͕ϴϱϬ͛ &HPHQWSOXJ DWOHDVW¶ ZLWK7R&DW ¶0' RUORZHU ^dEZt>>WZKhZ E/dZK'EKWZd/KE^ ϭϮͬϬϴͬϮϬϭϱ &/E>ǀϭ WĂŐĞϭŽĨϭ ϭ͘Ϳ D/ZhEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ>ŝƋƵŝĚEŝƚƌŽŐĞŶdƌĂŶƐƉŽƌƚ͘ Ϯ͘Ϳ EŽƚŝĨǇWĂĚKƉĞƌĂƚŽƌŽĨƵƉĐŽŵŝŶŐEŝƚƌŽŐĞŶŽƉĞƌĂƚŝŽŶƐ͘ ϯ͘Ϳ WĞƌĨŽƌŵWƌĞͲ:Žď^ĂĨĞƚǇDĞĞƚŝŶŐ͘ZĞǀŝĞǁEŝƚƌŽŐĞŶǀĞŶĚŽƌƐƚĂŶĚĂƌĚŽƉĞƌĂƚŝŶŐƉƌŽĐĞĚƵƌĞƐĂŶĚ ĂƉƉƌŽƉƌŝĂƚĞ^ĂĨĞƚǇĂƚĂ^ŚĞĞƚƐ;ĨŽƌŵĞƌůǇD^^Ϳ͘ ϰ͘Ϳ ŽĐƵŵĞŶƚ ŚĂǌĂƌĚƐ ĂŶĚ ŵŝƚŝŐĂƚŝŽŶ ŵĞĂƐƵƌĞƐ ĂŶĚ ĐŽŶĨŝƌŵ ĨůŽǁ ƉĂƚŚƐ͘ /ŶĐůƵĚĞ ƌĞǀŝĞǁ ŽŶ ĂƐƉŚǇǆŝĂƚŝŽŶ ĐĂƵƐĞĚ ďǇ ŶŝƚƌŽŐĞŶ ĚŝƐƉůĂĐŝŶŐŽǆǇŐĞŶ͘ DŝƚŝŐĂƚŝŽŶ ŵĞĂƐƵƌĞƐ ŝŶĐůƵĚĞĂƉƉƌŽƉƌŝĂƚĞ ƌŽƵƚŝŶŐŽĨĨůŽǁůŝŶĞƐ͕ĂĚĞƋƵĂƚĞǀĞŶƚŝŶŐĂŶĚĂƚŵŽƐƉŚĞƌŝĐŵŽŶŝƚŽƌŝŶŐ͘ ϱ͘Ϳ ^ƉŽƚWƵŵƉŝŶŐhŶŝƚĂŶĚdƌĂŶƐƉŽƌƚ͘ŽŶĨŝƌŵůŝƋƵŝĚEϮǀŽůƵŵĞƐŝŶƚƌĂŶƐƉŽƌƚ͘ ϲ͘Ϳ ZŝŐƵƉůŝŶĞƐĨƌŽŵƚŚĞEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚƚŽƚŚĞǁĞůůĂŶĚƌĞƚƵƌŶƐƚĂŶŬ͘^ĞĐƵƌĞůŝŶĞƐǁŝƚŚǁŚŝƉ ĐŚĞĐŬƐ͘ ϳ͘Ϳ WůĂĐĞ ƐŝŐŶƐ ĂŶĚ ƉůĂĐĂƌĚƐ ǁĂƌŶŝŶŐ ŽĨ ŚŝŐŚ ƉƌĞƐƐƵƌĞ ĂŶĚ ŶŝƚƌŽŐĞŶ ŽƉĞƌĂƚŝŽŶƐ Ăƚ ĂƌĞĂƐ ǁŚĞƌĞ EŝƚƌŽŐĞŶŵĂǇĂĐĐƵŵƵůĂƚĞŽƌďĞƌĞůĞĂƐĞĚ͘ ϴ͘Ϳ WůĂĐĞƉƌĞƐƐƵƌĞŐĂƵŐĞƐĚŽǁŶƐƚƌĞĂŵŽĨůŝƋƵŝĚĂŶĚŶŝƚƌŽŐĞŶƉƵŵƉƐƚŽĂĚĞƋƵĂƚĞůǇŵĞĂƐƵƌĞƚƵďŝŶŐ ĂŶĚĐĂƐŝŶŐƉƌĞƐƐƵƌĞƐ͘ ϵ͘Ϳ WůĂĐĞƉƌĞƐƐƵƌĞŐĂƵŐĞƐƵƉƐƚƌĞĂŵĂŶĚĚŽǁŶƐƚƌĞĂŵŽĨĂŶǇĐŚĞĐŬǀĂůǀĞƐ͘ ϭϬ͘Ϳ tĞůůƐŝƚĞDĂŶĂŐĞƌƐŚĂůůǁĂůŬĚŽǁŶǀĂůǀĞĂůŝŐŶŵĞŶƚƐĂŶĚĞŶƐƵƌĞǀĂůǀĞƉŽƐŝƚŝŽŶŝƐĐŽƌƌĞĐƚ͘ ϭϭ͘Ϳ ŶƐƵƌĞƉŽƌƚĂďůĞϰͲŐĂƐĚĞƚĞĐƚŝŽŶĞƋƵŝƉŵĞŶƚŝƐŽŶƐŝƚĞ͕ĐĂůŝďƌĂƚĞĚ͕ĂŶĚďƵŵƉƚĞƐƚĞĚƉƌŽƉĞƌůǇƚŽ ĚĞƚĞĐƚ>>ͬ,Ϯ^ͬKϮͬKϮůĞǀĞůƐ͘ŶƐƵƌĞEŝƚƌŽŐĞŶǀĞŶĚŽƌŚĂƐĂǁŽƌŬŝŶŐĂŶĚĐĂůŝďƌĂƚĞĚĚĞƚĞĐƚŽƌĂƐ ǁĞůůƚŚĂƚŵĞĂƐƵƌĞƐKϮůĞǀĞůƐ͘ ϭϮ͘Ϳ WƌĞƐƐƵƌĞƚĞƐƚůŝŶĞƐƵƉƐƚƌĞĂŵŽĨǁĞůůƚŽĂƉƉƌŽǀĞĚƐƵŶĚƌǇƉƌĞƐƐƵƌĞŽƌDW^W;DĂǆŝŵƵŵWŽƚĞŶƚŝĂů ^ƵƌĨĂĐĞWƌĞƐƐƵƌĞͿ͕ǁŚŝĐŚĞǀĞƌŝƐŚŝŐŚĞƌ͘dĞƐƚůŝŶĞƐĚŽǁŶƐƚƌĞĂŵŽĨǁĞůů;ĨƌŽŵǁĞůůƚŽƌĞƚƵƌŶƐƚĂŶŬͿ ƚŽϭ͕ϱϬϬƉƐŝ͘WĞƌĨŽƌŵǀŝƐƵĂůŝŶƐƉĞĐƚŝŽŶĨŽƌĂŶǇůĞĂŬƐ͘ ϭϯ͘Ϳ ůĞĞĚŽĨĨƚĞƐƚƉƌĞƐƐƵƌĞĂŶĚƉƌĞƉĂƌĞĨŽƌƉƵŵƉŝŶŐŶŝƚƌŽŐĞŶ͘ ϭϰ͘Ϳ WƵŵƉŶŝƚƌŽŐĞŶĂƚĚĞƐŝƌĞĚƌĂƚĞ͕ŵŽŶŝƚŽƌŝŶŐƌĂƚĞ;^&DͿĂŶĚƉƌĞƐƐƵƌĞ;W^/Ϳ͘ůůŶŝƚƌŽŐĞŶƌĞƚƵƌŶƐ ĂƌĞƚŽďĞƌŽƵƚĞĚƚŽƚŚĞƌĞƚƵƌŶƐƚĂŶŬ͘ ϭϱ͘Ϳ tŚĞŶĨŝŶĂůŶŝƚƌŽŐĞŶǀŽůƵŵĞŚĂƐďĞĞŶĂĐŚŝĞǀĞĚ͕ŝƐŽůĂƚĞǁĞůůĨƌŽŵEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ ďůĞĞĚĚŽǁŶůŝŶĞƐďĞƚǁĞĞŶǁĞůůĂŶĚEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ͘ ϭϲ͘Ϳ KŶĐĞǇŽƵŚĂǀĞĐŽŶĨŝƌŵĞĚůŝŶĞƐĂƌĞďůĞĚĚŽǁŶ͕ŶŽƚƌĂƉƉĞĚƉƌĞƐƐƵƌĞĞǆŝƐƚƐ͕ĂŶĚŶŽŶŝƚƌŽŐĞŶŚĂƐ ĂĐĐƵŵƵůĂƚĞĚďĞŐŝŶƌŝŐĚŽǁŶŽĨůŝŶĞƐĨƌŽŵƚŚĞEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ͘ ϭϳ͘Ϳ &ŝŶĂůŝǌĞũŽďůŽŐĂŶĚĚŝƐĐƵƐƐŽƉĞƌĂƚŝŽŶƐǁŝƚŚtĞůůƐŝƚĞDĂŶĂŐĞƌ͘ŽĐƵŵĞŶƚĂŶǇůĞƐƐŽŶƐůĞĂƌŶĞĚ ĂŶĚĐŽŶĨŝƌŵĨŝŶĂůƌĂƚĞƐͬƉƌĞƐƐƵƌĞͬǀŽůƵŵĞƐŽĨƚŚĞũŽďĂŶĚƌĞŵĂŝŶŝŶŐŶŝƚƌŽŐĞŶŝŶƚŚĞƚƌĂŶƐƉŽƌƚ͘ ϭϴ͘Ϳ ZDKEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ>ŝƋƵŝĚEŝƚƌŽŐĞŶdƌĂŶƐƉŽƌƚ͘ 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: CTU/N2 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: 3345, 3450, 3618, Total Depth measured 4,264 feet 3715, 3772, 3955 feet true vertical 3,636 feet >3,955' (plug) feet Effective Depth measured 3,307 feet 2,241 feet true vertical 2,699 feet 1,831 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.4# / L-80 2,267' MD 1,848' TVD Packers and SSSV (type, measured and true vertical depth)HES PHL Ret Pkr; N/A 2,241' MD 1,831' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Contact Email: Authorized Title:Contact Phone: 321-352 & 321-417 Sr Pet Eng: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. 0 600 Ryan Rupert, Operations Engineer ryan.rupert@hilcorp.com 907-777-8503Dan Marlowe, ASC Team Operations Manager, 907-283-1329 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 0 00 0 500 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 67' 1,553' 0 Structural TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-088 50-133-20540-00-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA028077 Swanson River / Sterling/Upper Beluga Gas Pool Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Swanson River Unit (SRU) 241-16 measuredPlugs Junk measured N/A Length 67' 1,553' Size Conductor Surface Intermediate 16" 9-5/8" Production Liner 4,264' Casing 67' 1,388' 3,636'4,264'7"5,410psi 2,980psi 5,750psi 7,240psi Burst Collapse 1,410psi 3,090psi t Fra O 6. A PG , R Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Meredith Guhl at 2:41 pm, Dec 10, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.12.10 14:15:47 -09'00' Dan Marlowe (1267) BJM 01/14/22 RBDMS HEW 12/13/2021 DSR-12/10/21SFD 12/15/2021 Rig Start Date End Date 8/2/21 11/14/21 08/05/2021 - Thursday 08/06/2021- Friday Crew arrives at facility. Permits, JSA, job scope. Rig up Slickline to well. PT 250 low/ 2500 high. RIH w/ 2.25''x7' DD bailer falling slow from 2600' to 3279'slm tag w/tool. POOH full mud. RIH w/ same to fluid level at 1210' SLM continue to 2120' SLM start falling very slow continue to 2200' SLM POOH To check Bailer OOH/w thick fluid. RIH w/ same tools falling faster to 3278'slm w/tool pooh empty. Flapper stuck open. RIH w/ same w/ball bottom to 3277' SLM w/t poor/slow action POOH OOH/w thick slurry. Add 5' of stem(15' total). RIH/w 2" x 6.5' DD bailer to 3279'slm w/tool pooh small amount of sand only / possible wash out. RIH w/ same w/ ball bottom to 3278' SLM w/t POOH OOH/w small amount of sand. . Drop 5 gallons diesel to cut E-line grease. - RIH/W same to 3278' SLM w/t POOH OOH/w mostly fluid light amount of sand. RIH w/2.25'' pump bailer to 3278'SLM w/tool pooh full thick slurry. Production bleeds pressure from 1300psi down to ~200psi to try and loosen up sand due to not making any hole. . RIH/w Same to 3131' SLM w/t lose hole to 3123' SLM w/t lose hole to 3113' SLM Pickup to 2740' SLM set 10 mins then go back down to 3098' SLM w/t lose hole to 3091' SLM POOH Contact supervisor. OOH/empty bailer. Standby for production to bull head gas to tubing. 1300# on tubing RIH w/ 2.25'' pump bailer to 3264' SLM pickup fall thru to 3320' SLM w/t 3322' SLM. POOH. w/ 2'' DD bailer to 3317' SLM see spangs one time then have overpull on pickup start working tools up lost spang action and no Jars - bleed well PSI down to 400 PSI come Free POOH. Lay down lubricator, secure well. Pressure well up to 1500 psi. Crew leaves facility. 08/02/2021 - Monday Rig up to well. PT 250 psi low/ 2500 psi high. Equalize well and lubricator. RIH with 2 7/8" Spiral TTBP. Sat down easy at 3285'. Attempt pass at up to 60 FPM. Desired plug depth is 3332'. Standby for Engineer to decide what plan forward is. Decide to POOH to get Slickline out to bail/drift. Crew rigs down. Crew arrives at facility. PJSM, JSA, Permits. Stand up lubricator, PT 250 low/2500 high. RIH w/ 2.25''x11' pump bailer to 3257'slm w/tool very sticky POOH OOH/w small amount of fluid. Bleed tubing pressure down to 900# set for 20 mins to settle out. RIH/w Same to 3257' SLM w/t to 3260' SLM POOH OOH/w fluid small amount of sand. . RIH/w Tail Locator to 2268'slm tag tubing tale - shear off pooh. RIH w/ 2.25'' pump bailer to 3260'slm w/tool pooh fluid only. RIH w/ 2.25'' DD bailer to 3260' SLM w/t to 3262' SLM POOH OOH/w 1 cup fine sand. Pressure up to tubing to 1500# set for 20 min. to settle out. . RIH w/ 2.25'' DD bailer to 12' w/ tool to 22' pooh w/ hydrates hook up triplex pump methanol. Continue RIH w/ same to 3260'slm w/tool pooh empty. discuss options with engineer. Decide to rig down and move to next well. Rig down from well. secure well. move to next well. 08/08/2021 - Sunday Rig up to well. Pump 9.2 BBL @ 1.8 BPM pressure up to 2100 psi. slow rate to ~.5 BPM steady pressure increase to 2900 psi @ ~15 BBL total pumped. Slickline RIH W 2.25''x5' DD bailer to 3260'. (Same depth as before pressure was added. Crew rigs down and move equipment to next well. Daily Operations Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 241-16 50-133-20540-00-00 204-088 Rig Start Date End Date 8/2/21 11/14/21 Daily Operations Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 241-16 50-133-20540-00-00 204-088 Arrive @ Swanson river, talk w/ company rep, sign permits. TGSM. Rig up on well. SITP= 1310psi PT 2000 PSI- Pass. Rih w/ tubing tail locater to 2283' kb, tag tubing tail ( 16' deep), pooh. Rih w/ 2.25 X 6' DD Bailer to 3217' kb, beat down 3X, fall through to 3367' kb, w/t 3370' kb, pull back up to 3217' kb, work tools up and down through tight spot till cannot see anymore, pooh. Ooh w/ tools, rig down. SITP= 1310psi 10/26/2021 - Wednesday FL shot taken at 16:00. SITP = 1350psi. FL shot found FL = 2650' MD 10/21/2021 - Thursday Move from SRU 12-15. RU SITP = 1450psi PT to 1500 psi, good test RIH w/ 1.75 x 4' DD bailer to 3227' KB. Tag, w/t, POOH w/ small amount of sand, mostly water RD move to SRU 12-15 SITP = 1450psi 10/23/2021 - Saturday 10/10/2021 - Sunday Conduct JSA and approve PTW. Weaver move manlift to location. Weaver move and spot supply/return tank. Spot in SLB coil equipment and RU. SLB Coil. Install BOP's on well. No BOP test required, last BOP test on 10/4/21 while on CLU-14 (Test to 250 psi low / 4000 psi high.) Function test rams. MU lubricator and slim BHA. 1.75" connector. 1.75" dual checks, 1.75"stinger, 1.75" stinger, 1.75" JSN. PT stack out choke skid 250/4000 psi. Open well. Tubing pressure = 140 psi. RIH and Dry tag at 3187' ctmd. Online with pump, holding 800 psi on choke. Pump gel pill and cleanout to 3340' ctmd. Chase uphole to 2600'. Getting 1:1 returns. Pump gel pill and cleanout to 3350' ctmd. Chase bite up into tubing tail at 2200'. Hold 800 psi on well. Get 1:1 returns. Get bottoms up and shut down pump. RIH and dry tag at 3354' ctmd. Pump N2 down coil and recover 62 bbls of fluid at surface. Trap 1600 psi on well. Close swab and upper master valve. Laydown BHA and lubricator. ND BOP's. Install tree cap. LDFN. t BOP test on 10/4/21 while on CLU-14 (Test to 250 psi low / 4000 psi high.) Rig Start Date End Date 8/2/21 11/14/21 Daily Operations Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 241-16 50-133-20540-00-00 204-088 10/30/2021 - Saturday BLED TUBING DOWN TO 0PSI / RUN #13 . RIH W/ 2" X 40' CMT DUMP BAILER DUMPED 5.4GALS FOR 3.4' OF FILL T.O.C. = 3310.6 (TAGGED T.O.C. PRIOR TO DUMPING AND TAGGED @ 3314') RIH W/ 2" X 40' CMT BAILER DUMPED 5.4 GALS FOR 3.4' OF FILL T.O.C. = 3307.2' 10/31/2021 - Sunday Sign in. Mobe to location. PTW and tailgate meeting. Arm gun, rig up lubricator, PT to 250 low and 2500 psi high. TP - 3 psi. RIH w/GPT tool, 2"x5' HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and find FL at 2932'. Pressure tubing to 1000 psi. Run correlation log and send to town. Get ok to perf from 3269' to 3274'. Spot and fire gun w/953 psi. After 5 min - 948 psi, 10 min - 945 psi and 15 min - 941 psi. POOH. All shots fired, Gun was wet. FL drop to 2954' after perf. Rig down off well and turn it over to field. Rig down rest of equipment and leave location. 10/28/2021 - Thursday Sign in. PTW and JSA. Mobe to location. Spot equipment and rig up lubricator. MU 2.19" Spiral Plug. PT lubricator to 250 psi low and 2500 psi high. TP - 1300 psi. RIH w/GPT tool, 2.19"x6-1/2' running measurements and tie into OHL(Las). Fluid level is 2964' Engr are here on location. Decision made to push some fluid away. Pressured up from 1340 psi to 1750 psi surface and 2057 psi BHP. Didn't look like we pushed any away. Ryan, Sara and Jeff were out here today. Decision was made to set plug at 3345' w/1700 psi on surface. Lost 100 psi when set. PU 20' and. go back down and lightly tag plug. POOH. Setting tool look good. Will be dumping ceramic beads. Pressure lubricator to 1700 psi before opening up to well. RIH w/2"x15' dump bailer filled w/ceramic beads and tie into plug log. Tag plug at 3345' and dumped 1.35' of beads on top of plug. POOH. Good dump. Pressure lubricator to 1700 psi before opening up to well. RIH w/2"x15' dump bailer filled w/ceramic beads and tie into plug log. Dumped 1.35' of beads on top of first dump. POOH. Good dump. A total of 2.70' of beads on top of plug. POOH. Good dump. Pressure lubricator to 1700 psi before opening up to well. RIH w/2"x40' dump bailer filled with 16 ppg cement (3.18'/6.4 gal) and dump cement on top of beads at 3343'. POOH. Good dump. Having some problem with bottom fill. Fixed it. Pressure lubricator to 1700 psi before opening up to well. RIH w/2"x40' dump bailer filled with 16 ppg cement to 20' and cant go deeper. Going to dump 5 gals of diesel to cut wireline grease. if that doesn't work we will check grease head to see if it is freezing up. Diesel didn't help so going to dump cement in bucket and lay down lubricator and check grease head. Double. check type of grease they are using. POOH and found a piece of what looks like wire line grease or valve grease. Will leave on Kraigs desk. Rig down for tonight. Close all valves with 1700 psi on tubing. 10/29/2021- Friday RIH W/ 2.25" GAUGE AND CCL HAD TO WORK WAY DOWN FROM 36' TO 120' THEN TOOLS WENT TO EOT WITH NO PROBLEM . RIH W/ 2" X 40' DUMP BAILER DUMPED 3.4' CMT (5.48 GAL) T.O.C. = 3335'. RIH W/ 2" X 40' DUMP BAILER DUMPED 3.4' CMT (5.48 GAL) T.O.C. = 3331.6 RIH W/ 2" X 40' DUMP BAILER DUMPED 3.4' CMT (5.48 GAL) T.O.C. = 3328.2 RUN #10. RIH W/ 2" X 40' CMT BAILER DUMPED 5.4 GALS FOR 3.4' OF FILL T.O.C. = 3324.8 RUN #11. RIH W/ 2" X 40' CMT BAILER DUMPED 5.4 GALS FOR 3.4' OF FILL T.O.C. = 3321.4' RUN #12 . RIH W/ 2" X 40' CMT BAILER DUMPED 5.4 GALS FOR 3.4' OF FILL T.O.C. = 3318' MP BAILER DUMPED 3.4' CMT (5.48 GAL) T.O.C. = 3331.6 RIH W/ 2" X 40' DUMP BAILER DUMPED Get ok to perf from 3269' to 3274'. Spot and fire gun w/953 psi. o set plug at 3345' w/1700 psi on surface. Lost 100 psi when set. dump cement on top of beads at 3343' L T.O.C. = 3307.2' A total of 2.70' of beads on top of plug. 4' RUN #12 . RIH W/ 2" X 40' CMT BAILER DUMPED 5.4 GALS FOR 3.4' OF FILL T.O.C. = 3318' Dumped 1.35'of beads on top of first dump. Tag plug at 3345' and dumped 1.35' of beads on top of plug. Rig Start Date End Date 8/2/21 11/14/21 Daily Operations Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 241-16 50-133-20540-00-00 204-088 11/14/2021 -Sunday Bail / chisel sand from 2102' - 2120' MD, stopped there. Bail / chisel sand from 2024' - 2094' MD. 11/12/2021 - Friday Bail / chisel sand from 2061' - 2083' MD. 11/13/2021- Saturday Bail / chisel sand from 2086' - 2107' MD. 11/11/2021 - Thursday Updated by DMA 12-10-21 SCHEMATIC SRU 241-16 PTD: 204-088 API: 50-133-20540-00-00 1 TD = 4,264' MD / 3,636’ TVD PBTD =3,307’ MD / 2,699’TVD Max hole angle = 51.5q @ 1,822’ RKB = 338.5' / GL = 318.0’ AMSL RKB to THF = 20.5’ CASING DETAIL Size Wt Grade Conn ID Top Btm 16"68 J-55 Weld Surf.66.5' 9-5/8"40 L-80 BTC 8.835"Surf.1,553' 7 26 L-80 BTC 6.276"Surf.4,264' TUBING DETAIL 2-7/8"6.4 L-80 IBT 2.441"Surf 2,267’ JEWELRY DETAIL No.Depth ID Item 1 25’2.441"Cross - Over 4-1/2" 12.6# x 2-7/8" 6.4# IBT Box x Pin 2 2,241’2.360”7” HES PHL Production Packer 3 2,250’2.313”X Nipple Profile 4 2,267’2.441"Wire Line Entry Guide 5 3,345’-Spiral TTBP – TOC @ 3,307’ MD (10/28/21) 6 3,450’-CIBP set on rig w/ 35’ cement – TOC @ 3,415’ (9/30/20) 7 3,618’-Spiral Plug w/ cement – TOC @ 3,560’ (8/7/20) 8 3,715 -Spiral Plug w/ cement – TOC @ 3,680’ (7/20/20) 9 3,772’-TT Plug Assembly w/ ~22.5’ cement 4/21/15. ToC at 3772’ MD 10A 3,850’-Cement (5 bbls of 15.8# LXT Cement): ToC 3850’ MD 10B 3,955’-Failed Posiset Plug (pushed downhole w/ coil 5/30/08) 11 Unknown -Failed TTS Umbrella Plug (did not tag at 4,030’ 5/29/07) PERFORATION DETAIL Date Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Gun Size Comments 10/31/21 A-11U 3,269’3,274’2,663’2,558’5’2”Open 3/30/21 A-11L 3,367’3,369’2,755’2,756’2’1.75”Isolated (10/28/21) 10/13/20 A-12 3,378’3,387’2,765’2,773 9’1.75”Isolated (10/28/21) 8/11/20 A-14 3,468’3,476’2,848’2,894’8’1.75”Isolated 7/20/20 B-2 3,667’3,672’3,043’3,048’5’1.75”Isolated 6/24/20 B-3 3,728’3,733’3,103’3,108’5’1.75”Isolated 4/26/15 B4L 3,765’3,770’3,139’3,144’5’2”Isolated 4/11/12 B-4A 3,803’3,810’3,177’3,184’5’1-11/16”Isolated 6/06/08 B-4A 3,805’3,810’3,179’3,184’5’1-11/16”Isolated 9/16/04 B-6 4,027’4,032’3,400’3,404’5’2.0”Isolated 9/16/04 B-6 4,033’4,037’3,405’3,409’4’2.0”Isolated 9/15/04 B-6 4,027’4,032’3,400’3,404’5’2.0”Isolated B-6 3 2 B-4A X 4 9 10A/B 11 16” 9-5/8” 7” B-4L TOC @ 2,170’ A14 B2 B3 8 7 A11L / A12 6 5 A11UTOC @ 3,307’ TOC @ 3,415’ TOC @ 3,560’ TOC @ 3,680’ TOC @ 3,772’ TOC @ 3,850’ ()()()() 10/31/21 A-11U 3,269’3,274’2,663’2,558’5’2”Open (MD)(MD)(TVD)(TVD) 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: CTU/N2 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 4,264'>3,772' (plug) Casing Collapse Structural Conductor 1,410 psi Surface 3,090 psi Intermediate Production 5,410 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Todd Sidoti Operations Manager Contact Email: Contact Phone: 777-8443 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 9/6/2021 2-7/8" 4,264' Perforation Depth MD (ft): See Attached Schematic 4,264' 3,636'7" 16" 9-5/8" 66.5' 1,553' 2,980 psi 5,750 psi 66.5' 1,388' 66.5' 1,553' 6.5# / L-80 TVD Burst 2,267' 7,240 psi MDLength Size CO 716 Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028077 204-088 50-133-20540-00-00 Swanson River Unit (SRU) 241-16 Swanson River / Sterling/Upper Beluga Gas Pool COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic todd.sidoti@hilcorp.com 3,636'3,415'3,223'~937 psi 3,772' HES PHL Pkr; N/A 2,241' MD / 1,831' TVD; N/A Perforation Depth TVD (ft): Tubing Size: eee d ed ss No ss No Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 1:46 pm, Aug 23, 2021 321-417 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.08.23 13:31:41 -08'00' Taylor Wellman (2143) SFD 8/24/2021 10-404 SFD 8/24/2021 BJM 9/1/21 DSR-8/23/21 CO 716.001 and CT BOP test to 4500 psi. X dts 9/1/2021 JLC 9/2/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.02 13:45:26 -08'00' RBDMS HEW 9/3/2021 Well Prognosis Well: SRU 241-16 Date: 8/11/2021 Well Name: SRU 241-16 API Number: 50-133-20540-00-00 Current Status: SI Gas Well Leg: N/A Estimated Start Date: 9/6/2021 Rig: CTU Reg. Approval Req’d? 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 204-088 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (C) Second Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) Maximum Expected BHP: ~ 1,212 psi @ 2,755’ TVD Based on a 0.44psi/ft gradient. Max. Potential Surface Pressure: ~ 937 psi Gas gradient to surface @ 0.1 psi/ft Brief Well Summary Objective The purpose of this work is to clean out fill to 3350’, plug back and perforate more uphole Sterling A sands. Coiled Tubing 1. MIRU coiled tubing. Pressure test BOPE to 250 psi Low / 4,500 psi High. a. Notify State for option to witness. 2. RU nitrogen pump. 3. RIH with jet swirl nozzle. 4. Dry tag fill located at ~3260’ SLMD. 5. Clean out in increments with produced water and N2 down to 3350’ CTMD. 6. Blow well dry with Nitrogen. 7. Trap 1500 psi on well. E-line 1. MIRU E-line. Pressure test lubricator to 250 psi low / 2,500 psi high. 2. RIH and set Spiral TTBP at 3317’. Cap with beads and 35’ (56.5 gallons) of cement. 3. Perforate the following sand intervals from bottom to top: Sand MD Top MD Bottom TVD Top TVD Bottom Total Footage A-9 ~3081’ ~3090’ ~2493’ ~2501’ ~9 A-10 ~3143’ ~3151’ ~2548’ ~2555’ ~8 A-11 ~3268’ ~3285’ ~2662’ ~2678’ ~17 a. Trap 1100 psi on tubing for the initial A-11 perforations. b. If perforating an interval results in water production: we will rig up field gas and depress fluid into the perforations, set a through-tubing plug and dump bail 35’ of cement before moving uphole. c. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to Geologist (Jeff Nelson) and Reservoir Engineer (Meredyth Richards) for confirmation. clean out fill to 3350’, plug back and perforate more uphole Sterling A sands. Well Prognosis Well: SRU 241-16 Date: 8/11/2021 d. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record a tubing Surface pressure before each run and after each gun firing of 5, 10, 15 min reading intervals. e. The Sterling Sands are governed by Conservation Order 716. 4. POOH. RDMO e-line. 5. Turn well over to production. Attachments 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. CT BOPE Schematic 4. Standard Nitrogen Procedure Updated by DMA 05-13-21 SCHEMATIC Swanson River Unit Well: SRU 241-16 Completion Ran: 10/01/20 PTD: 204-088 API: 50-133-20540-00-00 1 TD = 4,264' MD; 3,636’ TVD PBTD =3,415’ MD; 2,799’ TVD Max hole angle = 51.5q @ 1,822’ RKB = 338.5' / GL = 318.0’ AMSL RKB to THF = 20.5’ CASING DETAIL Size Wt Grade Conn ID Top Btm 16" 68 J-55 Weld Surf. 66.5' 9-5/8" 40 L-80 BTC 8.835" Surf. 1,553' 7 26 L-80 BTC 6.276" Surf. 4,264' TUBING DETAIL 2-7/8" 6.4 L-80 IBT 2.441" Surf 2,267’ JEWELRY DETAIL No. Depth ID Item 1 25’ 2.441" Cross - Over 4-1/2" 12.6# x 2-7/8" 6.4# IBT Box x Pin 2 2,241’ 2.360” 7” HES PHL Production Packer 3 2,250’ 2.313” X Nipple Profile 4 2,267’ 2.441" Wire Line Entry Guide 5 3,450’ - TTBP w/ 35’ cement – TOC @ 3,415’ 9/30/20 6 3,618’ - Spiral Plug w/ cement – TOC @ 3,560’ 8/7/20 7 3,715 - Spiral Plug w/ cement – TOC @ 3,680’ 7/20/20 8 3,772’ - TT Plug Assembly for 7” casing w/ ~22.5’ cement 4/21/15 9 3,850’ - Cement (5 bbls of 15.8# LXT Cement) 10 3,955’ - Failed Posiset Plug (pushed downhole w/ coil 5/30/08) 11 Unknown - Failed TTS Umbrella Plug (did not tag at 4,030’ 5/29/07) PERFORATION DETAIL Date Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Gun Size Spf Phase Comments 3/30/21 A-11 3,367’ 3,369’ 2,755’ 2,756’ 2’ 1.75” 6 60 Open 10/13/20 A-12 3,378’ 3,387’ 2,765’ 2,773 9’ 1.75” 6 60 Open 8/11/20 A-14 3,468’ 3,476’ 2,848’ 2,894’ 8’ 1.75” 6 60 Isolated 7/20/20 B-2 3,667’ 3,672’ 3,043’ 3,048’ 5’ 1.75” 6 60 Isolated 6/24/20 B-3 3,728’ 3,733’ 3,103’ 3,108’ 5’ 1.75” 6 60 Isolated 4/26/15 B4L 3,765’ 3,770’ 3,139’ 3,144’ 5’ 2” 6 60 Isolated 4/11/12 B-4A 3,803’ 3,810’ 3,177’ 3,184’ 5’ 1-11/16” 7.5 45° Isolated 6/06/08 B-4A 3,805’ 3,810’ 3,179’ 3,184’ 5’ 1-11/16” 7.5 45° Isolated 9/16/04 B-6 4,027’ 4,032’ 3,400’ 3,404’ 5’ 2.0” 6 60° Isolated 9/16/04 B-6 4,033’ 4,037’ 3,405’ 3,409’ 4’ 2.0” 6 60° Isolated // B-6 3 2 TOC @ 3,850’ Fill @ 4,233’ B-4A X 4 8 10 11 Fill @ 3,784’ SLM 16” 9-5/8” 7” B-4L 9 TOC @ 3,772’ WLM TOC @ 2,170’ A14 B2 B3 7 6 TOC @ 3,680’ WLM TOC @ 3,560’ WLM A12 5 A11 TOC @ 3,415’ WLM Updated by TCS 08-12-21 PROPOSED SCHEMATIC Swanson River Unit Well: SRU 241-16 Completion Ran: 10/01/20 PTD: 204-088 API: 50-133-20540-00-00 1 TD = 4,264' MD; 3,636’ TVD PBTD =3,282’ MD; 2,689’ TVD Max hole angle = 51.5q @ 1,822’ RKB = 338.5' / GL = 318.0’ AMSL RKB to THF = 20.5’ CASING DETAIL Size Wt Grade Conn ID Top Btm 16" 68 J-55 Weld Surf. 66.5' 9-5/8" 40 L-80 BTC 8.835" Surf. 1,553' 7 26 L-80 BTC 6.276" Surf. 4,264' TUBING DETAIL 2-7/8" 6.4 L-80 IBT 2.441" Surf 2,267’ JEWELRY DETAIL No. Depth ID Item 1 25’ 2.441" Cross - Over 4-1/2" 12.6# x 2-7/8" 6.4# IBT Box x Pin 2 2,241’ 2.360” 7” HES PHL Production Packer 3 2,250’ 2.313” X Nipple Profile 4 2,267’ 2.441" Wire Line Entry Guide 4A 3,317’ - Spiral TTBP w/ 35’ of cement – TOC @ 3,282’ 5 3,450’ - TTBP w/ 35’ cement – TOC @ 3,415’ 9/30/20 6 3,618’ - Spiral Plug w/ cement – TOC @ 3,560’ 8/7/20 7 3,715 - Spiral Plug w/ cement – TOC @ 3,680’ 7/20/20 8 3,772’ - TT Plug Assembly for 7” casing w/ ~22.5’ cement 4/21/15 9 3,850’ - Cement (5 bbls of 15.8# LXT Cement) 10 3,955’ - Failed Posiset Plug (pushed downhole w/ coil 5/30/08) 11 Unknown - Failed TTS Umbrella Plug (did not tag at 4,030’ 5/29/07) PERFORATION DETAIL Date Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Gun Size Spf Phase Comments TBD A-9 ~3,081’ ~3,090’ ~2,493’ ~2,501’ ~9 - - - Open TBD A-10 ~3,143’ ~3,151’ ~2,548’ ~2,555’ ~8 - - - Open TBD A-11 ~3,268’ ~3,285’ ~2,662’ ~2,678’ ~17 - - - Open 3/30/21 A-11 3,367’ 3,369’ 2,755’ 2,756’ 2’ 1.75” 6 60 Isolated 10/13/20 A-12 3,378’ 3,387’ 2,765’ 2,773 9’ 1.75” 6 60 Isolated 8/11/20 A-14 3,468’ 3,476’ 2,848’ 2,894’ 8’ 1.75” 6 60 Isolated 7/20/20 B-2 3,667’ 3,672’ 3,043’ 3,048’ 5’ 1.75” 6 60 Isolated 6/24/20 B-3 3,728’ 3,733’ 3,103’ 3,108’ 5’ 1.75” 6 60 Isolated 4/26/15 B4L 3,765’ 3,770’ 3,139’ 3,144’ 5’ 2” 6 60 Isolated 4/11/12 B-4A 3,803’ 3,810’ 3,177’ 3,184’ 5’ 1-11/16” 7.5 45° Isolated 6/06/08 B-4A 3,805’ 3,810’ 3,179’ 3,184’ 5’ 1-11/16” 7.5 45° Isolated 9/16/04 B-6 4,027’ 4,032’ 3,400’ 3,404’ 5’ 2.0” 6 60° Isolated 9/16/04 B-6 4,033’ 4,037’ 3,405’ 3,409’ 4’ 2.0” 6 60° Isolated 9/15/04 B-6 4,027’ 4,032’ 3,400’ 3,404’ 5’ 2.0” 6 60° Isolated B-6 3 2 TOC @ 3,850’ Fill @ 4,233’ B-4A X 4 8 10 11 Fill @ 3,784’ SLM 16” 9-5/8” 7” B-4L 9 TOC @ 3,772’ WLM TOC @ 2,170’ A14 B2 B3 7 6 TOC @ 3,680’ WLM TOC @ 3,560’ WLM A12 5 A11 TOC @ 3,415’ WLM TOC @ 3,282’ WLM 4A Coiled Tubing Services Pressure Category 1 BOP Configuration (0-3,500 psi) Client: Hilcorp Date: April 3rd, 2017 Drawn: Chad Barrett Revision: 0 Well Category: CAT I 4-1/16" 10K Combi BOP Top Set: Blind/Shear Second Set: Pipe/Slip Wellhead 4-1/16" 10K Conventional Stripper 4-1/16" 10K x Wellhead Adapter Flange 5K CO62 x 4-1/16" 10K Flange 5K CO62 Lubricator 4-1/16" 10K Flow Cross Manual 2x2 Valve 1: 2" 1502 x 2-1/16" 10K Flange Manual 2x2 Valve 2: 2-1/16" 10K x 2-1/16" 10K Flange Manual 2x2 Valve 3: 2-1/16" 10K x 2-1/16" 10K Flange Manual 2x2 Valve 4: 2" 1502 x 2-1/16" 10K Flange 21 3 4 WH PSI 2" 1502 x 2-1/16 10K Flanged Valve (Manual) 2-1/16 10K x 2-1/16 10K Flanged Valve (Manual) Kill Port Coiled Tubing HR580 Injector Head & Gooseneck Weight = 12,850 lbs Swanson River Field SRU 241-16 10/20/2020 STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 1. 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: 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): 4,264'>3,772' (plug) Casing Collapse Structural Conductor 1,410 psi Surface 3,090 psi Intermediate Production 5,410 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Todd Sidoti Operations Manager Contact Email: Contact Phone: 777-8443 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng todd.sidoti@hilcorp.com 3,636'3,415'3,223'~937 psi 3,772' HES PHL Pkr; N/A 3,370' MD / 2,757' TVD; N/A Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028077 204-088 50-133-20540-00-00 Swanson River Unit (SRU) 241-16 Swanson River / Sterling/Upper Beluga Gas Pool Length Size CO 716 Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 6.5# / L-80 TVD Burst 3,396' 7,240 psi MD 2,980 psi 5,750 psi 66.5' 1,388' 66.5' 1,553' 3,636'7" 16" 9-5/8" 66.5' 1,553' 4,264' Perforation Depth MD (ft): See Attached Schematic 4,264' Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 8/1/2021 2-7/8" Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:11 am, Jul 16, 2021 321-352 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.07.16 00:02:04 -08'00' Taylor Wellman (2143) BJM 7/22/21 SFD 7/16/2021 10-404 DSR-7/19/21 dts 7/22/2021 JLC 7/22/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.22 16:38:22 -08'00' RBDMS HEW 7/22/2021 Well Prognosis Well: SRU 241-16 Date: 7/15/2021 Well Name: SRU 241-16 API Number: 50-133-20540-00-00 Current Status: SI Gas Well Leg: N/A Estimated Start Date: 8/1/2021 Rig: Eline Reg. Approval Req’d? 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 204-088 First Call Engineer: Todd Sidoti (907) 777-8443 (O)(907) 632-4113 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (O)(985) 867-0665 (C) Maximum Expected BHP: ~ 1,212 psi @ 2,755’ TVD Based on a 0.44psi/ft gradient. Max. Potential Surface Pressure: ~ 937 psi Gas gradient to surface @ 0.1 psi/ft Brief Well Summary SRU 241-16 is a deviated well drilled in May 2004 near the Sterling’s structural crest in Block 6. For 15 years, gas was prolific from B6, B4, and B3. In mid-2020, once the B3 died, the B2L was added with the B3 still open, but production did not recover. Shortly later the B3 and B2L were isolated and the B2U was shot, also without effect. Curiously, the gun returned full of dry sand, leading to a bailing intervention that discovered excessive grease and fill. After a diesel cleaning, SL tagged bottom but the well still did not flow. Less than two weeks later, work to plug back B2U found fill covering all B2L perfs and the FL at ~700’ MD. Efforts to push fluid and some fill into the B2L perfs were unsuccessful, so the plug was set in a column of water. Similarly, SL could only swab down to ~3300’ MD and the A14 perfs were added under ~168’ of water. The guns (obviously) returned wet and pressure fell without any flow. A post-perf echo meter showed the FL had risen to ~1200’ MD, suggesting the A14 is wet. In October 2020 the well was recompleted moving the packer uphole for access to more Sterling intervals. The A-12 and a small section of the A-11 were shot and produced for 9 months before watering out. Objective The purpose of this work is to plug back and perforate more uphole Sterling A sands. BLM Variance Request Hilcorp is requesting a variance to Onshore Order 2 section G.2.i requiring that a bridge plug must be set between 50 and 100 feet from the open perforations. In order to get a 35’ cement cap and be able to perforate our new sand we are requesting to set the plug 35’ above the perforations. Operations 1. Shoot fluid level. 2. Depress fluid into formation with gas lift injection. Note breakover pressure. 3. Shoot fluid level. 4. Trap 1100 psi on tubing. E-line 1. MIRU E-line. Pressure test lubricator to 250 psi low / 2,500 psi high. 2. RIH and set Spiral TTBP at 3332’. Cap with beads and 35’ (56.5 gallons) of cement. perforate more uphole Sterling A sands. Well Prognosis Well: SRU 241-16 Date: 7/15/2021 3. Perforate the following sand intervals from bottom to top: Sand MD Top MD Bottom TVD Top TVD Bottom Total Footage A-9 ~3081’ ~3090’ ~2493’ ~2501’ ~9 A-10 ~3143’ ~3151’ ~2548’ ~2555’ ~8 A-11 ~3268’ ~3285’ ~2662’ ~2678’ ~17 a. Trap 1100 psi on tubing for the initial A-11 perforations. b. If perforating an interval results in water production: we will rig up field gas and depress fluid into the perforations, set a through-tubing plug and dump bail 35’ of cement before moving uphole. c. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to Geologist (Jeff Nelson) and Reservoir Engineer (Meredyth Richards) for confirmation. d. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record a tubing Surface pressure before each run and after each gun firing of 5, 10, 15 min reading intervals. e. The Sterling Sands are governed by Conservation Order 716. 4. POOH. RDMO e-line. 5. Turn well over to production. Attachments 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Updated by DMA 05-13-21 SCHEMATIC Swanson River Unit Well: SRU 241-16 Completion Ran: 10/01/20 PTD: 204-088 API: 50-133-20540-00-00 1 TD = 4,264' MD; 3,636’ TVD PBTD =3,415’ MD; 2,799’ TVD Max hole angle = 51.5q @ 1,822’ RKB = 338.5' / GL = 318.0’ AMSL RKB to THF = 20.5’ CASING DETAIL Size Wt Grade Conn ID Top Btm 16" 68 J-55 Weld Surf. 66.5' 9-5/8" 40 L-80 BTC 8.835" Surf. 1,553' 7 26 L-80 BTC 6.276" Surf. 4,264' TUBING DETAIL 2-7/8" 6.4 L-80 IBT 2.441" Surf 2,267’ JEWELRY DETAIL No. Depth ID Item 1 25’ 2.441" Cross - Over 4-1/2" 12.6# x 2-7/8" 6.4# IBT Box x Pin 2 2,241’ 2.360” 7” HES PHL Production Packer 3 2,250’ 2.313” X Nipple Profile 4 2,267’ 2.441" Wire Line Entry Guide 5 3,450’ - TTBP w/ 35’ cement – TOC @ 3,415’ 9/30/20 6 3,618’ - Spiral Plug w/ cement – TOC @ 3,560’ 8/7/20 7 3,715 - Spiral Plug w/ cement – TOC @ 3,680’ 7/20/20 8 3,772’ - TT Plug Assembly for 7” casing w/ ~22.5’ cement 4/21/15 9 3,850’ - Cement (5 bbls of 15.8# LXT Cement) 10 3,955’ - Failed Posiset Plug (pushed downhole w/ coil 5/30/08) 11 Unknown - Failed TTS Umbrella Plug (did not tag at 4,030’ 5/29/07) PERFORATION DETAIL Date Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Gun Size Spf Phase Comments 3/30/21 A-11 3,367’ 3,369’ 2,755’ 2,756’ 2’ 1.75” 6 60 Open 10/13/20 A-12 3,378’ 3,387’ 2,765’ 2,773 9’ 1.75” 6 60 Open 8/11/20 A-14 3,468’ 3,476’ 2,848’ 2,894’ 8’ 1.75” 6 60 Isolated 7/20/20 B-2 3,667’ 3,672’ 3,043’ 3,048’ 5’ 1.75” 6 60 Isolated 6/24/20 B-3 3,728’ 3,733’ 3,103’ 3,108’ 5’ 1.75” 6 60 Isolated 4/26/15 B4L 3,765’ 3,770’ 3,139’ 3,144’ 5’ 2” 6 60 Isolated 4/11/12 B-4A 3,803’ 3,810’ 3,177’ 3,184’ 5’ 1-11/16” 7.5 45° Isolated 6/06/08 B-4A 3,805’ 3,810’ 3,179’ 3,184’ 5’ 1-11/16” 7.5 45° Isolated 9/16/04 B-6 4,027’ 4,032’ 3,400’ 3,404’ 5’ 2.0” 6 60° Isolated 9/16/04 B-6 4,033’ 4,037’ 3,405’ 3,409’ 4’ 2.0” 6 60° Isolated // B-6 3 2 TOC @ 3,850’ Fill @ 4,233’ B-4A X 4 8 10 11 Fill @ 3,784’ SLM 16” 9-5/8” 7” B-4L 9 TOC @ 3,772’ WLM TOC @ 2,170’ A14 B2 B3 7 6 TOC @ 3,680’ WLM TOC @ 3,560’ WLM A12 5 A11 TOC @ 3,415’ WLM Updated by TCS 07-15-21 PROPOSED SCHEMATIC Swanson River Unit Well: SRU 241-16 Completion Ran: 10/01/20 PTD: 204-088 API: 50-133-20540-00-00 1 TD = 4,264' MD; 3,636’ TVD PBTD =3,297’ MD; 2,689’ TVD Max hole angle = 51.5q @ 1,822’ RKB = 338.5' / GL = 318.0’ AMSL RKB to THF = 20.5’ CASING DETAIL Size Wt Grade Conn ID Top Btm 16" 68 J-55 Weld Surf. 66.5' 9-5/8" 40 L-80 BTC 8.835" Surf. 1,553' 7 26 L-80 BTC 6.276" Surf. 4,264' TUBING DETAIL 2-7/8" 6.4 L-80 IBT 2.441" Surf 2,267’ JEWELRY DETAIL No. Depth ID Item 1 25’ 2.441" Cross - Over 4-1/2" 12.6# x 2-7/8" 6.4# IBT Box x Pin 2 2,241’ 2.360” 7” HES PHL Production Packer 3 2,250’ 2.313” X Nipple Profile 4 2,267’ 2.441" Wire Line Entry Guide 4A 3,332’ - Spiral TTBP w/ 35’ of cement – TOC @ 3,297’ 5 3,450’ - TTBP w/ 35’ cement – TOC @ 3,415’ 9/30/20 6 3,618’ - Spiral Plug w/ cement – TOC @ 3,560’ 8/7/20 7 3,715 - Spiral Plug w/ cement – TOC @ 3,680’ 7/20/20 8 3,772’ - TT Plug Assembly for 7” casing w/ ~22.5’ cement 4/21/15 9 3,850’ - Cement (5 bbls of 15.8# LXT Cement) 10 3,955’ - Failed Posiset Plug (pushed downhole w/ coil 5/30/08) 11 Unknown - Failed TTS Umbrella Plug (did not tag at 4,030’ 5/29/07) PERFORATION DETAIL Date Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Gun Size Spf Phase Comments TBD A-9 ~3,081’ ~3,090’ ~2,493’ ~2,501’ ~9 - - - Open TBD A-10 ~3,143’ ~3,151’ ~2,548’ ~2,555’ ~8 - - - Open TBD A-11 ~3,268’ ~3,285’ ~2,662’ ~2,678’ ~17 - - - Open 3/30/21 A-11 3,367’ 3,369’ 2,755’ 2,756’ 2’ 1.75” 6 60 Isolated 10/13/20 A-12 3,378’ 3,387’ 2,765’ 2,773 9’ 1.75” 6 60 Isolated 8/11/20 A-14 3,468’ 3,476’ 2,848’ 2,894’ 8’ 1.75” 6 60 Isolated 7/20/20 B-2 3,667’ 3,672’ 3,043’ 3,048’ 5’ 1.75” 6 60 Isolated 6/24/20 B-3 3,728’ 3,733’ 3,103’ 3,108’ 5’ 1.75” 6 60 Isolated 4/26/15 B4L 3,765’ 3,770’ 3,139’ 3,144’ 5’ 2” 6 60 Isolated 4/11/12 B-4A 3,803’ 3,810’ 3,177’ 3,184’ 5’ 1-11/16” 7.5 45° Isolated 6/06/08 B-4A 3,805’ 3,810’ 3,179’ 3,184’ 5’ 1-11/16” 7.5 45° Isolated 9/16/04 B-6 4,027’ 4,032’ 3,400’ 3,404’ 5’ 2.0” 6 60° Isolated 9/16/04 B-6 4,033’ 4,037’ 3,405’ 3,409’ 4’ 2.0” 6 60° Isolated 9/15/04 B-6 4,027’ 4,032’ 3,400’ 3,404’ 5’ 2.0” 6 60° Isolated B-6 3 2 TOC @ 3,850’ Fill @ 4,233’ B-4A X 4 8 10 11 Fill @ 3,784’ SLM 16” 9-5/8” 7” B-4L 9 TOC @ 3,772’ WLM TOC @ 2,170’ A14 B2 B3 7 6 TOC @ 3,680’ WLM TOC @ 3,560’ WLM A12 5 A11 TOC @ 3,415’ WLM TOC @ 3,297’ WLM 4A 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 and return one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Hilcorp North Slope, LLC Date: 06/23/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type SRU 11-22 50133206120000 213055 11/3/2020 PERF GAMMA RAY SRU 12-15 50133101380000 183032 10/14/2020 SET PLUG SRU 12-15 50133101380000 183032 10/21/2020 PERF GAMMA RAY SRU 213-15 50133206520000 215100 6/25/2020 PERF GAMMA RAY/GPT SRU 241-16 50133205400000 204088 10/13/2020 PERF GAMMA RAY SRU 241-16 50133205400000 204088 3/30/2021 PERF GAMMA RAY KGSF 1A 50133101600100 220063 11/13/2020 PERF GAMMA RAY Please include current contact information if different from above. 06/28/2021 Received By: 37' (6HW By Abby Bell at 12:21 pm, Jun 28, 2021 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 and return one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Hilcorp North Slope, LLC Date: 06/23/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type SRU 11-22 50133206120000 213055 11/3/2020 PERF GAMMA RAY SRU 12-15 50133101380000 183032 10/14/2020 SET PLUG SRU 12-15 50133101380000 183032 10/21/2020 PERF GAMMA RAY SRU 213-15 50133206520000 215100 6/25/2020 PERF GAMMA RAY/GPT SRU 241-16 50133205400000 204088 10/13/2020 PERF GAMMA RAY SRU 241-16 50133205400000 204088 3/30/2021 PERF GAMMA RAY KGSF 1A 50133101600100 220063 11/13/2020 PERF GAMMA RAY Please include current contact information if different from above. 06/28/2021 Received By: 37' (6HW By Abby Bell at 12:21 pm, Jun 28, 2021 1. Operations Abandon Plug Perforations Fracture Stimulate RWO Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: N2 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: 3,450; 3,618; 3,715; Total Depth measured 4,264 feet 3,772; 3955 feet true vertical 3,636 feet >3,955' (plug) feet Effective Depth measured 3,415 feet 3,370 feet true vertical 2,799 feet 2,757 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)2-7/8" 6.4# / L-80 2,267' MD 1,848' TVD Packers and SSSV (type, measured and true vertical depth)HES PHL Ret Pkr; N/A 2,241' MD 1,831' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Todd Sidoti Authorized Title:Operations Manager Contact Email: Contact Phone:777-8443 todd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 2,980psi 7,240psi 67' 1,388'5,750psi Collapse 1,410psi 3,090psi 5,410psi Casing Structural 16" 9-5/8" Length 67' 1,553' 4,264' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 265 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-389 153 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 100 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-088 50-133-20540-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 00 Swanson River Unit (SRU) 241-16 N/A FEDA028077 Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Swanson River / Sterling/Upper Beluga Gas PoolN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 7"4,264'3,636' WINJ WAG 0 Water-Bbl MD 67' 1,553' 50 t Fra O 6. A G L SPPP assss G , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Meredith Guhl at 8:44 am, May 17, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.05.14 16:28:30 -08'00' Taylor Wellman (2143) RBDMS HEW 5/17/2021 DSR-5/17/21 SFD 5/20/2021BJM 8/10/21 Rig Start Date End Date 9/25/20 5/11/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 241-16 50-133-20540-00 204-088 Daily Operations 09/25/2020 - Friday 09/29/2020 - Tuesday Hold PTSM & review jsa's with rig personnel. Test bope per AOGCC approved sundry, tested annular to 250/2,500, tested vbr, blind, choke & kill line valves, & choke manifold to 250/3,500. All held same. VBR was tested with 2-7/8" tubing. L/D test joint assembly & break down, P/U landing joint, back out hold down pins. Pull hanger off of head with 23k, pull up to 63K & packer come free. Shut in annular. Pump 65 bbls down tbg attempting to circulate, unable to obtain returns. R/U Foster tongs & prepare to pooh. Pull hanger to rig floor, break & l/d same. continue pooh with 2- 7/8" 6.4# ibt ssc tbg, rolling control line onto spooler. L/D 30 jts unneeded for new completion, continue pooh racking 37 stands in derrick. Total of 104 joints out of hole, 142 bands, 4 pup joints, chemical mandrel, & packer out of hole. Secure well & rest crew. Hold PTSM with rig personnel. L/D derrick onto carriage, secure guy line cables & prep rig for road transport. Load out rig 401 & all support equipment onto trailers. P/U herculiner & clean location. Transport rig & 13 of 19 loads equipment from BCU-19 to SRU 241-16. 09/28/2020 - Monday Hold PTSM & review jsa with rig crew. Open well, SITP = 0 PSI, Pump 75 bbls of 8.4 produced water @ 4bpm & 400 psi down tbg. shut pump down. well on slight vacuum. Set bpv, N/D production tree, dress lift threads inside of hanger & remove (6) rusted studs inside of tbg head spool. N/U 11" X 7" Dsa, mud cross, double ram bop, & hydril. hook up Koomey lines, N/U choke & kill lines onto flow cross. Install rig floor with hand rails & stairs. attempt to pressure up Koomey system & found leaking 1" HP nipple. Shut down unit, secure & bleed down same. Report 1/4 gallon hydraulic spill to John Coston & send photos of incident, Clean fluid off of herculiner. Remove & replace 1" nipple, found hair line crack in threads of replaced nipple. Install 2-7/8" test joint assembly & void test bope to 250/3,000. Held same. Perform general housekeeping, service rig & rest crew for night. 09/27/2020 - Sunday Hold PTSM with rig crew. Dress location around well head. Lay out felt & herculiner. Spot base beam & rig 401. Level rig carriage, install landings & stairs. Perform pre-lift inspection. Lift & fully scope derrick, secure guy wires. Spot choke house, 170 bbl mud tank, fluid pump, Koomey house, generator & other support equipment. Build containment around rig. Hook up communications. Lay out & hook up choke & kill lines, Koomey remote panel, pvt & gas detection equipment, pump lines & all electrical lines. N/D blind flange from production tree & N/U pump in flange onto wing valve. Perform walk around inspection. Rig 100 percent rigged up & in compliance @1800 hrs. e pooh with 2- 7/8" 6.4# ibt ssc tbg, Rig Start Date End Date 9/25/20 5/11/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 241-16 50-133-20540-00 204-088 Daily Operations 09/30/2020 - Wednesday Hold PTSM & review jsa's with rig & AK eline personnel. Spot & R/U AK e-line unit & pressure control equipment. N/U 11" x 7" adaptor flange & shooting flange to top of hydril. P/U 5.80 GR/JB, test lubricator to 500/3,000, test good. RIH with 5.80" GR/JB to 3,543' & tag same. Log up & make tie-in. Send tie-in log to Anchorage to advise. POOH to surface, L/D JB/GR. P/U 5.60" CIBP for 7" 26# casing. RIH & make final tie-in. Set plug per approved sundry @ 3,450' with a 300 lb weight loss. P/U 50', lower tools & tag plug. Plug in place, log off plug 100' & pooh. Perform MIT-IA to 1,500 psi on chart for 30 minutes. Held same. P/U 3 X 10' sections of 5" bailer, load with 17# Neo super slurry cement. RIH to 3,450' & dump cement, POOH same & L/D bailer. Change out blasting cap, mix & reload bailer with cement, RIH to to 3,432'. dump cement leaving cement estimated top @ 3,415'. POOH & L/D bailer assembly. R/D AK E-line, N/D 11" X 7" adaptor flange & shooting flange from top of hydril. Secure well & rest crew. 10/01/2020 - Thursday Hold PTSM & review JSA'S with rig personnel & Halliburton packer tech. P/U WLEG with tail pipe assembly. X-N, Halliburton 7" 26# permalock packer. RIH same on 2-7/8" ibt tbg , Install hanger & landing joint, land out tbg with WLEG @2,267.13'. Tbg weight = 15k. x-n @ 2,256.44', Hydraulic set permalock Packer top @ 2,240.97'. Run in lock down pins, Hook up circulating lines. Displace tbg & IA with 115 bbls of clean 3% kcl. Drop ball /rod & allow to fall. Pressure up on tbg to 3,000 psi, hold for 5 minutes to set packer per Halliburton recommendation. Bleed off tbg. Perform MIT test against packer to 1,500 psi on chart for 30 minutes. Held same. L/D landing joint & install bpv. Clear rig floor, l/d elevators & bails, remove hand rails & stairs, R/D rig floor. N/D & load out 11" hydril, double gate bop, & flow cross. Dress hanger, Install 11" x 3-1/8" tree. install wing valve. Test void & tree to 5,000 psi. Held same. Rig released from SRU 241-16 @ 1900 hrs. 10/02/2020 - Friday Hold PTSM with rig crew. Inspect derrick for lowering. Scope in & lay over derrick onto carriage. Separate Hilcorp & rental subs. Release all rental equipment. Clean mud pits, r/d electrical wiring & pump lines. Remove landings & walkways from rig. Load out & prep all equipment for road transport. Clean & police location. 10/07/2020 - Wednesday PTW/JSA with petrospec, Cruz and Hilcorp Rep. MIRU Petrospec CTUJ 131 with 1.75" CT. Spot return tank, choke skid, iron rack and crane. Stab pipe through injector head. Break wellhead flange . Install 4 1/16 combi BOP stack. Start BOPE test. Test all rams and valves 250/4000 psi. Perform accumulator draw down test. Good test. spot in SLB N2 pump. Perform location walk around. Location secure. SDFN. P/U 5.60" CIBP for 7" 26# casing. RIH & make final tie-in. Set plug per approved sundry @ 3,450' c set permalock Packer top @ 2,240.97' Test void & tree to 5,000 psi. to 1,500 psi on chart for 30 minutes. MIT test against packer r t P/U WLEG with tail pipe assembly. X-N, Halliburton 7" 26# permalock packer. RIH same on 2-7/8" ibt tbg , Perform MIT-IA to 1,500 psi o g cement estimated top @ 3,415'. P Test all rams and valves 250/4000 psi. Rig Start Date End Date 9/25/20 5/11/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 241-16 50-133-20540-00 204-088 Daily Operations 05/11/2021 - Tuesday Operations Engineer met with Swanson River Reservoir Engineer and Geologist to discuss this well. Decision was made to close out this sundry even though well is declining and water production is up. We will explore installing a plunger lift system. 10/08/2020 - Thursday Sign in. Mobe to location. PTW and JSA. Spot and rig up equipment. PT lubricator to 250 psi low and 3,000 psi high. TP - 1,900 PSI. RIH w/1.75"x9' Razor HC, 6 spf, 60 deg phase, tie into SLB CBL and tag TOC at 3,411'. Ran correlation and send to town. Get ok to perf from 3,378' to 3,387' with 1,100 psi on tubing. Bleed tubing down to 1,042 psi. with crystal gauge. Spotted and fire gun with 1,042 psi on tubing. After 5 min - 1,037 psi, 10 min - 1,034 psi and 15 min - 1,031 psi. POOH. All shots fired and gun was wet. Unscrewed bull plug and fluid pour out. Rig down lubricator and turn over to field. Will be back in the morning to perf or rig down and move to SRU 12-15 to set plug and dump cement. We will also do both jobs tomorrow if it calls for it. 03/30/2021 - Tuesday Crew arrives at location. Permit, JSA jobscope. Rig up E-line. PT 250 low/2,500 high. RIH W/ 7' 1-11/16'' WB, 1-11/16'' GG W/ 1.75'' x 2' 6 SPF/60 degree to 3,385'. Make correlation pass (3,367'-3,369'). Send to town. No depth correction needed. Spot and shoot, A11, 3,367'-3,369'. POOH. Weight loss when guns went off. POOH. OOH. All shots fired. Gun was fired in fluid. WHP pre shots: 150 psi, shots fired: 153 psi, 5 min: 182 psi, 10 min: 263 psi, 15 min: 333 psi. Rig down E-line. Turn well over to production. E-line signs out/leaves facility. 10/13/2020 - Tuesday PTW, JSA with Petrospec, Cruz crane opearator, SLB N2 crew and Hilcorp Rep. Perform SIMOPS with Pollard slick line working on the same pad. Pick injector head. Make up Coil connector, DFCV, Jet swirl nozzle. Petrospec unable to perform reverse N2 blow down due to coil connector and DFCV assembly being one item. Rig up SLB N2 pump with 1500 gallons of N2 on truck. Stab on well. PT stack 250/4,000 psi for 5 minutes. Open swab and upper master valve. Initial WHP 0 psi. RIH with 1.75" Coil . Did not get returns from coil displacment right away. 500' returns at tank. 2,500' start cooling down N2. Waiting on Air Liquid N2 tanker delivery of 6,000 gallons. Tag top of cement at 3,420' CTMD. PT nitrogen iron to 250/5,000 psi. Online with N2 down coil at 1,500 scf/min 92*F. Circ pressure 2,450 psi. Air Liquid lost. Send rescue/recovery team to locate. Air liquid on locating 12:30. Transfer N2 from tanker to N2 pump. 55.8 bbls of KCL returned from wellbore. N2 gas at surface. Drop N2 rate to 800 scf/min. POOH to surface with coil. Close choke. While tripping OOH with coil walk WHP up to 2,150 psi. (2,000 psi required by sundry). Tagged up at surface. Close upper master and swab valve. 2,150 psi SITP. 55.8 bbls of fluid lifted from wellbore. Calculated wellbore volume is 57.55 bbls. 2,150 gallons of N2 pumped during job. Rig down Petrospec CTU, SLB N2 pump, and Cruz crane. Haul 55.8 bbls of KCL to Skim pit. Post job location walk around completed with coil crew. Location secure. Crews will de-mobe in AM. SDFN. Spot and shoot, A11, 3,367'-3,369' Spotted and fire gun w tag TOC at 3,411' o perf from 3,378' to 3,387' f Updated by DMA 05-13-21 SCHEMATIC Swanson River Unit Well: SRU 241-16 Completion Ran: 10/01/20 PTD: 204-088 API: 50-133-20540-00-00 1 TD = 4,264' MD; 3,636’ TVD PBTD =3,415’ MD; 2,799’ TVD Max hole angle = 51.5q @ 1,822’ RKB = 338.5' / GL = 318.0’ AMSL RKB to THF = 20.5’ CASING DETAIL Size Wt Grade Conn ID Top Btm 16" 68 J-55 Weld Surf. 66.5' 9-5/8" 40 L-80 BTC 8.835" Surf. 1,553' 7 26 L-80 BTC 6.276" Surf. 4,264' TUBING DETAIL 2-7/8" 6.4 L-80 IBT 2.441" Surf 2,267’ JEWELRY DETAIL No. Depth ID Item 1 25’ 2.441" Cross - Over 4-1/2" 12.6# x 2-7/8" 6.4# IBT Box x Pin 2 2,241’ 2.360” 7” HES PHL Production Packer 3 2,250’ 2.313” X Nipple Profile 4 2,267’ 2.441" Wire Line Entry Guide 5 3,450’ - TTBP w/ 35’ cement – TOC @ 3,415’ 9/30/20 6 3,618’ - Spiral Plug w/ cement – TOC @ 3,560’ 8/7/20 7 3,715 - Spiral Plug w/ cement – TOC @ 3,680’ 7/20/20 8 3,772’ - TT Plug Assembly for 7” casing w/ ~22.5’ cement 4/21/15 9 3,850’ - Cement (5 bbls of 15.8# LXT Cement) 10 3,955’ - Failed Posiset Plug (pushed downhole w/ coil 5/30/08) 11 Unknown - Failed TTS Umbrella Plug (did not tag at 4,030’ 5/29/07) PERFORATION DETAIL Date Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Gun Size Spf Phase Comments 3/30/21 A-11 3,367’ 3,369’ 2,755’ 2,756’ 2’ 1.75” 6 60 Open 10/13/20 A-12 3,378’ 3,387’ 2,765’ 2,773 9’ 1.75” 6 60 Open 8/11/20 A-14 3,468’ 3,476’ 2,848’ 2,894’ 8’ 1.75” 6 60 Isolated 7/20/20 B-2 3,667’ 3,672’ 3,043’ 3,048’ 5’ 1.75” 6 60 Isolated 6/24/20 B-3 3,728’ 3,733’ 3,103’ 3,108’ 5’ 1.75” 6 60 Isolated 4/26/15 B4L 3,765’ 3,770’ 3,139’ 3,144’ 5’ 2” 6 60 Isolated 4/11/12 B-4A 3,803’ 3,810’ 3,177’ 3,184’ 5’ 1-11/16” 7.5 45° Isolated 6/06/08 B-4A 3,805’ 3,810’ 3,179’ 3,184’ 5’ 1-11/16” 7.5 45° Isolated 9/16/04 B-6 4,027’ 4,032’ 3,400’ 3,404’ 5’ 2.0” 6 60° Isolated 9/16/04 B-6 4,033’ 4,037’ 3,405’ 3,409’ 4’ 2.0” 6 60° Isolated // B-6 3 2 TOC @ 3,850’ Fill @ 4,233’ B-4A X 4 8 10 11 Fill @ 3,784’ SLM 16” 9-5/8” 7” B-4L 9 TOC @ 3,772’ WLM TOC @ 2,170’ A14 B2 B3 7 6 TOC @ 3,680’ WLM TOC @ 3,560’ WLM A12 5 A11 TOC @ 3,415’ WLM 3/30/21 A-11 3,367’3,369’2,755’2,756’2’1.75” 6 60 Open 10/13/20 A-12 3,378’3,387’2,765’2,773 9’1.75” 6 60 Open 8/11/20 1”8’289 ’28 8’36’368’1 ld606 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: N2 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): 4,264'>3,772' (plug) Casing Collapse Structural Conductor 1,410 psi Surface 3,090 psi Intermediate Production 5,410 psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Todd Sidoti Operations Manager Contact Email: Contact Phone: 777-8443 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 9/25/2020 2-7/8" 4,264' Perforation Depth MD (ft): See Attached Schematic 4,264' 3,636'7" 16" 9-5/8" 66.5' 1,553' 2,980 psi 5,750 psi 66.5' 1,388' 66.5' 1,553' 6.5# / L-80 TVD Burst 3,396' 7,240 psi MDLength Size CO 716 Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028077 204-088 50-133-20540-00-00 Swanson River Unit (SRU) 241-16 Swanson River / Sterling/Upper Beluga Gas Pool COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic todd.sidoti@hilcorp.com 3,636' 3,850' 3,223' ~ 1,089 psi 3,772' HES PHL Pkr; N/A 3,370' MD / 2,757' TVD; N/A Perforation Depth TVD (ft): Tubing Size: Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 7:54 am, Sep 22, 2020 320-389 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.09.21 10:37:14 -08'00' Taylor Wellman X DLB 09/22/2020 DSR-9/24/2020 N2 401/ CTU *3000 psi BOPE test (401) *4000 psi BOPE test (CTU) RWO X Tubing 10-404 gls 9/23/20Comm 9/25/2020 dts 9/25/2020 JLC 9/25/2020 Well Prognosis Well: SRU 241-16 Date: 9/17/2020 Well Name: SRU 241-16 API Number: 50-133-20540-00-00 Current Status: SI Gas Well Leg: N/A Estimated Start Date: 10/1/20 Rig: 401 Reg. Approval Req’d? 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 204-088 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (C) Maximum Expected BHP: ~ 1,400 psi @ 3,110’ TVD Based on a 0.44psi/ft gradient. Max. Potential Surface Pressure: ~ 1,089 psi Gas gradient to surface @ 0.1 psi/ft Brief Well Summary SRU 241-16 is a deviated well drilled in May 2004 near the Sterling’s structural crest in Block 6. For 15 years, gas was prolific from B6, B4, and B3. In mid-2020, once the B3 died, the B2L was added with the B3 still open, but production did not recover. Shortly later the B3 and B2L were isolated and the B2U was shot, also without effect. Curiously, the gun returned full of dry sand, leading to a bailing intervention that discovered excessive grease and fill. After a diesel cleaning, SL tagged bottom but the well still did not flow. Less than two weeks later, work to plug back B2U found fill covering all B2L perfs and the FL at ~700’ MD. Efforts to push fluid and some fill into the B2L perfs were unsuccessful, so the plug was set in a column of water. Similarly, SL could only swab down to ~3300’ MD and the A14 perfs were added under ~168’ of water. The guns (obviously) returned wet and pressure fell without any flow. A post-perf echo meter showed the FL had risen to ~1200’ MD, suggesting the A14 is wet. Objective The purpose of this work is to recomplete the well moving the packer uphole so that more Sterling intervals can be shot and tested. Rig 401 1. MIRU 401 workover rig. 2. Load well with 8.4 ppg lease water. a. It is ok to inject into the A-14 perfs as they will be abandoned. 3. Set BPV/TWC. 4. ND tree, NU BOPE and test to 250 psi low & 3000 psi high, annular to 250 psi low & 2,500 psi high. a. Notify AOGCC 24 hrs in advance of BOP test. b. Record accumulator pre-charge pressures and chart tests. c. Test rams on 2-7/8” test joint. d. Submit completed form 10-424 to AOGCC within 5 days of BOPE test. 5. Pull BPV/TWC 6. Top of well with lease water to determine fill-up rate required. 7. Stab 4-1/2” landing joint into tubing hanger. 8. Pull tension on tubing to shear and release packer at 3,370’ MD. 9. POOH with 2-7/8” completion. a. Spool up chemical injection line while pulling tubing until the injection mandrel is laid down. 10. RU E-line and pressure test lubricator to 250 psi low / 3,000 psi high. 11. RIH with JB/GR and drift for CIBP. 12. RIH with CIBP and set at ~3450’, tag plug to confirm set. Objective The purpose of this work is to recomplete the well moving the packer uphole 3000 psi BOPE test (consider tubing punch before pulling tubing) (2 7/8" max yield 145K lbs ) (verify IA/tbg fluid level and pressure is 0 psi ) plug perfs. so that more Sterling intervals can s be shot and tested.e s Well Prognosis Well: SRU 241-16 Date: 9/17/2020 a. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to Geologist (Jeff Nelson) and Reservoir Engineer (Meredyth Richards) for confirmation. 13. Dump bail 35’ of cement on top of CIBP. 14. RD E-line. 15. RIH with 2-7/8” completion and jewelry. 16. Land tubing in hanger to position packer at ~2270’. 17. Reverse circulate 80 bbls of 3% inhibited KCl down the IA taking returns from the tubing. a. Current fluid in the IA is 3% inhibited KCl. 18. Drop ball and rod to and pressure up to manufacturer’s recommendation to set packer. 19. Perform MIT-IA to 1500 psi charted for 30 minutes. 20. RU Slickline. Pressure test lubricator to 250 psi low / 3,000 psi high. RIH and retrieve ball and rod. RDMO Slick line. 21. RDMO Rig 401. Post-rig 1. MIRU Coil tubing unit. Pressure test BOP to 250 psi low / 3,000 psi high. 2. RU Nitrogen. RIH W/ Coil and blow well dry leaving 2,000 psi on wellhead. 3. RDMO Nitrogen and CTU. 4. MIRU E-line. Pressure test lubricator to 250 psi low / 3,000 psi high. 5. Perforate the following sand intervals from bottom to top: Sand MD Top MD Bottom TVD Top TVD Bottom Total Footage A-9 ~3081’ ~3090’ ~2493’ ~2501’ ~9 A-10 ~3143’ ~3151’ ~2548’ ~2555’ ~8 A-11 ~3268’ ~3285’ ~2662’ ~2678’ ~17 A-12 ~3378’ ~3387’ ~2765’ ~2773’ ~9 a. Trap 1100 psi on tubing for the initial A-12 perforations. b. If perforating an interval results in water production: we will rig up N2 and depress fluid into the perforations, set a through-tubing plug and dump bail 35’ of cement before moving uphole. c. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to Geologist (Jeff Nelson) and Reservoir Engineer (Meredyth Richards) for confirmation. d. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record a tubing Surface pressure before each run and after each gun firing of 5, 10, 15 min reading intervals. e. The Sterling Sands are governed by Conservation Order 716. 6. POOH. RDMO e-line. 7. Turn well over to production. Attachments 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Wellhead Schematic 4. Rig BOP Schematic 4000 psi *review N2 SOP with crews A-9 ~3081’ ~3090’ ~2493’~2501’~9 A-10 ~3143’ ~3151’ ~2548’~2555’ ~8 A-11 ~3268’ ~3285’ ~2662’~2678’ ~17 A-12 ~3378’ ~3387’ ~2765’~2773’~9 *notify inspector to witness MIT- casing/plug MIT-IA 1500 psi ( test casing/plug to 1500 psi / 15 min) Well Prognosis Well: SRU 241-16 Date: 9/17/2020 5. Coiled Tubing BOP Schematic 6. Standard Nitrogen Procedure 7. RWO Sundry Revision Change Form Updated by TCS 08-12-20 SCHEMATIC Swanson River Unit Well: SRU 241-16 Completion Ran: 6/07/04 PTD: 204-088 API: 50-133-20540-00-00 1 TD = 4,264' MD; 3,636’ TVD PBTD =3,560’ MD; 2,939’ TVD Max hole angle = 51.5q @ 1,822’ RKB = 338.5' / GL = 318.0’ AMSL RKB to THF = 20.5’ CASING DETAIL Size Wt Grade Conn ID Top Btm 16" 68 J-55 Weld Surf. 66.5' 9-5/8" 40 L-80 BTC 8.835" Surf. 1,553' 7 26 L-80 BTC 6.276" Surf. 4,264' TUBING DETAIL 2-7/8" 6.4 L-80 IBT 2.441" Surf 3,396' JEWELRY DETAIL No. Depth ID Item 1 25’ 2.441" Cross - Over 4-1/2" 12.6# x 2-7/8" 6.4# IBT Box x Pin 2 2,478’ 2.347” SFO-1C1 Chemical Injection Mandrel 3 3,370’ 2.360” 7” HES PHL Production Packer 4 3,382’ 2.313” X Nipple Profile 5 3,396’ 2.441" Wire Line Entry Guide 6 3,618’ - Spiral Plug w/ cement – TOC @ 3,560’ 8/7/20 7 3,715 - Spiral Plug w/ cement – TOC @ 3,680’ 7/20/20 8 3,772’ - TT Plug Assembly for 7” casing w/ ~22.5’ cement 4/21/15 9 3,850’ - Cement (5 bbls of 15.8# LXT Cement) 10 3,955’ - Failed Posiset Plug (pushed downhole w/ coil 5/30/08) 11 Unknown - Failed TTS Umbrella Plug (did not tag at 4,030’ 5/29/07) PERFORATION DETAIL Date Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Gun Size Spf Phase Comments 8/11/20 A-14 3,468’ 3,476’ 2,848’ 2,894’ 8’ 1.75” 6 60 Open 7/20/20 B-2 3,667’ 3,672’ 3,043’ 3,048’ 5’ 1.75” 6 60 Isolated 6/24/20 B-3 3,728’ 3,733’ 3,103’ 3,108’ 5’ 1.75” 6 60 Isolated 4/26/15 B4L 3,765’ 3,770’ 3,139’ 3,144’ 5’ 2” 6 60 Isolated 4/11/12 B-4A 3,803’ 3,810’ 3,177’ 3,184’ 5’ 1-11/16” 7.5 45° Isolated 6/06/08 B-4A 3,805’ 3,810’ 3,179’ 3,184’ 5’ 1-11/16” 7.5 45° Isolated 9/16/04 B-6 4,027’ 4,032’ 3,400’ 3,404’ 5’ 2.0” 6 60° Isolated 9/16/04 B-6 4,033’ 4,037’ 3,405’ 3,409’ 4’ 2.0” 6 60° Isolated 9/15/04 B-6 4,027’ 4,032’ 3,400’ 3,404’ 5’ 2.0” 6 60° Isolated B-6 4 3 TOC @ 3,850’ Fill @ 4,233’ 2 B-4A X 5 8 10 11 Fill @ 3,784’ SLM 16” 9-5/8” 7” B-4L 9 TOC @ 3,772’ WLM TOC @ 2,170’ A14 B2 B3 7 6 TOC @ 3,680’ WLM TOC @ 3,560’ WLM Updated by TCS 08-12-20 PROPOSED SCHEMATIC Swanson River Unit Well: SRU 241-16 Completion Ran: 6/07/04 PTD: 204-088 API: 50-133-20540-00-00 1 TD = 4,264' MD; 3,636’ TVD PBTD =3,415’ MD; 2,799’ TVD Max hole angle = 51.5q @ 1,822’ RKB = 338.5' / GL = 318.0’ AMSL RKB to THF = 20.5’ CASING DETAIL Size Wt Grade Conn ID Top Btm 16" 68 J-55 Weld Surf. 66.5' 9-5/8" 40 L-80 BTC 8.835" Surf. 1,553' 7 26 L-80 BTC 6.276" Surf. 4,264' TUBING DETAIL 2-7/8" 6.4 L-80 IBT 2.441" Surf ~2,270’ JEWELRY DETAIL No. Depth ID Item 1 25’ 2.441" Cross - Over 4-1/2" 12.6# x 2-7/8" 6.4# IBT Box x Pin 2 ~2,250’ 2.360” 7” Production Packer 3 ~2,260’ 2.313” X Nipple Profile 4 ~2,270’ 2.441" Wire Line Entry Guide 5 ~3,450’ - CIBP w/ cement – TOC @ 3,415’ x/x/20 6 3,618’ - Spiral Plug w/ cement – TOC @ 3,560’ 8/7/20 7 3,715 - Spiral Plug w/ cement – TOC @ 3,680’ 7/20/20 8 3,772’ - TT Plug Assembly for 7” casing w/ ~22.5’ cement 4/21/15 9 3,850’ - Cement (5 bbls of 15.8# LXT Cement) 10 3,955’ - Failed Posiset Plug (pushed downhole w/ coil 5/30/08) 11 Unknown - Failed TTS Umbrella Plug (did not tag at 4,030’ 5/29/07) PERFORATION DETAIL Date Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Gun Size Spf Phase Comments TBD A-9 ~3,081’ ~3,090’ ~2,493 ~2,501 ~9’ 1.75” 6 60 - TBD A-10 ~3,143’ ~3,151’ ~2,548’ ~2,555’ ~8’ 1.75” 6 60 - TBD A-11 ~3,268’ ~3,285’ ~2,662’ ~2,678’ ~17’ 1.75” 6 60 - TBD A-12 ~3,378’ ~3,387’ ~2,765’ ~2,773 ~9’ 1.75” 6 60 - 8/11/20 A-14 3,468’ 3,476’ 2,848’ 2,894’ 8’ 1.75” 6 60 Isolated 7/20/20 B-2 3,667’ 3,672’ 3,043’ 3,048’ 5’ 1.75” 6 60 Isolated 6/24/20 B-3 3,728’ 3,733’ 3,103’ 3,108’ 5’ 1.75” 6 60 Isolated 4/26/15 B4L 3,765’ 3,770’ 3,139’ 3,144’ 5’ 2” 6 60 Isolated 4/11/12 B-4A 3,803’ 3,810’ 3,177’ 3,184’ 5’ 1-11/16” 7.5 45° Isolated 6/06/08 B-4A 3,805’ 3,810’ 3,179’ 3,184’ 5’ 1-11/16” 7.5 45° Isolated 9/16/04 B-6 4,027’ 4,032’ 3,400’ 3,404’ 5’ 2.0” 6 60° Isolated 9/16/04 B-6 4,033’ 4,037’ 3,405’ 3,409’ 4’ 2.0” 6 60° Isolated 9/15/04 B-6 4,027’ 4,032’ 3,400’ 3,404’ 5’ 2.0” 6 60° Isolated B-6 3 2 TOC @ 3,850’ Fill @ 4,233’ B-4A X 4 8 10 11 Fill @ 3,784’ SLM 16” 9-5/8” 7” B-4L 9 TOC @ 3,772’ WLM TOC @ 2,170’ A14 B2 B3 7 6 TOC @ 3,680’ WLM TOC @ 3,560’ WLM A12 5 A11 A10 A9 TOC @ 2,170’ Swanson River SRU 241-16 09-20-2020 16'’ Casing hanger, Surface, Cameron, 13 5/8 x 9 5/8 BTC box bottom x LH acme, w/ T-103 neck Csg head, Cameron MBS- Lower, 11 5M x T-103 pocket bottom, w/ 2- 2'’ LPO Casing Spool, Cameron MBS- upper, 11 5M stdd top and bottom, w/ 2- 2 1/16 5M SSO Tubing hanger, CIW-CXS, 11 X 4 ½ IBT lift and susp, w/ 4'’ type H BPV profile, ¼’’ non continuous control line, 9 ¼ EN Swanson River SRU 241-16 16 x 9 5/8 x 7 x 4 ½ Valve, Master, CIW-FL, 4 1/16 5M FE, HWO, AA trim Valve, Upper Master, CIW-FL, 4 1/16 5M FE, HWO, AA trim Valve, Swab, CIW-FL, 4 1/16 5M FE, HWO, AA trim BHTA, Bowen, 4 1/16 5M FE x 7'’ Bowen union top 9 5/8'’ 7'’ 2 7/8'’ Coiled Tubing Services Pressure Category 1 BOP Configuration (0-3,500 psi) Client: Hilcorp Date: April 3rd, 2017 Drawn: Chad Barrett Revision: 0 Well Category: CAT I 4-1/16" 10K Combi BOP Top Set: Blind/Shear Second Set: Pipe/Slip Wellhead 4-1/16" 10K Conventional Stripper 4-1/16" 10K x Wellhead Adapter Flange 5K CO62 x 4-1/16" 10K Flange 5K CO62 Lubricator 4-1/16" 10K Flow Cross Manual 2x2 Valve 1: 2" 1502 x 2-1/16" 10K Flange Manual 2x2 Valve 2: 2-1/16" 10K x 2-1/16" 10K Flange Manual 2x2 Valve 3: 2-1/16" 10K x 2-1/16" 10K Flange Manual 2x2 Valve 4: 2" 1502 x 2-1/16" 10K Flange 21 3 4 WH PSI 2" 1502 x 2-1/16 10K Flanged Valve (Manual) 2-1/16 10K x 2-1/16 10K Flanged Valve (Manual) Kill Port Coiled Tubing HR580 Injector Head & Gooseneck Weight = 12,850 lbs Swanson River Field SRU 241-16 9/16/2020 STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well SRU 241-16 (PTD 204-088) Sundry #: XXX-XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Asset Team Operations Manager Date Prepared: First Call Operations Engineer Date 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: 3,618; 3,715; Total Depth measured 4,264 feet 3,772; 3955 feet true vertical 3,636 feet >3,955' (plug) feet Effective Depth measured 3,560 feet 3,370 feet true vertical 2,939 feet 2,757 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / L-80 3,395' MD 2,782' TVD Packers and SSSV (type, measured and true vertical depth)HES PHL Ret Pkr; N/A 3,370' MD 2,757' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Todd Sidoti Authorized Title:Operations Manager Contact Email: Contact Phone:777-8443 WINJ WAG 322 Water-Bbl MD 67' 1,553' 0 Oil-Bbl measured true vertical Packer 7"4,264'3,636' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Swanson River / Sterling/Upper Beluga Gas PoolN/A measured TVD Tubing Pressure 1701 Swanson River Unit (SRU) 241-16 N/A FEDA028077 Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-088 50-133-20540-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-260 0 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 100 Authorized Signature with date: Authorized Name: 100 Casing Pressure Liner 0 0 Representative Daily Average Production or Injection Data 67' 1,553' 4,264' Conductor Surface Intermediate Production 5,410psi Casing Structural 16" 9-5/8" Length 5,750psi Collapse 1,410psi 3,090psi todd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 2,980psi 7,240psi 67' 1,388' t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Jody Colombie at 12:05 pm, Aug 14, 2020 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.08.13 13:54:17 -08'00' Taylor Wellman RBDMS HEW 8/14/2020 Gas Perforate gls 10/22/20 DSR-8/17/2020 Plug Perforations SFD 8/17/2020 Rig Start Date End Date 6/24/20 8/10/20 06/24/2020 - Wednesday Sign in. Mobe to location. PTW, JSA and SIMOPS with Yellowjacket. Spot equipment and rig up lubricator. PT to 250 psi low and 2,000 psi high. Well flowing 300K at 180 psi. RIH w/GPT, tie into OHL and tag TOC at 3,772'. Run correlation log and send to town. We didn't find a solid fluid level. There was a couple hundred feet of soapy or gas cut fluid at the botton. Ran log with well flowing. POOH. RIH w/ 1-3/4" x 5' HC, Razor, 6spf, 60 deg phase and tie into OHL. Ran correlation log and send to town. Told to shift up 5' (subtract 5'). Shift log up 5'. Spotted and fired gun from 3,728' to 3,733' with well flowing 300K at 180 psi. After approx. 4 min well died with 165 psi. Well is bouncing f rom 0 flow to 17K. POOH. All shots fired and gun was wet. Rig down equipment and turn well over to field. Daily Operations: Hilcorp Alaska, LLC Weekly Operations Summary API Number Well Permit NumberWell Name SRU 241-16 50-133-20540-00 204-088 07/15/2020 - Wednesday Sign in. Mobe to location. PTW/JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 2,000 psi high. TP - 1,500 psi. RIH w/GPT tool and 2-1/8" Spiral Plug and tie into Halliburton log. Run correlation log and send to town. Told to subtract 5' from out log. Subtract 5' and spot top at 3,715' with 1,100 psi on tubing. Pick up 30' and go back down and lightly tag plug. POOH. Good set. We pressure up out lubricator to the well pressure before we open up to the well. We do that every time using field gas to keep plug stable. Run w/ two 2-1/4" x 40' bailer of beads and dump them on top of plug at 3,715'. POOH. Tag on 2d dump and it was good. RIH w/ two 2-1/4" x 40' bailers of 17 ppg cmt and tag bead easy. Pick up 2' and dump cement on top of beads. Both dumps were good. Found 2 section of bailer out of round and would hardly go in hole. Tried straighting them out but could not. Call town. Decision was made to SDFN and let Yellowjackect get there bailers straight and be back in morning to finish thed dump bailing. Rig down for the night. Be back in the morning. 07/16/2020 - Thursday 07/20/2020 - Monday Sign in. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT from 250 psi low and 3,000 psi high. Well had 950 psi om. Pressured up to 1,100 psi. RIH w/ 1-3/4" x 5' gu and tie into the OHL. Tag TOC at 3,680'. Ran correlation log and send to town. Told to subtract 1.5' from correlation log. Took 1.5' off correlation log and spotted gun from 3,667' to 3,672'. Fired gun with 1,100 psi on tubing. After 5 min - 1,100 psi, 10 min - 1,150 and 15 min - 1,150. POOH. All shots fired. Gun bull plug full of dry sand. Rig down lubricator and turn well over to field. Sign in. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT lubricator to 250 psi low and 3,000 psi high. TP - 1,100 psi. RIH w/ 1-11/16" x 40' Bailer and tagged cement at 3,704'. Dumped 17 ppg cement on top of cement. POOH and good dump. We made 9 more cement bailer runs and got good dumps on all runs. Cement samples were cured this morning from yesterday. Got samples for every run saved on back of trailer at SRU 241-16. I took last run sample with me. CIP at 2130 hrs. Est TOC - 3,679'. Rig down lubricator and secure swell. Will be back Monday to perforate. d gun was wet. Rig down e gun from 3,667' to 3,672' H w/GPT tool and 2-1/8" Spiral Plug and tie spot top at 3,715' with Perf B3 Perf B2 setCIBPat3715ft Tag TOC at 3,680'. Spotted and fired gun from 3,728' to 3,733' with well flowing 300K at 180 psi. Rig Start Date End Date 6/24/20 8/10/20 Daily Operations: Hilcorp Alaska, LLC Weekly Operations Summary API Number Well Permit NumberWell Name SRU 241-16 50-133-20540-00 204-088 07/25/2020 - Saturday SPOT EQUIPMENT, RU SLICKLINE, PT LUB TO 1,500 PSI. RIH W/ 2.25" DD BAILER, SET DOWN HARD @ 770KB AND BEGIN TO FALL VERY SLOWLY TO 1,025'KB. POOH W/ FULL BAILER OF E-LINE GREASE AND LIGHT SAND. RIH W/1.85 G- RING TO SAME AND FALL SLOWLY, PUMP 1/2 BARREL METHANOL AND BEGIN TO FALL FASTER THEN STOP MOVING AT 1,400FT, CALL PRODUCTION AND DELIVER DIESEL TRAILER, BEGIN TO PUMP ~ 1 BBL DIESEL DOWNHOLE AND FALL TO 3,637KB, TAG BOTTOM, POOH. OOH, RD SLICKLINE, CLEAN WELLSITE, RETURN EQUIPMENT TO BULLRAIL. SIGN-OUT, TURN IN PERMIT, DEPART FIELD. 07/26/2020 - Sunday ARRIVE AT SWANSON OFFICE, JSA, PERMIT. JUMP START CRANE TRUCK. RIG UP .125 S/L. RIH W/ 2.25'' x 4' DD BAILER TO 5,905'KB SIT DOWN, PICK UP FALLS THROUGH, MAKE SEVERAL PASSES THROUGH SPOT NO OBSTRUCTION RIH TO 6,285'KB. POOH - TAKE OFF KNUCKLE. FIND FLAT SPOT ON WIRE, SLIP AND CUT WIRE. RIH W/ SAME W/O KNUCKLE JOINT ON T/S TO 6.285'KB. POOH. RIG DOWN. DEPART FIELD, END TICKET. 08/05/2020 - Wednesday Sign in. Mobe to location. PTW and JSA. Spot and rig up Lubricator. PT to 250 psi low and 3,000 psi high. TP 1,600 psi. RIH w/GPT and 2.1" OD Spiral Plug and tie into CBL Log. Tagged at 3,618' and FL was 700' and 610' coming out of hole. Pressure was 1,600 psi. POOH. Called town and discussed. Fill was covering open perfs. RIH w/2.25" Gauge Ring and they didn't pressure up lubricator and pressure went to 900 psi. FL didn't change and tagged at same spot at 3,618'. Spudded approx. 7 times with gauge ring and didn't do any good. Started getting sticky so we POOH. Shut well in and let it settle down over night. Rig down for stand by and secure well. Will be back in am. 08/06/2020 - Thursday Sign in. Mobe to location. PTW and JSA. Rig up lubricator. PT to 250 psi low and 3,000 psi high. TP - 750. RIH w/GPT and 2 -1/8" OD Spiral Plug and tie into GPT log from yesterday. Tagged at 3,618' and found FL at 610'. Run Plug correlation log and send to town. Get ok to set plug at 3,600'. Spotted and set plug with 750 psi on tubing. Lost 100 lb of line tension. POOH. Good set. Had to run in hole at 50 fpm. Had a little trouble with panel but trouble shot and fixed. Ran in hole w/ 2" x 30' dump bailer loaded with beads and dumped on top of plug at 3,600'. POOH. Run 2d bailer full of beads and dumped on top of the first beads. POOH. Both dumps were good. We pressured up lubricator to 750 psi before we opened back up to well to keep it well stabilized. RIH w/ 2" x 30' Dump bailer filled with 17 ppg with accelerant and dumped cement on top of beads on top of plug. POOH good dump. RIH w/2d bailer full of 17 ppg cement w/accelerant and dumped on top of cement. POOH and good dump. Cement in place at 1400 hrs and est TOC at 3,591'. POOH and good dump. I have 2 cement samples with me and should be cured enough to dump the rest of cement tomorrow. Lay down lubricator and secure well. Will be back in morning to finish dump bailing rest of cement. y. Tagged at 3,618' and found FL at 610' . Get ok to set plug at 3,600' CIBP at 3600 ft D Spiral Plug and tie into CBL Log. Tagged at 3,618' and FL was 700' and 6 Rig Start Date End Date 6/24/20 8/10/20 Daily Operations: Hilcorp Alaska, LLC Weekly Operations Summary API Number Well Permit NumberWell Name SRU 241-16 50-133-20540-00 204-088 08/09/2020 - Sunday ARRIVE SWANSON RIVER, PJSM, PERMIT. PRE-TRIP EQUIPMENT, TRAVEL TO WELL. RD E-LINE CRANE, SPOT EQUIPMENT, RU SLICKLINE PT TO 1500 PSI. PASS. RIH w/ 2.25" DD BAILER, TAG @ 3,560' KB. POOH W/ BAILER FULL (1/2 GREASE, 1/2 WATER). RIH W/ 2 MANDRELS, 2 SWAB CUPS EACH TO 450' KB, BEGIN SWAB OPERATIONS. C/O CUPS (4 NEW). CONTINUE SWAB OPS FROM 1,190' KB. C/O CUPS (6 NEW). CONTINUE SWAB OPS FROM 1,790' KB. C/O CUPS (6), ADD 5' STEM IN BETWEEN MANDRELS. CONTINUE SWAB OPS FROM 2,700' KB. C/O CUPS (6), CONTINUE FROM 2,900' KB. SWAB TO 3,330' KB. CALL BILLY APPLEWHITE W/ RESULTS. DEPTH IS ACCEPTABLE. RD FUEL EQUIPMENT, TURN IN PERMIT, SIGN OUT. DEPART FIELD. ARRIVE PWL SHOP. 08/10/2020 - Monday Sign in. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 3,000 psi high. TP - 0. RIH w/ 2" x 8' Razor HC, 6 spf, 60 deg phase and tie into SLB CBL. Sent to town and told to down shift our log 8'. Shifted log 8' down and spotted and fired gun from 3,468' to 3,476' with 1,000 psi on tubing. After 5 min - 1,000 psi, 10 min - 990 psi, 15 min - 975 psi. POOH. All shots fired and gun was wet. Rig down lubricator and equipment. Turn well over to field. 08/07/2020 - Friday Sign in. Mobe to location. PTW and JSA. Rig up lubricator. PT to 250 psi low and 3,000 psi high. TP 750 psi. Cement samples were 100% cured. RIH w/ 2" x 30' dump bailer filled with 17 ppg cement and tag at 3,591'. Pick up 3' and dumped cement on top of cement from yesterday. Make 10 more successful cement dumps. Est TOC - 3,563' (37'), CIP at 1930 hrs. Rig down off to the side so slickline can swab well sunday. Secure well. Close all valves. RIH w/ 2" x 30' dump bailer filled with 17 ppg cement and tag at 3,591'. fired gun from 3,468'to 3,476' w Perf zone A14 Updated by TCS 08-12-20 SCHEMATIC Swanson River Unit Well: SRU 241-16 Completion Ran: 6/07/04 PTD: 204-088 API: 50-133-20540-00-00 1 TD = 4,264' MD; 3,636’ TVD PBTD =3,560’ MD; 2,939’ TVD Max hole angle = 51.5q @ 1,822’ RKB = 338.5' / GL = 318.0’ AMSL RKB to THF = 20.5’ CASING DETAIL Size Wt Grade Conn ID Top Btm 16" 68 J-55 Weld Surf. 66.5' 9-5/8" 40 L-80 BTC 8.835" Surf. 1,553' 7 26 L-80 BTC 6.276" Surf. 4,264' TUBING DETAIL 2-7/8" 6.4 L-80 IBT 2.441" Surf 3,396' JEWELRY DETAIL No. Depth ID Item 1 25’ 2.441" Cross - Over 4-1/2" 12.6# x 2-7/8" 6.4# IBT Box x Pin 2 2,478’ 2.347” SFO-1C1 Chemical Injection Mandrel 3 3,370’ 2.360” 7” HES PHL Production Packer 4 3,382’ 2.313” X Nipple Profile 5 3,396’ 2.441" Wire Line Entry Guide 6 3,618’ - Spiral Plug w/ cement – TOC @ 3,560’ 8/7/20 7 3,715 - Spiral Plug w/ cement – TOC @ 3,680’ 7/20/20 8 3,772’ - TT Plug Assembly for 7” casing w/ ~22.5’ cement 4/21/15 9 3,850’ - Cement (5 bbls of 15.8# LXT Cement) 10 3,955’ - Failed Posiset Plug (pushed downhole w/ coil 5/30/08) 11 Unknown - Failed TTS Umbrella Plug (did not tag at 4,030’ 5/29/07) PERFORATION DETAIL Date Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Gun Size Spf Phase Comments 8/11/20 A-14 3,468’ 3,476’ 2,848’ 2,894’ 8’ 1.75” 6 60 Open 7/20/20 B-2 3,667’ 3,672’ 3,043’ 3,048’ 5’ 1.75” 6 60 Isolated 6/24/20 B-3 3,728’ 3,733’ 3,103’ 3,108’ 5’ 1.75” 6 60 Isolated 4/26/15 B4L 3,765’ 3,770’ 3,139’ 3,144’ 5’ 2” 6 60 Isolated 4/11/12 B-4A 3,803’ 3,810’ 3,177’ 3,184’ 5’ 1-11/16” 7.5 45° Isolated 6/06/08 B-4A 3,805’ 3,810’ 3,179’ 3,184’ 5’ 1-11/16” 7.5 45° Isolated 9/16/04 B-6 4,027’ 4,032’ 3,400’ 3,404’ 5’ 2.0” 6 60° Isolated 9/16/04 B-6 4,033’ 4,037’ 3,405’ 3,409’ 4’ 2.0” 6 60° Isolated 9/15/04 B-6 4,027’ 4,032’ 3,400’ 3,404’ 5’ 2.0” 6 60° Isolated B-6 4 3 TOC @ 3,850’ Fill @ 4,233’ 2 B-4A X 5 8 10 11 Fill @ 3,784’ SLM 16” 9-5/8” 7” B-4L 9 TOC @ 3,772’ WLM TOC @ 2,170’ A14 B2 B3 7 6 TOC @ 3,680’ WLM TOC @ 3,560’ WLM 8/11/20 A-14 3 468’3 476’2,848’2,894’8’1.75”6 60 Open A14 TOC @ 3,560’ wet 6 3,618’-Spiral Plug w/ cement – TOC @ 3,560’ 8/7/20 7/20/20 B-2 7 3,715 -Spiral Plug w/ cement – TOC @ 3,680’ 7/20/20 TOC @ 3,680’ 6/24/20 B-3 wet By Samantha Carlisle at 12:44 pm, Jun 15, 2020 320-260 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.06.15 12:28:58 -08'00' Taylor Wellman SFD 6/15/2020 10-404 DSR-6/15/2020gls 6/16/20 6/16/2020 dts 6/16/2020 JLC 6/16/2020 RBDMS HEW 6/18/2020 Find fluid level Proposed Perforations. STATE OF ALASKA ALARA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Plug Perforations U Fracture Stimulate Li Pull Tubing Li Operations shutdown Li Performed: Suspend ❑ -perforate-meg' Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC / tw Development 0 Exploratory ❑ 204-088 3.Address: 3800 Centerpoint Drive,Suite 1400 res(..., Stratigraphic III Service ❑ 6.API Number: Anchorage,AK 99503 50-133-20540-00 7.Property Designation(Lease Number): 71, 6e-7.l4 8.Well Name and Number: FEDA028077 Swanson River Unit(SRU)241-16 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Sterling-Upper Beluga Gas Pool 11.Present Well Condition Summary: RECEIVED Total Depth measured 4,264 feet Plugs measured 3,955 feet true vertical 3,636 feet Junk measured >3,955'(plug) feeN OV 14 ?Mb ffi Effective Depth measured 3,850 feet Packer measured 3,370 fee `G J RSD cc true vertical 3,223 feet true vertical 2,757 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 66.5' 16" 66.5' 66.5' 2,980 psi 1,410 psi Surface 1,553' 9-5/8" 1,553' 1,388' 5,750 psi 3,090 psi Intermediate Production 4,264' 7" 4,264' 3,636' 7,240 psi 5,410 psi Liner t� Perforation depth Measured depth See Attached Schematic SCANNED MAR: 5 2017 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 3,396'MD 2,782'ND Packers and SSSV(type,measured and true vertical depth) HES PHL Ret Pkr;N/A 3,370'MD 2,757'ND N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 497 94 140 155 Subsequent to operation: 0 2581 0 125 210 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development❑� Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas Q✓ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-486 Contact Joe Kaiser-777-8393 Email jkaiserehilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature //. �`�' Phone 907-777-8405 Date lIJI%/kp Form 10-404 Revised 5/2015 (1 f(-13-(c RBDMS bmit Original Only , /4 `'SOV 1 6 2�6 • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 241-16 E-Line 50-133-20540-00 204-088 10/3/16 10/5/16 Daily Operations: 10/03/2016- Monday Held PJSM-Permit. MIRU EL, pressure test lub, good test. RIH w/ 1-11/16" GR/CCL to bottom at 3,777'. Made pass and tie-in log. Sent log in to Achorage. POOH RD EL. MIRU SL pressure tested lub,good test. RIH w/2.25" DD bailer to 3,777', worked bailer. POOH w/ 1 cup of sand. RIH w/2" DD bailer to 3,777'worked tool. POOH w/ 1 cup of sand. RIH w/2" DD bailer to 3,777', worked bailer. POOH w/1 cup of sand. RDMO SL. MIRU EL, RIH w/30' of 2" bailer and dump beads and cleaner. POOH. MU cement. RIH w/4 gals of cement and dumped. POOH. RIH and dumped 4 gals of cement and dumped. POOH. RDMO EL 10/04/2016-Tuesday SI Well waiting for cement to cure. 10/05/2016- Friday PJSM and permit. MIRU SL, pressure tested lub-good. RIH w/2" bailer and tagged @ 3,772'. POOH. 2 cups of E-line grease recovered from bailer. RDMO SL. Swanson River Unit Well: SRU 241-16 • SCHEMATIC Completion PTD:204088 Ran:6/07/04 Ilikor p Alaska.1.1.c API: 50-133-20540-00 RKB=338.5'/GL=318.0'AMSL RKB to THF=20.5' 1 CASING DETAIL Size Wt Grade Conn ID Top Btm 16" 16" 68 J-55 Weld Surf. 66.5' 9-5/8" 40 L-80 BTC 8.835" Surf. 1,553' 7 26 L-80 BTC 6.276" Surf. 4,264' TUBING DETAIL 2-7/8" 6.4 L-80 IBT 2.441" Surf 3,396' JEWELRY DETAIL 9.5/82 , No. Depth ID Item 1 25' 2.441" Cross-Over 4-1/2"12.6#x 2-7/8"6.4#IBT Box x Pin 2 2,478' 2.347" SFO-1C1 Chemical Injection Mandrel 3 3,370' 2.360" 7"HES PHL Production Packer 4 3,382' 2.313" X Nipple Profile 5 3,396' 2.441" Wire Line Entry Guide D 2 6 3,785' - TT Plug Assembly for 7"casing w/—15'cement 7 3,796' - TT Plug Assembly for 7"casing w/7.5'cement 8 3,850' - Cement(5 bbls of 15.8#LXT Cement) TOC @ 2,170' 9 3,955' - Failed Posiset Plug(pushed downhole w/coil 5/30/08) 10 Unknown - Failed TTS Umbrella Plug(did not tag at 4,030'5/29/07) 3 °'' =,;WC WC 4 PERFORATION DETAIL Date Zone Top Btm Top Btm Amt Gun Size Spf Phase Comments X 4 (MD) (MD) (TVD) (TVD) 4/26/15 B4L 3,765' 3,770' 3,139' 3,144' 5' 2" 6 60 Open 5 4/11/12 B-4A 3,803' 3,810' 3,177' 3,184' 5' 1-11/16" 7.5 45° Isolated 6/06/08 B-4A 3,805' 3,810' 3,179' 3,184' 5' 1-11/16" 7.5 45° Isolated 9/16/04 B-6 4,027' 4,032' 3,400' 3,404' 5' 2.0" 6 60° Isolated ' , ° 9/16/04 B-6 4,033' 4,037' 3,405' 3,409' 4' 2.0" 6 60° Isolated 9/15/04 8-6 4,027' 4,032' 3,400' 3,404' 5' 2.0" 6 60° Isolated B-4L TOC@ 3,772' *" WLM r 6 ,• .*,.,;' .. . .r '' TOC @ 3,789' 7 Fill @ ~'~'~'5"'4""'�"' :.r.r.r.r.r.r.r.r.r.� rLr~r~r~r~r~r~rtirtir~_B-4A 3,784'SLM }1}:}�}:}ti}'1.• �}ti7 '� o ' 18 TOC @ 3,850' ' 9 mMMEIMIM B 6 Max hole angle=51.5°@ 1,822' 10 , Y!::::•::.:r•r•r. r•r•r•r•r•r• 1.1.ti•L•ti•tiK•ti•ti•1.1 r•r•r•r•r•r•r•r•r•r• Fill @ 4,233' _ti!'L!1•ti!5.1•ti•ti•ti•ti•1 7" '... . 4 TD=4,264'MD;3,636'TVD PBTD=3,850'MD;3,223'TVD Downhole Revised:12/30/14 Updated by DMA 11-04-16 ID • SOF T4 Iyy:' A THE STATE Alaska Oil and Gas t � 9� Of Conservation C® CommissionE, � iA S 333 West Seventh Avenue ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 .r� Main: 907.279.1433 ALASY Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Sterling/Upper Beluga Gas Pool, SRU 241-16 Permit to Drill Number: 204-088 Sundry Number: 316-486 Dear Mr. Helgeson: sumo FE13 £ all?, Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathyal6-7 Foerster Chair DATED this 23 day of September, 2016. RBDMS LL S L & 016 • • RECEIVED STATE OF ALASKA S E P 2 1 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOC C 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations E • 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: ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development ❑.r 204-088 ' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service Li 6.API Number. Anchorage,Alaska 99503 50-133-20540-00. 7.If perforating: 7/6 A 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 20.C-29.05r p.Zj-4 Will planned perforations require a spacing exception? Yes ❑ ._ No 0Swanson River Unit(SRU)241-16 9.Property Designation(Lease Number): 10.Field/Pool(s): rr'ic�� ' 4; FEDA028077 Swanson River/Stet 17n �as�� /i,rp (�,�b 11. PRESENT WELL CONDITION SUMMARY 7 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 4,264' 3,636' 3,850' 3,223' 800 psi 3,955' >3,955(plug) Casing Length Size MD TVD Burst Collapse Structural Conductor 66.5' 16" 66.5' 66.5' 2,980 psi 1,410 psi Surface 1,553' 9-5/8" 1,553' 1,388' 5,750 psi 3,090 psi Intermediate Production 4,264' 7" 4,264' 3,636' 7,240 psi 5,410 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80 3,396' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): HES PHL Ret Pkr;N/A 3,370'MD-2,757'TVD;N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑✓ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: October 5,2016 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Joe Kaiser-777-8393 Email jkaiserc hilcorn.com Printed Name Chad Helgeson Title Operations Manager ;6/ Signature /"17 / Phone 907-777-8405 Date / W Z i COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. \ — Li (-it? Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Asc. CHI i g Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No E Subsequent Form Required: /6 ._ :Z/O y RBDMS LL SEP 2 6 2016 APPROVED BY Approved by:aze / _... .4_,,,L4......_ COM ISSIONER THE COMMISSION Date: 47.- Z 3-�(, CIRIQ � 7',L'lSubmit Form and Form 10-403 Revised 11/2015 I tib Is va 1 for 12 rrrNNN666nths from the date of approval. Attachments in Duplicate • • Well Prognosis Well: SRU 241-16 [Ekon)Alaska,LLC Date:9/21/2016 Well Name: SRU 241-16 API Number: 50-133-20540-00 Current Status: Gas Well Leg: N/A Estimated Start Date: Oct. 5th, 2016 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 204-088 First Call Engineer: Joe Kaiser (907) 777-8393 (0) (907) 952-8897 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: —640 psi @ 3,154' TVD (Based on 1HR build-up on 8/18/15) Max. Predicted Surface Pressure: —800 psi (Surface pressure applied from gas lift) Brief Well Summary Swanson River Unit Well 241-16 was drilled in 2004 with the first perforations in the Sterling B-6 Sand.This sand was produced until 2008. In 2008, attempts to isolate the B-6 sand with through tubing plugs failed.At this time,the decision was made to push the plug to near the top of the B-6 perforations and place cement on top. Once the B-6 zone proved to be isolated, the B-4A sand was perforated. In 2012, the B-4A zone was reperforated and flowed until the well flowed too much sand to handle at surface and was shut-in. In 2015, the B-4A sand was isolated and perforated in the B4L sand zone. In June 2016,the water production started to increase and a spinner survey was run on 7/6/2016 which had signs that the plug at 3,789' is not isolating,.&.4A.,. zone below. fere PL"a . Hilcorp is requesting to isolate the B-4A sand and perforate the sands uphole. Notes Regarding Wellbore Condition • Well is currently producing about 100 bbl/day water. • Fill was tagged at 3,666'on 9/14/16. 7; • Utilize gas lift supply to pressure up well and push away water prior to setting any TTP plug. • Slickline may be used to tag bottom, bail fill, and run gauge ring/dummy guns prior to E-line procedures below. • Eline/slickline will be used post isolation and perforations to determine fluid levels and collect water samples. E-line Procedure: Isolate 8-4A Sand 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU gauge ring assembly. RIH and tag bottom. POOH. 3. RU through tubing plug(TTP) assembly for 7" casing. RIH with plug assembly.Tag TOC at 3,789' and pull up 2'. (Do not set TTP across collar). If there is fill on cement plug, use slickline bailer to remove debris. 4. Set plug in 7" casing at"3,785'. POOHp,-,_ 5. RU bailer assembly. RIH with bailer assembly. Dump 1 bailer of PW. POOH. 6. RIH with bailer assembly. Dump bail sufficient cement on top of TTP to bottom of B4L perf at 3,770'.Approximately 15'of cement. POOH. Wait 24hrs for cement to cure before flowing well. 7. RD E-line 8. Turn well over to Operations and test well to see if B-4A zone is still leaking by the plug. ` • Well Prognosis Well: SRU 241-16 Hilcorp Alaska,LLC Date:9/21/2016 E-line Procedure (Continued): If existing B-4L/B-4A zone continues to produce water. 9. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 10. RU gauge ring assembly. RIH and tag bottom. POOH. 11. RU bailer assembly. RIH with bailer assembly. Dump bail —30' of cement to 3,740'. POOH. Wait 24hrs for cement to cure. 12. RU gauge ring. RIH and and tag bottom. POOH. 13. RU w/ HC 6 spf wireline guns. 14. RIH and perforate the following intervals: Zone Sands Top (MD) Btm (MD) FT SPF Sterling B-0 3,440' 3,490' 50' 6 Sterling B2 3,580' 3,630' 50' 6 Sterling B3L 3,665' 3,679' 14' 6 Sterling B4 3,725' 3,735' 10' 6 a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Bleed down tubing pressure per Engineer's instructions prior to perforating. d. Correlate using correlation log. Use Gamma/CCL/to correlate. e. Install Crystal gauges before perforating. Record tubing pressures before and after each perforating run. f. All perforations in table above are located in the Sterling/Upper Beluga Pool based on Conservation Order No. 716. 15. RD E-line. 16. Turn well over to production. E-line Procedure(Contingency): If any zone produces minimal gas,sand and/or water. 17. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 18. RU gauge ring assembly. RIH and tag bottom. POOH. 19. Utilize gas lift supply to pressure up well to 800 psig and push water into formation. 20. RU through tubing plug assembly for 7" casing. RIH with plug assembly. 21. Set plug in 7" casing at"'10' above top perforation of open zone. POOH. (Do not set plug across collar.) 22. RU bailer assembly. RIH with bailer assembly. Dump 1 bailer of PW. POOH. 23. RIH with bailer assembly. Dump bail cement. POOH. Wait 24hrs for cement to cure. a. If spacing allows between Top of TTP and 5'below bottom of proposed perf interval, 35'of cement must utilized to meet BLM requirements. Otherwise, dump bail cement from Top of TTP and within 5'of proposed perf interval. 