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ǀŝĂĞŵĂŝůƌĞƉůǇŽŶϭͬϯϭͬϮϬϮϬΛϭϰϯϳŚƌƐ͘^ƚĂƌƚKWƚĞƐƚ͘dĞƐƚĂůůƌĂŵƐĂŶĚǀĂůǀĞƐϮϱϬͬϭϱϬϬƉƐŝ͘WĞƌĨŽƌŵ<ŽŽŵĞǇĚƌĂǁ ĚŽǁŶƚĞƐƚ͘ĚũƵƐƚƐůŝĐŬůŝŶĞĞƋƵŝƉŵĞŶƚ͘^ƉŽƚĂŶĚƌŝŐƵƉŚĂŵŵĞƌƵŶŝƚ͘WŝĐŬƐůŝĐŬůŝŶĞůƵďƌŝĐĂƚŽƌ͘ZĞŵŽǀĞƐŶŽǁĨƌŽŵWΘ^ ǇĂƌĚƚŽƉƵůůŽƵƚƐůŝĐŬůŝŶĞƚƌƵĐŬĨŽƌŚĂŵŵĞƌƵŶŝƚĂŶĐŚŽƌ͘ZŝŐƵƉƐůŝĐŬůŝŶĞůƵďƌŝĐĂƚŽƌĂŶĚƚŽŽůƐ͘>ĂǇĚŽǁŶĨŽƌŶŝŐŚƚ͘ ϬϭͬϯϭͬϮϬϮϮͲDŽŶĚĂǇ Wdt͕:^ǁŝƚŚĐƌĞǁƐ͘ϮϰŚƌKWƚĞƐƚǁŝƚŶĞƐƐŶŽƚŝĨŝĐĂƚŝŽŶƐĞŶƚƚŽƐƚĂƚĞ͘ϮϰŚŽƵƌŶŽƚŝĐĞŽĨǁŽƌŬƐƚĂƌƚŝŶŐƐĞŶƚƚŽ>D͘WĂĚ ŽƉĞƌĂƚŽƌƐŚƵƚƐŝŶǁĞůů͘ůĞĞĚ/ͬůŝĨƚŐĂƐĚŽǁŶĨůŽǁůŝŶĞƚŽǌĞƌŽ͘ůĞĞĚƚƵďŝŶŐĚŽǁŶƚŽǌĞƌŽƉƐŝ͘DŽǀĞƐŶŽǁǁŝƚŚůŽĂĚĞƌ͘ ^ƉŽƚŝŶϰϬϭ<ŽŽŵĞǇƵŶŝƚ͕ƌƵǌĐƌĂŶĞ͘>ĂǇƉŝƚůŝŶĞƌ͘^ƉŽƚŚŽƚŽŝůƚƌƵĐŬ͕WŽůůĂƌĚƐůŝĐŬůŝŶĞŚĂŵŵĞƌƵŶŝƚ͘ZŝŐƵƉKWƐƚĂĐŬĂƐ ƉƌŽƉŽƐĞĚŝŶƚŚĞƐƵŶĚƌǇ͘ϳΗƐƚĂĐŬŝŶƐƚĂůůĞĚŽŶƉƌŽĚƵĐƚŝŽŶƚƌĞĞ͘/ŶƐƚĂůůŚǇĚƌĂƵůŝĐůŝŶĞƐƚŽKW͘/ŶƐƚĂůů<dηϭǁŽƌŬƉůĂƚĨŽƌŵ ŽǀĞƌǁĞůů͘^&E͘ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ϭͬϯϭͬϮϮ ϯͬϭϬͬϮϮ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ ^ZhϮϯͲϮϮ ϱϬͲϭϯϯͲϭϬϭϰϴͲϬϭͲϬϬ ϮϭϮͲϬϳϴ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ϬϮͬϬϰͬϮϬϮϮͲ&ƌŝĚĂǇ W:^DĂŶĚWdt͘tĂƌŵͲƵƉĞƋƵŝƉŵĞŶƚ͘ůĞĂƌƐŶŽǁĂŶĚŽƌŐĂŶŝǌĞƉĂĚ͘^ƉŽƚĂŶĚƌŝŐƵƉ^>ĞƋƵŝƉŵĞŶƚ͘EhϳͲϭͬϭϲǆŽǁĞŶ ĂĚĂƉƚĞƌŽŶƚŽƉŽĨKWΖ^͘WƌĞƐƐƵƌĞƚĞƐƚůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝͬϭϱϬϬƉƐŝ͘^ůŝŐŚƚůĞĂŬŽŶƚŚĞϳͲϭͬϭϲǆŽǁĞŶĂĚĂƉƚĞƌĨůĂŶŐĞ͘ ůĞĞĚŽĨĨĂŶĚƚŝŐŚƚĞŶĨůĂŶŐĞ͘ ZĞͲƚĞƐƚůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝͬϭϱϬϬƉƐŝͲdĞƐƚŐŽŽĚ͘Z/,ǁŝƚŚϮ͘ϴϭΗK>/͕ǁŽƌŬ>/ĨƌŽŵϳϱϬĨƚƚŽϵϬϬĨƚͲWKK,͘EŽŵĂƌŬƐ͕ ƚŽŽůƐĐŽĂƚĞĚŝŶƉĂƌĂĨĨŝŶ͘Z/,ǁŝƚŚϮ͘ϱϬΗK>/͕ĐĂŶŶŽƚƉĂƐƐƚŚĞƚƌĞĞĚƵĞƚŽƉĂƌĂĨĨŝŶďƵŝůĚͲƵƉ͘Z/,ǁŝƚŚϮ͘ϰϬΗKƉĂƌĂĨĨŝŶ ŬŶŝĨĞ͕ĐĂŶŶŽƚƉĂƐƐƚŚĞƚƌĞĞĚƵĞƚŽƉĂƌĂĨĨŝŶďƵŝůĚͲƵƉ͘Z/,ǁŝƚŚϮ͘ϱϬΗKĂŝůĞƌ͕ǁŽƌŬƚŽŽůƐĚŽǁŶƚŽϭ͕ϬϱϰΖͲWKK, ďĂŝůĞƌĨƵůůŽĨƉĂƌĂĨĨŝŶ͘Z/,ǁŝƚŚϮ͘ϮϰΗK>/͕ǁŽƌŬƚŽŽůƐĚŽǁŶƚŽϵ͕ϱϬϮΖͲWKK,͕ŐŽŽĚŝŵƉƌĞƐƐŝŽŶŽĨ'ĨŝƐŚŝŶŐŶĞĐŬ͘Z/, ǁŝƚŚϮ͘ϳϬΗKƉĂƌĂĨĨŝŶŬŶŝĨĞ͘WƵŵƉϯϬ>ŽĨŚŽƚǁĂƚĞƌĚŽǁŶƚƵďŝŶŐǁŚŝůĞǁŽƌŬŝŶŐƚŽŽůƐ͘tŽƌŬƚŽŽůƐƚŽϵ͕ϬϬϬΖͲWKK,͘ Z/,ǁŝƚŚϯΗ'^ƚŽϵ͕ϱϬϮΖ͕ůĂƚĐŚƐŝƉŚŽŶƐƚƌŝŶŐ͘DĂŬĞϱũĂƌůŝĐŬƐĨƌŽŵϵϱϬůďƐƚŽϭ͕ϱϬϬůďƐƚŽĞŶƐƵƌĞƚŽŽůƐůĂƚĐŚƉƌŽƉĞƌůǇ͘^ŚĞĂƌ ĚŽǁŶĂŶĚWKK,͘ZͬƐůŝĐŬůŝŶĞ͘^ĞĐƵƌĞǁĞůůĂŶĚ^&E͘ ϬϮͬϬϱͬϮϬϮϮͲ^ĂƚƵƌĚĂǇ W:^DĂŶĚWdt͘DŽǀĞƐŶŽǁ͕ƌĞͲƐƉŽƚĞƋƵŝƉŵĞŶƚĨŽƌĐŽŝůƌŝŐƵƉ͘>ŽĂĚŽƵƚ^>ĞƋƵŝƉŵĞŶƚ͘ZŝŐƵƉ&ŽǆĐŽŝůƚƵďŝŶŐƵŶŝƚ͘Dͬhd KWƐĂŶĚĂĚĂƉƚĞƌĨůĂŶŐĞƐ͘KWƚĞƐƚƚŽϮϱϬƉƐŝͬϯϱϬϬƉƐŝ;dĞƐƚǁŝƚŶĞƐƐǁĂŝǀĞĚďǇ:ŝŵZĞŐŐϮͬϰͬϮϬϮϮΛϯ͗ϯϲWDǀŝĂͲ ŵĂŝůͿ͘'ŽŽĚKWƚĞƐƚ͘^ĞĐƵƌĞǁĞůůĂŶĚ^&E͘ ϬϮͬϬϲͬϮϬϮϮͲ^ƵŶĚĂǇ W:^DĂŶĚWdt͘dƵďŝŶŐϮϴϬƉƐŝ͕/ϬƉƐŝ͘ tĂƌŵͲƵƉĞƋƵŝƉŵĞŶƚ͘WƵŵƉϭϮϬ>ŽĨůĞĂƐĞǁĂƚĞƌƚŽŬŝůůǁĞůůͲdƵďŝŶŐŽŶĂǀĂĐƵƵŵ͕dͬ/ϬƉƐŝ͘ WŝĐŬƵƉdůƵďƌŝĐĂƚŽƌ͕Dhz:ĐŽŝůĐŽŶŶĞĐƚŽƌ͕ĂŶĚƉƵůůƚĞƐƚƚŽϯϬŬ͘ Dhz:ĨŝƐŚŝŶŐ,͘ϯΗ'^͕ĐŝƌĐƐƵď͕ŚǇĚĚŝƐĐŽŶŶĞĐƚ͕ŝͲĚŝƌĞĐƚŝŽŶĂůũĂƌ͕ĂĐĐĞůĞƌĂƚŽƌ͕ĚƵĂůĨůĂƉƉĞƌĐŚĞĐŬǀĂůǀĞ͘DĂǆKϮ͘ϳϬΗ͘ WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝͬϯϱϬϬƉƐŝͲdĞƐƚŐŽŽĚ͘ WĞƌĨŽƌŵŬŝĐŬǁŚŝůĞƚƌŝƉƉŝŶŐĚƌŝůů;tŝƚŶĞƐƐǁĂŝǀĞĚďǇ:ŝŵZĞŐŐ͕K'ǀŝĂƉŚŽŶĞͿ͘Z/,ǁŝƚŚϭ͘ϳϱΗKĐŽŝůƚƵďŝŶŐƚŽϵ͕ϬϬϬΖ ƵƉǁĞŝŐŚƚϭϴŬ͘ dĂŐĂƚϵ͕ϰϴϰΖ͕ƐĞƚĚŽǁŶϴŬĂŶĚůĂƚĐŚĨŝƐŚ͘WƵůůϮϴŬĂŶĚĨŝƐŚĐĂŵĞƵƉŚŽůĞϮϬΖƚŚĞŶŚƵŶŐƵƉ͘ tŽƌŬĨŝƐŚƵƉƚŽϰϱŬ͕ŚŝƚŽŶĞũĂƌůŝĐŬ͘>ŽƐƚĨŝƐŚ͘ Z/,ĂŶĚůĂƚĐŚĨŝƐŚĂƚϵ͕ϰϲϰΖ͘WƵůůϮϴŬĂŶĚĨŝƐŚďĞŐĂŶƚŽŵŽǀĞ͕ǁĞŝŐŚƚƐůŽǁůǇĨĞůůƚŽϮϱŬ͘WKK,ǁŝƚŚϳŬŽǀĞƌƉƵůů͘ WƵŵƉϲϬ>ŽĨƉƌŽĚƵĐĞĚǁĂƚĞƌĂƚϭϳϬĚĞŐƌĞĞƐƚŽĐůĞĂŶƉĂƌĂĨĨŝŶĂŶĚĨůƵŝĚƉĂĐŬƚŚĞǁĞůůďŽƌĞ͘dͬ/ϬƉƐŝ͘ŚĞĐŬǁĞůůĨŽƌ ĨůŽǁͲŶŽĨůŽǁ͘ ^ĂĨĞƚǇŵĞĞƚŝŶŐĨŽƌŽŝůKWƌĞŵŽǀĂů͘ ƌĞĂŬŽĨĨŽŝůKW^͘;zĞůůŽǁũĂĐŬĞƚKWΖƐƐƚŝůůŝŶƉůĂĐĞͿ^ĞĐƵƌĞĂŶĚƌĞůĞĂƐĞĨŝƐŚ͘^ĞĐƵƌĞǁĞůů͘ Z&ŽǆŽŝůdƵďŝŶŐhŶŝƚ͘ZŝŐƵƉϭ͘ϵϬΗKŚĂŶĚůŝŶŐĞƋƵŝƉŵĞŶƚ͘>ĂǇĚŽǁŶƋƚǇϰϴ͕ϮϬͲ&ƚũŽŝŶƚƐŽĨƚƵďŝŶŐ͘&ƵůůƌĞĐŽǀĞƌǇŽĨ ϭ͘ϵϬΗƚƵďŝŶŐ͘dŽƚĂůůĞŶŐƚŚϵϲϬĨƚŽĨƚƵďŝŶŐƌĞĐŽǀĞƌĞĚ͕ƚƵďŝŶŐŝŶŐŽŽĚĐŽŶĚŝƚŝŽŶ͘^ĞĐƵƌĞǁĞůůĂŶĚ^&E͘ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ϭͬϯϭͬϮϮ ϯͬϭϬͬϮϮ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ ^ZhϮϯͲϮϮ ϱϬͲϭϯϯͲϭϬϭϰϴͲϬϭͲϬϬ ϮϭϮͲϬϳϴ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ϬϮͬϬϳͬϮϬϮϮͲDŽŶĚĂǇ Wdt͕:^ǁŝƚŚKĂŶĚƌƵǌĐƌĂŶĞŽƉĞƌĂƚŽƌ͘ZŝŐĚŽǁŶ<dηϭƌŝŐ͘D/ZhWŽůůĂƌĚƐůŝĐŬůŝŶĞ͘WdϮϱϬͬϭϱϬϬƉƐŝ͘Z/,ͬǁϮ͘ϲϴΗ ŐĂƵŐĞƌŝŶŐƚŽϵϱϱϬΖ^>DƚƵďŝŶŐĐůĞĂƌWKK,͘Z/,ͬǁϭϯͬϰΗdƵďŝŶŐdĂŝů>ŽĐĂƚŽƌͬǁϭϯͬϰΗ^ĂŵƉůĞďĂŝůĞƌƚŽƚĂŝůůŽĐĂƚĞϵϱϭϳΖ ^>D;ϵϱϬϮΖZ<ŶĞŐϭϱΖĐŽƌƌĞĐƚŝŽŶͿƚŚĞŶĐŽŶƚŝŶƵĞĚŽǁŶƚŽϭϭϰϵϮΖ^>D;ϭϭϰϳϳΖZ<ŶĞŐϭϱΖĐŽƌƌĞĐƚŝŽŶͿǁͬƚWKK,KK,ͬǁ ĐůĂǇůŝŬĞƐĂŶĚŚŝŐŚůǇĐŽŵƉĂĐƚĞĚ͘Z/,ͬǁϮϭͬϴΗǆϮϬΖŽĨƵŵŵǇ'ƵŶƐƚŽϭϭϰϵϮΖ^>D;ŶĞŐϭϱΖĐŽƌƌĞĐƚŝŽŶϭϭϰϳϳΖZ<Ϳǁͬƚ WKK,ůĞĂŶƌŝĨƚŶŽŝƐƐƵĞƐ͘ ZŝŐĚŽǁŶůĞĂŶĂŶĚ^ĞĐƵƌĞĂƌĞĂĂŶĚtĞůůŚĞĂĚͲWƌĞƉƋƵŝƉŵĞŶƚĨŽƌƚƌĂǀĞů͘ &ƵĞůƋƵŝƉŵĞŶƚƚŚĞŶWĂƌŬhŶŝƚͲdƵƌŶŝŶZĂĚŝŽĂŶĚWĞƌŵŝƚͲƐŝŐŶŽƵƚŽĨ&ŝĞůĚ͘ ϬϮͬϭϬͬϮϬϮϮͲdŚƵƌƐĚĂǇ ƌƌŝǀĞĚĂƚŽĨĨŝĐĞĨŝůůŽƵƚΘƐŝŐŶƉĞƌŵŝƚƐĂŶĚ:^Ζ^͘DŽďĞĞƋƵŝƉŵĞŶƚƚŽůŽĐĂƚŝŽŶĂŶĚƐƉŽƚĂŶĚƌŝŐƵƉͲůŝŶĞ͕ŵĂŬĞƵƉƚŽŽůƐϭͲ ϯͬϴĐĂďůĞŚĞĂĚ͕Ϯ͘ϲϬΗ͘ϵϲƌŽůůĞƌƐ͕ϭͲϭϭͬϭϲ'Wdϴ͘ϱϬΖ͕ϭͲϭϭͬϭϲƐŚŽĐŬƐƵďϮ͘ϬϬΖϮͲϯͬϴƉƌĞĨŐƵŶϯϰ͘ϲϬΖƌŽůůĞƌϮ͘ϲϬΗ͕ϭ͘ϵϬΖ ŽǀĞƌĂůůůĞŶŐƚŚϰϳĨƚ͘>ĂǇĚŽǁŶůƵďƌŝĐĂƚŽƌĂŶĚƚĂŬĞƚǁŝƐƚŽƵƚŽĨůŝŶĞĐĂďůĞĂďŽǀĞůƵďƌŝĐĂƚŽƌŵĂŬĞďĂĐŬƵƉƚŽŽůƐ͘dĞƐƚ ůƵďƌŝĐĂƚŽƌƚŽϮϱϬůŽǁĂŶĚϯϬϬϬƉƐŝ͕ŽƉĞŶǁĞůůǁŝƚŚϰϱϬƉƐŝŽŶƐĂŵĞ͘ZƵŶŝŶŚŽůĞǁŝƚŚƚŽŽůƐƐĞƚƚŝŶŐĚŽǁŶĂƚϴϳϲϮĨƚ͘>D ĂƉƉĞĂƌĞĚƚŽďĞŝŶƚŚĞŐƌĞĂƐĞŚĞĂĚ͘WŽŽŚůĂǇĚŽǁŶůƵďƌŝĐĂƚŽƌĂŶĚƌĞŵŽǀĞƚŚĞϮ͘ϴϯŐƌĞĂƐĞŝŶũĞĐƚŽƌƚƵďĞƐĨƌŽŵŚĞĂĚ͕Ϯ͘ϴϰ ƚƵďĞƐĂƌƌŝǀĞĚĂƚϭϯϮϱŚƌƐ͘/ŶƐƚĂůůƚƵďĞƐ͕ƌĞŚĞĂĚƌŽƉĞƐŽĐŬĞƚ͕ĐŚĞĐŬĨŝƌĞ͘'ŽŽĚ͕ƐƚĂďŽŶůƵďƌŝĐĂƚŽƌ͘dĞƐƚůƵďƌŝĐĂƚŽƌƚŽϮϱϬ ůŽǁĂŶĚϮϱϬϬƉƐŝŐŽŽĚƚĞƐƚŽƉĞŶǁĞůůƚďŐƉƌĞƐƐƵƌĞϴϱϬZ/,ǁŝƚŚƚŽŽůƐƐƚƌŝŶŐ͕ϭͲϯͬϴĐĂďůĞŚĞĂĚ͕Ϯ͘ϲϬΗ͘ϵϲƌŽůůĞƌƐ͕ϭͲϭϭͬϭϲ 'Wdϴ͘ϱϬΖ͕ϭͲϭϭͬϭϲƐŚŽĐŬƐƵďϮ͘ϬϬΖϮͲϯͬϴƉƌĞĨŐƵŶϯϰ͘ϲϬΖƌŽůůĞƌϮ͘ϲϬΗ͕ϭ͘ϵϬΖŽǀĞƌĂůůůĞŶŐƚŚϰϳĨƚ͘ǁŽƌŬƚŽŽůƐĚŽǁŶĨƌŽŵ ϭϬ͘ϴϱϵĨƚ͘>DƚŽϭϭ͕ϭϲϱĨƚ͘>D͕ŵĂĚĞƐĞǀĞƌĂůĂƚƚĞŵƉƚƐƚŽŐĞƚĚĞĞƉĞƌ͘ŚĂĚĚŝƐĐƵƐƐŝŽŶǁŝƚŚŽƉƐĞŶŐŝŶĞĞƌ͘WŽŽŚƚŽĚƌŽƉ ďŽƚƚŽŵϭϭĨƚ͘ƉĞƌĨŐƵŶ͕ƐƚĂďŽŶůƵďƌŝĐĂƚŽƌ͕ŽƉĞŶǁĞůů͕Z/,ǁŝƚŚƐŚŽƌƚĞƌĂƐƐĞŵďůǇ͕ϭͲϯͬϴĐĂďůĞŚĞĂĚ͕Ϯ͘ϲϬΗ͘ϵϲƌŽůůĞƌƐ͕ϭͲ ϭϭͬϭϲ'Wdϴ͘ϱϬΖ͕ϭͲϭϭͬϭϲƐŚŽĐŬƐƵďϮ͘ϬϬΖϮͲϯͬϴƉĞƌĨŐƵŶϮϯ͘ϲϬΖƌŽůůĞƌϮ͘ϲϬΗ͕ϭ͘ϵϬΖŽǀĞƌĂůůůĞŶŐƚŚϯϲ͘ϬĨƚ͘dĂŐŐŝŶŐƵƉĂƚ ϭϭ͕ϬϴϴĨƚ͘ŵĂĚĞƐĞǀĞƌĂůĂƚƚĞŵƉƚƐƚŽŐĞƚĚĞĞƉĞƌ͘,ĂĚĚŝƐĐƵƐƐŝŽŶǁŝƚŚŽƉƐĞŶŐŝŶĞĞƌ͘WŽŽŚǁŝƚŚͲůŝŶĞ͕ƌŝŐĚŽǁŶůŝŶĞĂŶĚ ůƵďƌŝĐĂƚŽƌŵŽďŽƵƚĞƋƵŝƉŵĞŶƚ͕ƚƵƌŶǁĞůůďĂĐŬŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ͘ ϬϮͬϮϯͬϮϬϮϮͲtĞĚŶĞƐĚĂǇ Wdt͕:^ǁŝƚŚĐƌĞǁ͘ƌƌŝǀĞĂƚǁĞůůƐŝƚĞ͘^ƉŽƚĞƋƵŝƉŵĞŶƚ͘dĂŝůƌŽůůĂŶĚƐĞƚƌĞŶƚĂůƉƵŵƉĂŶĚŝƌŽŶďĂƐŬĞƚ͘ƌƵǌǀĂĐƚƌƵĐŬĨŝůůŝŶŐ ƵƉǁŝƚŚϲϱďďůƐŽĨƉƌŽĚƵĐĞĚǁĂƚĞƌĨŽƌƉƵŵƉŝŶŐͲůŝŶĞĚŽǁŶ͘ZŝŐƵƉz:^͘^ƚĂďŽŶǁĞůů͘WdϮϱϬͬϯϬϬϬƉƐŝ͘DĂŬĞƵƉͲůŝŶĞ ,͘ϭϯͬϴΗǆϭΖĐĂďůĞŚĞĂĚǁŝƚŚϭΗĨŝƐŚŝŶŐŶĞĐŬ͘ϭϭϭͬϭϲΗǆϴ͘ϱΖ'Wd͕ϭϭϭͬϭϲΗǆϮΖƐŚŽĐŬƐƵď͘ϭϭϭͬϭϲΗǆϮΖƉƵŵƉĚŽǁŶ ĐĞŶƚƌĂůŝǌĞƌ͕Ϯ͘ϯϳϱΗǆϮ͘ϱΖďůĂƐƚƐůĞĞǀĞ͕Ϯ͘ϯϳϱΗǆϮϭΖƉĞƌĨŐƵŶ͕Ϯ͘ϯϳϱΗǆϭϭΖƉĞƌĨŐƵŶ͕ϮϯͬϴΗǆϰΗďƵůůƉůƵŐ͕ϭϭϭͬϭϲΗǆϮϵΗ ƉƵŵƉĚŽǁŶĐĞŶƚƌĂůŝǌĞƌ͘dŽƚĂů,ůĞŶŐƚŚϱϭΖ͘&ůŽǁůŝŶĞƐŚƵƚŝŶďǇƉƌŽĚƵĐƚŝŽŶŽƉĞƌĂƚŽƌ͘Z/,ǁŝƚŚWĞƌĨŐƵŶ͘z:ĞůŝŶĞŚĂŶĚ ŽƉĞŶĞĚĨůŽǁůŝŶĞƚŽĚƌŽƉt,WƚŽĞĂƐĞŐƌĞĂƐĞĐŽŶƚƌŽů͘ŽƚƚŽŵͲůŝŶĞƐŚĞĂǀĞĚƌŽƉƉĞĚƚŽŐƌŽƵŶĚ͘ͲůŝŶĞŽƉĞƌĂƚŽƌƐŝŐŶĂůĞĚ ŐƌŽƵŶĚŚĂŶĚƚŽĐůŽƐĞĨůŽǁůŝŶĞ͘hƉŽŶĐůŽƐƵƌĞǁĞŝŐŚƚŝŶĐƌĞĂƐĞĚĂŶĚůŝŶĞƉƵůůĞĚŽƵƚŽĨƌŽƉĞƐŽĐŬĞƚĂƚϲϱϬΖ͘>ŽƐƚ ĐŽŵŵƵŶŝĐĂƚŝŽŶǁŝƚŚƚŽŽůƐƚƌŝŶŐ͘WKK,ƚŽƐƵƌĨĂĐĞ͘ůĞĂŶďƌĞĂŬŽŶƌŽƉĞƐŽĐŬĞƚ͘EŽǁŝƌĞůĞĨƚŝŶŚŽůĞ͘ůĞĂŶĨŝƐŚŶĞĐŬ͘ZŝŐ ĚŽǁŶz:^͘ZĞůĞĂƐĞĐƌƵǌǀĂĐƚƌƵĐŬ͘ĂůůWŽůůĂƌĚƐůŝĐŬůŝŶĞƚŽƐĞƚƵƉĨŽƌĨŝƐŚŝŶŐŝŶƚŚĞD͘ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ϭͬϯϭͬϮϮ ϯͬϭϬͬϮϮ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ ^ZhϮϯͲϮϮ ϱϬͲϭϯϯͲϭϬϭϰϴͲϬϭͲϬϬ ϮϭϮͲϬϳϴ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ϬϯͬϬϵͬϮϬϮϮͲtĞĚŶĞƐĚĂǇ zĞůůŽǁũĂĐŬĞƚͲůŝŶĞĂƌƌŝǀĞůŽĐĂƚŝŽŶ͘ŽŶĚƵĐƚ:^ĂŶĚĂƉƉƌŽǀĞWdt͘ D/ZhͲůŝŶĞĞƋƵŝƉŵĞŶƚ͘ sĂĐƚƌƵĐŬǁŝƚŚůĞĂƐĞǁĂƚĞƌŽŶůŽĐĂƚŝŽŶ͘ DhůƵďƌŝĐĂƚŽƌͬǁŝƌĞůŝŶĞǀĂůǀĞƐĂŶĚƉĞƌĨŽƌĂƚŝŶŐƚŽŽůƐƚƌŝŶŐ͘ ^ŚƵƚŝŶǁĞůů͘ WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϯϬϬϬƉƐŝŚŝŐŚ͘Z/,ǁŝƚŚ'Wd͕ϮͲϯͬϴΗǆϯϭΖƉĞƌĨŐƵŶ͕ĐĞŶƚƌĂůŝǌĞƌƐǁŝƚŚƉƵŵƉĚŽǁŶďĂƐŬĞƚƐ͘ &ŝŶĚĨůƵŝĚůĞǀĞůĂƚϲϱϬϬΖ͘^ƚĂƌƚŝŶŐƚŽŐĞƚƐƚŝĐŬǇΕϵϴϬϬΖ͘ ŽŶƚŝŶƵĞƚŽǁŽƌŬƚŽŽůƐƚƌŝŶŐĚŽǁŶŚŽůĞ͘ZĞĂĐŚĞĚĚĞƉƚŚŽŶĐĂďůĞǁŚŝĐŚŝƐƵŶƐĞĂƐŽŶĞĚ͘ŝĨĨŝĐƵůƚŐŽŝŶŐƚŚƌŽƵŐŚŐƌĞĂƐĞ ƚƵďĞƐĂƚƐƵƌĨĂĐĞ͘ WKK,ƚŽĐŚĂŶŐĞŽƵƚŐƌĞĂƐĞƚƵďĞƐ͘ŚĂŶŐĞŐƌĞĂƐĞƚƵďĞƐĂƚƐƵƌĨĂĐĞ͘ Z/,ǁŝƚŚ'Wd͕ϮͲϯͬϴΗǆϯϭΖƉĞƌĨŐƵŶ͕ĐĞŶƚƌĂůŝǌĞƌƐǁŝƚŚƉƵŵƉĚŽǁŶƉĂƌĂĐŚƵƚĞ͘ &ĂůůĨƌĞĞůǇƚŽϭϬ͕ϲϱϬΖ͕ƵŶĂďůĞƚŽŐĞƚĂŶǇĚĞĞƉĞƌ͘ ƌŝŶŐƉƵŵƉŽŶůŝŶĞ͘WƵŵƉϲϬďďůƐĂŶĚĐĂƚĐŚĨůƵŝĚůĞǀĞůŝŶƚƵďŝŶŐ͘dŽŽůƐƐƚĂƌƚŵŽǀŝŶŐĚŽǁŶŚŽůĞ͘ WƵŵƉŝŶŐϮďƉŵΛϭϬϬϬƉƐŝ͘ZƵŶŽƵƚŽĨĨůƵŝĚǁŝƚŚƚŽŽůƐƚƌŝŶŐĂƚΕϭϭ͕ϬϬϬΖ͘ ^ĞŶĚsĂĐƚƌƵĐŬƚŽŐĞƚŵŽƌĞĨůƵŝĚ͘WƵŵƉĂƚϯ͘ϱďƉŵΛϮϴϬϬƉƐŝƚƵďŝŶŐƉƌĞƐƐƵƌĞĂŶĚƉƵŵƉƉĞƌĨŽƌĂƚŝŶŐƚŽŽůƐƚƌŝŶŐĚŽǁŶƚŽ ϭϭ͕ϰϮϬΖ͘ >ŽŐƵƉŚŽůĞƚŽΕϭϭ͕ϴϲϬΖĨŽƌĐŽƌƌĞůĂƚŝŽŶůŽŐ͘ ^ĞŶĚĐŽƌƌĞůĂƚŝŽŶĚĂƚĂƚŽZͬ'K͘KŶĚĞƉƚŚ͘ ZƵŶŽƵƚŽĨĨůƵŝĚǁŚŝůĞƚƌǇŝŶŐƚŽƉƵŵƉƚŽŽůƐĚŽǁŶŚŽůĞ͘ ^ĞŶĚǀĂĐƚƌƵĐŬƚŽŐĞƚŵŽƌĞĨůƵŝĚ͘WƵŵƉƉĞƌĨŐƵŶĚŽǁŶƚŽϭϭ͕ϯϵϬΖ͘,WсϰϳϰϬΖ͘ KƉĞŶƵƉŐĂƐůŝĨƚĂŶĚďƌŝŶŐǁĞůůŽŶůŝŶĞ͘tĂŝƚĨŽƌ,WƚŽƌĞĚƵĐĞƚŽϭϳϬϬƉƐŝ͘ WƵůůŝŶƚŽƉŽƐŝƚŝŽŶĂŶĚǁĂŝƚĨŽƌ,WƚŽƌĞĚƵĐĞƚŽϭϲϬϬƉƐŝ͘WĞƌĨŽƌĂƚĞ'ϮǌŽŶĞϭϭ͕ϯϮϲͲϭϭϯϱϳΖǁŝƚŚǁĞůůĨůŽǁŝŶŐĂŶĚ,WŽĨ ϭϲϬϬƉƐŝ͘ tĂŝƚĨŽƌϱŵŝŶƵƚĞƐĂŶĚůĞƚǁĞůůĨůŽǁ͘ ^ŚƵƚŝŶǁĞůůĂŶĚWKK,͘ ůůƐŚŽƚƐĨŝƌĞĚ͘'ƵŶŝƐǁĞƚ͘>ĂǇĚŽǁŶƉĞƌĨŽƌĂƚŝŶŐƚŽŽůƐƚƌŝŶŐĂŶĚůƵďƌŝĐĂƚŽƌ͘^ĞĐƵƌĞǁĞůůǁŝƚŚŶŝŐŚƚĐĂƉ͘^&E͘ ϬϮͬϮϰͬϮϬϮϮͲdŚƵƌƐĚĂǇ Z/'hWtͬ>ͲϵϬΖK&>hͲWd>hϮϬϬͲϮϬϬϬW^/Ͳ'KK͘ Z/,tͬϭϯͬϴΗ:tͬϮ͘ϳϮΗ>>'h/dKϭϭ͕ϭϲϵ^dKtEͲ>d,>/E&/^,ͲWKK,͘ KK,tͬ>/E&/^,ͲWZ&'hE,^EKdE^,KdͲKt^WZ/E'EdZ>/Z^EhDZ>>^,sE D'Ͳϲ,>s^K&Kt^WZ/E'^D/^^/E'EW/^K&WhDWKtEhDZ>>͘ ^dEz&KZ>/EdKZZ/sdK/^^^D>WZ&'hEE>/EdKK>^͘ Z/'KtEtͬ>Ͳ^hZt>>͘ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ϭͬϯϭͬϮϮ ϯͬϭϬͬϮϮ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ ^ZhϮϯͲϮϮ ϱϬͲϭϯϯͲϭϬϭϰϴͲϬϭͲϬϬ ϮϭϮͲϬϳϴ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ϬϯͬϭϬͬϮϬϮϮͲdŚƵƌƐĚĂǇ zĞůůŽǁũĂĐŬĞƚͲůŝŶĞŽŶůŽĐĂƚŝŽŶ͘ŽŶĚƵĐƚ:^ĂŶĚĂƉƉƌŽǀĞWdt͘ DhƉĞƌĨŽƌĂƚŝŶŐƚŽŽůƐƚƌŝŶŐĂŶĚŐŽƚŽƚŚĞǁĞůů͘Z/,ǁŝƚŚ'Wd͕ϮͲϯͬϴΗǆϯϭΖƉĞƌĨŐƵŶ͕ĐĞŶƚƌĂůŝǌĞƌƐǁŝƚŚƉƵŵƉĚŽǁŶ ƉĂƌĂĐŚƵƚĞ͘ &ŝŶĚĨůƵŝĚůĞǀĞůĂƚϴϲϬϬΖ͘^ƚĂƌƚƉƵŵƉŝŶŐĚŽǁŶƚƵďŝŶŐĂƚϯ͘ϱďƉŵŽŶĐĞͲůŝŶĞƌĞĂĐŚĞĚΕϵϬϬϬΖ͘ WĞƌĨƚŽŽůƐƚƌŝŶŐŵĂĚĞŝƚƚŽϭϭ͕ϯϱϬΖǁŝƚŚŽƵƚĨůƵŝĚƉĂĐŬŝŶŐǁĞůůďŽƌĞ͘^ŚƵƚĚŽǁŶƉƵŵƉ͘WƵŵƉƚŽƚĂůϯϬďďůƐ͘ >ŽŐƵƉĨŽƌĐŽƌƌĞůĂƚŝŽŶůŽŐ͘Z;DĞƌĞĚǇƚŚͿŽŶůŽĐĂƚŝŽŶƚŽĐŽŶĨŝƌŵŽŶĚĞƉƚŚ͘ Z/,ĂŶĚƐƚĂƌƚŐĂƐůŝĨƚƚŽďƌŝŶŐǁĞůůŽŶůŝŶĞ͘'ĂƐůŝĨƚŐĞƚƐƚŽΕϮϭϬϬƉƐŝĂŶĚƐƚĂƌƚƚŽƐĞĞĂŶŝŶĐƌĞĂƐĞŝŶƚƵďŝŶŐƉƌĞƐƐƵƌĞ͘ KƉĞŶǁĞůůƚŽƉƌŽĚƵĐƚŝŽŶĂŶĚŵŽŶŝƚŽƌ,W͘ ƚϭϴϬϬƉƐŝƐƚĂƌƚƚŽůŽŐƵƉŝŶƚŽƉŽƐŝƚŝŽŶ͘ZĞͲƉĞƌĨ'ϮǌŽŶĞϭϭ͕ϮϰϰͲϭϭ͕ϮϳϱΖǁŝƚŚǁĞůůĨůŽǁŝŶŐĂŶĚ,WсϭϱϬϬƉƐŝ͘ tĂŝƚĨŽƌǁĞůůƚŽĨůŽǁϱŵŝŶƵƚĞƐ͘^ŚƵƚŝŶĨůŽǁůŝŶĞĂŶĚWKK,͘'ƵŶĂƚƐƵƌĨĂĐĞ͘ůůƐŚŽƚƐĨŝƌĞĚ͘'ƵŶŝƐǁĞƚ͘ ZDK͘ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ŽǁŶŚŽůĞZĞǀŝƐĞĚ͗ϲͬϬϴͬϭϰ hƉĚĂƚĞĚďǇDϬϯͲϮϱͲϮϮ ^,Dd/ ^ŽůĚŽƚŶĂƌĞĞŬhŶŝƚ tĞůů͗^ZhϮϯͲϮϮ ŽŵƉůĞƚŝŽŶZĂŶ͗ϭϬͬϭϭͬϮϬϭϮ Wd͗ϮϭϮͲϬϳϴ W/͗ϱϬͲϭϯϯͲϭϬϭϰϴͲϬϭͲϬϬ Wdсϭϭ͕ϲϱϰ͛DͬϭϬ͕ϴϳϭ͛ds dсϭϭ͕ϳϰϭ͛DͬϭϬ͕ϵϬϮ͛ds DĂǆĞǀŝĂƚŝŽŶϳϮΣΛϭϭ͕ϭϴϮ͛ DĂǆŽŐůĞŐϴ͘ϴΣͬϭϬϬ͛Λϵ͕ϵϮϲ͛ 'ƌŽƵŶĚůĞǀ͗Ϯϯϵ͛ďŽǀĞD^> <Ͳd,&͗ϭϵ͘ϬϬ͛ ^/E'd/> ^ŝǌĞdǇƉĞtƚ'ƌĂĚĞŽŶŶ͘/dŽƉƚŵ ϮϮ͟ŽŶĚƵĐƚŽƌͲͲͲ^ƵƌĨϯϴ͛ ϭϭͲϯͬϰΗ^ƵƌĨ͘ƐŐϰϳ:Ͳϱϱdϭϭ͘ϬϬ͟^ƵƌĨϯ͕ϬϬϭ͛ ϳΗ/ŶƚĞƌŵĞĚŝĂƚĞ ϮϵEͲϴϬdϲ͘ϭϴϰ͟^ƵƌĨϭϭϰ͛ ϮϯEͲϴϬdϲ͘ϯϲϲ͟ϭϭϰ͛ϰ͕ϴϴϲ͛ ϮϲEͲϴϬdϲ͘Ϯϳϲ͟ϰ͕ϴϴϲ͛ϲ͕ϳϴϭ͛ ϮϵEͲϴϬdϲ͘ϭϴϰ͟ϲ͕ϳϴϭ͛ϴ͕ϱϲϱ͛ ϮϵWͲϭϭϬdϲ͘ϭϴϰ͟ϴ͕ϱϲϱ͛ϵ͕ϳϮϬ͛ ϰͲϭͬϮΗWƌŽĚ>ŶƌϭϮ͘ϲEͲϴϬ/dϯ͘ϵϱϴΗϵ͕ϱϭϮ͛ϭϭ͕ϵϴϮ͛ dh/E'd/> ϯͲϭͬϮΗWƌŽĚƵĐƚŝŽŶϵ͘ϯ>ͲϴϬϴZϮ͘ϵϵϮ͟^ƵƌĨϵ͕ϱϬϳ͛ ´ ´ ´ :t>Zzd/> EŽ͘ĞƉƚŚ/K/ƚĞŵ ϭϭϵ͛Ϯ͘ϵϵϮ͟ͲdƵďŝŶŐ,ĂŶŐĞƌ ϮϮ͕ϳϬϰ͛Ϯ͘ϴϲϳ͟ϱ͘ϯϭϯ͟ϯͲϭͬϮ͟^&KͲϭDĂŶĚƌĞůϴZ ϯϱ͕ϬϬϰ͛Ϯ͘ϴϲϳ͟ϱ͘ϯϭϯ͟ϯͲϭͬϮ͟^&KͲϭDĂŶĚƌĞůϴZ ϰϲ͕ϴϯϭ͛Ϯ͘ϴϲϳ͟ϱ͘ϯϭϯ͟ϯͲϭͬϮ͟^&KͲϭDĂŶĚƌĞůϴZ ϱϳ͕ϵϴϲ͛Ϯ͘ϴϲϳ͟ϱ͘ϯϭϯ͟ϯͲϭͬϮ͟^&KͲϭDĂŶĚƌĞůϴZ ϲϴ͕ϵϮϬ͛Ϯ͘ϴϲϳ͟ϱ͘ϯϭϯ͟ϯͲϭͬϮ͟^&KͲϭDĂŶĚƌĞůϴZ ϳϵ͕ϰϳϰ͛Ϯ͘ϴϲϳ͟ϱ͘ϯϭϯ͟ϯͲϭͬϮ͟^&KͲϭDĂŶĚƌĞůϴZ ϴϵ͕ϰϴϳ͛Ϯ͘ϴϭϯ͟ϱ͘ϴϳϱ͟KŶͬKĨĨdŽŽůǁͬyͲEŝƉƉůĞ ϵϵ͕ϰϴϴ͛Ϯ͘ϵϵϮ͟ϱ͘ϴϳϱ͟ƌƌŽǁƐĞƚ^ϭͲyDĞĐŚĂŶŝĐĂůWĂĐŬĞƌ ϭϬϵ͕ϱϬϮ͛Ϯ͘ϴϭϯ͟ϯ͘ϵϬϬ͟yͲEŝƉƉůĞ ϭϭϵ͕ϱϬϳ͛ϯ͘ϬϬϬ͟ϰ͘ϭϮϱ͟t>ŶƚƌǇ'ƵŝĚĞ ´ WZ&KZd/KEd/> ĂƚĞŽŶĞdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿ^W&&ƚWŚĂƐĞŽŵŵĞŶƚƐ ϳͬϭϵͬϭϯ'ͲϮϭϭ͕ϮϰϮ͛ϭϭ͕Ϯϳϳ͛ϭϬ͕ϳϯϮ͛ϭϬ͕ϳϰϯ͛ϲϯϱϲϬϮ͟, ϯͬϭϬͬϮϮ'ͲϮϭϭ͕Ϯϰϰ͛ϭϭ͕Ϯϳϱ͛ϭϬ͕ϳϯϮ͛ϭϬ͕ϳϰϮ͛ϯϭKƉĞŶʹϮͲϯͬϴ͟ ϯͬϵͬϮϮ'ͲϮϭϭ͕ϯϮϲ͛ϭϭ͕ϯϱϳ͛ϭϬ͕ϳϱϵ͛ϭϬ͕ϳϲϵ͛ϯϭKƉĞŶʹϮͲϯͬϴ͟ ϭϬͬϭϬͬϭϮ'ͲϮϭϭ͕ϰϯϯ͛ϭϭ͕ϰϰϬ͛ϭϬ͕ϳϵϱ͛ϭϬ͕ϳϵϳ͛ϲϳϲϬϮͲϯͬϰ͟dW,Dy ϭϬͬϯϬͬϭϯ,Ͳϭϭϭ͕ϰϲϱ͛ϭϭ͕ϰϴϮ͛ϭϬ͕ϴϬϲ͛ϭϬ͕ϴϭϮ͛ϲϭϳϲϬϮͲϭͬϮ͟, ϭϬͬϯϬͬϭϯ,ͲϮϭϭ͕ϰϴϮ͛ϭϭ͕ϰϴϱ͛ϭϬ͕ϴϭϮ͛ϭϬ͕ϴϭϯ͛ϲϯϲϬϮͲϭͬϮ͟, ϭϬͬϭϬͬϭϮ,ͲϮϭϭ͕ϰϴϮ͛ϭϭ͕ϱϬϳ͛ϭϬ͕ϴϭϮ͛ϭϬ͕ϴϮϬ͛ϲϮϱϲϬϮͲϯͬϰ͟dW,Dy ϭϬͬϭϬͬϭϮ,Ͳϯϭϭ͕ϱϯϰ͛ϭϭ͕ϱϲϵ͛ϭϬ͕ϴϯϬ͛ϭϬ͕ϴϰϮ͛ϲϯϱϲϬϮͲϯͬϰ͟dW,Dy ϭϬͬϭϬͬϭϮ,Ͳϯϭϭ͕ϱϵϱ͛ϭϭ͕ϲϭϴ͛ϭϬ͕ϴϱϭ͛ϭϬ͕ϴϱϵ͛ϲϮϯϲϬϮͲϯͬϰ͟dW,Dy dŽƉŽĨ>ŝŶĞƌ ,ĂŶŐĞƌΛϵ͕ϱϭϮ͛ ,Ͳϭ ,Ͳϯ ,ͲϮ ,Ͳϯ ´KROH ; 'ͲϮ 'ͲϮ 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: 3/24/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SRU 23B-22 (PTD 212-078) PERF 3/09/2022 Please include current contact information if different from above. 212-078 T36429 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.29 09:49:20 -08'00' THE STATE °fALASKA May 3, 2021 GOVERNOR MIKE DUNLEAVY Mr. Taylor Wellman Operations Manager — Cl Onshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No -Flow Verification Swanson River Unit 2313-22 PTD 2120780 Dear Mr. Wellman: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 ww .00gcc.olaska.gov On April 22, 2021 the Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector sent you a letter confirming a passing no -flow test of Swanson River Unit 2313-22. The no -flow test was witnessed by an AOGCC Inspector on April 20, 2021. The letter states "Swanson River Unit 2313-22 may be produced without a subsurface safety valve." The purpose of today's letter is to rescind that approval. AOGCC has learned that kill weight fluid was pumped into the well before the no -flow test was performed. That information was not available to AOGCC prior to the April 22 letter. Should you have any questions about this decision, please contact me at 907-793-1236 or jim.regg@alaska.gov. Please retain a copy of this letter at the Swanson River Field office. Sincerely, James B. Reg W..2021,05.a M.1B s B. James