24. Follow steps 13—16 above at new intervals. Attachments: 1. Actual Schematic 2. Proposed Schematic . • 0 Swanson River Unit Well: SRU 241-16 IIACTUAL SCHEMATIC Completion Ran:6/07/04 PTD:204-088 Hi!carp Alaska,LLC API: 50-133-20540-00 RKB=338.5'/GL=318.0'AMSL RKB to THF=20.5' 1 CASING DETAIL Size Wt Grade Conn ID Top Btm 16"J 16" 68 J-55 Weld Surf. 66.5' 9-5/8" 40 L-80 BTC 8.835" Surf. 1,553' 7 26 L-80 BTC 6.276" Surf. 4,264' TUBING DETAIL 2-7/8" 6.4 L-80 IBT 2.441" Surf 3,396' 9-5/82 JEWELRY DETAIL No. Depth ID Item 1 25' 2.441" Cross-Over 4-1/2"12.6#x 2-7/8"6.4#IBT Box x Pin 2 2,478' 2.347" SFO-1C1 Chemical Injection Mandrel IIM=111 .• 3 3,370' 2.360" 7"HES PHL Production Packer 2 4 3,382' 2.313" X Nipple Profile 5 3,396' 2.441" Wire Line Entry Guide TOC @ 2,170' 6 3,789' - TT Plug Assembly for 7"casing w/7.5'cement 7 3,850' - Cement(5 bbls of 15.8#LXT Cement) cA !1 8 3,955' - Failed Posiset Plug(pushed downhole w/coil 5/30/08) 6. 9 Unknown - Failed TTS Umbrella Plug(did not tag at 4,030'5/29/07) J PERFORATION DETAIL 1.1 Date Zone Top Btm Top Btm Amt Gun Size Spf Phase Comments NM 3 t`, (MD) (MD) (ND) (ND) PP I faI I k 4 4/26/15 B4L 3,765' 3,770' 3,139' 3,144' 5' 2" 6 60 Open r.,A* 4/11/12 B-4A 3,803' 3,810' 3,177' 3,184' 5' 1-11/16" 7.5 45° Open—Plug Leaks By 41 © 41,1 6/06/08 B-4A 3,805' 3,810' 3,179' 3,184' 5' 1-11/16" 7.5 45° Open—Plug ., 4 ,� Leaks By s 9/16/04 B-6 4,027' 4,032' 3,400' 3,404' 5' 2.0" 6 60° Isolated Fill @ 5 9/16/04 B-6 4,033' 4,037' 3,405' 3,409' 4' 2.0" 6 60° Isolated f?j}'f�r�rtif:}�fPj},f��" 9/15/04 B-6 4,027' 4,032' 3,400' 3,404' 5' 2.0" 6 60° Isolated 3,666'SLM { ;{ti. r 7::::::41:::::Y::::::::ti;1titititir B-4L 9/14/16 r_r r r�r .r_,�, wwar� rte':! .: • .0 e 4 TOC @ 3,789' 4* ' ' 6 3181 M 0� "iRti{:titititii4titi + : f t'Ae e;SI SW1ti B-4At6 . r}sissrtirsrtirrc. . e�� , - ,a 4t, ., _.� .- 7 TOC @ 3,850' lor 3 } 8 4kB-6 Max hole angle=51.5°@ 1,822' A8 i: ed'Int� Fill @ 4,233' 4. ror 01 44 TD=4,264'MD;3,636'TVD PBTD=3,850'MD;3,223'TVD Downhole Revised:12/30/14 Updated by JEK 09/14/2016 M • . 0 Swanson River Unit Well: SRU 241-16 PROPOSED SCHEMATIC PTD: Ililcorp Alaska,LLC API: 50-133-20540-00 RKB=338.5'/GL=318.0'AMSL RKB to THF=20.5' IIIIIW1 CASING DETAIL Size Wt Grade Conn ID Top Btm 16';e116" 68 J-55 Weld Surf. 66.5' 9-5/8" 40 L-80 BTC 8.835" Surf. 1,553' 7 26 L-80 BTC 6.276" Surf. 4,264' TUBING DETAIL 2-7/8" 6.4 L-80 IBT 2.441" Surf 3,396' JEWELRY DETAIL 9-5/8LS. No. 1 IIMISi 2 3 Depth ID Item 25' 2.441" Cross-Over 4-1/2"12.6#x 2-7/8"6.4#IBT Box x Pin 2,478' 2.347" SFO-1C1 Chemical Injection Mandrel 3,370' 2.360" 7"HES PHL Production Packer 4 3,382' 2.313" X Nipple Profile 5 3,396' 2.441" Wire Line Entry Guide 2 6 3,785' - TT Plug Assembly for 7"casing w/'15'cement 7 3,796' - TT Plug Assembly for 7"casing w/7.5'cement 8 3,850' - Cement(5 bbls of 15.8#LXT Cement) 9 3,955' - Failed Posiset Plug(pushed downhole w/coil 5/30/08) 10 Unknown - Failed TTS Umbrella Plug(did not tag at 4,030'5/29/07) i 3 ' 3E n 1 �h PERFORATION DETAIL Date Zone Top Btm Top Btm Amt Gun Size Spf Phase Comments ` , ii (MD) (MD) (ND) (TVD) Vv, >`,..1 4 1111B-0 3,440' 3,490' 2,824' 2,871' 50' 2" 6 60 Proposed 1 5 s+ j-- B2 3,580' 3,630' 2,958' 3,007' 50' 2" 6 60 Proposed 1y " 63L 3,665' 3,679' 3,041' 3,055' 14' 2" 6 60 Proposed i '"� B4 3,725' 3,735' 3,100' 3,110' 10' 2" 6 60 Proposed ,7 1'1f;�l/26/15 B4L 3,765' 3,770' 3,139' 3,144' 5' 2" 6 60 +sel tt ,( trM- ' ;"j,,,- 4/11/12 B-4A 3,803' 3,810' 3,177' 3,184' 5' 1-11/16" 7.5 45° Isolated B-4L 6/06/08 B-4A 3,805' 3,810' 3,179' 3,184' 5' 1-11/16" 7.5 45° Isolated TOC @ 3,770'. - 9/16/04 B-6 4,027' 4,032' 3,400' 3,404' 5' 2.0" 6 60° Isolated + 9/16/04 B-6 4,033' 4,037 3,405' 3,409' 4' 2.0" 6 60° Isolated O1 / 6 9/15/04 B-6 4,027' 4,032' 3,400' 3,404' 5' 2.0" 6 60° Isolated ++# j __., TOC@. g ;fir, ' 7 Fill @ F•r•r•r•r•r•r•r•r•r• ti.ti.ti.ti.ti•ti•ti.'L•ti.ti 3,784'SLM ' :•r•r•r•r•r•r•r•r•r• B-4A r~r~r~r1f~r1J'tiJ:1LltP:I= ' '8 TOC @ 3,850' ' 9 Z B-6 Max hole angle=51.5°@ 1,822' • 10 •r•V.V r f•r•r•r•r• ' ,{.1.1.1.;.ti..,.1.ti.1.1 •r•r•r•r•r•r•r•r•r• • . Fill @ 4,233' ,ti•1.1.1.1.1.1.1.1,1.1 7„ ' e a � TD=4,264'MD;3,636'TVD PBTD=3,850'MD;3,223'ND Downhole Revised:12/30/14 Updated by JEK 9-15-16 STATE OF ALASKA . AL .A OIL AND GAS CONSERVATION COM 3ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LJ Plug Perforations Li/ Fracture Stimulate LJ Pull Tubing LJ Operations shutdown Li Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑✓ Exploratory ❑ 204-088 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99504 50-133-20540-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028077 Swanson River Unit(SRU)241-16 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Sterling Undef Gas 11.Present Well Condition Summary: Total Depth measured 4,264 feet Plugs measured 3,955 feeR E C E I V`/ E D true vertical 3,636 feet Junk measured >3,955'(plug) feet MAY 2 1 2015 Effective Depth measured 3,850 feet Packer measured 3,370 feet AOGCC true vertical 3,223 feet true vertical 2,757 feet G Casing Length Size MD TVD Burst Collapse Structural Conductor 66.5' 16" 66.5' 66.5' 2,980 psi 1,410 psi Surface 1,553' 9-5/8" 1,553' 1,388' 5,750 psi 3,090 psi Intermediate Production 4,264' 7" 4,264' 3,636' 7,240 psi 5,410 psi Liner Perforation depth Measured depth See Attached Schematic scAHHED .10N 0 i 2015 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 3,396'MD 2,782'ND Packers and SSSV(type,measured and true vertical depth) HES PHL Ret Pkr;N/A 3,370'MD 2,757'ND N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 60 440 Subsequent to operation: 0 2739 0 150 570 14.Attachments: 15.Well Class after work: Daily Report of Well Operations CI Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas Q WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-203 Contact Joe Kaiser Email jkaiser(c�hilcorp.com Printed NameJoe Kaiser Title Operations Engineer f Signature Z________Z________ '+' t —..-.0°116- - --- -- Phone 907-777-8393 Date 5..... Vrt."5---- �� Form 10-404 Revised 5/2015 s 1 i5 RBDIVI mit Origin'aTOnl9 2015 , ot s/ ice ar Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 241-16 50-133-20540-00 204-088 4/19/15 4/26/15 Daily Operations: 04/19/2015 -Sunday RU slickline. PT lubricator to 1,500 psi-test OK.Tag at 3,811' RKB. RIH w/2.25" bailer to 3,811', recover full bailer of sand. Locate tubing tail at 3,394' RKB. RIH w/2.25" x 20' bailer to 3,812' RKB. RD. Move to SCU 43B-08. 04/20/2015- Monday PTW and JSA. Mobe to location. Spot equipment and rig up lubricator. Pressure test lubricator to 250 psi and 1,500 psi high. TP-300 psi. RIH with 2-1/8" GR. Tag fill at 3,804' (3,799' open hole log). POOH. Test setting tool. RIH w/2-1/2"TTBP. Set plug at 3,795' (3,790' open hole log):yOOH. RIH w/2" x 30' positive displacement dump bailer and dump 2-1/2'of cement on top of plug at 3,795' (3,790' open hole log). POOH. Good dump. RIH w/2" x 30' positive displacement dump bailer and dump 2-1/2' of cement (5'total) on top of plug at 3,795' (3,790' open hole log). POOH. Good dump. RIH w/2" x 30' positive displacement dump bailer,tie into Halliburton GR run correlation log dated 4/20/15 and dump 2-1/2' of cement(7.5' total) on top of plug at 3,795' (3,790' open hole log). POOH. Good dump. Cement in Place at 2130 hrs.TOC approx 3,787.5' (3,782.5' open hole log). Rig down lubricator and secure well. 04/26/2015-Sunday PTW and JSA. Mobe to location. Spot equipment and rig up lubricator. Pressure test lubricator to 250 psi and 1,500 psi high. TP-573 psi. RIH w/2.25" GR and junk basket. RIH,tag cement at 3,788.5'. RIH w/2" x 5' HC, 6 spf, 60 deg perf gun. Spotted shot from 3,770'to 3,775' (3,765'to 3,770'OHL).Tubing pressure 573 psi. Fired shot and pressure went to 600 psi within a minute and to 618 psi within 5 min. POOH.All shots fired. Rig down lubricator and turn well over to field.TP-632 psi. Swanson River Unit Well: SRU 241-16 II ACTUAL SCHEMATIC PTD 2104-088an:6/07/04 Ililcorp Alaska,LLC API: 50-133-20540-00 RKB=338.5'/GL=318.0'AMSL RKB to THF=20.5' 1 - LCASING DETAIL Size Wt Grade Conn ID Top Btm 16" 16" _ 68 J-55 Weld Surf. 66.5' 9-5/8" 40 L-80 BTC 8.835" Surf. 1,553' 7 26 L-80 BTC 6.276" Surf. 4,264' TUBING DETAIL 2-7/8" 6.4 L-80 IBT 2.441" Surf 3,396' 9 5/82 JEWELRY DETAIL No. Depth ID Item 1 25' 2.441" Cross-Over 4-1/2"12.6#x 2-7/8"6.4#IBT Box x Pin 2 2,478' 2.347" SFO-1C1 Chemical Injection Mandrel _ 3 3,370' 2.360" 7"HES PHL Production Packer 2 4 3,382' 2.313" X Nipple Profile 5 3,396' 2.441" Wire Line Entry Guide 6 3,789' - TT Plug Assembly for 7"casing w/7.5'cement 7 3,850' - Cement(5 bbls of 15.8#LXT Cement) 8 3,955' - Failed Posiset Plug(pushed downhole w/coil 5/30/08) 9 Unknown - Failed TTS Umbrella Plug(did not tag at 4,030'5/29/07) • fiIo i 3 1 PERFORATION DETAIL I 1`- I 1 Date Zone Top Btm Top Btm Amt Gun Size Spf Phase Comments - " (MD) (MD) (ND) (TVD) 14/26/15 B4L 3,765' 3,770' 3,139' 3,144' 5' 2" 6 60 Open 4/11/12 B-4A 3,803' 3,810' 3,177' 3,184' 5' 1-11/16" 7.5 45° Open X 4 6/06/08 8-4A 3,805' 3,810' 3,179' 3,184' 5' 1-11/16" 7.5 45° Open lir 9/16/04 8-6 4,027' 4,032' 3,400' 3,404' 5' 2.0" 6 60° Isolated 5 9/16/04 B-6 4,033' 4,037' 3,405' 3,409' 4' _ 2.0" 6 60° Isolated 9/15/04 13-6 4,027' 4,032' 3,400' 3,404' 5' 2.0" 6 60° Isolated B-41 - TOC @ 3,789' 6 Fill @ •;:?.. f•f•f•r•r•f•f ti•ti•ti•ti•ti•ti•ti•1•ti•ti• 3,784'SLM r•f▪f•f•f•f•f•,F: . B-4A .,�tir1,1,1r1,y fti�1�1 f "▪ . - 7 TOC @ 3,850' Ill 1 . 8 =B-6 Max hole angle=51.5°@ 1,822' :, wook }.f.r.r.r.f.f.f.}.r.. {_ti:tietiatitirti:ti_ti_ti_ti� FIII @ 4,233' r TD=4,264'MD;3,636'ND PBTD=3,850'MD;3,223'ND Downhole Revised:12/30/14 Updated by DMA 05-20-15 OF T� • Alaska Oil and Gas �w � �jjs� THE STATE ofALASIc:A Conservation Commission __=_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 jv OF ALAS' Fax: 907.276.7542 www.aogcc.alaska.gov Joe Kaiser same Operations Engineer 1bZ "�$1 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Sterling Undefined Gas Pool, SRU 241-16 Sundry Number: 315-203 Dear Mr. Kaiser: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 0 OF Daniel T. Seamount, Jr. Commissioner DATED this fig-7 day of April, 2015 Encl. RECEIVED STATE OF ALASKA APR 0 7 2015 • ALASKA OIL AND GAS CONSERVATION COMMISSION ^� C APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon 0 Plug for Redrill ❑ Perforate New Pool❑ Repair Wel❑ Change Approved Program 0 Suspend❑ Plug Perforations Q • Perforate Q ' Pull Tubing 0 Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other. ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to DriN Number Exploratory ❑ Development ❑ • 204-088 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service Cl • 6.API Number. Anchorage,Alaska 99503 50-133-20540-00 7.If perforating: 8.WeN Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055 Swanson River Unit(SRU)241-16 • Will planned perforations require a spacing exception? Yes ❑ No Q 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028077• Swanson River/Sterling Undef Gas . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 4,264 • 3,636 • 3,850 3,223 3,955' >3,955'(plug) Casing Length Size MD TVD Burst Collapse Structural - Conductor 66.5' 16" 66.5' 66.5' 2,980 psi 1,410 psi Surface 1,553' 9-5/8" 1,553' 1,388' 5,750 psi 3,090 psi • Intermediate Production 4,264' 7" 4,264' 3,636' 7,240 psi 5,410 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80 3,396' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): HES PHL Ret Pkr;N/A 3,370'MD-2,757'TVD;N/A 12.Attachments: Description Summary of Proposal Q X13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Q Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 04/17/15 Commencing Operations: Oil 0 Gas Q , WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned 0 Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Kaiser Email jkaiserictilcorD.com Printed Name Joe Kaiser Title Operations Engineer _ Signatur e2('-' Phone 907-777-8393 Date y/7`Z0 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 1C-2°3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No [r Subsequent Form Required: lb._••-f oil APPROVED BY r Approved by: j COMMISSIONER THE COMMISSIONO� �/ Date: 1 [4- 1.1S e 10315— f/^_'1�1F^_�% �'11 AA ,' x171 7"' '• / Submit Forrn and Form 10-403( ised 10/20 2) gpltc*' I ippliFa�l91�� r 12 months from the date of approval. / / Attachments in Duplicate S ar APR 1 8 203r -- Well Prognosis • Well: SRU 241-16 Hilcorp Alaska,LL' Date:4/07/2015 Well Name: SRU 241-16 API Number: 50-133-20540-00 Current Status: Gas Well Leg: N/A Estimated Start Date: April 17th, 2015 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 204-088 First Call Engineer: Joe Kaiser (907) 777-8393 (0) (907)952-8897 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: — 534 psi @ 3,178' TVD (Based on Survey taken on 4/13/13) Maximum Expected BHP: — 800 psi @ 3,140' TVD (Estimate based on offset wells) Max. Allowable Surface Pressure: --486 psi (Based on gas gradient[0.10psi/ft]) Brief Well Summary Swanson River Unit Well 241-16 was drilled in 2004 with the first perforations in the Sterling B-6 Sand. This sand was produced until 2008. In 2008, attempts to isloate the B-6 sand with through tubing plugs failed.At this time, the decision was made to push the plug to near the top of the B-6 perforations and place cement on top. Once the B-6 zone proved to be isolated, the B-4A sand was perforated. In 2012, the B-4A zone was reperforated. In 2014, sand production heavily increases so the well was shut-in. In 2015, Hilcorp would like to isolate the B-4A zone, bail cement, and reperforate in the B4L sand zone. Notes Regarding Wellbore Condition • Well is currently shut-in. OBJECTIVE OF WORKOVER Plugback Sterling B-4A. Add new perfs in the Sterling B4L bench. E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU gauge ring assembly. RIH and tag bottom. POOH. 3. RU through tubing plug assembly for 7" casing. RIH with plug assembly. 4. Set plug in 7" casing at 3,798'. POOH. 5. RU bailer assembly. RIH with bailer assembly. Dump bail +/-5' of cement. POOH.Wait 24hrs for cement to cure. 6. RD E-line. Slickline Procedure: 7. MIRU Slickline, PT lubricator to 1,500 psi Hi 250 Low. 8. RU Swabbing assembly. RIH with Swabbing assembly. Swap fluid level down to+/- 3,370'. POOH. 9. RD Slickline. E-line Procedure: 10. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 11. RU 2.0" 6 spf SLB PowerNova wireline guns (6spf shot density). Well Prognosis • Well: SRU 241-16 Ililcorp Alaska,LL Date:4/07/2015 a. Est Res BHP=800 psi. Est hydrostatic=465 psi. (Fluid level to Packer at 2,757'TVD,gas to surface and SITP of 160 psi) 12. RIH and perforate Sterling B4L interval from 3,765'—3,770' (5'). POOH. 13. Bleed tubing pressure down as directed by Reservoir Engineer. 14. RIH and perforate the following intervals: Zone Sands Top (MD) Btm (MD) FT SPF Sterling BO 3,469' 3,474' 6 6 Sterling B3-A2 3,667' 3,672' 5 6 Sterling B3L 3,728' 3,734' 6 6 Sterling B4L 3,765' 3,770' 5 6 a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using proposed Cement Bond log. (Tie-in log depth is pending). d. Record tubing pressures before and after each perforating run. 15. RD E-line. 16. Turn well over to production. E-line Procedure(Contingency): 17. If any zone produces minimal gas, sand and/or water. 18. MIRU E-line &Slickline,to follow the same procedures above at new intervals. Attachments: 1. Current Schematic 2. Proposed Schematic Swanson River Unit Well: SRU 241-16 ACTUAL SCHEMATIC 2104-0881-1 6/07/04 PTD Ilii,orp Alaska,LLC API: 50-133-20540-00 RKB=338.5'/GL=318.0'AMSL RKB to THF=20.5' _I. 1 CASING DETAIL Size Wt Grade Conn ID Top Btm 16" 16" 68 J-55 Weld _ Surf. 66.5' 9-5/8" 40 L-80 BTC 8.835" Surf. 1,553' 7 26 L-80 BTC 6.276" Surf. 4,264' TUBING DETAIL 2-7/8" 6.4 L-80 IBT 2.441" Surf 3,396' 9-5/82 L. JEWELRY DETAIL No. Depth ID Item 1 25' 2.441" Cross-Over 4-1/2"12.6#x 2-7/8"6.4#IBT Box x Pin 2 2,478' 2.347" SFO-1C1 Chemical Injection Mandrel I, 3 3,370' 2.360" 7"HES PHL Production Packer 2 4 3,382' 2.313" X Nipple Profile 5 3,396' 2.441" Wire Line Entry Guide 6 3,850' - Cement(5 bbl of 15.814 LXT Cement) 7 3,955' - Failed Posiset Plug(pushed downhole w/coil 5/30/08) 8 Unknown - Failed TTS Umbrella Plug(did not tag at 4,030'5/29/07) v 3 PERFORATION DETAIL --3.1 l + Date Zone Top Btm Top Btm Amt Gun Size Spf Phase Comments (MD) (MD) (TVD) (TVD) -� 4/11/12 B-4A 3,803' 3,810' 3,177' 3,184' 5' 1-11/16" 7.5 45° Open ' 6/06/08 B-4A 3,805' 3,810' 3,179' 3,184' 5' 1-11/16" 7.5 45° Open - X , 4 1, 9/16/04 B-6 4,027' 4,032' 3,400' 3,404' 5' 2.0" 6 60° Isolated 9/16/04 B-6 4,033' 4,037' 3,405' 3,409' 4' 2.0" 6 60° Isolated 5 9/15/04 B-6 4,027' 4,032' 3,400' 3,404' 5' 2.0" 6 60" Isolated •r•1r1r •rr1r•r•rti B 4A .tif•1f.1i1i11i1r1r1r1r 1 LI •r1rrr•1rr•1rrr1rrr1: Fill @ 3 ,784'S L M C:1ti ':.":[f1?11t TOC @ 3,850' 6 ' tIti f -_• , '' 7 i, '4' " '"n'B-6 Max hole angle=51.5°@ 1,822' ' •rr,,.:11 •• r � 1.•1.r•1.1.1.1.1.1.1.1.1• Fill @ 4,233':::::::::::::::7474:::.:.:.:.:..:.::. 1_1 7" G S' TD=4,264' MD;3,636'TVD PBTD=3,850'MD;3,223'TVD Downhole Revised:12/30/14 Updated byJEK 12/31/14 Swanson River Unit Well: SRU 241-16 . n P R 0 P O S E D S C H E M Al I C PTD 2104-088an:6/07/04 Hilcorp Alaska,LLC API: 50-133-20540-00 RKB=338.5'/GL-318.0'AMSL RKB to THF=20.5' 1 CASING DETAIL Size Wt Grade Conn ID Top Btm 16" 16" 68 J-55 Weld Surf. 66.5' 9-5/8" 40 L-80 BTC 8.835" Surf. 1,553' 7 26 L-80 BTC 6.276" Surf. 4,264' TUBING DETAIL 2-7/8" 6.4 L-80 IBT 2.441" Surf 3,396' JEWELRY DETAIL 9 8L No. Depth ID Item 1 25' 2.441" Cross-Over 4-1/2"12.64 x 2-7/8"6.44 IBT Box x Pin 2 2,478' 2.347" SFO-1C1 Chemical Injection Mandrel 3 3,370' 2.360" 7"HES PHL Production Packer 4 3,382' 2.313" X Nipple Profile 5 3,396' 2.441" Wire Line Entry Guide i o 6 3,798' - TT Plug Assembly for 7"casing w/+/-5'cement 2 7 3,850' - Cement(5 bbl of 15.84 LXT Cement) 8 3,955' - Failed Posiset Plug(pushed downhole w/coil 5/30/08) 9 Unknown - Failed TTS Umbrella Plug(did not tag at 4,030'5/29/07) ', PERFORATION DETAIL Date Zone Top Btm Top Btm Amt Gun Size Spf Phase Comments 1 3 (MD) (MD) (ND) (ND) y a 1 ' '' Proposed BO 3,469' 3,474' 2,851' 2,856' 6' 2" 6 60 SLB PwrNova ,e Proposed B3-A2 3,667' 3,672' 3,043' 3,048' 5' 2" 6 60 SLB PwrNova 4-4 -- ; 1 Proposed B3L 3,728' 3,734' 3,103' 3,109' 6' _ 2" 6 60 SLB PwrNova Proposed B4L . 3,765' 3,770' 3,139' 3,144' 5' 2" - 6 60 SLB PwrNova 4/11/12 B-4A 3,803' 3,810' 3,177' 3,184' 5' 1-11/16" 7.5 45° Open X 4 6/06/08 B-4A - 3,805' 3,810' 3,179' 3,184' 5' 1-11/16" - 7.5 45° Open ` 9/16/04 B-6 4,027' 4,032' 3,400' 3,404' 5' 2.0" 6 60° Isolated Enj 5 9/16/04 B-6 4,033' 4,037' 3,405' 3,409' 4' 2.0" 6 60° Isolated 9/15/04 B-6 4,027' 4,032' 3,400' 3,404' 5' i 2.0" 1 6 60° Isolated B-4L F,. a. ...;- .• Fill@ d„ 'F.VA7•:}7}S7 3,784'SLM i r;�;j f�.4.1.4:4 - B-4A J �" ,j�; a 7 TOC @ 3,850' i""` - _ 8 Max hole angle=51.5°@ 1,822' -t B-6 vIC 11 %71,.r9.r.r r. r r.�.. „ }•} itil{lam��;�: �( Fill @ 4,233' TD=4,264'MD;3,636'TVD PBTD=3,850'MD;3,223'TVD Downhole Revised:12/30/14 Updated by JEK 12/31/14 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~o.lþ. - 0 g ~ Well History File Identifier Page Count from Scanned File: h 3 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES ~ Date 7/17 lOb If NO in stage 1, page(s) discrepancies were found: YES Organizing (done) o Two-sided 1111111111111111111 ';;;'CAN DIGITAL DATA Color Items: o Diskettes, No. ~reYSCale Items: \r~ o Other, NolType: o Poor Quality Originals: o Other: NOTES: Date7/f710Þ BY: ( Maria J Project Proofing BY: ~ Date 7/17 lot, Scanning Preparation ~ x 30 = (06 + BY: ~ Date7!17/DG Production Scanning Stage 1 BY: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: o Rescan Needed 111111111111111I11I OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: VV1f 151 11I1111111111111111 151 mp to:+-. wvP ~ = TOTAL PAGES (Count does not include cover sheet) 151 11I111111111111111I NO 151 vvtp NO 151 111111/1111I111111I IIIIIIIIIIII~ 11111 151 Quality Checked 11I11111111I1111111 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA AL~ OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS JUl_ a ZQC~~ 1. Operations Abandon Repair Well Plug Perforations ~ Stimulate Ot h er p ~ Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver ^ Ti r>`sf~ Change Approved Program ^ Operat. Shutdown^ Perforate ^ , Re-enter Suspended Well[~~'C~` _-~'~`;.'- 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Develo ment ~ Ex lorato p ^ p ry^ 204-088 . 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic^ Service^ 6. API Number: 50-133-20540-00 7, KB Elevation (ft): 9. Well Name and Number: 20.5 Swanson River Unit (SRU) 241-16 8. Property Designation: 10. Field/Pool(s): Swanson River ADL 0028077. Swanson River /Sterling Undef Gas 11. Present Well Condition Summary: Total Depth measured 4,264 feet Plugs (measured) 3,955' true vertical 3,636 feet Junk (measured) Effective Depth measured 3,850 feet true vertical 3,223 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 66.5' 16" 66.5' 66.5' 2,980 psi 1,410 psi Surface 1,553' 9-5/8" 1,553' 1,388' 5,750 psi 3,090 psi Intermediate Production 4,264' 7" 4,264' 3,636' 7,240 psi 5,410 psi Liner ' ~~~~~ `~~~ '~` Z~U~ ' ' ' Perforation depth: Measured depth: 3,805 - 3,810 & 4,027 - 4,037 True Vertical depth: 3,178' - 3,183' & 3,399' - 3,409' Tubing: (size, grade, and measured depth) 2-7/8" IBT L-80 6.5# 3,396' Packers and SSSV (type and measured depth) HES PHL Ret Pkr 3,370' N/A 12. Stimulation or cement squeeze summary: See attached summary Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 526 • 0 50 900 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development ^~ '" Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil^ Gas ^~ ~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-184 Contact Marcus Barbee 263-7605 Printed Name Timothy C. Brandenburg Title Drilling Manager .. r, Signatur i y ,,~ 13 r.... ~ ....~ ,- ~~ Phone 263-7657 Date 7/2/2008 Form 10-404 Revised 04/2006 ORIGINA S~F~1~~,~:~~.~QO~ ~ i Submit Original On ~ ~~ 7. ~. ~a P Chevron Chevron -Alaska Daily Operations Summary Well Name SRU 241-16 Field Name SWANSON RIVER API/UWI 501332054000 Lease/Serial ADL028077 CHEVNO HP3278 License No./Prope... 2040880 Orig KB Elev (RKB) 20.5 Water Depth (ft) Jobs - - --- --- - -_ Job Cal Type AFE No. QC Eng Well Service Perforating UWDAK R8009 _ _ -- DailyOperations 5/23/2008 00:00 - 5/24/2008 00:00 Operations Summary Prep Pad for coil work to begin monday 5/24/2008 00:00 - 5/25/2008 00:00 Operations Summary Prep pad and move coil tubing unit onto location 5/25/2008 00:00 - 5/26/2008 00:00 Operations Summary Contintae Pad preperations and Coil Tubing rig up, contacted AOGCC for 24 Hr notice for BOPE test tomorrow which was waived by Lou Grimaldi. 5/26/2008 00:00 - 5/27/2008 00:00 Operations Summary Finish Coit tubing, Pressure test BOP.s, Make up bottom hole assembly and pressure test same, AOGCC witness waived by Lou Grimaldi. 5/27/2008 00:00 - 5/28/2008 00:00 Operations Summary Run in hole w/ motor and mill /POOH when unable to pump through coil /found ball and hypoturbine from yesterdays operations /prep coil for tomorrows ops 5/28/2008 00:00 - 5/29/2008 00:00 Operations Summary tagged posi-set plug @ 3575 CTM (3595.5' RKB CTM) attempt to push or pressure plug down hole, unable to move plug w/3,000 psi 5/29/2008 00:00 - 5/30/2008 00:00 Operations Summary Prepped location for cement work in the AM, rolled fluid in the RFR tank & added 20 gal of J313 friction reducer. Wrote procedure for cement job and reviewed with Drilling Superintendant Evan Harness . 5/30/2008 00:00 - 5/31 /2008 00:00 Operations Summary PJSM, RBU CTU & Cementers, PT RIH and engage posi-set plug, pushed and pressured plug from 3,595.5' RKB CTM to 3,936' RKB CTM. POOH RB CTU, trap 1,000 psi on well head, secure well and location. Contacted BLM -Tom Zelenka, discussed plan and change in plan, no change in scope filing required at this time, include discription of job in post filing. Contacted AOGCC, Tom Maunder via email addressing change in plan and plan forward approved. 5/31 /2008 00:00 - 6/1 /2008 00:00 Operations Summary Pumped 5 Bbls of 15.8# LXT Cement from 3,955' RKB CTM to 3,825' RKB CTM and washed out to 3,850' RKB CTM, POOH and trap 500 psi on 2-7/8" production tubing, RB CTU 6/1/2008 00:00 - 6/212008 00:00 Operations Summary Tested and tagged cement plug witnessed by AOGCC Lou Grimaldi, Spotted KCL pill across zone of interest, and blew well dry from 3720'. Trapped 1950 psi on well head. 6/2/2008 00:00 - 6/3/2008 00:00 Operations Summary Rig down and demob coil, Hold safety stand down. 6/3/2008 00:00 - 6/4/2008 00:00 Operations Summary Finish Demob and Secure pad 6/6/2008 00:00 - 6/7/2008 00:00 Operations Summary Perf B-4a sand from 3,805' to 3,810' w/1-11/16"x 5' Power Jet, 7.5 SPF, 45 degree pendilum phased gun. • • MEMORAN®lJM State of Alaska Alaska Oil and Gas Conservation Commission TO: FROM: Jim Regg ~~~, , , ; DATE: June 2, 2008 P. I. Supervisor I~u~ ~~_~jL~~ Lou Grimaldi SUBJECT: Plug Verification Petroleum Inspector Chevron Swanson River Field SRU 241-16 PTD 204-088 June 1, 2008: I witnessed the pressure test of abandonment plug in the Casing of Chevron ("CVX") well SRU 241-16 in the Swanson River Field. I arrived to find Schlumberger finishing their rig-up of the coil unit. I met with Marcus Barbee and Joe Dalebout (CVX rep's) and discussed the wells condition and state. It was reported to me that a cement plug of approximately 10,5' had been laid on an old expandable bridge plug in the casing that had been fQUnd to have moved up hole. The E.P.B. was pushed back down hole by coil and pressure and the new cement plug was laid in on top of it. The coil unit applied a pressure test to the plug of 3000 psi, at first there was a ~ constant decline of 25 psi per 5 minute period which eventually tapered off to 15 psi per 5 minute period. There were many suspect areas that could have been leaking. Grease crew was called out to service valves and the field operator was summoned to see about closing some additional valves on the flow line. During this time the coil unit ran in the hole to tag the plug. The top of cement was ;~, expected at 3850' (RKB) and was found exactly there. The unit circulated the hole out with 9 ppg KCI water and a 1100 psi pressure test was applied which held solid. I had discussed the reduced test pressure with Tom Maunder (A.O.G.C.C. engr.) and gotten approval. I feel circulating the hole out helped the pressure test. The pressure test of this plug is good. Attachments: none Non-Confidential ~w;~111- JUL ~ ~ 2008 Wellboreplug verification SRU 241-16 06-01-08 LG.doc Page 1 of 2 • Maunder, Thomas E (DOA) • From: Maunder, Thomas E (DOA) Sent: Friday, May 30, 2008 2:11 PM To: 'Walsh, Chantal [Petrotechnical]' Cc: Barbee, Marcus [Consultant]; Dalebout, Joseph [APRs]; Harness, Evan Subject: RE: Plan forward on SRU 241-16 (204-088) Sundry 308-184 Chantal, Interesting, your "jug" is getting bigger. Placing cement on top of the plug when it finally stops moving is acceptable. When it is finally determined that the plug is not moving, it is appropriate to conduct and record your 3000 psi casing test. After WOC, it is appropria#e to conduct and record a similar pressure test. t believe Marcus has been in contact with an Inspector for possible witness. Call or message with any questions. ~~~~ ~U~ ~ ~ Z~d~ Tom Maunder, PE AOGCC From: Walsh, Chantal [Petrotechnical] [mailto:WalshC@chevron.com] Sent: Friday, May 30, 2008 1:55 PM To: Maunder, Thomas E (DOA) Cc: Barbee, Marcus [Consultant]; Dalebout, Joseph [APRs]; Harness, Evan Subject: FW: Plan forward on SRU 241-16 Sundry 308-184 Tom, We went out to the SRU 241-16 well this morning to commence operations as we discussed below. In our pre coif work, we pressured up on the well to verify the well was jug tight to 3000 psi. The well pressured up to 3000 psi and then fell off. We repeated this sequence a number of times (2800 - 3000 psi). We then went in and tagged the plug ~60' deeper than previous tags. We are currently trying to work with pressure to continue to move the plug down hole. Failing that, we will plan to continue as previously described: • Lay in, with coil, a minimum of 35' of cement on top of the plug at its current location to enable the isolation/abandonment of the B-6 perforations. • WOC • Tag TOC • Blow well dry with nitrogen. . Secure operations for later perforating of the BO sands. With the depth of the plug being the location the plug discontinues its movement downhole. We are requesting your approval. Please let me know if you have any questions. Chantal 263-7627 From: Walsh, Chantal [Petrotechnical] Sent: Wednesday, May 28, 2008 5:02 PM To: 'Maunder, Thomas E (DOA)' Cc: Barbee, Marcus [Consultant]; Harness, Evan; Dalebout, Joseph [APRs]; Kirschner, Khristina; Winslow, Paul M 5/30/2008 Page 2 of 2 • • Subject: Plan forward on SRU 241-16 Sundry 308-184 Tom, We have been working our coil tubing plan on the SRU 241-16 well (Sundry #308-184). We were able to clear the tubing of its obstruction, but have not made any progress on moving the damaged Posi-set plug. We applied 3000# of weight with coil. The applied 3000 psi surface pressure over a 8.7ppg fluid, and an assumed reservoir pressure in the B-6 sand of 1,300psi leads to a differential on the plug of +/- 3000psi, giving a cross sectional force of 92,000#. This load is above the rated capacity of the posiset. During operations, the well remained jugged up with no pressure bled off. Our conclusion is the perfs must be plugged off. The current location of the plug is at 3606' and the top of the perforations are at 4027'. Our current plan is: • Lay in, with coil, a minimum of 35' of cement on top of the plug at its current location to enable the isolation/abandonment of the B-6 perforations. • WOC • Tag TOC • Blow well dry with nitrogen. . Secure operations for later perforating of the BO sands. We are requesting your approval. Please let me know if you have any questions. Chantal 263-7627 5/30/2008 Page 1 of 2 Maunder, Thomas E (DOAj From: Maunder, Thomas E (DOA) Sent: Thursday, May 29, 2008 8:40 AM L ~~~~VN~~ MAY `~ ~ 2008 To: 'Walsh, Chantal [Petrotechnical]' Cc: Barbee, Marcus jConsultant]; Harness, Evan; Dalebout, Joseph jAPRS]; Kirschner, Khristina; Winslow, Paul M Subject: RE: Plan forward on SRU 241-16 (204-088) Sundry 308-184 Chantal, Your proposal is appropriate. According to 20 AAC 25.112 (c)(1)(C) allows placing the plug above the top of fill or junk if ... the objectives of this subsection will be met. The pressure test you describe indicates the perforations are isolated. I will place a copy of this message in the file. Call or message with any questions. Also, thanks for including the sundry number. Please include the PTD as well. Tom Maunder, PE AOGCC From: Walsh, Chantal [Petrotechnical] [mailto:WalshC@chevron.com] Sent: Thursday, May 29, 2008 8:10 AM To: Maunder, Thomas E (DOA) Cc: Barbee, Marcus [Consultant]; Harness, Evan; Dalebout, Joseph [APRs]; Kirschner, Khristina; Winslow, Paul M Subject: RE: Plan forward on SRU 241-16 Sundry 308-184 Tom, We intend to have a minimum of at least 12 feet of rat hole below the lowest planned perfs in the BO interval. We will likely put more than. the minimum 35' of cement on the plug. Chantal From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, May 28, 2008 5:04 PM To: Walsh, Chantal [Petrotechnical] Cc: Barbee, Marcus [Consultant]; Harness, Evan; Dalebout, Joseph [APRs]; Kirschner, Khristina; Winslow, Paul M Subject: RE: Plan forward on SRU 241-16 Sundry 308-184 Chantal, I agree, it appears that a competent plug exists. A question, where is the BO with relation to your intended top of cement? Tom From: Walsh, Chantal [Petrotechnical] [mailto:WalshC@chevron.com] Sent: Wednesday, May 28, 2008 5:02 PM To: Maunder, Thomas E (DOA) Cc: Barbee, Marcus [Consultant]; Harness, Evan; Dalebout, Joseph [APRs]; Kirschner, Khristina; Winslow, Paul M Subject: Plan forward on SRU 241-16 Sundry 308-184 Tom, We have been working our coil tubing plan on the SRU 241-16 well (Sundry #308-184). We were able to clear the tubing of its obstruction, but have not made any progress on moving the damaged Posi-set plug. We applied 5/2912008 Page 2 of 2 • 3000# of weight with coil. The applied 3000 psi surface pressure over a 8.7ppg fluid, and an assumed reservoir pressure in the B-6 sand of 1,300psi leads to a differential on the plug of +/- 3000psi, giving a cross sectional force of 92,000#. This load is above the rated capacity of the posiset. During operations, the well remained jugged up with no pressure bled off. Our conclusion is the perfs must be plugged off. The current location of the plug is at 3606' and the top of the perforations are at 4027'. Our current plan is: • Lay in, with coil, a minimum of 35' of cement on top of the plug at its current location to enable the isolation/abandonment of the B-6 perforations. • WOC • Tag TOC • Blow well dry with nitrogen. • Secure operations for later perforating of the BO sands. We are requesting your approval. Please let me know if you have any questions. Chantal 263-7627 5/29/2008 • ~~ t `~ A ~_ AI.ASSA OIL A1~TD GA,S COI~TSERVA7'IO1~T COMl-IISSIOI~T L' SARAH PALlN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 .~~~~ MAY ~ ~ 200 Anchorage, AK 9951 qq ~. - D d.,b Re: Swanson River >~eld, Sterling Undefined Gas Pool, SRU 241-16 Sundry Number: 308-184 Dear Mr. Brandenburg: 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, Daniel T. Seamount, Jr. Chair DATED this ~ day of May, 2008 Encl. "' ~~trU STATE OF ALASKA S- ~ F~EC~I ~'~` ALASF~A OIL AND GAS CONSERVATION COMM SIGN d/ '~ der MAY 2 a ~~ APPLICATION FOR SUNDRY APPROVALS ~j 20 AAC 25.280 ..., „ .~.__ n,,.,r ("`nmrYtifiSlOf! 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^~ _ giv e r Other ^ ~~ nn Alter casing ^ Repair well ^ Plug Perforations Q - Stimulate ^ Time ExtensibN' OfB~C' Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^ Exploratory ^ 204-088 3. Address: Stratigraphic ^ Service ^ 6. API Number: P.O.Box 196247, Anchorage, Alaska 99519 50-133-20540-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^~ SRU 241-16 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): Swanson River ADL 0028077 ~ 20.5 Swanson River Unit /Sterling Gas 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 4264' ~ 3636' 4233' 3605' 3,606 4232' Casing Length Size MD TVD Burst Collapse Structural n/a n/a n/a n/a n/a n/a Conductor 66.5' 16" 66.5' 66.5' 2980' 1410' Surface 1553' 9-5/8" 1553' 1388' 5750' 3090' Intermediate Production 4264' 7" 4264' 3636' 7240' 5410' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4027'-4037' 3399' - 3409' 2-7/8" 6.5# IBT L-80 3396' Packers and SSSV Type: HES "PHL" Ret Packer Packers and SSSV MD (ft): Production pkr 3370' / No SSSV 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 06-06-2008 for E-Line operations 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas Q Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Marcus Barbee 263-7605 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ,r ~ , ~ Phone 907-276-7600 Date ~J ~~ -~' -t~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~g ~ ~'~ ~~\ ~4S ~~~ P~uC~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ ~\ nLE ~ ~ > '3 '~ 1 0 - Other: ~~~~ ~ 5 ~ ~~ ~~ ~J `~ C..~ ~~~}~ ~"'S ~'"~~~ ~~~.. r~A~ 2 2 ?00~ ~1 Subsequent Form Required: ~,~(`~ l APPROVED BY Approved ~ COMMISSIONER THE COMMISSION Date: ~ 1 Form 10-403 Revised 06/20 6 Submit in Duplicate ~`~"~ '~1RIC~INAL Chevron Swanson River Unit Perforation Data: SRU 241-16 Note: Failed Posi-Set plug moved up hole to 3, 606' after 10' of cement was dumped on top Obiectives• • Plug the B6 sands • Perforate B4 & Boa sands • Actual recompletion interval will depend on diagnostic results. Boa, B4, B3a, B3, BO low, & BO up; are targets below the production packer Procedure of work proposed for SRU 241-16 • Utilize CT to remove obstruction in production tubing & push posi-set plug below 3,850' to refusal & prep well for E-Line operations • Utilize E-Line to set posi-set plug above top perforation & dump bail cement on top of plug • Pressure test plug & record data in well report • Utilize E-Line to perforate zones of interest once good PT is achieved • Turn well over to production Alternate procedure if unable to move posi-set plus to desired depth • Utilize E-Line & dump bail Cement or Spot cement with CT above failed posi-set plug • Pressure test plug & record data in well report • Perforate secondary targets above final plug depth • Turn well over to production DATE INTERVAL MD INTERVAL TVD INTERVAL SUB SEA Footage DESCRIPTION ONE TOP BTM TOP .BTM TOP BTM Current 4,027' 4,037' 3,399' 3,409' 3,061' 3,071' 10' Current erforations 66 ro osed 3, 803' 3, 818' 3,177' 3,192' 2, 839' 2, 854' 15' ro osed 84a ro osed 3, 771' 3, 792' 3,145' 3,166' 2, 807' 2, 828' 21 ' ro osed 84 ro osed 3, 735' 3, 740' 3,110' 3,115' 2, 771' 2, 776' S' ro osed 83a ro osed 3, 672' 3, 705' 3, 047' 3, 081' 2, 709' 2, 743' 34' ro osed 83 ro osed 3,488' 3,514' 2,869' 2,895' 2,531' 2,557' 26' ro osed BO low ro osed 3, 470' 3, 488' 2, 852' 2, 869' 2, 514' 2, 531 ' 18' ro osed 80 u • • • • Chevron Swanson Rivs`he~~ c1-16 Current Lease 8 Seria #: ADL080028077 ORIGINAL RIG Field: Swanson River API fl: 50.13320540.00 ELEVATIONS Surface Location: Well Classificaton. Development Gas Well 2,219' FNL 8 985' FWL Total Depth: 4,264' Sec 15.T8N,R9W,SM PBTD: 3,606' RKB X: ASP4 348,837 Tubin 2-7/8" 6.4# L-80 IBT 20.50' Y: ASP4 2,480,040 Prod Pkrs: 7" Halliburton PHL 1 Well Status: Shut in Operator: Union Oil of Cal Ownership: Union Oil Compan of California 100 GL-MSL: Spud Date: 05/28/04 RKB-AMSL: 339' Other: BHP' BHT: CA81 g Descnption Wei ht Grade Conn ID Len th Top Btm 70C Conductor 16" 68# J-55 Weld 66.5' 0' 66.5' driven ObStfUCtiOn Sudace 9-518" 40.01! L-80 BTC 1,553' 0' 1,553' 2,163' Production 7" 26.Ok L-80 BTC 4,264' 0' 4,264' 2 Tubin 41/2" 12.6# L-80 IBT 3.958" 25' 0' 25' 2-7I8" 6.4# L-80 IBT 2.441" 3,371' 25' 3.396' Descri tion De th Len th ID OD 1 Crass -Over 4-1/2" 12.6# x 2-7/8" 6.4# IBT Box x Pin 25' 1.00' 2.441" 2 SFO - 1C1 Chemical Inection Mandrel 2,478' 2.347" 3 7" HES "PHL" Production Packer 3,370' 4 X Nipple Profile 3,382' 2.313" 5 Wire Line Entry Guide WLEG 3,396' 2.441" 6 Faded Pos.-Set Plu 3,606' 3 4 5 Failed Posi- •w• Set Plug ~ 6 - Perforations 9,606 Zone Top Btm Amt Gun Siu SPF Phase Status Date B6 4,027 4,032 5 2.0" 6 60° temp iso 9N 512004 B6 4,027 4,032 5' 2.0" 6 60° temp iso 9N 612004 B6 4,033 4,037 5' 2.0" 6 60° temp iso 911612004 66 Fish: Failed Umbrella Plug Fill ~ 4 233' , TD = 4,264' MD = 3,636' Directional Well Current Schematic 05-06-08 Prepared B : Marcus Barbee • • Chevron Swanson RiverUnR 241-16 Proposed Schematic Permit to Drill#: 204088 Lease 8 Serial#: ADL - 0028077 ORIGI A R G Field: Swanson River API #: 50.133-20540.00 N L I ELEVATIONS Surface Location. Well Classificaton. Development Gas Well 2,219' FNL 8985' FWL Total Depth: 4,264' Sec 15,T8N,R9W,SM PBTD: 3.950 proposeo RKB - X: ASP4 348,837 Tubi 2-7/8" 6.4# L-80 IBT 20.50' V: ASP4 2,480,040 Pmd Pkrs: 7^ Halliburton PHL 1 Well Slatus: Flowin as Operator: Union Oil of Cal Ownership: Union Oil Company of California 100% GL-MSL: Spud Date: 05/28/04 RKB-AMSL: 339' Other: 8HP BHT l.Tubing Descnption Wei ht Grade Conn ID Len th To Btm 70C u~, , Conductor 16" 68# J-55 Weld 66.5' 0' 66.5' driven Surface 9-518" 40.0# L-80 BTC 1,553' 0' 1,553' Production 7^ 26.0# L-80 BTC 4,264' 0' 4,264' 2 Tubin 4-1/2" 12.6# L-80 IBT 3,958" 25' 0' 25' 2-7/8" 6.4# L-80 IBT 2.441" 3,371' 25' 3,396' bvretry 8 Flsh Descnption Depth Len th ID OD 1 Cross -Over 4-1/2" 12.6# x 2-7I8" 6.4# IBT Box x Pin 25' 1.00' 2.441" 2 SFO- 1C7 Chemical Idection Mandrel 2,478' 2.347" 3 7" HES "PHL" Production Packer 3,370' 4 X Nipple Profile 3,382' 2.313" 5 Wire Line Ent Guide WLEG) 3,396' 2.441" 6 peso-se; n~.i ; w'10' ,;ement cap (proposed) 3.990' 3 4 5 PerTOratlons Zone Top Btm Amt Gun Siu SPF Phase Status Date B6 4,027 4,032 5 2.0" 6 60° doa„yo~~ea 512012008 B6 4,027 4,032 5' 2.0" 6 60° -oa~,ao~,ea 5/20/2008 Posi-Set ~`~ ;~ ` B6 4,033 4,037 5' 2.0" 6 60° aye„ao„eo 5/20/2008 Plug (dl 6 Boa 3,803 3.878 15' 2.0" 6 60' proposed 4,000' B4 3.771 3,792 27' 2.0" 6 60° Proposed B6 83a 3.136 3.740 5' 2.0" 6 60' proposed B3 3.672 3.705 34' 2.0" 6 60' proposed Fish: Failed POST- 801ow 3.488 3.514 26' 2.0" 6 60` proposed Set plug 8 BO up 3.470 3.488 78' 20" 6 60" proposed Umbrella Plug Fill ~ 4 233' , TD = 4,264' MD = 3,636' Directional Well Proposed Schematic 005-OB Prepared B : Mamus Barbee • r `~ _: rte= .. ~. ~"~ MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_InsertsiMicrofilm_Marker.doc . ~1f~1fŒ lID~ ~~~~[K\~ . AI',AlliliA. OIL AlQ) GAS CONSBRVATlON COMMISSION SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 sGANNED MAY O' 9 2007 f6'6 clQ ~ ~ 0 Re: Swanson River Field, Sterling Undefmed Gas Pool, SRU 241-16 Sundry Number: 307-151 Dear Mr. Brandenburg: 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 me 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, Dan T. Seamount Commissioner DATED this 8 day of May, 2007 Enc!. I STATEOFX{iSÍ,Jò-'D? -:ff$1 RECEIVED ALA OIL AND GAS CONSERVATION COM.ION kr~ MAY 0 2 2007 APPLICATION FOR SUNDRY APPROVALS 20 MC 25 280 Alaska Oil & Gas Cons. Commission ; 1. Type of Request: Abandon 0 Suspend 0 Operational shutdown 0 Perforate [2] Waiver AØchorage Other 0 Alter casing 0 Repair well 0 Plug Perforations [2] Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development [2] Exploratory 0 204-088 3. Address: Stratigraphic 0 Service 0 6. API Number: P.O. Box 196247, Anchorage, Alaska 99519 50-133-20540-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes 0 No [2] SRU 241-16 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): Swanson River 20.5' Swanson River Unit 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 4264' RKB 3636' RKB 4233' RKB 3605' RKB Casing Length Size MD TVD Burst Collapse Structural Conductor 66.5' 16" 66.5' 66.5' 2980 psi 1410 psi Surface 1553' 9-5/8" 1553' 1388' 5750 psi 3090 psi Intermediate Production 4264' 7" 4264' 3636' 7240 psi 5410 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4027' - 4037'; 3399' - 3409'; 2-7/8" 6.5# IBT L-SO, 3396' Packers and SSSV Type: HES "PHL" Ret Packer Packers and SSSV MD (ft): 3370' 13. Attachments: Description Summary of Proposal [2] 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development [2] Service 0 15. Estimated Date for 5/1/2007 16. Well Status after proposed work: Commencing Operations: Oil 0 Gas [2] Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler - 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ¿·__~tLS Phone 907-276-7600 Date '7 -Z3-ÐT- ..-.r' ¿::::::> Þ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ðJ7~ I~/ Plug Integrity ~ BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: c.o~~~c..\--Tr--.~<tc~\~ ~\\-~ ":>'::> ~R 'S""...:\'\é \c: s \-. ~"> \-<:> <1aJ\~ b~~~~ " S"b..."entFo'm~ RBDMS 8Ft MAYO 9 20D7 APPROVED BY sit / 7 Approved by: ~ COMMISSIONER THE COMMISSION Date: .. Form 10-403 Revised 06/2006 U R \ G \ N A L Submit in Duplicate ·Chevron !IIII' . . . SwC:c.'t--<:'C' \(\ -.j{ r ..JI'IiiI'ffigJH(Unit Well # SRU 241-16 3/15/07 OBJECTIVE: · Recomplete well in the Sterling B4a Sand. PROCEDURE SUMMARY: · Run 2.28" Gauge Ring and tag fill at 4264' RKB (+/-). · Run static BHP survey. · Run 2.25"xlO' bailer as a dummy gun and also to get fluid sample. · Squeeze fluid back into perfs with 1300 psi (+/-) with field gas pending slickline work. · Set bridge plug at 4000' (+/-). Dump 10' of cement on top of plug. TTS · Perform MIT. Pressure tubing to 1300 psi (+/-) for 12 hrs and 100 psi for negative test for 12 hrs. · Perforate Sterling B4a sand from 3805" to 3810' with surface pressure at 1070 psi for 10% underbalance. · Turn well over to production. SRU 241-16 J 0 ~ ~C ~o~ \. \ \ .~ <.. (\ <..~\ <.."E '> ~ \\o~'~ S?\~ ~~\ r_\;~) ',,~; G ~ \' "~S<Ì '\(\-0 S 9 dS iÌ o~ð~~\, ~çh\ ~0C~~Cé~-\-.. ~5 1 C~UL~~\-'\,^, "\.\' (û.s.\,,~ \. ":>"~CJ...'"'1 ,~~\ (L\~SG.\\O~c:,) ö\ ,-~~~\-~\j\,,", ~'~ C\ ~'-.)~b~~o\- W,~\\,,<c \"'"'-.)" ~ ~'C> V'O-c:Q. -\-~ ~C) \ \,,} ~~ .. C~~~\~,,~~~"::.~~ \-0 <.û"~'-X...\- \:>0\"'- ~";,\'\~f<: ~ "'€~~¥\~ ~ R:~~\e \-<!: '>:... c 1,.- \à- ~'" ~ ð'0 ,0-\-\<:> "-. ~'L:, ~ \<:: "> -\ '> s. ~ \'0 ê~C.~'f '\' \C~~ '\ "=> C) \ü-\\:<:)\..... ) (}O Þ-~Cd5, \\;) ~~ d\o~c;:> \-~~C,,^~'~\O,,-'0\~(st-\'\Ö\t) \-0 Q~vro~<è G-'-Jú.,,~X- \-0 ,\- \'.Jè \> \\.)~~ '\.~ ~~0\ \"( \'AE. ~~ í \- + \-...(¡ ~~ \ ì "0. ~'\r')C'" \ "'-I ~ -Ç4 C-\-" -.) E .. < Ú ",<¿) V ~ 0<1 (\. -\:, ç\'-.)~'ð """-~ "t:. ~ ""\- \t'-~ ",-{à\Cc..CA.C\oO~ 0,'0 -\\'E~ wo:.-\t \: c..~fè.û~~~ ~t\O~SO-\ S~~\~ Ù~é~~Û--\-~\, ~mi~Q: \so\:>'-+Th"- I rQCO~o-<\<6.SJ ~~~",Q \, Æ ~ ~\::rŒVISED BY: BCA 3/15/07 S ~-O" RKB - 20.5' 3 4 5 3950' B6 Fill at 4233' TD = 4264' MD, 3636' TVD Directional Wen SRU 241-16 Schematic 16" 68# J-55 Weld Surface 9-5/8" 40# L-80 BTC Surface 434 sxs 7" 26# L-80 BTC Surface 290 sxs TUBING 4-1/2 " 12.6 L-80 IBT Surface 2-7/8" 6.5# L-80 IBT 25' Item L 25' XO - 2-7/8" Butt Pin x 4-1/2" Butt Box 2. 2478' SFO-lCI CIM (2.347" 3. 3370' 7" HES "PHL' Packer 4. 3382' XNi Ie (2.313") 5. 3395' WLREG 6. 9/15/04: Tagged fill w/2"x20' Dummy Gun at 4233' RKB (slm) Revised 2/27/07 BCA "'i RKB - 20.5' 3 4 5 J-55 Weld Surface L-80 BTC Surface L-80 BTC Surface 12.6# L-80 IBT Surface 25' 6.5# L-80 IBT 3396' l. 2. 3. 4. 5. 6. XO - 2-7/8" Butt Pin x 4-1/2" Butt Box SFO-ICI CIM (2.313") T' HES "PHL' Packer X Ni Ie (2.313") WLREG TTS Brid e Plu wllO' cmt on to 9/J5/04: Tagged fill wl2"x20' Dummy Gun at 4233' RKB (slm) B4a Sand Proposed 6 Plug and 10' cement Proposed B6 Sand Fill at 4233' TD = 4264' MD, 3636' TVD Directional Well SRU 241-16 Schematic 9/15/04 Revised 2/27/07 BCA I'''''''''''' v ...u . STATE OF ALASKA _.a' ALAS OIL AND GAS CONSERVATION COMMWJO~ 2 2007 REPORT OF SUNDRY WELL ~lI~NSns. Commission ~ .:S-..r~-; . -.- 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate ld Other ~ Cancelled Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development [2] Exploratory 0 204-088 , 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic 0 Service 0 6. API Number: 50-133-20540-00 - 7. KB Elevation (ft): 9. Well Name and Number: 20.5' ( SRU 241-16 - 8. Property Designation: 10. Field/Pool(s): Swanson River ./ Swanson River Unit - 11. Present Well Condition Summary: Total Depth measured 4264' " feet Plugs (measured) none true vertical 3636' ( feet Junk (measured) none Effective Depth measured 4233' feet true vertical 3605' feet ~~NED MAY 0'92007 Casing Length Size MD TVD Burst Collapse Structural Conductor 66.5' 16" 66.5' 66.5' 2980 psi 1410 psi Surface 1553' 9-5/8" 1553' 1388' 5750 psi 3090 psi Production 4264' 7" 4264' 3636' 7240 psi 5410 psi Liner Perforation depth: Measured depth: 4027'-4037' True Vertical depth: 3399'-3409' Tubing: (size, grade, and measured depth) 2-7/8" L-80 IBT 3396' Packers and SSSV (type and measured depth) HES "PHL" Pkr 3370' 12. Stimulation or cement squeeze summary: Intervals treated (measured): 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory 0 Development [2] Service 0 Daily Report of Well Operations 16. Well Status after work: OilD Gas [2] WAG 0 GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or N/A if C.O. Exempt: 307-081 ~ Contact Steve Tyler Printed Name Timothy C. Brandenburg Title Drilling Manager 7- -~->~ C -/,) - Signature ( // Phone 907-276-7600 Date 2/12/2007 L./ ¿..-/ Form 10-404 Revised 04/2006 RBDMS BFl MAYO 7 2007 45 J.'\ Submit Original Only SRU 241-16 Perforation Depths e e 1 of 1 3/22/2007 7:34 AM . . SARAH PALIN, GOVERNOR AI.ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 ",""." . Re: Swanson River Field, Swanson River Undefined Gas Pool, SRU 241-16 Sundry Number: 307-081 SCANNED MAR {} 9 2007 \~ - O~<; ~ \) -, Dear Mr. Brandenburg: 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 2. day of March, 2007 EncL .. STATE OF ALASKA . AlA~ Oil AND GAS CONSERVATION COM~ION APPLICATION FOR SUNDRY APPROVALS 20 MC 25 280 RECEIVED MAR 0 2 2007 1. Type of Request: Suspend D Repair well D Pull Tubing D Operational shutdown D Plug Perforations 0 Perforate New Pool D 4. Current Well Class: Development 0 Stratigraphic D .. - Perforate 0 vvalve~~~L uUII;). Stimulate D Time Extension ~nchDrage Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 204-088 Service D 6. API Number: - Abandon D Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: UIner L.J P.O. Box 196247, Anchorage, Alaska 99519 50-133-20540-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes D 9. Property Designation: Swanson River 12. 8. Well Name and Number: Total Depth MD (ft): 4264' RKB Casing Structural Conductor Surface I ntermed iate Production Liner Total Depth TVD (ft): 3636' RKB Length No 0 SRU 241-16 10. KB Elevation (ft): 11. Field/Pool(s): 20.5' Swanson River Unit PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 4233' RKB 3605' RKB Plugs (measured): Junk (measured): Size MD TVD Burst Collapse . 66.5' 16" 1553' 9-5/8" 4264' 7" 66.5' 1553' 66.5' 1388' 2980 psi 5750 psi 1410 psi 3090 psi 4264' 3636' 7240 psi 5410 psi Perforation Depth MD (ft): 4027' - 4037' Packers and SSSV Type: Perforation Depth TVD (ft): 3399' - 3409' HES "PHL" Ret Packer Tubing Size: Tubing Grade: 2-7/8" 6.5# IBT L-80, Packers and SSSV MD (ft): Tubing MD (ft): 3396' 3370' 13. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 15. Estimated Date for Commencing Operations: 14. Well Class after proposed work: 17. Verbal Approval: Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Na~~y C. Brandenburg Title Drilling Manager Signa~ ........... -L r: Phone r-$07-276-7600 r A. . A ... ,..T;""" I ~r~b"''-9 I ...., , COMMISSION ~E ONLY Date: Exploratory D Development 0 Service D 3/12/2007 16. Well Status after proposed work: Oil D Gas 0 Plugged D Abandoned D WAG D GINJ D WINJ D WDSPL D Contact Steve Tyler - 263-7649 Date ~/I , 01 I . Conditions of approval: Notify Commission so that a representative may witness Sundry Number: <..."301... 08 / Plug Integrity _ Q Other: BOP Test D Mechanical Integrity Test D Location Clearance D Approved by: S'b,"",eo' Fo"" Req';,",,' '-\() ~ ç;, _ 4,,~ C> \<>H-~<>- -Irtc:>,,- ..,. 0 \}- \Ç\~ Irt:...,,\-" cZ r ~r;, APPROVED BY 4 A '2- / ./'Vr-.jMISSIONER ._ 2"HE COMMISSION Date: 3 -,"'7 Form 1 0-403 Revisee/~i G I rr A Ý' '-.--' Dtt: MAR 1 2 1007 Submit in Duplicate Chevron === . . Trading Bay Unit Well # SRU 241-16 2/26/07 OBJECTIVE: · Recomplete well in the Sterling B5 sandC\~\ "t-~ \.o.~II"'\~ t'{.~\\:"'i~~\\~~ \3<ø ~r\s PROCEDURE SUMMARY: · Run 2.28" Gauge Ring and tag fill at 4264' RKB (+/-). Cut scale if necessary. · Run static BHP survey. · Run 2.25"x5' bailer as a dummy gun and also to get fluid sample. · Squeeze fluid back into perfs with 1300 psi (+/-) with field gas pending slickline work. · Set bridge plug at 4000' (+/-). Dump 10' of cement on top of plug. · Perform MIT. Pressure tubing to 1300 psi (+/-) for 12 hrs and 100 psi for negative test for 12 hrs. · Perforate Sterling B5 sand fÌ'om 3550' to 3554' with surface pressure at 1000 psi for 10% underbalance. · Turn well over to production. SRU 241-16 REVISED BY: BCA 2/26/07 RKB - 20.5' 3 4 5 3950' Fill at 4233' B6 TD = 4264' MD, 3636' TVD Directional Well SRU 241-16 Schematic J-55 Weld Surface L-80 BTC Surface 434 sxs L-80 BTC Surtàce 290 sxs L-80 IBT 27' 3396' L-80 IBT 27' 3396' 1. 2. 3. 4. 5. 6. 25' 2478' 3370' 3382' 3395' XO - 2-7/8" Butt Pin x 4-1/2" Butt Box SFO-l CI CIM 7" HES "PHL' Packer XNi Ie WLREG 9/15/04: Tagged fill w/2"x20' Dummy Gun at 4233' RKB (slm) 2" HC, 60 de phase Revised 2/27107 BCA RKB 20.5' 3 4 5 84# J-55 Weld Surface 40# L-80 BTC Surface 26# L-80 BTC Surface 4-1/2" L-80 lBT 27' 3396' 2-7/8" 6.5# L-80 lBT 27' 3396' 1. 2. 3. 4. 5. 6. 25' 2478' 3370' 3382' 3395' 4000' XO - 2-7/8" Butt Pin x 4-l/2" Butt Box SPOol Cl ClM 7" HES "PHL' Packer XNi Ie WLREG TTS Brid e Plu wIlD' emt on to 9/15/04: Tagged fin w!2"x20' Dummy Gun at 4233' RKB (slm) B5 Sand Proposed 6 Plug and 10' cement Proposed B6 Sand Fill at 4233' TD = 4264' MD, 3636' TVD Directional Well SRU 241-16 Schematic 9/15/04 - 2" HC, 60 de hase Revised 2/27/07 BCA \0 ~~'J DATA SUBMITTAL COMPLIANCE REPORT 6/26/2006 Permit to Drill 2040880 Well Name/No. SWANSON RIV UNIT 241-16 MD 4264/ TVD 3636· /" Completion Date 6/10/2004 REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: CBT, Neutron, GRlCCL, Temp Survey Well Log Information: Log/ Data Type ............ED Electr Digital Dataset Med/Frmt Number Name C Las 12535 Induction/Resistivity J.e'9 Induction/Resistivity ~D C Pds 12667 Gamma Ray ~ 12667 Gamma Ray .d:ã9 12667 Cement Evaluation - ..A:ög 12667 1r1'Ä'Ction/Roci\,livily _ ~Sl /D C Pds 12777 Completion yg 12777 Completion Well Cores/Samples Information: Name Interval Start Stop Operator UNION OIL CO OF CALIFORNIA Completion Status 1-GAS Current Status 1-GAS Sl~! ~¡~ ~y API No. 50-133-20540-00-00 UIC N Samples No Directional SurveC yes') _ (data taken from Logs Portion of Master Well Data Maint OH/ CH Received Comments Open 6/16/2004 Density GR Includes meta Graphics 1570 4300 Open 6/16/2004 TWO LOGS (MD & TVD) DSN 12535 o 4176 6/21/2004 RST-NEUTRON POROSITY, GR-CCL- SCMT-CEMENT BOND LOG , GR-CCL SCMT-CEMENT BOND LOG RST-NEUTRON POROSITY COMPLETION RECORD 2" HSD POWERJETS COMPLETION RECORD 2" HSD POWERJETS Log Log Run Scale Media No Interval Start Stop 1545 4300 25 Bo( ~ B~ B~ 0 4176 6/21/2004 0 4176 Case 6/21/2004 0 4176 Open 6/21/2004 4027 4032 10/5/2004 4027 4032 10/5/2004 B~ Sent Sample Set Number Comments Received . . Permit to Drill 2040880 MD 4264 TVD 3636 ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? Yïf:r- Analysis Y ~ Received? Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 6/26/2006 Well Name/No. SWANSON RIV UNIT 241-16 Operator UNION OIL CO OF CALIFORNIA Completion Date 6/10/2004 Completion Status 1-GAS Daily History Received? Formation Tops ~ API No. 50-133-20540-00-00 Current Status 1-GAS t Date: UIC N )7 J~ÑS"ÕV1 . . . about:blank . Steve, A followup to our conversation about SRU Wells today. We have some well pool errors and production allocation isn't correct in our production database or UNOCAL's. We have found some paperwork submitted to us with the wrong pools on the forms and the wrong data was assigned to the wells. We will creat a pool code if the operator indicates production to a new pool. The wells in question are SRU 12-15, SRU 23-22 and SRU 241-16. For each well Bob Crandall would like a discription of the gas pools in the Tyonek, Sterling and Beluga formations. A date or time when these wells produced in specific pool. Illustration of the well with cross sections. We will insert this response into each well file to reduce confusion in the future about these wells and hopefully better explanations will acompany well recompletions and new permits in the future. Steve '3Jd to ~ Tv~ Q UnðGAL ~(J>V 30') ;;00'7 ßð ~.~ ;W-Ai{~ c,c, eBb 10 ~d rJ<LL J 1 of 1 11/30/2004 9:35 AM 1 a. Well Status: STATE OF ALASKA ALAS. AND GAS CONSERVATION COMMIS8J WELL COMPLETIO'W' OR RECOMPLETION RE:1!"ORT AND OilD Gas [] Plugged 0 Abandoned 0 Suspended 0 WAG 0 1 b. Well Class: 20AAC25.105 20AAC25.110 Development [] ExplÓ/'atdryW'; No. of Completions Other Service 0 Stratigraphic TestD 5. Date Comp., Susp., or 12. Permit to Drill Number: Aband.: 6/10/04 2040880 6. Date Spudded: 13. API Number: May 28,2004 50-133-20540-00 7. Date TD Reached: 14. Well Name and Number: June 4,2004 SRU 241-16 8. KB Elevation (ft): 15. Field/Pool(s): 20.5' RKB to GL 9. Plug Back Depth(MD+ TVD): 4,264/3,636' 10. Total Depth (MD + TVD): 4,264/3,636' 11. Depth Where SSSV Set: n/a 19. Water Depth, if Offshore: nla feet MSL R. Lc9&T 2 6 2004 GINJD WINJD WDSPLD 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 4a. Location of Well (Governmental Section): Surface: 2,219' FNL, 985' FWL, Sec. 15, T8N, R9W SM Top of Productive Horizon: n/a Total Depth: Swanson River Fieldl Sterling 1214 FNL, 565 FEL, Sec. 16, T8N, R9W 4b. Location of Well (State Base Plane Coordinates): Surface: X = 348,837 Y = 2,480,040 TPI: nla Total Del X = 347,308 Y = 2,481,071 18. Directional Survey: Yes [] No D 16. Property Designation: Swanson River 17. Land Use Permit: A-028077 20. Thickness of Permafrost: n/a 21. Logs Run: CBT, Neutron, GRlCCL, Temp Survey 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD I AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 68 K-55 0 67 0 66 driven see schematic for cement detail 9-5/8" 40 L-80 0 1553 0 1388 12.25 see schematic for cement detail 7" 26 L-80 0 4264 0 3,636 see schematic for cement detail 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): Date MD TVD 9/15/04 4,027 - 4,037' 3,399 - 3,409' 6 SPF 24. SIZE 2-7/8" TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 3,396' 3,370' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT AND KIND OF MATERIAL USED see schematic for cement detail 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): n/a flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: 10/25/2004 24 hours Test Period ... nla 4,219 MCF/day Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Press. 1,067 psi 0 24-Hour Rate ... n/a 4,219 MCF/day 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". Water-Bbl: o Water-Bbl: o IGaS-Oil Ratio: n/a Oil Gravity - API (corr): n/a Choke Size: none r(;~iä¡' -.: ,~.&~; <~l0 .~ OR\GU~AL. RBOt.AS Bft. OC1 2 9 ~f' ~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE 28. NAME A9 Al0 All 80 81 82 83 B4 65 66 TD GEOLOGIC MARKE:~ 3, iff' 3,268 3,399 3,470 3,535 3,580 3,666 3,764 3,850 4,025 4,300 TVD 2,537 2,662 2,785 2,852 2,914 2,958 3,042 3,137 3,223 3,397 3,672 29. FORMATION TESTS Include and briefly su.e test results. List intervals tested, and attach detailed supporting da necessary. If no tests were conducted, state "None", none 30. List of Attachments: morning report summary, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: Printed Name: Tim C. BrandenburQ ~ f /5 Contact: Steve Tyler263-7649 Title: Drilling Manager Phone: 907-276-7600 10/20/2004 INSTRUCTIONS Date: Item 29: List all test information. If none, state "None". Item 4b: TPI (Top of Producing Interval). Item 20: True vertical thickness. Item 27: If no cores taken, indicate "none". Form 10-407 Revised 12/2003 u General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for / njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). ('. lJ !