B. Regg Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors THE STATE °fALASKA April 22, 2021 GOVERNOR MIKE DUNLEAVY Mr. Taylor Wellman Operations Manager — Cl Onshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No -Flow Verification Swanson River Unit 2313-22 PTD 2120780 Dear Mr. Wellman: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 �.aogcc.alaska.gov On April 20, 2021 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no -flow test of Swanson River Unit 2313-22. The well is operated by Hilcorp Alaska, LLC (Hilcorp). The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up on Swanson River Unit 2313-22 for the test. The well performance was monitored for approximately 2 hours consisting of flow rate checks each preceded by 1 -hour pressure build up periods. There was no liquid or gas flow to surface during the no -flow test. Swanson River Unit 2313-22 may be produced without a subsurface safety valve. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Swanson River Unit 2313-22 demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a new no -flow test. Please retain a copy of this letter at the Swanson River Field office. Sincerely, James B. Regg =!2" m= o7'a 36�=Y James B. Regg Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg )�Q 7I `1�1�4�n DATE: P. I. Supervisor �I t FROM: Lou Laubenstein SUBJECT: Petroleum Inspector 4/20/2021 No Flow Test SRU 2313-22 - Hilcorp Alaska LLC PTD 2120780 - 4/20/2021: 1 traveled out to Swanson River Field for a No -Flow Test on SRU 23B-22. The well was opened and bled to 0 psi prior to my arrival. A pressure gauge and flow meter were rigged up and ready for the test to begin. The rig up was necked down to 3/8 -inch tubing with the flow meter having a3/4 -inch run. The operator and I decided that re -rigging was in order: it was changed to Y2 -inch and the manifold was rigged up directly off the riser piping. There was 10 feet of 1/2 -inch hose rigged to a bleed trailer, but it wasn't used; the flow was instead directed to a half drum downstream of the flow meter. All equipment used had current calibrations and all were in good condition. This well doesn't have and any supporting injection wells. After 2 hours of monitoring and bleeding there was no pressure, gas flow rate or liquid period. I called the test a pass after 2 hours due to no change in pressure and flow. This test proved this well is ✓ incapable of unassisted flow to surface. Tha fnllnwinn tahla chnws test details: TimePressures' (psi) Flow Rate' Remarks Gas — scf/hr Liquid — al/hr 9:15 0/0/0 Shut in for build u 9:30 0/0/0 15 -minute reading 945 0/0/0 30 -minute reading 10:00 0/0/0 45 -minute reading 10:15 0/0/0 0 0 O ened to flow; no pressure 10:16 0/0/0 Shut in for build u 10:31 0/0/0 15 -minute reading 10:46 0/0/0 30 -minute reading 11:01 0/0/0 45 -minute reading 11:16 0/0/0 1 0 0 1 Test concluded ' Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr Attachments: none V/ !.TOTE `iiUs GI -AS rrSG,-,�vi Iiee- 5+'3/7,0ZA rc. 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BOP test pressure = 1500 psi. Perform kick while tripping drill for making up Safety joint and shutting in the well prior to pulling the tubing. The drill should simulate the crews ability to recognize that the well is flowing, pick up the safety joint and shut in the well. X BJM 06/10/21 Standing orders must be posted on location and the roles and responsibilities for shutting in the well must be understood by the crews. AOGCC inspectors will test crew's understanding during BOP test. dts 6/11/2021 6/11/21 Jessie L. Chmielowski Digitally signed by Jessie L. 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Pump wellbore volume of KWF before disconnecting lubricator. 7b. No-flow test before disconnecting lubricator. 7c. Perform kick while tripping drill before disconnecting lubricator. MPSP is based on reservoir pressure minus a gas gradient. RU wireline valves and lubricator and pressure test to 1500 psi. NU BOP per attached diagram. test BOP to 1500 psi 1027 psi tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗^ZhϮϯͲϮϮ ĂƚĞ͗ϯͬϯϬͬϮϬϭϴ ϭϬ͘ZŝŐĚŽǁŶďƌĂŝĚĞĚͲůŝŶĞƵŶŝƚ͘ tĞůůŽŶƚƌŽůŝƐĐƵƐƐŝŽŶ tŚŝůĞƚŚĞƉƌŝŵĂƌǇďĂƌƌŝĞƌƚŽƌĞƐĞƌǀŽŝƌƉƌĞƐƐƵƌĞŝƐƚŚĞĨĂĐƚƚŚĞǁĞůůŝƐƵŶĂďůĞƚŽĨůŽǁ͕ƚŚĞďĞůŽǁƚǁŽŽƉƚŝŽŶƐ ƌĞŵĂŝŶĂƐƐĞĐŽŶĚĂŶĚƚŚŝƌĚůĂǇĞƌƐŽĨƉƌŽƚĞĐƚŝŽŶĚƵƌŝŶŐƚŚĞƉĞƌŝŽĚǁŚĞŶƚŚĞϭ͘ϵϬ͟ƚƵďŝŶŐŝƐĂĐƌŽƐƐƚŚĞƚƌĞĞ͗ /͘ůŽƐĞƚŚĞƉŝƉĞƌĂŵƐ͕ƐƚĂďƚŚĞd/tǀĂůǀĞΘƉƵŵƉŬŝůůǁĞŝŐŚƚĨůƵŝĚ;ǁĂƚĞƌͿĚŽǁŶƚŚĞϯЪ͟ƚƵďŝŶŐ ǀŝĂƚŚĞĐŽŵƉĂŶŝŽŶǀĂůǀĞƚŽƉůĂĐĞƚŚĞǁĞůůŽŶĂǀĂĐƵƵŵ͘ //͘KƉĞŶƚŚĞƐůŝƉƐ͕ŽƉĞŶƚŚĞĞůĞǀĂƚŽƌƐ͕ĚƌŽƉƚŚĞƚƵďŝŶŐƐƚƌŝŶŐΘĐůŽƐĞŝŶƚŚĞǁĞůůĂƚƚŚĞŵĂƐƚĞƌ͘ WĞƌĨŽƌĂƚŝŶŐ ϭϭ͘ZhͲůŝŶĞ͘Wd>ƵďƌŝĐĂƚŽƌƚŽϮϱϬůŽǁͬϯϬϬϬƉƐŝŚŝŐŚ͘ ϭϮ͘WĞƌĨŽƌĂƚĞƚŚĞďĞůŽǁƐĂŶĚƐĨƌŽŵƚŚĞďŽƚƚŽŵƵƉ͗ EŽƚĞ͗ŽƚŚƐĂŶĚƐůŝĞŝŶƚŚĞ,ĞŵůŽĐŬŽŝůƉŽŽůĂŶĚĚŽŶŽƚƌĞƋƵŝƌ ĞĂĐŽŵŵŝŶŐůŝŶŐĂŐƌĞĞŵĞŶƚ͘ ^ĂŶĚ dKWD KdD dŽƚĂů dKWds Kdds WŽŽů ƐƚWƌĞƐƐƵƌĞ;ƉƐŝͿ dǇŽŶĞŬ'Ϯ ϭϭϯϬϮ ϭϭϰϯϯ ϭϯϭ ϭϬϳϱϭ ϭϬϳϵϱ ^Zh,ĞŵůŽĐŬͬ 'ŽŶĞϰϴϱϵ ,ϰ ϭϭϲϯϲ ϭϭϲϱϰ ϭϴ ϭϬϴϲϱ ϭϬϴϳϮ ^Zh,ĞŵůŽĐŬͬ 'ŽŶĞϰϵϭϭ ͲůŝŶĞWƌŽĐĞĚƵƌĞ;ŽŶƚŝŶŐĞŶĐǇͿ ϭ͘/ĨĂŶǇǌŽŶĞƉƌŽĚƵĐĞƐƐĂŶĚĂŶĚͬŽƌǁĂƚĞƌŽƌŶĞĞĚƐŝƐŽůĂƚĞĚ͗ Ϯ͘D/ZhͲ>ŝŶĞĂŶĚƉƌĞƐƐƵƌĞĐŽŶƚƌŽůĞƋƵŝƉŵĞŶƚ͘WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝ>ŽǁͬϮ͕ϱϬϬƉƐŝ,ŝŐŚ͘ ϯ͘Z/,ĂŶĚƐĞƚϯͲϭͬϮ͟ĂƐŝŶŐWĂƚĐŚŽƌƐĞƚϯͲϭͬϮ͟/WĂďŽǀĞƚŚĞǌŽŶĞĂŶĚĚƵŵƉϯϱ͛ŽĨĐĞŵĞŶƚŽŶƚŽƉ ŽĨƚŚĞƉůƵŐ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ĐƚƵĂů^ĐŚĞŵĂƚŝĐ Ϯ͘WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘t>sĂůǀĞŝĂŐƌĂŵ An additional Sundry will be required if deploying a casing patch that is too long to be fully lubricated. - bjm BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB Downhole Revised: 6/08/14 Updated by STP 6/13/14 ACTUAL SCHEMATIC Soldotna Creek Unit Well: SRU 23B-22 Completion Ran: 10/11/2012 PTD: 212-078 API: 50-133-10148-01 PBTD =11,654’ MD/ 10,871’ TVD TD = 11,741’ MD/ 10,902’ TVD Max Deviation 72° @ 11,182’ Max Dogleg 8.8°/100’ @ 9,926’ Ground Elev: 239’ Above MSL KB-THF: 19.00’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 22” Conductor - - - Surf 38’ 11-3/4" Surf. Csg 47 J-55 BTC 11.00” Surf 3,001’ 7" Intermediate 29 N-80 BTC 6.184” Surf 114’ 23 N-80 BTC 6.366” 114’ 4,886’ 26 N-80 BTC 6.276” 4,886’ 6,781’ 29 N-80 BTC 6.184” 6,781’ 8,565’ 29 P-110 BTC 6.184” 8,565’ 9,720’ 4-1/2" Prod Lnr 12.6 N-80 IBT 3.958" 9,512’ 11,982’ TUBING DETAIL 3-1/2" Production 9.3 L-80 8RD 2.992” Surf 9,508’ 1.900” V-String 2.75 L-80 10RD 1.610” 9,502’ 10,462’ 22” ” ” JEWELRY DETAIL No. Depth ID OD Item 1 19’ 2.992” - Tubing Hanger 2 2,704’ 2.867” 5.313” 3-1/2” SFO-1 Mandrel 8RD 3 5,004’ 2.867” 5.313” 3-1/2” SFO-1 Mandrel 8RD 4 6,831’ 2.867” 5.313” 3-1/2” SFO-1 Mandrel 8RD 5 7,986’ 2.867” 5.313” 3-1/2” SFO-1 Mandrel 8RD 6 8,920’ 2.867” 5.313” 3-1/2” SFO-1 Mandrel 8RD 7 9,474’ 2.867” 5.313” 3-1/2” SFO-1 Mandrel 8RD 8 9,487’ 2.813” 5.875” On/Off Tool w/ X-Nipple 9 9,488’ 2.992” 5.875” Arrowset AS1-X Mechanical Packer 10 9,502’ 2.813” 3.900” X-Nipple 11 9,507’ 3.000” 4.125” WL Entry Guide A 9,502’ 1.600” 2.850” Profile Hanger Sub B 10,462’ 1.135” 1.900” XN-Nipple (1.250” X; 1.135” XN) ” PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 7/19/13 G-2 11,242’ 11,277’ 10,732’ 10,743’ 6 35 60 2” HC 10/10/12 G-2 11,433’ 11,440’ 10,795’ 10,797’ 6 7 60 2-3/4”TCP HMX 10/30/13 H-1 11,465’ 11,482’ 10,806’ 10,812’ 6 17 60 2-1/2” HC 10/30/13 H-2 11,482’ 11,485’ 10,812’ 10,813’ 6 3 60 2-1/2” HC 10/10/12 H-2 11,482’ 11,507’ 10,812’ 10,820’ 6 25 60 2-3/4”TCP HMX 10/10/12 H-311,534’ 11,569’ 10,830’ 10,842’ 6 35602-3/4”TCP HMX 10/10/12 H-311,595’ 11,618’ 10,851’ 10,859’ 623602-3/4”TCP HMX Top of Liner Hanger @ 9,512’ H-1 H-3 H-2 H-3 ” hole ; G-2 G-2 $ % 9HORFLW\6WULQJ ,QVWDOOHG 1.900” MWVof 1.900” 2.75# NU 10RD(20’ jts; string wt 5,200# 7RS %RWWRP 0'9,502’10,462’ 79'9,502’ ’ Tbg vol = 83 bbls Liner volume = 32 bbls 1.9" string weight = 2640 lbs BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ŽǁŶŚŽůĞZĞǀŝƐĞĚ͗ϲͬϬϴͬϭϰ hƉĚĂƚĞĚďǇD<ZϬϯͬϭϮͬϮϭ WZKWK^^,Dd/ ^ŽůĚŽƚŶĂƌĞĞŬhŶŝƚ tĞůů͗^ZhϮϯͲϮϮ ŽŵƉůĞƚŝŽŶZĂŶ͗ϭϬͬϭϭͬϮϬϭϮ Wd͗ϮϭϮͲϬϳϴ W/͗ϱϬͲϭϯϯͲϭϬϭϰϴͲϬϭ Wdсϭϭ͕ϲϱϰ͛DͬϭϬ͕ϴϳϭ͛ds dсϭϭ͕ϳϰϭ͛DͬϭϬ͕ϵϬϮ͛ds DĂǆĞǀŝĂƚŝŽŶϳϮΣΛϭϭ͕ϭϴϮ͛ DĂǆŽŐůĞŐϴ͘ϴΣͬϭϬϬ͛Λϵ͕ϵϮϲ͛ 'ƌŽƵŶĚůĞǀ͗Ϯϯϵ͛ďŽǀĞD^> <Ͳd,&͗ϭϵ͘ϬϬ͛ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚ 'ƌĂĚĞ ŽŶŶ͘ / dŽƉ ƚŵ ϮϮ͟ŽŶĚƵĐƚŽƌͲͲͲ^ƵƌĨϯϴ͛ ϭϭͲϯͬϰΗ^ƵƌĨ͘ƐŐϰϳ:Ͳϱϱdϭϭ͘ϬϬ͟^ƵƌĨϯ͕ϬϬϭ͛ ϳΗ /ŶƚĞƌŵĞĚŝĂƚĞ ϮϵEͲϴϬdϲ͘ϭϴϰ͟^ƵƌĨϭϭϰ͛ ϮϯEͲϴϬdϲ͘ϯϲϲ͟ϭϭϰ͛ϰ͕ϴϴϲ͛ ϮϲEͲϴϬdϲ͘Ϯϳϲ͟ϰ͕ϴϴϲ͛ϲ͕ϳϴϭ͛ ϮϵEͲϴϬdϲ͘ϭϴϰ͟ϲ͕ϳϴϭ͛ϴ͕ϱϲϱ͛ ϮϵWͲϭϭϬdϲ͘ϭϴϰ͟ϴ͕ϱϲϱ͛ϵ͕ϳϮϬ͛ ϰͲϭͬϮΗWƌŽĚ>Ŷƌ ϭϮ͘ϲEͲϴϬ/dϯ͘ϵϱϴΗϵ͕ϱϭϮ͛ϭϭ͕ϵϴϮ͛ dh/E'd/> ϯͲϭͬϮΗWƌŽĚƵĐƚŝŽŶϵ͘ϯ >ͲϴϬϴZϮ͘ϵϵϮ͟^ƵƌĨϵ͕ϱϬϴ͛ ϭ͘ϵϬϬ͟sͲ^ƚƌŝŶŐϮ͘ϳϱ>ͲϴϬϭϬZϭ͘ϲϭϬ͟ϵ͕ϱϬϮ͛ϭϬ͕ϰϲϮ͛ ´ ´ ´ :t>Zzd/> EŽ͘ ĞƉƚŚ / K /ƚĞŵ ϭϭϵ͛Ϯ͘ϵϵϮ͟ͲdƵďŝŶŐ,ĂŶŐĞƌ ϮϮ͕ϳϬϰ͛Ϯ͘ϴϲϳ͟ϱ͘ϯϭϯ͟ϯͲϭͬϮ͟^&KͲϭDĂŶĚƌĞůϴZ ϯϱ͕ϬϬϰ͛Ϯ͘ϴϲϳ͟ϱ͘ϯϭϯ͟ϯͲϭͬϮ͟^&KͲϭDĂŶĚƌĞůϴZ ϰϲ͕ϴϯϭ͛Ϯ͘ϴϲϳ͟ϱ͘ϯϭϯ͟ϯͲϭͬϮ͟^&KͲϭDĂŶĚƌĞůϴZ ϱϳ͕ϵϴϲ͛Ϯ͘ϴϲϳ͟ϱ͘ϯϭϯ͟ϯͲϭͬϮ͟^&KͲϭDĂŶĚƌĞůϴZ ϲϴ͕ϵϮϬ͛Ϯ͘ϴϲϳ͟ϱ͘ϯϭϯ͟ϯͲϭͬϮ͟^&KͲϭDĂŶĚƌĞůϴZ ϳϵ͕ϰϳϰ͛Ϯ͘ϴϲϳ͟ϱ͘ϯϭϯ͟ϯͲϭͬϮ͟^&KͲϭDĂŶĚƌĞůϴZ ϴϵ͕ϰϴϳ͛Ϯ͘ϴϭϯ͟ϱ͘ϴϳϱ͟KŶͬKĨĨdŽŽůǁͬyͲEŝƉƉůĞ ϵϵ͕ϰϴϴ͛Ϯ͘ϵϵϮ͟ϱ͘ϴϳϱ͟ƌƌŽǁƐĞƚ^ϭͲyDĞĐŚĂŶŝĐĂůWĂĐŬĞƌ ϭϬϵ͕ϱϬϮ͛Ϯ͘ϴϭϯ͟ϯ͘ϵϬϬ͟yͲEŝƉƉůĞ ϭϭ ϵ͕ϱϬϳ͛ϯ͘ϬϬϬ͟ϰ͘ϭϮϱ͟t>ŶƚƌǇ'ƵŝĚĞ ´ WZ&KZd/KEd/> ĂƚĞ ŽŶĞ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ ^W& &ƚ WŚĂƐĞ ŽŵŵĞŶƚƐ WZKW'ͲϮ ϭϭϯϬϮϭϭϰϯϯϭϬϳϱϭϭϬϳϵϱϲϭϯϭϲϬWZKWK^ ϳͬϭϵͬϭϯ'ͲϮ ϭϭ͕ϮϰϮ͛ϭϭ͕Ϯϳϳ͛ϭϬ͕ϳϯϮ͛ϭϬ͕ϳϰϯ͛ϲϯϱϲϬϮ͟, ϭϬͬϭϬͬϭϮ'ͲϮ ϭϭ͕ϰϯϯ͛ϭϭ͕ϰϰϬ͛ϭϬ͕ϳϵϱ͛ϭϬ͕ϳϵϳ͛ϲϳϲϬϮͲϯͬϰ͟dW,Dy ϭϬͬϯϬͬϭϯ,Ͳϭ ϭϭ͕ϰϲϱ͛ϭϭ͕ϰϴϮ͛ϭϬ͕ϴϬϲ͛ϭϬ͕ϴϭϮ͛ϲϭϳϲϬϮͲϭͬϮ͟, ϭϬͬϯϬͬϭϯ,ͲϮ ϭϭ͕ϰϴϮ͛ϭϭ͕ϰϴϱ͛ϭϬ͕ϴϭϮ͛ϭϬ͕ϴϭϯ͛ϲϯϲϬϮͲϭͬϮ͟, ϭϬͬϭϬͬϭϮ,ͲϮ ϭϭ͕ϰϴϮ͛ϭϭ͕ϱϬϳ͛ϭϬ͕ϴϭϮ͛ϭϬ͕ϴϮϬ͛ϲϮϱϲϬϮͲϯͬϰ͟dW,Dy ϭϬͬϭϬͬϭϮ,Ͳϯ ϭϭ͕ϱϯϰ͛ϭϭ͕ϱϲϵ͛ϭϬ͕ϴϯϬ͛ϭϬ͕ϴϰϮ͛ϲϯϱϲϬϮͲϯͬϰ͟dW,Dy ϭϬͬϭϬͬϭϮ,Ͳϯ ϭϭ͕ϱϵϱ͛ϭϭ͕ϲϭϴ͛ϭϬ͕ϴϱϭ͛ϭϬ͕ϴϱϵ͛ϲϮϯϲϬϮͲϯͬϰ͟dW,Dy WZKW,Ͳϰ ϭϭϲϯϲϭϭϲϱϰϭϬϴϲϱϭϬϴϳϮϲϭϴϲϬWZKWK^ dŽƉŽĨ>ŝŶĞƌ ,ĂŶŐĞƌΛϵ͕ϱϭϮ͛ ,Ͳϭ ,Ͳϯ ,ͲϮ ,Ͳϯ ´KROH ; 'ͲϮ 'ͲϮ 'Ͳϭ ,Ͳϰ 3URSRVHG:LUHOLQH9DOYH'LDJUDP .HQDL*DV)LHOG 658% >ƵďƌŝĐĂƚŽƌƚŽŐƌĞĂƐĞŚĞĂĚ ĨŽƌЬ͟ďƌĂŝĚĞĚůŝŶĞ ϭ͘ϵϬΗWŝƉĞZĂŵƐ tŝƌĞsĂůǀĞƐ WŝƉĞZĂŵƐ ϰЪ͟ŽǁĞŶŽŶŶĞĐƚŝŽŶ ϯЪ͟KƚŝƐŽŶŶĞĐƚŝŽŶ Superseded FlowlineOpen Top Tank(Monitoring Tank)2” Kill LineSRU 23B-22 Ariel Layout of Monitoring Tank and Kill Line (PROPOSED)These valves left open while pulling 1.90” tubing to monitor for flow*** 7” BOP flanged above swab valve is not pictured ***SwabValve Swanson River CURRENT WELLHEAD DRAWING SRU 23B-22 04/13/2021 Adapter, Seaboard SM-E-CLN 7 1/16 5M stdd X 3 1/8 5M stdd top, 5 ½ EN pocket Tubing hanger, TC-1A-EN, 7 X 3 ½ EUE 8rd Lift and susp, 3'’ Type H BPV profile, 5 ½ neck Valve, master, VG-M, 3 1/8 5M FE, HWO Valve, upper master, VG-M, 3 1/8 5M FE, HWO Swab V a l v e , V G - M , 3 1/8 5 M F E , H W O BHTA, Bowen, 3 1/8 5M FE (2) Wing Valves, VG-M, 3 1/8 5M FE, HWO Qty 2 Compa n i o n V a l v e , V G - M , 2 1/16 5 M F E , H W O Tbg head, Seaboard, TCM, 13 5/8 3M X 7 1/16'’ 5M, w/ 2- 2 1/16 5M SSO Valve, Seaboard, 2'’ LPO Valve, Seaboard, 2 1/16 5M FE, HWO, Qty 2 Ground level Swanson River SRU 23B-22 11 3/4 X 7 X 3 ½ Valve, Wing,SSV, VG-M, 3 1/8 5M FE w/ Halliburton Hydraulic operator 2" line to open top tank, with valves to isolate tank and use as kill line if it is necessary to pump into the wellbore. Companion valve will be open to tank while pulling 1.90" tubing from well and watched continuously for flow. 7" BOP NO FLOW CROSS PLANNED, WE WILL USE THECOMPANION VALVE ON THE TREE FOR PUMPING Ati OF Tif • • 40\�\ �y�,SA THE STATE Alaska Oil and Gas mw `�s �� 9� of T c T e Conservation Commission ALAS 333 West Seventh Avenue ®F P GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALASy' Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLCsc ') l'a ale FEB 0 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SRU 23B-22 Permit to Drill Number: 212-078 Sundry Number: 318-026 Dear Mr. Helgeson: 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, Hollis S. French it( Chair DATED this 3° day of January, 2018. RECG'5 - 1 2018 0 • STATE OF ALASKA ECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION !AN 1 201 APPLICATION FOR SUNDRY APPROVALS OTS l 30 1 e 20 AAC 25.280 AO V 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program El Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing ❑ Other: Run Cap String 2° 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development ❑✓ 212-078 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service 0 6.API Number: Anchorage Alaska 99503 50-133-10148-01 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123B Swanson River Unit(SRU)23B-22' Will planned perforations require a spacing exception? Yes ❑ No Q 9.Property Designation(Lease Number): 10.Field/Pool(s): A028406- Swanson River Field/Hemlock Oil . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,741' ° 10,902' ° 11,650' 11,860' 1,901 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 38' 22" 38' Surface 3,001' 11-3/4" 3,001' 3,001' 3,070 psi 1,510 psi Intermediate 11,000' 7" 11,000' 11,000' 6,340 psi 3,830 psi Production Liner 2,222' 4-1/2" 11,741' 10,902' 8,430 psi 7,500P si Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/L-80 9,508' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Arrowset AS1-X Mech;N/A 9,488'MD/9,488'TVD;N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development ❑✓ ' Service 0 14. Estimated Date for 15.Well Status after proposed work: February 2,2018 Commencing Operations: OIL Q - WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR ❑ SPLUG 0 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. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer@hilcorp.com �� Contact Phone: 777-8420 Authorized Signature: Date: ' f(�j(( COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 318 - 02CQ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes El No ❑ Spacing Exception Required? j u 15 r! �_23 q p 9 P q Yes ❑ No Subsequent Form Required: ! Li._ ! �d.� � :w�e�;� �, I_�J - 1 2�18 LO)cf\ APPROVED BY 1 Approved by: COMMISSIONER THE COMMISSION Date: t 11 )ie) —21,, SubmiForm and Form 10-403 Revised 4/2017 Approved applicatio v I1..04N date of approval. �//�/ Attachments in Duplicate • • Well Prognosis Well: SRU 23B-22 IIilcorp Alaska,LLQ Date: 1/19/2018 Well Name: SRU 23B-22 API Number: 50-133-10148-01 Current Status: Active Gas Well Leg: N/A Estimated Start Date: February 2nd, 2018 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 212-078 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: —2,112 psi @ 10,858' TVD (Based on BHP buildup 4-12-13) Max. Potential Surface Pressure: — 1,901 psi (Based on 0.1 psi/ft to surface) Brief Well Summary SRU 23B-22 was sidetracked from the SRU 14-22 Well in September of 2012. The well was completed in the Hemlock benches 2 and 3 and in the lower lobe of the G-2. The upper lobe of the G-2 was added in July of 217 2013. In October 2013 the Hemlock bench 1 and bench 2 were added. ¶.S Cl , � , In June of 2014 a tubing tail extension consisting of 960' of 1.9"tubing was added to the bottom of the tubing string in order to extend the tubing down inside of the 4-1/2" liner. The purpose of this work/sundry is to install a capillary injection string to help minimize slugging and decrease the flowline and tubing pressures. Procedure: 1. MIRU Cap String Truck, PT lubricator to 3,000 psi Hi 250 Low. 2. PU 3/8" capillary string. RIH and set at+/-9,480' (+/-). 3. Set spool of remaining line near well. 4. Rig down Cap String Truck. 5. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic H . III Soldotna SRU 23B-22 Soldotna Creek Unit ACTUAL SCHEMATIC Completion Ran: 10/11/2012 PTD:212-078 llilcuro Alaska,LLC. API: 50-133-10148-01 Ground Elev:239'Above MSL KB-THF:19.00' 2z°° 1 1 L CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 22" Conductor - - - Surf 38' 11-3/4" Surf.Csg 47 J-55 BTC 11.00" Surf 3,001' 29 N-80 BTC 6.184" Surf 114' 23 N-80 BTC 6.366" 114' 4,886' 11-3/4"4 2 7" Intermediate 26 N-80 BTC 6.276" 4,886' 6,781' 1 a 29 N-80 BTC 6.184" 6,781' 8,565' a 29 P-110 BTC 6.184" 8,565' 9,720' _ 11 3 ilii 1 4-1/2" Prod Lnr 12.6 N-80 IBT 3.958" 9,512' 11,982' r TUBING DETAIL 3-1/2" Production 9.3 L-80 8RD 2.992" Surf 9,508' 1 4 1 1.900" V-String 2.75 L-80 10RD 1.610" 9,502' 10,462' V.: JEWELRY DETAIL No. Depth ID OD Item 5 1 1 19' 2.992" Tubing Hanger 2 2,704' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD I 3 5,004' 2.867" 5.313" 31/2"SFO-1 Mandrel 8RD 6 OR i a i0 4 6,831' 2.867" 5.313" 3--1/2"SFO-1 Mandrel 8RD 5 7,986' 2.867" 5.313" 3-1/2"SFO1 Mandrel 8RD 6 8,920' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD 7 9,474' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD 60 7 p '1,0 8 9,487' 2.813" 5.875" On/Off Tool w/X-Nipple I. ? 