~L Location: X=348, 0 E, Y=2,480,039.801 N Lat: 60° 47' 08.068 , Long: 150050' 45.271" W 2219' FNL, 985' FWL, Sec15, T8N, R9W, S.M. RKB = 20.5' AGL GL=318' AMSL RKB elevation == 338.5' AMSL RKB to GL = 20.50' 1U3ING HAN3ER 3.958 XXXXX 0.65 21.15 4112' L-80 BrC PLP JaNT ( An x An ) 3.958 4.500 3.40 21.80 1U3INGCF03S-Ov'ER41/2" x271S' BTCBoxxAn 2.441 5.200 1.70 25.20 1 JT. # 105 2-718' 6.5# IBr L-80 1U3ING 2.441 3.00) 31.00 26.80 2-71'8' 6.5# IBrL-80 PUP JaNT 2.441 3.00) 6.16 58.56 2-71'8' 6.5# IBr L-80 PLP JaNT 2.441 3.00) 6.11 64.72 2-718' 6.5# IBr L-80 PLP JaNT 2.441 3.00) 6.08 70.83 4 76JTS. #29-1042-718'6.5# IBr L-801U3ING 2.441 3.00) 2300.35 76.91 6 X2-7IS' IBrBoxXElEAn PLPJaNT 2.441 3.00) 5.19 2473.26 1 2-718' Pollard SFo.1Q a-EM IN.! IvB1dreI 2.347 5.125 7.43 2478.45 4' X 2-71'8' ElE Box X IBr AnPlP JaNT 2.441 3.00) 3.27 2485.88 26 JTS. #1-26 2-71'8' 6.5# 1ST L-80 1U3ING 2.441 3.00) 870.91 2489.15 6 X 2-718' IBr Box X ElE An PUPJaNT 2.441 3.00) 4.26 3360.00 6 X2-718' ElE M:O. L-80 PLP JaNT 2.441 3.00) 6.14 3364.32 7" X2-7IS' 23-29#1-£5 'PHI..' ÆT. PACKER 2.æJ 5.æo 5.36 3370.45 6 X2-7IS' ElEM:O. L-80 PLP JaNT 2.441 3.00) 6.11 3375.82 H'iI.lIBl..ma\l 'OX' LAf\DlNG NIPPLE 2.313 3.00) 1.24 3381.93 6 X2-71'8' ElE M:O. L-80 PUP JaNT 2.441 3.00) 6.00 3383.17 6 X2-7/f5' ElE M:O. L-80 PUP JaNT 2.441 3.00) 6.10 3389.23 a 2-71'8' EUE L -80 \I\ŒG 2.441 3.800 0.50 3395.33 EN) a= 1U3ING 3395.83 16" 9-5J8" 7" Weld BTC BTC (I<C) 66.5' BGL 1,553' 4,264' 68 40 26 1<-55 L-BO L-SO 0' I)' 0' 7 9-5/8" 12.25 545 97 276 12.8 Lead 8" 185 33 158 15.8 Tail / 7" 8.5 303 54 154 12.8 Lead 163 29 136 15.8 Tail Perforations Date MD TVD 9/15/04 4,027 - 4,037' 3,399 - 3,409' TD :::: 4,264' MD / 3,636' TVD SRU 241-16 Proposed REVISED: 10/20/04 DRAWN BY: SSL >Infotmation >Well >Directional Surveys >Fervey - ~~~ . Select Well: SRU 241-16 Report Name Well Date Created Position Log SRU 241-16 10/20/2004 Well Name CURRENT STATUS API KB Surf X Surf Y (ft) (ft) (ft) SRU 241-16 LOCATION 501332054000 339 348,837 2,480,040 MD TVD SSTVD X Off Y Off X Y Inc Azimuth (ft) (ft) (ft) (ft) (ft) (ft) (ft) (deg) (deg) 0 0 339 0 0 348,837 2,480,040 168 167 172 0 0 Inconsistant Data 348,837 2,480,040 Click HERE to view Directional Survey. 198 197 142 -1 0 348,836 2,480,040 230 229 110 -1 0 348,836 2,480,040 292 291 48 -4 0 348,833 2,480,040 353 352 -14 -8 3 348,829 2,480,043 415 414 -76 -15 7 348,822 2,480,047 476 474 -136 -24 13 348,813 2,480,053 537 533 -195 -35 21 348,802 2,480,061 598 592 -254 -48 30 348,789 2,480,070 660 651 -313 -63 40 348,774 2,480,080 721 709 -371 -80 51 348,757 2,480,091 782 766 -428 -98 63 348,739 2,480,103 846 825 -487 -119 77 348,718 2,480,117 910 883 -545 -141 93 348,696 2,480,133 973 938 -600 -165 109 348,672 2,480,149 1,036 993 -655 -192 126 348,645 2,480,166 1,099 1,046 -708 -220 145 348,617 2,480,185 1,161 1,097 -759 -250 164 348,587 2,480,204 1,225 1,147 -809 -282 187 348,555 2,480,227 1,287 1,195 -857 -315 209 348,522 2,480,249 1,349 1,243 -905 -348 231 348,489 2,480,271 1,411 1,289 -951 -383 253 348,454 2,480,293 1,474 1,334 -996 -420 277 348,417 2,480,317 1,513 1,361 -1,023 -443 293 348,394 2,480,333 1,634 1,443 -1,105 -517 342 348,320 2,480,382 1,697 1,485 -1,147 -556 369 348,281 2,480,409 1,761 1,526 -1,188 -596 397 348,241 2,480,437 1,822 1,565 -1,227 -635 423 348,202 2,480,463 1,886 1,605 -1,267 -677 451 348,160 2,480,491 1,950 1,645 -1,307 -718 479 348,119 2,480,519 2,076 1,724 -1,386 -799 534 348,038 2,480,574 2,141 1,765 -1,427 -840 563 347,997 2,480,603 2,204 1,806 -1,468 -880 590 347,957 2,480,630 2,266 1,847 -1,509 -919 615 347,918 2,480,655 2,330 1,892 -1,554 -957 641 347,880 2,480,681 2,393 1,937 -1,599 -993 667 347,844 2,480,707 2,456 1,982 -1,644 -1,028 691 347,809 2,480,731 2,520 2,030 -1,692 -1,064 715 347,773 2,480,755 2,583 2,078 -1,740 -1,097 739 347,740 2,480,779 2,647 2,127 -1,789 -1,131 762 347,706 2,480,802 2,709 2,176 -1,838 -1,162 783 347,675 2,480,823 2,773 2,228 -1,890 -1,193 804 347,644 2,480,844 2,836 2,281 -1,943 -1,222 825 347,615 2,480,865 2,900 2,335 -1,997 -1,249 845 347,588 2,480,885 2,963 2,389 -2,051 -1,275 863 347,562 2<.3 . 3,027 2,445 -2,107 -1,302 880 347,535 2,4 0 3,090 2,501 -2,163 -1,327 895 347,510 2,480,935 3,153 2,557 -2,219 -1,351 910 347,486 2,480,950 3,217 2,615 -2,277 -1,373 924 347,464 2,480,964 3,280 2,673 -2,335 -1,395 937 347,442 2,480,977 3,343 2,732 -2,394 -1,414 949 347,423 2,480,989 3,407 2,792 -2,454 -1,433 961 347,404 2,481,001 3,470 2,852 -2,514 -1,449 972 347,388 2,481,012 3,533 2,912 -2,574 -1,464 980 347,373 2,481,020 3,596 2,973 -2,635 -1,478 988 347,359 2,481,028 3,658 3,034 -2,696 -1,489 995 347,348 2,481,035 3,723 3,097 -2,759 -1,499 1,004 347,338 2,481,044 3,786 3,159 -2,821 -1,507 1,011 347,330 2,481,051 3,848 3,221 -2,883 -1,514 1,017 347,323 2,481,057 3,912 3,284 -2,946 -1,519 1,022 347,318 2,481,062 3,975 3,347 -3,009 -1,524 1,025 347,313 2,481,065 4,037 3,409 -3,071 -1,528 1,027 347,309 2,481,067 4,165 3,537 -3,199 -1,529 1,031 347,308 2,481,071 4,227 3,599 -3,261 -1,529 1,031 347,308 2,481,071 . . 5/26/04 Shut down waiting on crew.Sim-ops with production. Pre-job meeting with Peak and Kuukpik personnel.Kuukpik rig personnel started generators, Installed flowlines to pits, hung cutting hopper, set BOP trolley, hung beaver slide, installed stairs on sub, hung high line power, powered up buildings, RU high pressure mud liness, modified flowline to pits. Peak personnel set cutting boxes, filled tanks with water, set grating and laid liners for parking lot, Set Baker Inteq, Assisted electrician, Hooked up Sclumberger pumping, fueled up equipment.Continued rigging up. Due to no night Peak personnel broke rig crew to assist on capping wellhead on SRU 21-33 WO. 5/27/04 Continued rigging up Kuukpik rig # 5 w/ no peak night support crew - 3 Kuukpik hands continued assisting Capping wellhead @ SRU 21-33 WD for 2 hrs - hang lights in cellar- hook up choke line - hook up koomey lines & install vent on hot well Simops with production. Pre-job meeting with Peak and Kuukpik personnel. Continue R/up - R/up bails - hang scaffolding in cellar repair hopper valve - Pull TO grabber a-part for repair - hook up water lines - dress shakers - Repair leek on H.P's -Install new seals on TO grabber - House clean All personal attended Pre-spud meeting @ production office & Production Field Orientation of Service personnel. Continue R/up - Finish repair of TO gripper system - work on compensators Reroute - Perform Derrick inspection 0-12 hammer arrived & prep same for p/up & awaiting hammer operator from demobe of 0-32 hammer from red pad - Continue R/up - House clean & re-wrap service loop Install firstjt 16" 98# k-55 drive pipe wi 16" 10 shoe - P/up 0-12 hammer & work on rig Acceptance . 5/28/04 Inspect rig & Accepted rig @ 0001 hrs - Continue P/up 0-12 hammer & alignfirstjt full 40' jt of 98# K-55 16" drive pipe wi 16" 10, 17" 00 factory drive shoe Get hammer to fire & Drive first full jt from 31.50' rkb t/ 36.5' rkb @ average 18-20 Blows per foot & strap derrick height for max drive pipe length wi Kuukpik rig #5 = 25'Cut 2nd jt to length @ 25' - Prep for welding - P/up & position for welding Perform first weld w/25' jt - position hammer while 1/2 hr cool dn time Drive second 25' jt from 36.50' rkb t/ 60.5' rkb @ average 64.76 Blows per foot P/up & position third jt 16" @ 25' - perform second weld - position hammer while 1/2 hr cool dn time Drive third jt @ 25' jt from 60.50' rkb t/ 87.65' rkb @ average 112 Blows per foot - 16" shoe @ 66.5' below ground level wi min 14 BPF & Max 218 BPF R/dn 0-12 hammer Rough cut 16" & I/dn same -Install & weld base plate for 16" -Install & weld two 4" nipples above base plate WI ball valves - Pour +- 3.25 yards of cmt for +- 14" thick cellar floor below & up to base plate - fabricate scaffolding to work above wet cmtPerform final cut on 16" @ 42" below ground level & weld on starting flange wi weld procedure for 4140 wi face of flange @ 39" below ground level Let flange cool & cmt set & prep t/ install flow nipple & p/up Bha #1 5/29/04 Continue Let flange cool & cmt set & prep t/ install flow nipple & p/up Bha #1 & mixing mud & pressure test HP lines t/ 4500 psi Pull Rotary table - nipple up 16" flow nipple - install flow line & rotary tableP/up Bha #1 - Fill hole circ thru flow nipple - fix stroke counters#1 shaker mtr smoking trouble shoot same & clean out 16" conductor t/ 2' past shoe 90' @ reduced flow rate (only one shaker on line, taking some rig dn time here)Rig on dn time continue circ @ reduced rate over one shaker to shear mud & chg/out shaker mtrBoth shakers back on line total of 5 hrs dn time - drill fl 90' t/ 150' (a lot of gravel)Have rig work pipe & circ - attempt to get depth control from rig Pason system to BHI (no-go)Pump ooh & stand Back 2 std 4" HWDP & M/up Bha #2 Start kick off &dir drill 12-1/4" hole fl 150' t/ 227' (60% gravel- 30 % sand 10% coal & clay) 5/30104 SRU 241-16 summary, last revised 10/07/04, page 1 . . Continued directional drilling from 227' to 1,570' MD. Actual pipe in ground - 71' per hour (20 hrs), Actual sliding - 965' (5.9 hrs), Actual rotating - 378' (2.1 hrs). Circulated 2 bottoms up. Pumped a Carbide marker with 6% over calculated volume. C&C mud. POOH working through tight spots. Back reamed from 865' to 320' due to pack-off problems. 5/31/04 LD MWD tool and mud motorPU cleanout assembly (BHA #3). RIH w/same and tagged at 1,409'. Washed to bottom @ 1,570'. Circ & Cond mudPumped out of hole ,for 290'. Pulled out of hole and LD BHACleaned off rig floor to run casing. RU Weatherford casing equipment. Held PJSM.PU shoe and float equipment. Ran 37 jts 9-5/8", 40#, L-80 casing. Set centralizers on bottom 5 joints. Circ & Cond mud. Landed Cameron T-103 casing hanger. 9-5/8" casing shoe @ 1,560'RU Schlumberger cement equipment. Held PJSM. Tested lines to 3,000 psi. Pumped 40 bbls Mudpush XL. Pumped 97 bbls Lead cement @ 12.8 ppg followed by 33 bbls tail cement @ 15.8 ppg. Dropped ball and displaced with rig pump. During displacement noticed pressure increase at proper pump schedule. Bumped plug with 800 psi. Unable to get pressure above 800 psi. Continued pumping and overdisplaced 3 bbls. Returns were 11.2 ppg. Shut down pump and pressure decrease to 390 psi. Called town. Decision was made to pump 3 bbls. Pumped 3 bbls and pressure increased to 1,000 psi. Shut-off pumps. Pressure decreased to 450 psi. Let cement stand for 30 minutes. Tested float by bleeding 1/4 bbls to cement unit. Float held. Let cement stand for 30 minutes. Fluid level in stack dropped +/-17'.RD cement.Cleaned up possum belly and flowlinesLD landing jt. Removed mouse hole and rotary table. 6/1/04 ND bell nipple. Cleaned cellar. NU Cameron MBS well head. Tested void to 5,000 psi.NU BOPE.Tested BOPE to 250/2,500psi with 7", 4" and 2-7/8". Note: Mr. Tim Lowlor with BLM witnessed BOPE test. Mr. Jeff Jones with AOGCC waived witness of BOPE test. 6/2/04 Finished testing BOPE.Unsuccessfully attempted to test 9-5/8" casing to 2,500 psi. Broke down test jts. Installed wear bushing. MU BHA #4 to drill out float. RIH w/same and tagged Float collar @ 1,509'. Drilled out float and shoe. Drilled out 20' new hole to 1,580'. CBU. Performed LOT with a result of 13.1 ppg EMW. C&C mud. POOH.MU RTTS tool. RIH w/same and set same @ 1,489'. PU wt - 38K, SO wt - 28K. Tested casing to 2,500 psi for 30 minutes. Charted same. POOH & LD RTTS tooI.POOH.PU BHA #5. Oriented and programmed MWD tool. Held PJSM to load tool source. Loaded same. RIH w/same. Tested tool @ 400 gpm.Rig service. 6/3/04 RIH w/MWD/LWD tool and calibrated same for depth control. Held pit drill. Directional drilled from 1,580' to 3,761'. Actual pipe in ground - 99' per hour (22 hrs), Actual sliding - 851' (5.4 hrs), Actual rotating - 1,330' (5.4 hrs). Max gas units 671 @ 3,280'. 6/4/04 Directional drilled from 3,761' to 4,300'. TD @ 0715 hrs. APIG - 539' (7 hrs), AST -1.7 hrs, ART- 2.3 hrsCirc and Cond mud. PU wt - 92K, SO wt - 58K, Rotating wt - 68K, Rotating torque - 7K.POOH from 4,300'-3,594'. Monitored well for 10 minutes. POOH and LD BHA Pulled wear bushing.RU to run 7" casing. Held PJSM.Ran 7", 26#, L-80 Butt Mod casing casing. Checked float after 4 jts. Broke circulation and CBU @ 1,557'. Running casing @ 1,759' at 2400 hrs. 6/5/04 SRU 241-16 summary, last revised 10/07/04, page 2 . . Running 7", 26#, L-80 Butt Mod casing to 4,243Wash down from 4,243 to 4,265 Pipe became stuck while making connection - Talked with Anchorage Engineering Got OK to proceed Lay Down Jnt #105 - Rig up Cement HeadCir & cond for Cmnt job - Mix Mud Push - Held Pre-Job safety meeting Rig up Dowell - Pressure test lines - Cement 7" 26# L-80 Mod BTC casing as Follows 10bbl Chem wash + 30bbl Mud push (Drop Btm Plug) + 54bb (303CF, 154sks) Class "G" Mixed to 12.8ppg with 11.064gal/sk fresh water + .2%BWOC D-46 (Deafoam) + 2%BWOC D079 (Extender) + .8%BWOC D-167(Fluid Loss) + .75% BWOC S002 (Accelerator) + 29bbl (163cf, 136sks) Class "G" Mixed to 15.8ppg with 3.121Gal/sk fresh water + .3%BWOC D065 (Dispersent) + .5%BWOC S001 (Accl) + 2gal/sk D600G (Gas Block) + .2gal/sk D047 (anti Foam) + 3%BWOC D-174 Expanding CE - Drop Top Plug Displace with 5bbl mix water followed by 156bbl Drill mud with rig pump - CIP at 1 0:20hrs - Pressure up agianst plug to 3,500psi & hold same for 30min casing pressure test (lost 50psi & then held) Rig Down Cement Lines - Rig to Pick up Stack - Break every other Bolt on Wellhead - Work on Cleaning Pits After 7.5hrs after bumping plug - Finish unbolting BOP stack - Pick up and hang same - Set Emerengcy slips with 20k over pick up weight Rough cut 7" - Lay down stub - Final cut & Dress for Pack Off Pick Stack up & Nipple up Wellhead RIH with 8stnds 4" HW - Make up Packoff running tool - RIH and land same (Note all Valves & test ports were open when we landed packoff - Check placement OK - Release Pack Off & POH with HW - While POH Energise seals & pressure test Packoff to 3,500psi for 30min OK 6/6/04 Nipple Up Bell Nipple & Flow Line (Pack Off Pressure Tested to 3,500psi for 30min)Shell Test BOP Stack to 250 low & 2,500 psi HighSet Wear RingMake Up Bit & Casing ScraperRIH (Strap in) - Tag at 4,228 dpm - Rotate on rubber Plugs to confirm F/CDisplace well with Water - Pumped additional 80bbl flush Fill Pits & Mix 20bbl Dirt Magnet PillSpot 20bbl Dirt magnet in annulusFill Pits Cir Dirt Magnet around - Flush with 150bbl clean waterFill Pits & Mix Packer Fluid - Fresh Water With 3% KCL + 1% by Volume Baracor700 Corrision Inhibitor + 1/ppb Barascav D Oxygen Scavenger POH laying Down D.P. & ToolsPull Wear RingRig to run CBT tool under 1,500psi pressure (Land Hanger with Riser to Rig Floor, Close 7" Rams, Pressure test same to 2,OOOpsi 6/7/04 Rig up Schlumberger - Run CBT + Neturon+ GR/CCL - Tag at 4,222 - Log up to 9 5/8" shoe with full suite - Log up from 9 5/8" shoe with GR to surface. RD Schlumberger. RU weatherford to run production tubing. Held PJSM.Ran 2-7/8", 6.4#, L-80 Buttress tubing with accessories. Made up CIM. Tested same for opening pressures on surface. CIV opens at 1,200 psi. Ran same strapping control line to tubing. PU wt - 24K, SO wt - 21K.Made up hanger. Made up control line to hanger and tested same to 1,200 psi.Landed hanger and locked down pins. Dropped bar. Pressured up on tubing to 3,500 psi while monitoring casing. Set packer @ 3,370'. Held pressure for 15 minutes to allow packer to fully set. Tested CIM control line to 2,000 psi. Bled pressure to 0 psi. Tested B/S to 1,500 psi for 15 minutes.RU SL and tested to 1,000 psi. Ran 2.35" gauge to 3,376'. Tagged bar. POOH. RIH wi 2" "JDC" pulling tool and pulled bar. RIH with 2.20" GSPT. Latched and pulled plug body. RD SL.Set BPV. ND BOP stack. 6/8/04 Finished ND BOP and clean and inspecting rams NU short tree, test void to 5000 PSI! 15 minutes. Pull BPV and set TWC, shell test to 250/5000 PSI pull TWC and set BPV.Clean pits, drain boilers, and water tannks, Release rig at 12:00 HRSRig down, load trailers with Unocal owned and or rented equipment for return or shipment to HV. 6/9/04 Continue to RD, shipped sub base and derrick to HV stage at NNA (Wide Loads requiring permits, weekend restraints on wide loads) SRU 241-16 summary, last revised 10/07104, page 3 . . 6/10104 Continue with rig move some trailers to Happy Valley. Ship all Kuukpic camps, disconnect power and communications from all camps including Unocal. Clean up work on including Unocal. Ongoing cleanup work at pad. 9/15/04 No OperationsPJSM, RU Pollard Slickline , lubricator and pressure test to 2500 psi.Wait on cross over for tree connectionRIH with 2 7/8" swab cups. Tagged fluid at 40', pulled from 140'; tag at 70', pulled from 170'; tag at 110', pulled from 310'; tag at 270', pulled from 570'; tag at 525', pulled from 835'; tag at 565', pulled from 940'. POOH to change swab cupsRIH with new 27/8" swab cups and tagged fluid at 600'. Pulled from 850'. Tagged fluid at 830' KB. POOHRIH with 20' of 2" dummy guns and tagged at 4233' KB. POOHRD Pollard slickline and lubricator. Discussed next job with DSM and town. Drilling Peak crew hooked temporary line heater and flow line to flow mline on SRU 32A-15 and hydrotested flowline and line heater in atages up to 3000 psi. Fixed nine defferent leaks in system production put together.PJSM, RU Schlumberger and pressure test to 2500 psiRIH with 5', 2"OD HC, 6 spf perf gun. Tied into GR/CCL log, 6-6-04. Well had 0 psi on tubing. Spotted perf gun from 4027' to 4032' and fired gun. Pressure remained the same. POOH - all perfs fired. Turned well over to production. They replaced Schlumberger high pressure gauge with their own and found 36 psi on tbg. Pressure built up to 386 psi in about 2 hrs. Bled well down to 18 psi and it unloaded about 5 barrels of fluid. Pressure built back up to 170 psi. Tried to unload fluid to atmosphere and well bled down to 0 psi in just a few lJIinutes with no additional fluid. Rigged Schlumberger back up. RIH with 1q', 2" HC, 6 spf. Tied into GR/CCL log dated 6-6-04. Spotted perf gun from 4027' to 4037'. Well had 180 psi on it. Fired perf gun and pressure did not change. 9/16/04 Spot perf gun from 4027' to 4037'. Tubing pressure 180 psi. F.ired perf gun and pressure stayed the same. POOH Rig down Schlumberger..PJSM, RU Pollard ~Iickline and lubricator. Wait on swab mandrel.RIH with 2 7/8" swab cups and tag fluid at 440'. Swab from 540'. Tag fluid at 220' and swab from 280'. Tag fluid at 57' and swab from 300'. Pull up in lubricator because well started to unload. Best estimate was 29 barrels total was unloaded from well before it started to flow. (36 barrels total unloaded)Moniter well. 1000 psi - 2 mcf flow on 12/64 choke. Rig down Pollard. Put spider on well for 30 minutes and then shut in well at 14:00.Secure Well SRU 241-16 summary, last revised 10/07/04, page 4 . . Report Name I Well Field API KB Date Created Directional Survey SRU 241-16 UNKNOWN 501332054000 338.5 11/2/2004 MD (ft) Inclination Azimuth 168 0.57 258.32 198 0.83 277.06 230 1.65 284.94 292 3.43 293.88 353 5.77 297.69 415 8.69 302.43 476 11.52 305.14 537 14.03 304.56 598 16.75 304.47 660 18.02 303.11 721 19.84 302.07 782 21.92 303.2 846 24.27 304.16 910 26.47 304.01 973 28.68 302.7 1036 30.9 301.96 1099 33.63 301.76 1161 36.95 303.69 1225 38.94 303.55 1287 39.75 303.11 1349 40.63 302.6 1411 42.82 302.24 1474 45.88 302.45 1513 47.43 303 1634 47.39 302.93 1697 48.89 304.23 1761 50.27 303.71 1822 51.53 303.22 1886 51.28 303.62 1950 51.02 303.08 2076 50.99 304.07 2141 50.74 303.91 2204 48.98 302.64 2266 46.98 302.91 2330 45.11 303.93 2393 44.04 304.93 2456 42.68 302.88 2520 41.37 304.26 2583 40.09 304.45 ~ (J~l... 088 . 2647 2709 2773 2836 2900 2963 3027 3090 3153 3217 3280 3343 3407 3470 3533 3596 3658 3723 3786 3848 3912 3975 4037 4165 4227 4300 38.38 36.69 34.73 33.09 31.18 29.98 28.58 27.17 25.57 24.11 22.37 20.87 19.07 16.98 14.9 13.23 12.39 10.84 9.11 7.38 5.91 4.5 2.95 0.65 0.64 0.64 . 303.35 303.39 303.28 305.73 304.96 302.9 300.6 301.26 301.57 300.48 300.26 302.74 302.86 299.52 297.52 300.52 305.99 312.31 313 309.53 304.02 295.95 313.49 359.47 17.95 17.95 . Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unocal.com . UNOCAL Debra Oudean G & G Technician Date: September 30, 2004 To: AOGCC Helen Warman 333 W. ¡th Ave. Ste#100 Anchorage, AK 99501 ~.¡:'~'~~~'JI.w ~1'~¡i.f;·I"I~,:~.········;':I..·.. ;·I~.l...".I.m ··¡I.I'I_.:.·..,.....·.....·......:jl¡¡.II~=rrmill.·····.··i.:·:]'.......·.···;i...···I..t~I~~lmll~ ._.....;............... q _,,_._.._._._,%p~..,_._.«<_,,_ "'_._._._,._':'.., ,cc._,._,_J~it.___._,,,,,.,,.,.., ',' _.'.__._.____.'_.'_.',.,0,.."'".. m",_,._._.i1:1" .. ,,,""._c._y,,",,_.<_.._. ,_. __._:_._:___..,..,._..,.,.,.,.":,:,::_::,,lli.._y,._._...-.-...JillI~-__._____._,__,.,."... ,__,%._.:._.___._..._._.,_._,_H~ ,.<___________,..",;s,x,':',':":..,':"?",»_._..,.<-·,J!fBIII!'~- __._____________._~, ,-,-.<-__,_,_,,,... ..... . . j=i~~~ª~~~~~~~!i~~~iR~~~~d;~~~~~i·.jß Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Roce;veqJ/lüfL- Date: It Þ /01 ~~fÆ~E (ûJ e Jt¡q ® ~ ~(1 f[;\ DíJ J::J L#0. dû _.~ Lru e ~ I#AtliliA OIL Al'O) GAS CONSERVATION COlWllSSION FRANK H. MURKOWSK/, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 13,2004 Phil Krueger Drilling Manager Unocal PO Box 196247 J\nchorage,J\J( 99519 ~OLf - 08~ Re: Swanson River Field SRU 241-16 304-345 Dear Mr. Krueger: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for 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. Enc!. , , _ STATE OF ALASKA _ ALASWOIL AND GAS CONSERVATION COMM_ON APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: lJ.JG Æ fJv:5 ~, 1~IW04 7/ J3l 1- Annular Dispos. U Other D Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 338.5 AMSL 8. Property Designation: Swanson River Unit "11. Total Depth MD (ft): 4,264' 1. Type of Request: Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): n/a Packers and SSSV Type: Suspend U Repair well D Pull Tubing D Perforatel:J Waiver U Stimulate D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 204-088 / Development Stratigraphic D D / Exploratory D o Service 6. API Number: 50-133-20540-00 9. Well Name and Number: SRU 241-16 / 10. Field/Pools(s): Swanson River Field /Total Depth TVD (ft): 3,636 Length PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 4,264 3,636 Size MD rvD /JUnk (measured): nla Collapse Plugs (measured): nla Burst 67 1,553' 16" 67 67' 9-5/8" 1,553' 1,388' 5,750 psi 3,090 psi 7" 4,264' 3,636' 7,240 psi 5,410 psi 4,264' perfOration Depth TVD (ft): ITubing Size: 2-7/8" HES "PHL" Retrievable Packer Tubing Grade: 6.5#, L-80 Packers and SSSV MD (ft): Tubing MD (ft): 3,396' MD 3,370' MD 12. Attachments: Description Summary of Proposal l:J Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Philip J. Krueger Title Drilling Manager Signature~ ~ 9cr'~ Phone 907-276-7600 Date F(; f{ Ph: I k fl Ii ec¡ elf. COMMISSION USE ONLY Commission Representative: 13. Well Class after proposed work: Exploratory D Development 0 Ll..) 15. Well Status after proposed work: œ004 Oil D Gas 0 Plugged ~ WAG D GINJ D WINJ Abandoned WDSPL D D Service D D D Date: Contact Steve Tyler 263-7649 (/tY ~2004 BOP Test D D 3)4·346 Location clea~QE\VEO SEt> 1 0 'Lü04 . C mmiss\on 0'\ & Gas Coos. 0 Maska' r.,nchOTalJe Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity D Other: Mechanical Integrity Test RRt~~~FL ~~407 -403 R~d 12/2003 S~ l §'ì, COMMISSIONER BY ORDER OF ~~h ~ THECOMM'S:'ON D,te 9i/fðf rOR H3 J ~ t bmit in Duplicate INSTRUCTIONS ON REVERSE .. . . e e SRU 241-16 Work Summary · MIRV Slickline. Swab Fluid level to 700'. RIH wi dummy gun. RD Slickline · MIRU Eline. RIH wi 2", 6spfPowerJet HC. · PerfB-6 sand 4030'md to 4035'md (GR log will determine DIL depth for perf). · RD Eline. · Turn well over to production for testing. / f e e UN OCALe Swanson River Field SRU 241-16 Final Completion Location: X=348,837.220 E, Y=2,480,039.801 N Lat: 60047' 08.068" N, Long: 150050' 45.271" W 2219' FNL, 985' FWL, Sec15, T8N, R9W, S.M. RKB = 20.5' AGL GL=318' AMSL RKB elevation = 338.5' AMSL RKB to GL = 20.50' {:;:;:;:;:;:;:;:. ':'::::::'L »»> 1 .6;:;}}} 4 1 ::»::::d1 ;}::::}{; .---- .......... i:¡:i:::::¡:::i:i$fI:::t .=»>:::::: 2 . . . . . . . . .. ..................L1, .................,q .:-:.:.:-:.:-:.:.:...: 5 I}}}}} 6~··················· .;.:.:.:.:-:.:-:.:, 7 / 8 ,,¡p;....... i}}}: 'I!i!:::::::::::::: I¡It,:::::::::::::: 44\..':-:':-:':':-: '........,........... ::::::::::::;:::::~ I ~I .tt+.:.:.:.:.:.:.: tf, I::::::::::::: 1~M::Þ:::::::::::::: ;:~}\t/ ~:.:.:-:.:<.:' Date MD TBD - Pending OH Logs TVD ::::::::::::::::::~ ¡~¡I,¡}:;:;:::::: ~·II¡F::::::::::::: ill:::::::::::::::> '¡11<:::;:;:::;:; ;.:-:.;.;.:.;.:.;.:" ~¡'i~~ ;:;:;:;:::::;: {it::i:::::::::::: :;:;:;:;:;:;:;:::;:::;:::;:::::;:::::::::::::::::::::::;:::;::<::::::::::::::::::;:: :??:::If?::::/:::/}////ji~/:://:: 3 TO = 4,264' MO I 3,636' TVO SIZE 16" 9·5/8" 7" Pipe 9-5/8" 7" Jewelry Detail ll.BIl\G I-W\ŒR 3.sæ xxxxx 0.65 21.1: 4 1/2' L -00 STC PlP JaNr ( An x An ) 3.sæ 4.500 3.40 21.a: ll.BIl\G a:a:;s..oJER 4112' x 2 71S' STC Box x An 2.441 5.21) 1.70 25.2C 1 Jr. # 1052-7IS'6.5#1ST L-OOll.Bll\G 2.441 3.660 31.66 26.9: 2-7/S' 6.5# 1ST L-OO PlPJaNr 2.441 3.660 6.16 58.5E 2-71S' 6.5#ISTL-OO PlPJaNr 2.441 3.660 6.11 64.?:: 2-7/S' 6.5# 1ST L -00 PlP JaNr 2.441 3.660 6.00 7O.S:: 76JTS. #29-1042-7/S' 6.5# 1ST L-OOll.Bll\G 2.441 3.660 Z3OO.35 76.91 6' X2-7jg'IST Box X El£ An PlP JaNr 2.441 3.660 5.19 2473.~ 2-7/S' Pollard SFO 10 a-Bv1JNJ Mntel 2.347 5.125 7.43 2478.L 4' X 2-7/S' El£ Box X 1ST AnPLP JaNr 2.441 3.660 3.27 2485.f 28..ITS. #1-28 2-71S' 6.5#.lST L -00 ll.BIl\G 2.441 3.660 870.91 2489.1 6' X2-71S' 1ST Box X El£ An PlP JaNr 2.441 3.660 4.26 3360.( 6'X2-7jg'El£M:D L-OOPlPJaNr 2.441 3.660 6.14 æ64.~ 7' X2-71S' 23-29# f-ES 'FH: ÆT. PAŒER 2.æ:J 5.00) 5.35 :r370.L 6' X2-7JG' ElErvrn. L-OO PlPJaNr 2.441 3.660 6.11 :r375.f HAWI3l.RTO\I "X' l..,ANJIl\G I\IffiE 2.313 3.660 1.24 338H 6' X 2-7JG' El£ rvrn. L -00 PlP JaNr 2.441 3.600 6.00 3383.1 6' X2-7JG' El£ rvrn. L-OO PlP JaNr 2.441 3.660 6.10 3389.~ 2-7/S' El£ L -00 w...EG 2.441 3.800 0.:0 3395.~ Ef\l) CFll.BIl\G 3395.f CASING DETAIL WT GRADE CONN TOP BOTTOM 68 K-55 Weld 0' 66.5' BGL 40 L·80 BTC 0' 1,553' 26 L·80 BTC (KC) 0' 4,264' CEMENT DETAIL Hole Cu-Ft bbls Sx Wt Desc 12.25 545 97 276 12.8 Lead 185 33 158 15.8 Tail 8.5 303 54 154 12.8 Lead 163 29 136 15.8 Tail Perforations SRU 241-16 Proposed REVISED: 08/23/04 DRAWN BY: SSL e e Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unocal.com UNOCALi> Debra Oudean G & G Technician Date: June 15,2004 To: AOGCC Robin Deason 333 W. ih Ave. Ste#100 Anchorage, AK 99501 - SRU 241-16 SRU 241-16 ¡OPTIMIZED ROTATIONAL DENSITY CALIPER CORR 12/5 ;/ i NEUTRON MEASURED DEPTH ¡INCH SR'Ü241:16!OPTIMÎZEÕ-ROT A TIONAL DENSITY-CAUPERCOR'RI2/5 ·~---6/4/2Öà4.1.' 1570-4300 ì ~EUTR.0N TRUE VERTICAL DEPTH , i INCH' . . ,0' J c \~ J J S~3 j- Please aCknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Rece;ved By µ ò.~fi Date: I ~ J~ ~.~ .~ ~o~(- &õ~ Lv d1 r,l. t . . FRANK H. MURKOWSKI, GOVERNOR AlfASIiA OIL AND GAS CONSERVATION COMMISSION Steven Lambe Advising Drilling Engineer Unocal PO Box 196247 Anchorage AK 99519 333 w. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: SRU 241-16 Unocal Permit No: 204-088 Surface Location: 2219' FNL, 985' FWL, Sec. 15, T8N, R9W, SM Bottomhole Location: 1214' FNL, 565' FEL, Sec. 16, T8N, R9W, SM Dear Mr. Lambe: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 7. ager). BY ORDER çJ; THE COMMISSION DATED this~'ò day of May, 2004 cc: Department ofFish & Game, Habitat Section w/o encI. Department of Environmental Conservation w/o encl. e Unocal Corporation .. P.O. Box 196247 .. Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALe Thursday, May 27th, 2004 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Anchorage, Alaska 99501 Re: Application for Permit to Drill (Form 10-401) SRU 241-16 RECEI\/FD MAY 2 7 2004 Attn: Commission Chair John Norman Dear Commissioner Norman, Alaska Oil & ,,,,¡¡¡¡¡¡¡¡¡SHJn f\m::hofage Attached for your approval is an application for permit to drill (Form 10-401) for the SRU / 241-16. This Permit to Drill replaces the Permit to Drill for SRU 231-16 approved May 6th, 2004. The new Permit to Drill (Form 10-401) was required as the Bottom Hole location changed prior to spudding. Unocal respectfully requests a waiver of the requirement for a diverter on the 12-1/4" / surface hole as allowed under AOGCC Regulation 20 AAC 25.035 (h) (2). Please refer to attached supporting documentation. The anticipated spud date is Friday, MâY2~t:-=604. If you have any questions please contact myself at 263-7637. ~ ¿u Thank you and your staff in advance for an expedited turn around with this Permit to Drill. Sincerely, If// Steven Lambe Advising Drilling Engineer SSL/s Enclosure ORIGINAL 1"'. r""\ I I" , 'd ^ , w6A- S/z.ß/2.t.~ / .. STATE OF ALASKA . ALAS~ILAND GAS CONSERVATION COMMI rON PERMIT TO DRILL 20 MC 25.005 11 b. Current Well Class: Exploratory 0 Development Oil ~ Multiple Zone D Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 0 5. Bond: Blanket 0 Single Well 0 11. Well Name and Number: Bond No. 103515406-$200K SRU241-16/ 6. Proposed Depth: 12. Field/Pool(s): MD: 4182 TVD: 3539 7. Property Designation: Swanson River Field I Sterling A-028077 1 a. Type of Work: Drill 0 Redrill U Re-entry 0 2. Operator Name: Union Oil Company of California (Unocal) 3. Address: PO Box 196247, Anchorage, Alaska, 99519 4a. Location of Well (Governmental Section): Surface: 2219' FNL, 985' FWL, Sect. 15, T8N, R9W, S.M. Top of Productive Horizon: 1272' FNL, 475' FEL, Sect. 16, T8N, R9W, S.M. Total Depth: 1214' FNL, 565' FEL, Sect. 16, T8N, R9W, S.M. 4b. Location of Well (State Base Plane Coordinates): Surface:x- 348837 y- 2480039.8 Zone- 16. Deviated wells: Kickoff depth: Maximum Hole Angle: 4 150 feet 49 degrees 8. Land Use Permit: 13. Approximate Spud Date: NIA 5/28/2004 9. Acres in Property: 14. Distance to Nearest 2400 Property: 565 10. KB Elevation 15. Distance to Nearest Well (Height above GL): 340.5 feet Within Pool: 1200 17. Maximum Anticipated Pressures in psig (see 20 Me 25.035) Downhole: 1532 Surface: 1192 /" Setting Depth Quantity of Cement c.f. or sacks Top 18. Casing Program: Size Casing 16 9.625 7 Specifications 12.25 8.5 Weight Grade 106 K-55 40 L-80 26 L-80 Coupling Weld BTC BTC Length 40~80 1560 4182 MD TVD Bottom MD TVD (including stage data) o 40-80 40-80 NIA - Driven o 1560 1395 192 sx lead, 94 tail* o 4180 3539 230 sx lead, 112 tail* * Calc hole volume. Plan 50% & 30% excess for Surface & Production respectively / / Hole o o o 19. Total Depth MD (ft): PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Structural Conductor Surface Intermediate Production Liner Length Size Cement Volume MD rvD Perforation Depth MD (ft): 20. Attachments: Filing Fee L:J BOP Sketch l:0 Property Plat 0 Diverter Sketch 0 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Drilling Program ~ Seabed Report 0 Perforation Depth TVD (ft): Time v. Depth Plot L:J Shallow Hazard Analysis U Drilling Fluid Program 0 20 Me 25.050 requirements 0 Date Contact Printed Name sŒ71mb'4 _ , Title Advising Drilling Engineer Phone 907-263-7637 Date 27-May-04 Commission Use Only ,¡ Permit to Drill API Number: I Permit APproval¡;j.'1 /J.,/IIÍ ,/ / Is ee ~over..le....tter....f...O... r other Number: .2C5 Ÿ - () ~ f 50- /.33 _. 2. 0 .s- c¡ d Date: 'J {/?J fJ '1 reqUlrement~. Conditions of approval: Ct: \\1 \:: D Samples required Yes 0 No E Mud log required R E. '.Is- D . Ñ; ~ (). Hydrogen sulfide measures. Yes 0 N. 0 ~ Directional survey required I :'(y~m~ 0 Other:~r.~ UJ "t- ¡; Çf~~~,l,!'d W ~ do """,h... Ob......:·~~:-~:~ "'''''''''..' M~~~..... .,.r; h. ......"",\$':;\0\\ Appro, by. . .. THE COMMISSION I\.QIoII8 ()"\b"~ ~y Fo -40·~sed 12/2003 0 R \ G \ N A L Submit inDuplicate Signature e e WAIVER REQUEST Unocal respectfully requests waiver to; (1.) AOGCC regulations 20 AAC 25.035 (C) WAIVER #1 : Unocal request permission to drill the 12-1/4" surface hole to a depth of +/- 1395' TVD /1560' MD without a diverter. AOGCC regulation 20 AAC 25.035 / (h) (2) stipulates: (h) ilUpon request f the operator, the commission will, in its discretion, approve a variance ...... (2) from the diverter system requirements in (C) of this section if the variance provides at least equally effective means of diverting flow away from the drill rig or if drilling experience in the near vicinity indicates that a diverter system is not necessary. " Based on our experience drilling 12 %" surface holes in Swanson River Field, Tank Setting 2-15, it is conclusive that no shallow gas hazards exist beneath this pad to a depth of at least 1395' TVD BRT. The 12-1/4" surface hole for 231-16 will be drilled from the same pad as SRF 242-16 to a shallower depth. Shallow geology has been reviewed and the following summary of the lithologies to be encountered is provided: From surface to 1395' VD beneath the Tank Setting 2-15 surface pad, we anticipate the following lithologies: 0-375': interbedded med to coarse grained sand and coarse gravels 375'-680': interbedded -50%-50% black, carbonaceous shale, claystone, clayey siltstone and unconsolidated fine to medium grained sandstone. 680'-1395': interbedded black, carbonaceous shales, claystones, gray silty claystones, light gray, fine to medium grained sandstones, with a few thin brown, lignitic coals. Increase in claystone and shales toward base of interval. We do not anticipate any significant faulting, nor do we expect any oil or gas to be trapped, as no suitable seals exist within this shallow section. e e For the purpose of basic risk mitigation, Unocal will utilize a spud mud which is expected to weigh approximately 9.2 ppg when drilling at the planned suñace hole TO of 1560' MO 11395' TVO', to eliminate the risk of a shallow water flow. e e SRU 241-18 Bulle' Procedure Pre-Rig Activities Install cellar & Prepare pad & install liner, tankage & berms Turnkey MI & RU Drilling Rig Post Rig Activities Rig Acceptance. Hold pre-spud & HES meetings. Finish RU basic components & mix mud Drive 16" Surface Conductor RU Flow Nipple RU & function test TDS RU pipe handling equipment (tongs & hawkjaw) PU portion of spud BHA Clean-out conductor PU remainder of BHA & DP to drill to 4,200 / Drill 12 1/4" hole from: 0' to: 1560' MD 11395' TVD Circ clean & pump carbide indicator POH (pump out to BHA) LID 121/4" BHA // Clean rig floor & RU to run 9 518" csg Run 9 5/8" casing Land casing & M/U cement head Circulate, reciprocate & conduct safety meeting/ Pressure test lines & cement 9 5/8" casing / RD casing running equipment ND Flow Nipple & lines ND wellhead connection NU & test MBS wellhead NU BOPE & chokelkilllines & test 250 12500 / Pressure test 9 5/8" casing to 2,000 psi M/U 8 1/2" steerable BHA with Triple Combo LWD Drill out & perform LOT Drill 8 1/2" hole from: 1560' to: 4182' MD 13539' TVD Circulate clean (& pump nut plug sweep) POH wI 8 1/2" BHA POOH & LID BHA Clean stack, run test plug, change rams & test /" RU & run 7" casing . Land casing (includes washing down) & CirculatV Cement 7" casing RD cementers & casing running equipment Set pack-off & test MU 6-118" CIO Bit and Casing Scraper. RIH to PBTD @ 4900'. . Circulate Well Clean, Displace to Completion Brin~ Test 7" casing to 2,500 psi POOH & LD CIO BHA & DP . PU & RIH 2-718" Completion wI Hydo-Trip packer/ Set packer and Test TBG & Casing to 2,500 psi Set BPV ND BOPE, NU & test tree to 5,000 psi, Clean tanks, LID TDS & Hawkjaw Release Rig / UNOCAL8 e RKB to GL = 20.50' TD = 4,182' MD 13,539' TVD SRU 241-16 Proposed e Swanson River Field SRU 241-16 Proposed Completion J ewelrv Detail 1. 80'/-- " Drive Shoe 2. &60' -5/8" Surface Casing 3. , 82' 7" Production Casing 4. 2,500' Chemical Injection Mandrell 5. 3,400' 2-7/8" Tubing 6. 3,375' Retrievable Packer 7. 3,388' X Nipple 8. 3,400' WLEG Bit Sizes: 12-114", and 8-1/2" 9-5/8" Cemented to surface, 192 sx lead, 94 sx tail ,/ 7" Cemented to 1500',230 sx lead, 112 sx tail ~.. Note: Cement excludes excess. Plan 50% surf & 30% Prod. -"--,,,^,,~'~''"'" SIZE WT 16" 68 9-5/8" 40 7" 26 SIZE WT 2·7/8" 6.4 CASING DETAIL GRADE CONN TOP K·55 aTe 0' L-80 aTe O' L-80 aTe (KC) 0' TUBING DETAIL GRADE CONN TOP L-80 IBTC (AB Mod) 0' Perforations Date MD TBD - Pending OH Logs TVD REVISED: OS/27/04 DRAWN BY: SSL --. BOTTOM 80' 1,560' 4,182' BOTTOM 3,400' e Swanson River 241-16 9-5/8"" SHOE DESIGN SUMMARY & SKETCH 9-5/8" shoe 1,375 ft BML~ (1,395 ft rvD) \ I \ I \ I \ 8-1/2" Hole I \ / \ I \ / \ I \ I - mdb/01decOO / / METHOD 2: e 1 RT - MSL = 20.5 ft ! DESIGN DOWN: MW = 9.2 PPG Pform = 9.2 PPG EMW KT = 15 BBLS at 0 PPG FG = 0.7 PSI/FT Gas Gradient = 0.05 PSI/FT Drill Pipe = 4 INCH , '" The deepest 8-1/2 in hole that can be drilled = 5,064 ft BML or 5,084 ft TVD WD = 0 ft with 0.433 PSI/FT Gradient 9-5/8" shoe .... The shallowest 9-5/8"" shoe depth = 1,082 ft BML or 1,103 ft TVD ----- 8-1/2" Hole TD = 3,519 ft BML or 3,539 ft TVD METHOD 1: ~ \ I \ / \ I \ I \ I \ I \ I \ I \ I \ / . DESIGN UP: MW = 9.2 PPG Pform = 9.2 PPG EMW KT = 15 BBLS at 0 PPG FG = 0.7 PSI/FT Gas Gradient = 0.1 PSI/FT Drill Pipe = 4 INCH e e Maximum Anticipated Surface Pressure Calculation Swanson River Field 241-16 Kenai Peninsula, Alaska Assumptions: _/""_.., 1. Based on offset drilling & well test data, the pore pressure gradient is predicted to be a ~}P"~/ft gradient from surface to planned total depth at 3,539' VO BRT. . 2. The MAS.P. during drilling operations will be governed by the 9 5/8" shoe frac gradient, and is calculated based on a full column of gas between the 9 5/8" shoe and the surface. 3. The MAS.P. during production operations will be the estimated SIBHP minus the gas hydrostatic pressure between TD & the surface. M.A.S.P. During Production Phase: Max. pore pressure at T.D. = 3,539 ' VO x ~~/ = 1532 psi / 1532 psi - (0.096 psi/ft * 3,539 ft) = = 1192 psi MAS.P. (tbg leak at surface) = MAS.P. During Drilling Phase: Max. Est. Frac pressure at 7" shoe = 1395 ft. x 0.65 psi/ft* = = 907 psi MAS.P. during drilling = 907 psi - (.08 psilft x 1515 ft.) = = 795 psi * FIT test performed on SRF 242-16, 1989 WELL: SRU 241-16 Calculation & Casing Design Factors Swanson River Field 241-16 Kenai Peninsula, Alaska FIELD: Swanson River Sect. 1 121/4" hole MUD WT. Sect. 2 8-1/2" hole MUD WT. 9.1 PPG MASP= 795 psi" 9.1 PPG MASP= 1,192 psi SECTION CASING BOTTOM TOP LENGTH WT. 1 95/8" 1,560 0 1560 40 TVD 1,400 0 2 7" 4,182 0 4182 26 TVD 3,539 0 / DESCRIPTION GRADE THREAD L-80 BTC L-80 DATE: 27-May-04 ~WEIGHT W/OBF LBS 62,400 TENSION TOP OF SECTION LBS 62,400 BTC-mod 108,732 108,732 MINIMUM STRENGTH TENSION 1000 LBS 979 519 DESIGN BY: Steven Lambe ,/ SF TENSION 15.69 4.77 COLLAPSE COLLAPSE PRESS @ RESIST. /" BOTTOM wlo TENSION PSI' PSI SF COlL. 616 3090 5.02 1557 5410 3.47 " See attached sheet for calculation of MASP , Collapse pressure is calculated; Normal Pressure Fluid Gradient for external stress (.44 psilft) and the casing evacuated for the internal stress (0 psilft) Notes: 1. All wellhead components are rated to 5000 psi working pressure. MASP PSI" 921 MINIMUM YIELD PSI 5750 1237 ,.---/ SF BURST 6.24 7240 5.85 e e I Halliburton BAROID e UNOCAL -- Mud Program SRU 241-16 Introduction: The following mud program was prepared for a deviated well accessing the B gas sands in the Beluga formation at Swanson River on the Kenai Peninsula, Alaska. This well will be spudded with a 6% KCI drilling fluid and build to -510 by the 1,560' MD range. It will be drilled with a 12 'y,¡" hole size to 1 ,560' and 9 5/8" casing cemented at that depth. The surface casing will be drilled out with the existing mud system. The 8 W' interval will then be drilled holding 510 to -2,127'. The angle will then drop to vertical by TO at -4,181' MD. Seven inch casing will be run and cemented at this depth. Spud the well with a 9.0 ppg, 6% KCI/PHPA mud. The mud weight will then be held at 9.0 ppg to the surface hole TD unless hole conditions dictate otherwise. Our primary focus for surface hole drilling operations will be adequate mud weight for well control and sufficient mud viscosity for efficient hole cleaning. This spud mud is formulated with two mechanisms to provide waste minimization and effective wellbore stabilization, ionic inhibition (KCI) and polymer encapsulation (PHPA). This same 6% KCI/PHPA mud will be maintained through the intermediate interval. This mud offers good LCM responses if losses are encountered. Special emphasis should be placed on maintaining low ECD's and surge/swab pressures to minimize the potential for lost circulation. Primary Drillinq Objectives: · Zero fluid related HSE incidents · Achieve wellbore stability · Achieve good hole cleaning considering hole angle, geometry and anticipated ROP rates · Lost circulation mitigation/control · Achieve good Zonal Isolation as per plan · Achieve minimal formation damage in B sands · Minimize fluids related NPT · Minimize drilling wastes Critical Fluid Issues: · Maintaining a low ECD in the production zone to reduce risk of lost returns. · Maintaining a stable wellbore through any coal seams. · Reducing drilling wastes with the inhibited drilling fluid system. Well Specifics: Casing Program SRU 241-16 12 X" hole (9 5/8" casing) 8 %" hole ( 7 " casing) MD TVD Footage -1558' -1394' -1558' -4181' -3539' -2623' SRU 241-16 v1.1 2 OS/26//04 I Halliburton BAROID Surface Hole Recommendations Mud Type: 6%KCI, EZ Mud Properties: e e Mud Program UNOCAL Density Viscosity Plastic Viscosity Yield Point o - 1000' @ 60 - 85 7 - 16 30 - 40 1000-1558' . -9. 50-75 8-16 30-40 APIFL N/C <5 Q.t! 8.5-9.0 8.5-9.0 System Formulation: Product Water KCI KOH Barazan D EZ Mud DP Aldacide G Baroid Baracor 700 Barascav D 6%KCI, EZ Mud Concentration 0.905 bbl 20 ppb (30K chlorides) 0.2 ppb (9 pH) 1.25-1.5 ppb (as required 35 YP) 0.75 ppb 0.1 ppb to a 9.0 ppg 1 ppb 0.5 ppb (add as the well spuds) Special Mixing Instructions: . Mix in order as listed . Add polymers slowly to minimize fisheyes. Concerns and Continç¡encies Suñace Interval - ( 0 - 1,558' MD ) Mud Tvpe: 1. Mud weight: 2. Rheology: 3. Filtrate control: Operations Summary: 6 % KCI/PHPA Maintain a 9.0 ppg density or as directed. Maintain a YP between 30 - 40 or as needed to achieve adequate hole cleaning. No filtrate control is required prior to reaching 1000' MD. Additions of BDF-263 may be required to control screen blinding/bit balling. Seepage losses in this interval can be controlled with additions of 3-5 ppb BAROFIBRE or by dedicated LCM pills but are unlikely to occur. This section will drill a 12 X" hole. Build the 6% KCI fluid in the proper order of addition. If possible, shear the mud thru the hopper and gun lines prior to use to reduce shaker blinding from the EZ Mud. Always maintain a reduced pit volume during spud as losses are not expected in this section. Be prepared for sloughing gravels in the upper interval; increasing the system rheology with BARAZAN-D/N-Vis will assist in bringing this material out of the well, as will pumping dedicated high-viscosity sweeps. It is recommended that the pump rate be increased to the maximum practical rate while the hole is unloading gravel. Sweep Formulation: 30 barrels mud (500' annular coverage), add ca. 1.0 ppb BARAZAN D to achieve a tauO > 25. When penetrating high-clay content sections additions of BDF-263 ester are recommended to reduce the incidence of bit balling and shaker blinding. Be prepared to increase the YP if hole cleaning becomes an issue. Run DFG (Drilling Fluid Graphics) to confirm hole cleaning efficiency based on current rheology, flow rates and cuttings size. SRU 241-16 v1.1 3 OS/26//04 I Halliburton BARorD · UNOCAL ~Ud Program I At TD, a Wallnut (20 bbl pill with 15 ppb of Wallnut M) or carbide "flag" should be pumped to gauge hole washout and to calculate the required cement volume. The cement will then be pumped and drilling mud will be used to bump the plug. Pretreat this chase mud with 1 ppb Bicarb and 0.5 ppb citric acid. Hazards / Concerns - Surface Interval: · Preventing lost circulation through ECO management. · Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. · Maintain YP between 30 - 40 to optimize hole cleaning and to control ECO. · Pump high viscosity sweeps to enhance hole-cleaning efforts. Monitor sweep effectiveness. · Successfully cement casing. Maximum Acceptable ROP in fJh at Specified GPM and RPM GPM~ 550 600 650 80 rpm 131 146 158 100 rpm 141 167 178 Baroid's recommended flowrate for this interval is 650 gpm to maximize hole cleaning at high penetration rates. A minimum of 100 RPM's is recommended as the well builds angle to 51°. Production Hole Recommendations Mud Type: 6%KCI, EZ Mud Properties: 1558 - 4181' De[J Viscosity 9.0;,)r 40-50 Plastic Viscosity 6 - 15 Yield Point 18 - 25 APIFL <5 ID:! 8.5-9.0 System Formulation: Product Water KCI KOH Barazan D Dextrid EZ Mud DP Aldacide G Baracor 700 Barascav D 6%KCI, EZ Mud Concentration 0.905 bbl 19.8 ppb (30K chlorides) 0.2 ppb (9 pH) 1.25 ppb (as required 35 YP) 1-2 ppb 0.75 ppb 0.1 ppb 1 ppb 0.5 ppb (maintain per dilution rate) . Mix in order as listed . Add polymers slowly to minimize fisheyes. Concerns and ContinQencies Production Interval- ( 1558 - 4181' MD ) Mud Type: 6 % KCI/PHPA 1. Mud weight: 2. Rheology: 3. Filtrate control: Maintain the 9.0 - 9.2 ppg density or as directed. Maintain a YP between 18-25 (minimum TAU 0 of 5) Add Dextrid and/or Pac L to maintain the filtrate <5 cc/30 min. Additions of BDF- 263 may be required to control screen blinding/BHA balling. String in 10-12 sx an hour of Baracarb 25 while drilling the B sands (refer to DD for this exact depth). SRU241-16 v1.1 4 OS/26//04 I Halliburton BAROID Operations Summary: Drill out the cement/casing with the existing mud system. Bicarb or soda ash and citric acid should be used to pretreat for any negative effects of the cement. BARAZAN-D/N-Vis should be used to maintain rheological parameters. Maintain the mud as clean as possible while drilling. Should sweeps be required a BAROLlFT sweep is recommended. This sweep will help clean the hole with no neqative impacts on system mud weight or rheoloqy. Daily additions of X-Cide 207/Aldacide G should be made to control bacterial action. e UNOCAL . Mud Program Sweep Formulation: 25 bbl of mud with .25 ppb of Barolift added. Shear thouroughly prior to pumping. Dextrid and/or PAC L should be used for filtrate control. While drilling, monitor the torque and drag to determine if liquid lubricant is required. If required, additions of Torq Trim II or EZ Glide should be made in ~% increments. Do not overtreat with these expensive lubricants. Should metal to metal torque be suspected, light additions of EP Mudlube should be made, not to exceed 0.5%. When penetrating high- clay content sections additions of BDF-263 ester are recommended to reduce the incidence of bit balling and shaker blinding. Maintain the pH in the 8.5 - 9.0 range with caustic soda. System rheology may be relaxed as hole conditions allow. However, be prepared to increase the YP if hole cleaning becomes an issue. Run DFG (Drilling Fluid Graphics) to confirm hole cleaning efficiency based on current rheology, flow rates, angle and cuttings size. Running a reduced viscosity will lower the ECD and reduce stress on the wellbore. If the losses occur and remain high (above 30 bbl/hr static) after attempting LCM pills, STOP running the fluid as a KCI/EZ Mud system. All additions of these products should be halted and allow the system to slowly break back to an LSND system. Run the fluid loss and rheology as with the inhibited system. When running the LSND, stop addtions of Baracor and Barascav D when the chlorides drop below 6,000 ppm's. Maximum Acceptable ROP in fph at Specified GPM and RPM GPM- 450 500 550 80 rpm 58 63 74 100 rpm 68 93 105 Baroid recommends a flowrate in the 550 gpm range to maximize hole cleaning efficiencies at these penetration rates. Maximum rotation is key on this well. There is a large drop in efficiency if the rpm drops from 100 to 80. However if losses occur, the flow rate can be reduced in conjunction with a slower penetration rate which would reduce the ECD/losses. Reduce system YP with Therma Thin as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 20 ( check with the cementers to see what yp value they have targeted). Consider spotting a Steelseal LCM pill prior to running the 7" casing if losses have been seen in this interval. The plug will again be bumped with mud on the well. Hazards / Concerns -Intermediate Interval: · Optimize solids control equipment to maintain density and sand content. · Maintain YP between 18-25 to optimize hole cleaning and to control ECD. · Pump weighted high viscosity or Barolift sweeps to enhance hole-cleaning efforts. Monitor sweep effectiveness. · Successfully land and cement casing. SRU 241-16 v1.1 5 OS/26//04 20'6" or 246" Ground Level ../ e e SRU 241-16 BOP Stack Diagram Underside of Rotary Table Planned Test Pressure 2500 psi / / / .. .. .. .. ._----------------.----------------- ---------~-------------------------- ... ------------------------------------ .. ._---------._-----.--------------. ... ::;,:.~BS < j"I'" ~ I 9 5/8" Hanger ~ I Starter Head ~ _________~~~~~~_o_~__~ ~ 13-3/8" 68# K-55 _ Conductor (driven) - - _1_ I ~ .. ----------------------------1:---- -------_.------------------------ t Well Cellar 17' or 204" (Mat.." ... 8' or 96" .. . e e 2" 3H To Shaker 3" Panic To C?asbuster U .~ 1/8" ¡--[ r-I _ 0 I ... . r I '\ -_ /-¡-." /--', --- \ -T- ~,-+- ) ! + ) __m_ 2 1/16" .'¡::( \._~ \---;:-/ 2 1/16" rmLL /-- [n_LLL___ ,~-¡-" ,JL ¡ }__m_.mn..mn·'\.:l) r::::::::J¡ ¡'-----\J) L___________~ ] J[ 2 1'/~16" '¡:,Ltf, 2 1~/16" '~~~ (.+) ~~. \.nn) (+) Z Jf'" ~. ~-_.. \.... / """ c..o ~ ..... -j¡ ') :~ {O" n n /" ~ '- ,," Ll v ~ l (J L.I Ll ...,. "r-"--, ."~ ".<::, /"", N cr:> , + ) ~ ..¡.._; ( + ) , ~/Ji") ~0::\ c--?( f-- (~¡"') -f:l', ~n l._m.__.-\nt-_.. C___"\ [j ----- ,___J '.,::,.1 L----\lj ------ ."".. ¡-- ..n___,.n. " I ! ..", / L ..... ¡ t ¡ 2 1/;6" (~ 2 1/16" IVIanua! Choke 4 ,-~, Automatic Choke I 2 1/16" Inlet Pressure Sensor 3" 3" 5,000 PSI Choke IVBnifold , Kuukpik Drilling Rig 5 / RED =3 ¡t¡S" 5,000 PSI V/\LVES AND liNES BL.UE =: 2 '1/16" 5,000 PSI VALVES ../ SRU 241-16 PLAN DAYS VERSUS DEPTH UNOCAL 500 1,000 e 1,500 Z' 2,000 ~ ~ -- -= 2,500 c.. ~ Q 3,000 3,500 e 4,000 4,500 0 5,000 ... \ 5 10 15 20 Time (Days) ~. ,~_ ,. ._... _ _ -SRU 241-16 AFE DAYS -SRU 242-16 I - .__ ................_,..._ _..............._, II .__.....__ -- /-- u UNOCAL INTEQ Location: Kenai Peninsula, Alaska(lmported) Field: Swanson River Unit Installation: 2-15 Tank Setting Slot: SRU241-16 Well: SRU241-16 Wellbore: SRU241-16 Vers6 ¢:: Î 0 -200 0 .... II I 5 0 0> -.J (ij C) en 200 400 600 800 1000 1200 - - Q) Q) ~ 1400 :6 Co Q) 1600 C ëã to) 1800 ~ ~ ~ 2000 Q) :;, ~ .... 2200 I V 2400 2600 2800 ~ 3000 3200 3400 3600 3800 Scale 1 em = 100 ft East (feet) .> -1800 -1600 -1400 -1200 -1000 -800 -400 -200 -600 o _I C,~~q;..ø, .<.:~ &<::$ ~ 'Ii' ~ <Q~p ,,~ ~. ~ .~~ /~ ~ ~ <~ ~ ~ 13.00 "\' .~ DLS: 4.00 deg/100ft ~'''~';i<QØ<::$ .~~" 21 00 ~ . ~ ~OO ~ ~ ~ ~W ~' 37.00 00 ~, ~ 41.00 ~ *-0 45.00 ~49.00 '$-/ ~ EOC 9 5/8" Casing pt. ~ ~ 51.36 ~ '" Begin Drop ~ 48.86 ~ DLS: 2.50 deg/100ft " 43.86 "- 41.36 ~ 38.86 \6~33~86 31.36 28.86 26.36 23.86 21.36 18.86 KOP 2.00 4.00 Build 4/100 9.00 200 1200 1000 800 ^ I 600 Z 0 ;:¡. ::T 400 - c;' () - - 200 (J) " '" 0 CD " 3 II t -200 0 0 ;:! WELL PROFILE DATA ~ ' I 'I - Point MO Inc Az TVO North) laid ditgI100ft V. s.cC 0.00 0.00 0.00 KO" 150.00 0.00 302.96 150.00 0.00 400.00 5.00 302.96 399.68 5.93 Target 0.00 0.00 -9.15 2.00 10.90 End of Hold 2121.1351.36302.96 1748.44 295,64 -455.92 (~543.38 537.10 _828.271 0.00 987.17 1005.381,1550.42 2.50 1847.86 Created by: Planner Date plotted: 26-May-2004 Plot reference is SRU241-16 Vers6. Ref wellpath is SRU241-16 Ver 6. Coordinates are in feet reference SRU241-16. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 338.50 ft. Plot North is aligned t<>.TRUE North. End of BLlild 1558.95 51.36 302.96 1393.63 T.D.&TargølTDTgtRv 4181.45 0.00 302.96 3538.50 BO Target 8.86 6.36 3.86 1.36 13.86 B3 Target T' Casing PUTD I I -,--¡ -200 -0 200 Scale 1 cm = 100 ft Azimuth 400 600 800 1000 1200 1400 1600 1800 Vertical Section (feet) .> 302.96 with reference 0.00 N, 0.00 E from SRU241-16 2000 -------..-J -- B.. UNOCAL UNOCAL ... Location: Kenai Peninsula, Alaska(lmported) Slot: SRU241·16 Field: Swanson River Unit Well: SRU241·16 INTEQ Installation: 2·15 Tank Setting Wellbore: SRU241·16 Vers6 I Seale 1 em = 50 ft East geet) -> -1800 -1700 -1600 -1500 -1400 -1300 -1200 -1100 -1000 -900 -800 - 00 -600 -500 -400 -300 -200 -100 0 100 200 300 400 1300 ~ ,- -" - r 1300 1200 1200 1100 1100 .¡¥* ~r¡;,,->,,<§># 100_ 1000 ',¡' ,.* ,-- , ,¡' 900 .f' 900 ,* , ,# 800 if' 800 ,* , ,of' ^ 700 700 ^ . ,'# . :¡:;- z () 600 ,of' 600 0 .! ~ - ,,* ::r = - ~ 500 500 ø' 0 ,of CÞ - Z - 400 ,of 400 300 # 300e ,* 200 200 ,,* , ,of' 100 ,# 100 ¢: U> 0 . o;¡, '<¡, .... 0 10 "", Q) 'f;¡, <~o <'", '<¡, .s: ðò. "'00 v è'õ II 0 <>", <'", ~"......~6'00 ~o ~ -0 ~ <"" <<¡, <." "'", "'0 '~ '~ '-q, '~ '~ '"" ';:-" ",'I> E ,:;.l;¡; 0 () 3 () J II -¡¡¡ -100 -100 0"1 () 0 en ~ I ~ I I -r-T -1800 -1700 -1600 -1500 -1400 -1300 -1200 -1100 -1000 -900 -800 -700 -600 -500 -400 -300 -200 -100 0 100 200 300 400 Scale 1 em = 50 ft East (feet) -> e URaU". UNOCAL ,SRU241-16 2-15 Tank Setting, Swanson River Unit, Kenai Peninsula, Alaska(lmported) e PROPOSAL LISTING Page 1 Wellbore: SRU241-16 Vers6 Wellpath: SRU241-16 Ver 6 Date Printed: 26-May-2004 INTEQ L L All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 338.5ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 302.96 degrees Bottom hole distance is 1847.86 Feet on azimuth 302.96 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated e 1.1....,. UNOCAL ,SRU241-16 2-15 Tank Setting, Swanson River Unit,Kenai Peninsula, Alaska(lmported) e PROPOSAL LISTING Page 2 Wellbore: SRU241-16 Vers6 Well path: SRU241-16 Ver 6 Date Printed: 26-May-2004 INTEQ 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 348837.22 2480039.80 100.00 0.00 0.00 100.00 O.OON O.OOE 0.00 0.00 348837.22 2480039.80 150.00 0.00 302.96 150.00 O,OON O.OOE 0.00 0.00 348837.22 2480039.80 250.00 2.00 302.96 249.98 0.95N 1.46W 2.00 1.75 348835.77 2480040.77 350.00 4.00 302.96 349.84 3.80N 5.86W 2.00 6.98 348831.41 2480043.67 400.00 5.00 302.96 399.68 5.93N 9.15W 2.00 10.90 348828.15 2480045.85 500.00 9.00 302.96 498.92 12.56N 19.37W 4.00 23.09 348818.02 2480052.61 600.00 13.00 302.96 597.06 22.94N 35.38W 4.00 42.16 348802.15 2480063.19 700.00 17.00 302.96 693.63 37.02N 57.09W 4.00 68.04 348780.62 2480077 .55 800.00 21.00 302.96 788.17 54.73N 84.40W 4.00 100.59 348753.54 2480095.61 900.00 25.00 302.96 880.20 75.98N 117.18W 4.00 139.65 348721.04 2480117.28 1000.00 29.00 302.96 969.28 100.68N 155.26W 4.00 185.04 348683.28 2480142.46 1100.00 33.00 302.96 1054.98 128.69N 198.46W 4.00 236.54 348640.45 2480171.03 1200.00 37.00 302.96 1136.88 159.90N 246.58W 4.00 293.88 348592.74 2480202.85 1300.00 41.00 302.96 1214.58 194.13N 299.37W 4.00 356.80 348540.40 2480237.76 1400.00 45.00 302.96 1287.70 231.23N 356.58W 4.00 424.99 348483.68 2480275.59 1500.00 49.00 302.96 1355.88 271.01 N 417.93W 4.00 498.11 348422.85 2480316.15 1558.95 51.36 302.96 1393.63 295.64N 455.92W 4.00 543.38 348385.18 2480341.27 1600.00 51.36 302.96 1419.27 313.09N 482.82W 0.00 575.45 348358.51 2480359.06 1700.00 51.36 302.96 1481.71 355.58N 548.35W 0.00 653.55 348293.54 2480402.39 1800.00 51.36 302.96 1544.16 398.08N 613.89W 0.00 731.66 348228.56 2480445.73 1900.00 51.36 302.96 1606.60 440.57N 679.42W 0.00 809.76 348163.58 2480489.06 2000.00 51.36 302.96 1669.05 483.07N 744.95W 0.00 887.87 348098.61 2480532.39 2100.00 51.36 302.96 1731.49 525.57N 810.49W 0.00 965.98 348033.63 2480575.73 2127.13 51.36 302.96 1748.43 537.10N 828.27W 0.00 987.17 348016.00 2480587.49 2227.13 48.86 302.96 1812.56 578.84N 892.64W 2.50 1063.89 347952.18 2480630.05 2327.13 46.36 302.96 1879.98 619.02N 954.60W 2.50 1137.74 347890.75 2480671.02 2427.13 43.86 302.96 1950.55 657.56N 1014.04W 2.50 1208.58 347831.82 2480710.32 2527.13 41.36 302.96 2024.15 694.39N 1070.83W 2.50 1276.27 347775.50 2480747.88 2627.13 38.86 302.96 2100.62 729.44N 1124.88W 2.50 1340.69 347721.91 2480783.62 2727.13 36.36 302.96 2179.84 762.64N 1176.08W 2.50 1401.71 347671.15 2480817.47 2827.13 33.86 302.96 2261.64 793.93N 1224.33W 2.50 1459.22 347623.31 2480849.38 2927.13 31.36 302.96 2345.87 823.25N 1269.54W 2.50 1513.10 347578.49 2480879.27 3027.13 28.86 302.96 2432.37 850.54N 1311.63W 2.50 1563.26 347536.76 2480907.10 3127.13 26.36 302.96 2520.98 875.75N 1350.51W 2.50 1609.60 347498.21 2480932.81 3227.13 23.86 302.96 2611.52 898.83N 1386.11W 2.50 1652.03 347462.91 2480956.35 3327.13 21.36 302.96 2703.83 919.75N 1418.36W 2.50 1690.47 347430.94 2480977.68 3427.13 18.86 302.96 2797.72 938.45N 1447.20W 2.50 1724.84 347402.34 2480996.75 3527.13 16.36 302.96 2893.03 954.91 N 1472.58W 2.50 1755.09 347377.18 2481013.53 3627.13 13.86 302.96 2989.57 969.09N 1494.45W 2.50 1781.15 347355.50 2481027.99 3727.13 11.36 302.96 3087.15 980.96N 1512.76W 2.50 1802.98 347337.34 2481040.10 3827.13 8.86 302.96 3185.59 990.51 N 1527.49W 2.50 1820.53 347322.74 2481049.83 3927.13 6.36 302.96 3284.70 997.71N 1538.59W 2.50 1833.77 347311.73 2481057.18 4027.13 3.86 302.96 3384.30 1002.56N 1546.06W 2.50 1842.67 347304.32 2481062.12 4127.13 1.36 302.96 3484.18 1005.03N 1549.88W 2.50 1847.22 347300.54 2481064.64 4181.45 0.00 302.96 3538.50 1005.38N 1550.42W 2.50 1847.86 347300.00 2481065.00 All data is in Feet unless othelWise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 338.5ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 302.96 degrees Bottom hole distance is 1847.86 Feet on azimuth 302.96 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated e U..UI. UNOCAL ,SRU241-16 2-15 Tank Setting, Swanson River Unit, Kenai Peninsula, Alaska(lmported) e PROPOSAL LISTING Page 3 Wellbore: SRU241-16 Vers6 Well path: SRU241-16 Ver 6 Date Printed: 26-May-2004 INTEQ 150.0 400.0 1558.9 1561.1~ 2127.12 3475. 3~-------.-.2843.5C 3680.47 3041.5C 4181.4 3538.5C TD Tgt Rvsd 5/26/04 BO Tgt Rvsd N60 4717.9 W150 347300.0 2481065.0 15-Apr-2004 5/26/04 B3 Tgt Rvsd N60 47 17.9 W150 5116.50 347300.0 2481065.0 15-Apr-2004 5/26/04 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 338.511 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 302.96 degrees Bottom hole distance is 1847.86 Feet on azimuth 302.96 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated e e UHOUL. UNOCAL SRU241-16 Ver 6, SRU241-16 Vers6 SRU241-16, 2-15 Tank Setting CLEARANCE LISTING Page 1 Date Printed: 26-May-2004 Swanson River Unit, Kenai Peninsula, Alaska{lmported) INTEQ Ellipse separations are reported ONLY if BOTH wells have uncertainty data Only Depth and MaQnetic Reference Field error terms are correlated across tie points Cutoff is calculated on CENTRE to CENTRE distance Summary data uses Closest Approach clearance calculation for all minima Hole size/CasinQs are NOT included Hole size/CasinQs ARE subtracted from Centre-Centre distance Ellipses scaled to 2.85standard deviations. ClosinQ Factor Confidence limit of 99.80% Errors on Ref start at Slot Permanent Datum (0.00) Report uses Revised: (D-C)/E Factor Calculation 28.841 442.911 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Ri9 ( Datum #1 338.5ft above mean sea level) Reference MD's are from Ri9, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.56 (10) Prepared by Baker Hughes Incorporated e d....e. UNOCAL SRU241-16 Ver 6, SRU241-16 Vers6 SRU241-16, 2-15 Tank Setting 700.00 693.63 4 698.78 - 721.78 714.42' 738.19 730.00 800.00 788.17 - I I 1600.0~ 1700.0C 1419.27 1900.0 0.1 0.2 12.25 0.3 12.25 0.4 12.25 0.6 0.71 0.9 1.2 1.6 1.7 712.08 12.25 1.7 12.25 728.37 1.8 12.2' 12.25 1.8 1.9 2.1 2.5 3.0 3.5 4.2 4.9' 5.4 5.7 1566.2.< 8.50 6.6 I 8.50 1662.4~ 7.6 1766.2< 8.50 8.9 1882.6l 8.50 e CLEARANCE LISTING Page 2 Date Printed: 26-May-2004 Swanson River Unit, Kenai Peninsula, Alaska(lmported) 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 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 9.631 9.63 9.63 9.63 9.63 9.63 9.63 9.63 9.63 9.63 9.63 9.63 9.63 9.63 9.63 9.63 9.63 9.63 -161.1 9.63 -158.1 9.63 9.63 -154.4 7.001 7.00 7.00 7.001 -10.4 60.14 -10.21 -10.1 60.71 60.04 59.941 58.64 60.49 58.99 48.5 52.6 55.52 55.41 INTEQ 1.01 60.42 1.16 1.281 1.47 52.72 47.60 40.41 1.71 32.84 67.5 46.9 22.40 56.0 53.18 47.25 86.8 37.91 38.7 118.5 31.80 33.23 120.4 31.79 33.25 126.6 33.64 32.08' 132.4 34.411 40.66 38.96 32.79 152.1 173.3 58.36 60.19 .175l -169.2 -164.7 88.23 86.07' 121.10 118.44 158.36 155.06 -154.1 -153.01 -151.6 438.81 -149.8 482.11 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 338.5ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.56 (1 D) Prepared by Baker Hughes Incorporated 29.34 2.64 15.03 3.27 10.44 3.31 10.33 3.40 10.15 3.47 10.18 3.55 11.72 3.68 16.60 4.01 22.23 4.51 27.03 5.17 30.83 5.98 33.60 6.92 35.6 7.99 37.0 8.63 8.81 39.5 39.71 11.61 38.74 13.51 36.62 e Ulla.Rt. UNOCAL SRU241-16 Ver 6, SRU241-16 Vers6 SRU241-16, 2-15 Tank Setting e CLEARANCE LISTING Page 3 Date Printed: 26-May-2004 Swanson River Unit, Kenai Peninsula, Alaska(lmported) INTEQ 2000.0C 1669.05 10.1 8.50 SRU242-16 1989.5~ 0.0 7.00 -147.7 535.34 521.67 15.11 35.48 (AWS) 2100.0C 1731.4£ 11.3 8.50 SRU242-16 2090.7e 0.0 7.00 -145.5 574.50 559.11 16.83 34.16 (AWS) 2127.13 1748.4~ 11.6 8.50 SRU242-16 2116.5E 0.0 7.00 -144.9 584.98 569.14 17.30 33.85 (AWS) 2227.1 ~ 1812.5E 12.7 8.50 SRU242-16 2206.98 0.0 7.00 -143.7 622.37 604.85 18.98 32.82 (AWS) 2327.13 1879.98 14.0 8.50 SRU242-16 2301.58 0.0 7.00 -142.4 656.85 637.54 20.80 31.61 (AWS) 2427.13 1950.55 15.3 8.50 SRU242-16 2392.62 0.0 7.00 -141.1 688.56 667.47 22.60 30.50 (AWS) 2527.1 ~ 2024.1 e 16.6 8.50 SRU242-16 2485.6~ 0.0 7.00 -139.8 717.85 694.89 24.49 29.34 (AWS) 2627.1 ~ 2100.62 17.9 8.50 SRU242-16 2578.02 0.0 7.00 -138.3 744.69 719.81 26.42 28.21 (AWS) 2727.13 2179.8~ 19.4 8.50 SRU242-16 2676.6£ 0.0 7.00 -136.7 769.03 742.10 28.49 27.01 (AWS) 2827.1 ~ 2261.6~ 20.8 8.50 SRU242-16 2778.5C 0.0 7.00 -134.9 790.31 761.26 30.64 25.81 (AWS) 2927.13 2345.87 22.3 8.50 SRU242-16 2873.68 0.0 7.00 -133.2 808.98 777.90 32.69 24.77 (AWS) 3027.1~ 2432.37 23.6 8.50 SRU242-16 2965.9L 0.0 7.00 -131.4 825.90 792.83 34.69 23.83 (AWS) 3127.1~ 2520.98 25.0 8.50 SRU242-16 3058.47 0.0 7.00 -129.5 841.35 806.31 36.68 22.95 (AWS) 3227.13 2611.52 26.5 8.50 SRU242-16 3158.0~ 0.0 7.00 -127.3 855.36 818.23 38.79 22.07 (AWS) 3327.13 2703.8~ 27.9 8.50 SRU242-16 3251.5L 0.0 7.00 -125.1 867.65 828.58 40.76 21.30 (AWS) 3427.1 ~ 2797.72 29.2 8.50 SRU242-16 3341.42 0.0 7.00 -122.8 879.25 838.35 42.61 20.65 (AWS) 3527.1 ~ 2893.03 30.4 8.50 SRU242-16 3432.5C 0.0 7.00 -120.4 890.57 847.90 44.39 20.08 (AWS) 3627.1 ~ 2989.57 31.6 8.50 SRU242-16 3527.8C 0.0 7.00 -117.8 901.38 856.99 46.13 19.56 (AWS) 3727.1~ 3087.1 e 32.6 8.50 SRU242-16 3616.5£ 0.0 7.00 -115.2 912.45 866.58 47.62 19.17 (AWS) 3827.1 ~ 3185.59 33.6 8.50 SRU242-16 3709.4e 0.0 7.00 -112.4 923.95 876.70 49.01 18.86 (AWS) 3927.1 ~ 3284.7C 34.3 8.50 SRU242-16 3792.6~ 0.0 7.00 -109.9 936.44 888.17 50.05 18.72 (AWS) 4027.1 ~ 3384.3C 35.0 8.50 SRU242-16 3881.8E 0.0 7.00 -107.0 950.38 901.20 50.97 18.66 (AWS) 4127.1~ 3484.18 35.4 8.50 SRU242-16 3964.58 0.0 7.00 -104.4 966.09 916.35 51.54 18.76 (AWS) 4181.4e 3538.5C 35.5 8.50 SRU242-16 4009.9E 0.0 7.00 -160.0 975.66 925.71 51.74 18.87 (AWS) All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 338.5ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.56 (1 D) Prepared by Saker Hughes Incorporated e a....... UNOCAL SRU241-16 Ver 6, SRU241-16 Vers6 SRU241-16, 2-15 Tank Setting e CLEARANCE LISTING Page 4 Date Printed: 26-May-2004 Swanson River Unit, Kenai Peninsula, Alaska(lmported) All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 338.5ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.56 (10) Prepared by Baker Hughes Incorporated INTEQ e Ulldu.... UNOCAL SRU241-16 Ver 6, SRU241-16 Vers6 SRU241-16, 2-15 Tank Setting e CLEARANCE LISTING Page 5 Date Printed: 26-May-2004 Swanson River Unit, Kenai Peninsula, Alaska(lmported) INTEQ 0.00 0.00 0.0 12.25 SRU32A-15 7.50 0.0 9.63 80.5 46.42 47.33 (AWS) 16.40 16.40 0.1 12.25 SRU32A-15 23.90 0.0 9.63 80.5 46.42 47.24 1.01 46.84 (AWS) 100.00 100.00 0.2 12.25 SRU32A-15 107.50 0.0 9.63 80.5 46.42 47.09 1.16 40.94 (AWS) 150.00 150.00 0.3 12.25 SRU32A-15 157.50 0.0 9.63 80.5 46.42 46.97 1.28 37.02 (AWS) 164.04 164.04 0.3 12.25 SRU32A-15 171.54 0.0 9.63 137.6 46.45 46.96 1.31 36.09 (AWS) 250.00 249.98 0.4 12.25 SRU32A-15 257.48 0.0 9.63 138.9 47.72 48.08 1.48 32.91 (AWS) 350.00 349.84 0.6 12.25 SRU32A-15 357.34 0.0 9.63 142.6 51.78 51.87 1.75 30.15 (AWS) 400.00 399.68 0.7 12.25 SRU32A-15 407.18 0.0 9.63 145.0 54.95 54.88 1.90 29.36 -- (AWS) 442.91 442.37 0.8 12.25 SRU32A-15 449.87 0.0 9.63 147.3 58.60 58.37 2.06 28.84 (AWS) 500.00 498.92 0.9 12.25 SRU32A-15 506.42 0.0 9.63 150.9 65.32 64.90 2.25 29.43 (AWS) 557.74 555.75 1.1 12.25 SRU32A-15 563.25 0.0 9.63 154.5 74.39 73.75 2.48 30.35 (AWS) 600.00 597.06 1.2 12.25 SRU32A-15 604.56 0.0 9.63 157.0 82.54 81.75 2.63 31.79 (AWS) 700.00 693.63 1.5 12.25' SRU32A-15 701.13 0.0 9.63 162.0 106.90 105.74 3.00 35.95 (AWS) 800.00 788.17 1.7 12.25 SRU32A-15 795.67 0.0 9.63 165.8 138.32 136.81 3.36 41.44 (AWS) 900.00 880.20 1.9 12.25 SRU32A-15 887.70 0.0 9.63 168.6 176.57 174.71 3.71 47.85 ---1AWS) 1000.0C 969.28 2.2 12.25 SRU32A-15 976.78 0.0 9.63 170.6 221.37 219.17 4.05 54.92 (AWS) 1100.0C 1054.9E 2.4 12.25 SRU32A-15 1062.4E 0.0 9.63 172.0 272.43 269.91 4.38 62.45 (AWS) 1200.0C 1136.8E 2.6 12.25 SRU32A-15 1144.3E 0.0 9.63 173.1 329.45 326.61 4.70 70.31 (AWS) 1300.0C 1214.5E 2.9 12.25 SRU32A-15 1222.0E 0.0 9.63 173.8 392.12 388.97 5.01 78.39 (AWS) 1400.0C 1287.7C 3.1 12.25 SRU32A-15 1295.2C 0.0 9.63 174.4 460.11 456.66 5.32 86.64 (AWS) 1500.0C 1355.8E 3.3 12.25 SRU32A-15 1363.3E 0.0 9.63 174.8 533.08 529.33 5.62 95.00 (AWS) 1558.95 1393.63 3.4 12.25 SRU32A-15 1401.13 0.0 9.63 174.9 578.28 574.36 5.79 99.95 (AWS) 1600.0C 1419.27 3.5 8.50 SRU32A-15 1426.77 0.0 7.00 175.2 610.56 606.25 5.65 108.18 (AWS) 1700.0C 1481.71 3.7 8.50 SRU32A-15 1489.21 0.0 7.00 175.8 688.57 683.97 5.94 115.94 (AWS) 1800.0C 1544.16 3.9 8.50 SRU32A-15 1551.66 0.0 7.00 176.2 766.61 761.71 6.24 122.94 (AWS) 1900.0C 1606.6C 4.1 8.50 SRU32A-15 1614.1C 0.0 7.00 176.5 844.65 839.46 6.54 129.2' (AWS) All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 338.5ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.56 (1 D) Prepared by Saker Hughes Incorporated e a.dCAI. UNOCAL SRU241-16 Ver 6, SRU241-16 Vers6 SRU241-16, 2-15 Tank Setting e CLEARANCE LISTING Page 6 Date Printed: 26-May-2004 Swanson River Unit, Kenai Peninsula, Alaska(lmported) INTEQ 2000.0C 1669.05 4.2 8.50 SRU32A-15 1676.55 0.0 7.00 176.8 922.71 917.42 6.63 139.22 (AWB) 2100.0C 1731.4S 4.2 8.50 SRU32A-15 1738.9S 0.0 7.00 177.1 1000.77 995.38 6.74 148.53 (AWB) 2127.13 17 48.4~ 4.3 8.50 SRU32A-15 1755.93 0.0 7.00 177.1 1021.95 1016.53 6.77 150.95 (AWB) 2227.1 ~ 1812.56 4.3 8.50 SRU32A-15 1820.06 0.0 7.00 177.5 1 098.6~ 1093.09 6.90 159.29 (AWB) 2327.13 1879.9E 4.4 8.50 SRU32A-15 1887.4E 0.0 7.00 177.7 1172.46 1166.77 7.04 166.66 (AWB) 2427.13 1950.55 4.5 8.50 SRU32A-15 1958.05 0.0 7.00 178.0 1243.27 1237.4~ 7.19 173.09 (AWB) 2527.13 2024.15 4.7 8.50 SRU32A-15 2031.65 0.0 7.00 178.1 1310.9~ 1304.95 7.34 178.58 (AWB) 2627.13 2100.62 4.8 8.50 SRU32A-15 2108.12 0.0 7.00 178.3 1375.3~ 1369.19 7.51 183.19 (AWB) 2727.13 2179.8~ 4.9 8.50 SRU32A-15 2187.3~ 0.0 7.00 178.4 1436.35 1430.02 7.69 186.94 (AWB) 2827.13 2261.6~ 5.0 8.50 SRU32A-15 2269.1L 0.0 7.00 178.5 1493.8~ 1487.33 7.87 189.89 (AWB) 2927.13 2345.87 5.2 8.50 SRU32A-15 2353.37 0.0 7.00 178.6 1547.71 1541.01 8.06 192.07 (AWB) 3027.13 2432.37 5.3 8.50 SRU32A-15 2439.87 0.0 7.00 178.7 1597.86 1590.97 8.26 193.54 (AWB) 3127.13 2520.9E 5.4 8.50 SRU32A-15 2528.4E 0.0 7.00 178.8 1644.19 1637.0S 8.46 194.34 (AWB) 3227.13 2611.52 5.6 8.50 SRU32A-15 2619.02 0.0 7.00 178.8 1686.61 1679.31 8.67 194.52 (AWB) 3327.13 2703.83 5.7 8.50 SRU32A-15 2711.33 0.0 7.00 178.9 1725.0~ 1717.53 8.89 194.12 (AWB) 3427.13 2797.73 5.9 8.50 SRU32A-15 2805.22 0.0 7.00 178.9 1759.41 1751.6E 9.11 193.20 (AWB) 3527.13 2893.03 6.0 8.50 SRU32A-15 2900.53 0.0 7.00 178.9 1789.66 1781.7C 9.34 191.78 (AWB) 3627.13 2989.57 6.2 8.50 SRU32A-15 2993.3E 0.0 7.00 179.0 1815.77 1807.5E 9.57 189.85 (AWB) 3727.13 3087.15 6.4 8.50 SRU32A-15 3093.9L 0.0 7.00 179.0 1837.67 1829.25 9.80 187.59 (AWB) 3827.13 3185.5S 6.5 8.50 SRU32A-15 3189.0C 0.0 7.00 178.9 1855.32 1846.66 10.04 184.85 (AWB) 3927.13 3284.7C 6.7 8.50 SRU32A-15 3288.17 0.0 7.00 178.9 1868.8~ 1859.93 10.28 181.83 (AWB) 4027.13 3384.30 6.9 8.50 SRU32A-15 3390.95 0.0 7.00 178.9 1877.8E 1868.75 10.52 178.55 (AWB) 4127.13 3484.1 E 7.0 8.50 SRU32A-15 3491.7C 0.0 7.00 178.9 1882.45 1873.0E 10.76 174.98 (AWB) 4181.45 3538.5C 7.1 8.50 SRU32A-15 3544.82 0.0 7.00 121.9 1883.11 1873.6E 10.82 174.16 I (AWB) All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 338.5ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.56 (1 D) Prepared by Baker Hughes Incorporated e e Surface Use Program for SRU 241-16 43 CFR Part 3162.3 - 1 1) Existing Roads See Map. The existing road system will be utilized for the Drilling and support operations of SRU 241-16. No road upgrades or road civil work will be required other than routine grading of the existing roads. 2) Access Roads to be Constructed and Reconstructed Roads and Pad are already in place. Reference 2-15 Tank Setting. Routine road grading may be required as noted above to maintain a safe driving surface. No new roads or upgrades will be required for drilling SRU 241-16. 3) Location of Existing Wells See attached maps. SRU 241-16 will be the fourth well drilled on the 2-15 Tank Setting. SRU 241-16 surface location is South of the existing SRU 32a-15. 4) Location of Existing and/or Proposed Facilities Existing facilities will be utilized for Sterling gas production. New flow lines to the well will be required and contained on the existing pad. Typical pad thickness varies, but generally can be classified by +/- 2' of gravel cover over native soil. The flowlines are typically 3", schedule 80, buried in a direct route from the well to exisiting facilities at a depth of 4' to 6' below grade level. 5) Location and Type of Water Supply Fresh water is available from the adjacent facilities and will be used for the drilling of the well as a water based mud will be utilized. Water log usage is tracked and recorded. 6) Construction Materials Approximately 300' of 3" Schedule 80 pipe will be required to connect the well to the existing facilities. Additional manifolds and meters may be required pending the results of the well. 7) Methods of Handling Waste Disposal Solid waste in the form of drill cuttings will be hauled in cutting boxes to the SRF Central Waste Facility. Liquid drilling mud will be recirculated while drilling the well. At the end of the well, the liquid mud will be hauled to and disposed of in the field class II disposal well. Garbage will be burned at the incinerator at the P&S yard in the SRF or hauled to the Soldotna dump. Septic/sewage/gray water will be self-contained on site and will be hauled away by contract disposal. 8) Ancillary Facilities e e Three small trailers will be present on the drill site for use by the Unocal drilling supervisor and the contract drilling rig tool pusher. 9) Well Site Layout See attached pad layout diagram 10) Plans for Reclamation The road and pad for the proposed well will not be able to be reclaimed because they are currently in use. Well 242-16 is located on the same pad and currently producing gas from the sterling formation. 11) Surface Ownership U.S. Fish & Wildlife, Federal Government 12) Other Information None 13) Leassee's Representative and Certification Steven Lambe, Advising Drilling Engineer, Unocal Alaska 907-263-7628 I hereby certify that I, or persons under my direct supervision, have inspected the proposed drill site and access route; that I am familiar with the conditions which currently exist; that the statements made in this plan are to the best of my knowledge, true and correct; and that the work associated with operations proposed herein will be performed by Unocal and its contractors and subcontractors in conformity with this plan and the terms and conditions under which it is approved. This statement is subject to the provisions of 19 U.S.C. 1001 for the filing of false statement. Date: 5"/z.7/cl( Name and Title: Ji-/! ~ Steven Lambe, Advising Drilling Engineer ",.....". .~ JìtIt/¡fIft vi: -- ¡a...· i . . ; '----- ---.-~._----- - ---.,.. - -+-. -- -1/; ~ " -i_If' - -... " ,-', ___/""I..f; " \ \ \. I '~ I) - .~ ~ ,- ~ I I I ----+-.,-. I I I -' ; I ·-,#N -:,.,.... .. - ~lf I I I WAIl 4.\11I - I I --;--j- ,,,,,",AI - - ...... .- -·..w ..",.,If, "".-.0 ~.:, I ~K' I ! ~ - , ... .... ......... ..,. ..... ì 1. 1 tœlWJ!I!NINII\\J. iIWANSOH RJII!RJEI.t swMsoNRIVER !AYOOT MAP - ._--' i.q ~~ ~ ...: I·, " J"~'iiæ:._, "'" ~~ ~ '" ¡ -?:W-'1t:-~ ~ f , . v : 'r,W L .... t "Þ' "h·'""'§ ~ ..¡ ;" ;¡ j . ~' .¡ ~-~~ .. '" ~~¡ i:/ ~ ... 1-1' ,;1", \; i ¡"l -,m ~ -F' , ~ - r r"'":· , -., ......:.H 'r -- . -.!JM.i ~i91~ ~iiJ "~, -I\'Î WI fA .... , ¡ . <æ "" " I-'~ ~,_..--- ~ _,&ß,. . '!OJ d'!!' ,\ @.~ 1 \ f~ ¡J i , ... t ~ (i i J¡; - --- .:,J' ~ ~ ...:. '\ \-. ~,' ,. !d; , w ~ ,.=. r" \ !; ... . , ~ ~-, i~ l ~ ~ J '-¡ . II~ ~ e e SEC 9 SEC 10 SEC 16 SEC 15 I I I I I I I I I I I I I I I GRID N: 2,480,039,801 I GRID E: 348,837.220 LATITUDE: 60·47'08,068"N I LONGITUDE: 150·50' 45.271 "w I ELEV. 318' í iJER WELL I 32A-/5~ JWi15 / .} 985' FWL W 'f:!JT I PROPOSED SRU 216-31 /242-16/ WELL SURFACE LOCATioN 2-t./1 -It,§ SWANSON RIVER UNIT ?16-31 WELL SURFACE LOCATION STERLING, AK -- - - - - -----'?" - -- ---- ""'\\\" ,'<,- OF AI.. ., _' ~~"''''''''''~C\ I' - f...'?-:'" *"~L' - '" " ~/..y I : * ::49 II:i .... * ~ ,..................................., , ;¡ ;¡ , ,................................... , , ~ :.M. SCOTT McLANE.: ß .. I ~'. ,'~- " ~ ". 4928-S ....~- ''}j '. .' q' - " ~A····"....····t-~<;;)...... , . . 7ì'OF'tSSIO\'I>,\. \. " ,\\\\."" SCALE 1 inch = 300 ft. o 300 ~ 450 I 600 I NOTES 1) BASIS OF COORDINATES: NGS CORS STATION "KEN 1" NAD27 ALASKA STATE PLANE ZONE 4. 2) BASIS OF ELEVATION: NGS BM Q79 RESET NA VD88. 3) SECTION LINE OFFSETS DERIVED FROM TIES TO BLM MONUMENTS AT NE CORNER SECTION 15 AND SW CORNER SECTION 22 T8N R9W SM FOUND THIS SURVEY ...J Z u.. AS-BUlL T EXISTING WELLS ON PAD 32A-15 GRID N: 2480088.776 GRID E: 348831.035 LATITUDE: 60'47'08.549"N LONGITUDE: 150'50' 45.408"W 0) N N SECTION 15 TOWNSHIP 8 NORTH RANGE 9 WEST SEWARD MERIDIAN ALASKA 12-15 GRID N: 2480068.677 GRID E: 348912.321 LATITUDE: 60'47'08.362"N LONGITUDE: 150'50'43. 765"W 242-16 GRID N: 2480035.055 GRID E: 348887.855 LA TITUDE: 60'47'08.027"N LONGITUDE: 150'50' 44.249"W , N AS STAKED SRU 21 Ô 311.1//-/¿' <W TS 2-15 Grid P.C. Box 468 SOLDOTNA, AK 99669 Project: 043023 APPLICANT: UNDI:AL 909 W. 9th Avenue . Anchorage, AK 99519-7685 Consulting ~ roup Testing Revisions: 5/11/04 Dwg: 043023 Date: 4/23/04 FIGURE: 1 e Unocal Alaska a Union Oil Company of C"ia 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 Fax (907) 263-7698 UNOCAL8 RECEIV~E MAY 2 7 2004 Kevin A. Tabler, Manager Land/Government Affairs May 27, 2004 Alaska Oil & Gas Ä!1chorag$ Mr. Bob Crandall Alaska Oil and Gas Conservation Commission 333 West th Avenue, Suite 100 Anchorage, AK 99501 APPLICATION FOR SPACING EXCEPTION SWANSON RIVER UNIT (SRU) 241-16 WELL A-028277, A-028405 Dear Mr. Crandall: Union Oil Company of California (Unocal) hereby submits this Application for Spacing Exception to drill the referenced "SRU 241-16" well in the Swanson River Field. Our anticipated spud date is in May, 2004. In accordance with 20 AAC 25.005 (a), a Permit to Drill and associated filing fees are filed herewith. The SRU 241-16 well is situated in governmental Section 16, Township 8N - Range 9W S.M. and may require a spacing exception in accordance with 20 AAC 25.055 (a)(2). Should the results of the SRU 241-16 well be successful, said well will be within 1,500' of the unit boundary and a property line with a different royalty percentage landowner. This regulation provides in pertinent part, "a wellbore may be open to test or regular production within 1 ,500 feet of a property line only if the owner is the same and the landowner is the same on both sides of the line." In this instance the owner and the landowner are the same on each side of the property line and unit boundary however, the same landowners hold different royalty percentages in the captioned offsetting leases. Although Unocal believes the landowner is the same per the definition of landowner (AS 31.05.170 (7», in an overabundance of caution, we are submitting this application for spacing exception. This well location is structurally high on the formation and is a crestal withdrawal based on seismic, dip meter and subsurface data available to Unocal. Additionally, the correlative rights of all affected owners, landowners and operators will be protected by exception approval. At the date of this mailing, in accordance with 20 AAC 25.055 (d)(1), notice of our intent to drill has been sent by certified mail to all owners, landowners, and operators of all outlying properties within Mr. Bob Crandall March 27, 2004 Page 2 e e 3,000 feet of the SRU 241-16 well. This application was sent to each landowner and constitutes "landowner notice". Certified mailing receipts are attached to this application. Pursuant to 20 AAC 25.055 (d)(2), enclosed is a plat, identified at Exhibit "A", which shows the location of the well for which the exception is sought and all adjoining properties. Also enclosed, Exhibit "A-1" identifies the owners, landowners and operators associated with each tract. Pursuant to 20 AAC 25.055 (d)(3), an affidavit is enclosed stating the undersigned is acquainted with the facts and verifying that all facts are true. It is requested that the Commission approve an exception to the statewide spacing regulation for the drilling of the proposed SRU 241-16 well. If you require additional information regarding the SRU 241-16 drill site, please contact Mr. Steven Lambe, Drilling Engineer at 907-263-7637, or you may contact the undersigned at 907-263-7600. Very trulyyours, I D~Ç;lJ~tr. ~ Kevin A. Tabler DSW:KA T:dma Enclosures cc: Kirk McGee, CIRI Greg Noble, BLM .' . e e VERIFICATION OF APPLICATION FOR SPACING EXCEPTION COOK INLET, ALASKA A-028077 A-028405 SRU 241-16 WELL I, DAVID S. WHITACRE, Manager, Gas Resource, Union Oil Company of California, do hereby verify the following: I am acquainted with the application submitted for the drilling of the SRU 241-16 well in the Swanson River Field. I have reviewed the application submitted for the exception to 20 AAC 25.055 (a)(2) and all facts therein are true. I have reviewed the plat attached to said application, and it correctly portrays pertinent and required data. DATED at Anchorage, Alaska this 2yth day of May, 2004. , D~> lv ¡L:ft- , David S. Whitacre Manager, Gas Resource STATE OF ALASKA ) ) ss THIRD JUDICIAL DISTRICT ) SUBSCRIBED TO AND SWORN before me this 27th day of May, 2004. ~~\\\\\\lIlIlIIllll!¡h -$' ~\'<J:10 ~ ~..:..s ....·..·.../.(L~ .j§§ ~ 1...... ". Y': ~ ~* .' '. cP~ ~ / JI7fIOd\ ~ § ~Å'VuTO'U ~ - :::;N- ,aVLL J.~. ;:: ~?... ..:o~ ~Ó-:'" ",O~ ~ ~ '. .' ~ ~ ~ """.:.....:....":.:.J~~~. .~ P" ~ "'l ~ 'l!¡11111II1111\\\\\\\~ ~cØ- Ì'h .Q~~ NOTARY PUBLIC IN AND FOR 0 THE STATE OF ALASKA ' My Commission Expires: II / g / () 7 A028077 9 16 21 e UN c L SWANSON RIVER UNIT SRU 241-16 EXHIBIT A N A 1,000 500 0 1,000 I I Feet Alaska State Plane Zone 4, NAD27 ( .." .. LEASE A-028077 Sec. 9,16 T8N-R9W S.M. A-028405 Sec. 10 T8N-R9W S.M. e EXHIBIT "A-1" LANDOWNER BLM Anchorage Field Office 6881 Abbott Loop Road Anchorage, Alaska 99507-2591 Attn: Greg Noble Cook Inlet Region, Inc. 2525 C Street, Suite 500 Anchorage, AK 99509 Attn: Kirk McGee e OWNER OPERATOR Unocal Unocal .. .. e e 0:0 ["'- a- .-=I u.s. ... - . , - ¡ CERTIFIED MAIL RECEIPT (Domestic Mail Only; No Insurance Coverage Provided) .J] 0:0 0:0 1..11 Postage $ .-=I C C ["'- Certified Fee 1..11 C C C Return Receipt Fee (Endorsement Required) Restricted Delivery Fee (Endorsement Required) c ru \"T\ c Total Postage & Fees $ r.I..'liIe1t1iiøf:lll.__klilttll,,;'...III'i "'q"¡¡:II¡;(ä'DI..."f"..I.}.I....'1'If'[.II(.J.~ .-=I .J] a- .-=I U.S. .. '. - . , - ; CERTIFIED MAIL RECEIPT (Domestic Mail Only; No Insurance Coverage Provided) r:v# Postage $ "';@.\ ,F,>;;" . ,,~C~ -'>-.>.-;, .J] c( 0:0 1..11 Certified Fee Ul C C C Return Receipt Fee (Endorsement Required) Restricted Delivery Fee (Endorsement Required) c ru Total Postage & Fees $ IT1 ~:~;~~~~~Ui::: ["'- City, State, ZIP+4 ~ L {\;\ _'..I~'IY...,~II~lt·~1_1'l.,=I':'j~..y'.J,,~~'..'..8·TII. e e Fon IIJOUifìIE~; CCJì!ít\C r L(\C:i\TlCi.! WI I EriE IIJV()ICf:~; WIJH:(;UíJMIn H) CHECK NO. INVOICE/CREDIT MEMO NO. VOUCHER NO. GROSS 1031548 05-27-04 DISCOUNT 2007793 05-27-04 DRILLPERMIT24116 10183925 100.00 100.00 FORM 4-28181 (REV. 11-95) PRINTED IN U.S.A. DETACH STI.JU r!lJi \[11 I ;i}'():;rì !fie; (' !If ;i< I TOTAL Þ- 100.00 100.00 CITIBANK DELAWARE A Subsidiary of Citicorp ONE PENN'S WAY NEW CASTLE, DE 19720 62-20 3iT Union Oil Company of California Accounts Payable Field Disbursing 2007793 UNOCAL 76 Pay One Hundred Dollars And 00 Cents ************************************************************* 27-MAY-04 Check Amount **********100.00 Date To the order of STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501 United States Void after six months from above date. (ì)~ a.0!~ ,..- II' 20077 g :III' 1:0:1 ~ ~OO 20 gl: :I g ~ ~ a ~ :I 7 II' e e TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME S~?1 2 'II - / ~ PTD# 20 'i -- on ~ Development Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) Exploration Stratigraphic ~'CLUEn Tbe permit is for a new weJlbore segment of existing weD . Permit No, API No. Production. sbould continue to be reported as a function ·of tbe original API number. stated above. HOLE In accordance witb 20 AAC 25.005(1), all records, data and logs acquired for tbe pilot bole must be clearly differentiated In botb name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for we)) (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject ·to fuD compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of ~ conserv~tion order approving a spacing exception. (Company Name) assumes tbe liability of any protest to the spacing exception tbat may occur. An dry ditch sample sets submitted to tbe Commission must be in no greater than 30' sample intervals from below tbe permafrost or from where samples are first caught and ] 0' sample intervals through target zones. Field & Pool SWANSON RIVER, STERLING UND GS - 77255 Well Name: SRU 241-16 Program DEV Well bore seg D PTD#: 2040880 Company UNION OIL CO OF CALlFQRNIA Initial Classrrype DEV 11-GAS GeoArea - Uni On/Off Shore .0L Annular Disposal D Administration 1 P.ermit fee attached. · Y.es 2 .Leas.enumberappropriate. . · Y.es 3 .U.nlque well.n.am.e.anq Ol!mb.er . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Y.es - - - - - - - - - - - - - - - - - - - - - - . - -- 4 WeJUocat.ed [n.a defil1edppol. . No. 5 WelUocat.ed properdlstance from drilling ul1itb.oUl1dary · No. - - - - - 6 WeHJocat.ed properdlstance. from otlJer wells. . · Yes 7 .Sufficient acreage.available in.dJilliog l!njt. . · yes I~o Jf.d.eviated, js weJlbore platincJuded . · Y.es .Operator onl}' affected party. · No. · . If prpdl!ctil,'etlJis we it will prpdu.ce within 15.00 pf a property bou.ndry.. .Operator \Jas.apprppriate.bond inJorce . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Y.es . . . . . a spacing eGePtioJUS r.eQl!ired. .H.earjn.Q.nptic.e.draJted 011 5/'Z7. .. . 11 permit can be issued without conservation order No. The well wilLbedrilled prior to issuing the.spaGil1g.oJder. Appr Date 12 Permit can be iSSl!ed wrtlJout administratil,'e.apprpvaJ . . · No. RPC 5/27/2004 13 Can permit be approved before 15-day wait No 14 WeH .located wi.thin area and strata authorized by.lnjectipo Ord.er # (put 10# in. comm.ents). (For NA - - -- e 15 .AJlwells.within.114.mile.area.ofreviewid.eotified(Fprservjc.ewellpl1l}'}... _... _. _. _ _ _ _ .NA - - - - - - - - - - - - - - - - - - - - - - - - - 16 Pre-produced injector; duratiQnof pre-produc;tipnless than 3. months. (For service well only) . . NA - - - - 17 AGMP Findjngof Consistency h.as bee.n j&.sued. for. t\Jis project NA .- -- Engineering 18 .C.ondu.ctor stringpJovided . Y.es 119 .S.udace .ca&.ing PJotect&. alLknown. USDWs . Yes. 20 CMT. vpl adeQu.ate to circJJlate. on .cpnd.uctpr & su.rf csg . .Yes . · . .A.dequate excess, . 21 CMT. vPI. adequate to tie-in Jong .string to surf csg. . · Y.es. . 22 CMTwill coverall \{no.w.n.pro.ductive 1J0rizon.s . . · Yes. 23 C.asing designs ad.equa.te fp( C,T., B.&permafrost. . Yes 24 .Adequatetankage OJ re.serve pit . Yes. · . Kuukpik 5. 25 Jf.are-drilt hasa. 10c403 for abandonment beeo approved. · NA New welL 26 Adequat.e .wellbore separatjo_n .proposed. . . _ . . . . _ _ . . . . . . . _ . _ . . _ . . . Y.es . _ . _ . _ . _ . _ . . . _ . _ _ . _ _ _ . . . . . _ 27 Jf.djver:ter Jequired, does it meet reguJatiOl1s. . NA · . Waiver.apprpved.. . Appr Date 28 .DJilliog fJuidpJogram schematic.& eq.uipJist.adequat.e. . Y.es · . Max MW9,2 ppg.. . WGA 5/28/2004 29 B.OPEs,.doJhey meetreguJa.tioo . · Y.es. 30 .BOPE.press ratiog appropriate; .test to (put psig in.comments). · Y.es · . Test to .2500 psi. .MSF' 1192 psi. e 31 C.hokemanifold compJies wIAPIRF'-53 (May 84). . Y.es. . 32 Work will pcc.ur withput.operations\Jutdown. . .Y.es. 33 J&. presence of H2S gas. probable. .No 34 MeclJa.nlcalcpodition pf we.lls withil1 .A.OR verified (For. service well only) .NA - - -- Geology 35 P.ermit can be iSSl!ed wlo hYdrogen. sulfide measures · Y.es . 36 .D.ata.PJeseoted on. pote.ntial oveJpre&.sure .zones. . . .. NA Appr Date 37 .S.eisOlicanalysjs of shaJlow gas.zP(les NA RPC 5/27/2004 38 .S.eç¡bed .condjtip(l Sl!rvey(if off-sh.ore) . .NA - - - -- 139 . Contact namelphoneJorweekly prpgress.reports [exQlorç¡tory .only] .NA. Geologic Date: Engineering Date ~~r Commissioner Commissioner DJ5 Sj¿P/1