9 9,488' 2.992" 5.875" Arrowset AS1-X Mechanical Packer 10 9,502' 2.813" 3.900" X-Nipple +_g,t' 8 i h 11 9,507' 3.000" 4.125" WL Entry Guide _ ``i r A 9,502' 1.600" 2.850" Profile Hanger Sub l* Im 1 I e% B 10,462' 1.135" 1.900" XN-Nipple(1.250"X;1.135"XN) 9 I I. 11 10 �. A i Velocity String Installed 6/08/14 1.900" 48 jts of 1.900"2.75#NU lORD(20'jts;string wt 5,200#) 11 11 1 Top of Liner Top Bottom " Hanger @ 9,512' MD 9,502' 10,462' io I TVD 9,502' 10,382' id 7" I. B PERFORATION DETAIL 0; gp Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 7/19/13 G-2 11,242' 11,277' 10,732' 10,743' 6 35 60 2"HC IN 10/10/12 G-2 11,433' 11,440' 10,795' 10,797' 6 7 60 2-3/4"TCP HMX 441 At G-2 10/30/13 H-1 11,465' 11,482' 10,806' 10,812' 6 17 60 2-1/2"HC 1( l' 10/30/13 H-2 11,482' 11,485' 10,812' 10,813' 6 3 60 2-1/2"HC 110/10/12 H-2 11,482' 11,507' 10,812' 10,820' 6 25 60 2-3/4"TCP HMX G-2 10/10/12 H-3 11,534' 11,569' 10,830' 10,842' 6 35 60 2-3/4"TCP HMX 10/10/12 H-3 11,595' 11,618' 10,851' 10,859' 6 23 60 2-3/4"TCP HMX H-1 H-2 pi H-3 6 H-3 4-1/2" ii . 6"hole PBTD=11,654'MD/10,871'TVD TD=11,741'MD/10,902'TVD Max Deviation 72°@ 11,182' Max Dogleg 8.8°/100'@ 9,926' Downhole Revised:6/08/14 Updated by STP 6/13/14 H . � Soldotna Creek Unit Well: SRU 23B-22 PROPOSED SCHEMATIC Completion Ran:10/11/2012 PTD:212-078 Ilileorp Alaska,LLC API: 50-133-10148-01 Ground Elev:239'Above MSL KB-THF:19.00' l L CASING DETAIL 22" 41 0 Size Type Wt Grade Conn. ID Top Btm 22"42 Conductor - - - Surf 38' 14, Itt 11-3/4" Surf.Csg 47 J-55 BTC 11.00" Surf 3,001' 29 N-80 BTC 6.184" Surf 114' 2 23 N-80 BTC 6.366" 114' 4,886' 11-3/4" i 7" Intermediate 26 N-80 BTC 6.276" 4,886' 6,781' G !f+ 29 N-80 BTC 6.184" 6,781' 8,565' i 29 P-110 BTC 6.184" 8,565' 9,720' 3 4-1/2" Prod Lnr 12.6 N-80 IBT 3.958" 9,512' 11,982' TUBING DETAIL 11 I: 3-1/2" Production 9.3 L-80 8RD 2.992" Surf 9,508' 4 , 1.900" V-String 2.75 L-80 1ORD 1.610" 9,502' 10,462' 0 4 I ii JEWELRY DETAIL No. Depth ID OD Item 5 1 19' 2.992" - Tubing Hanger 2 2,704' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD (ti t 1/PJ 3 5,004' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD iii ili 6 4 6,831' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD 5 7,986' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD 6 8,920' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD 7 9,474' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD 7 Mg 1 8 9,487' 2.813" 5.875" On/Off Tool w/X-Nipple Ili 9 9,488' 2.992" 5.875" Arrowset AS1-X Mechanical Packer 10 9,502' 2.813" 3.900" X-Nipple i 61 r I: 11 9,507' 3.000" 4.125" WL Entry Guide 8 A 9,502' 1.600" 2.850" Profile Hanger Sub 40 I LO I B 10,462' 1.135" 1.900" XN-Nipple(1.250"X;1.135"XN) 9 1, lO f A 11 Top of Liner Capillary String Proposed to install Hanger @ 9,512' 3/8" 2205 Stainless Steel - , Top Bottom 7" itP I MD 0' 9,480' o `ki TVD 0' 9,480' k4 P4: t• Velocity String Installed 6/08/14 1.900" 48 jts of 1.900"2.75#NU LORD(20'jts;string wt 5,200#) ,NI( Top Bottom 1, VG-2 MD 9,502' 10,462' TVD 9,502' 10,382' I t) G-z PERFORATION DETAIL fe Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 14-1 7/19/13 G-2 11,242' 11,277' 10,732' 10,743' 6 35 60 2"HC H-2 10/10/12 G-2 11,433' ' 11,440' • 10,795' 10,797' 6 7 60 2-3/4"TCP HMX 10/30/13 H-1 11,465' ' 11,482' 10,806' 10,812' 6 17 60 2-1/2"HC 1. 10/30/13 H-2 11,482' • 11,485' • 10,812' 10,813' 6 3 60 2-1/2"HC H-3 10/10/12 H-2 11,482' • 11,507' • 10,812' 10,820' 6 25 60 2-3/4"TCP HMX r 10/10/12 H-3 11,534' . 11,569' • 10,830' 10,842' _ 6 35 60 2-3/4"TCP HMX H-3 10/10/12 H-3 11,595' • 11,618' • 10,851' 10,859' 6 23 60 2-3/4"TCP HMX 1.4 4-1/2" ,ai _ .+�'Jdi 6"hole PBTD=11,654'MD/10,871'TVD TD=11,741'MD/10,902'TVD Max Deviation 72°@ 11,182' Max Dogleg 8.87100'@ 9,926' Downhole Revised:6/08/14 Updated by DMA 07-07-17 o - 9 0 ✓ N 9 a a)a) a) a) 0 o 0 Z C N u)H N .0 r C C C C 2 M 0 N Q0 a0 a0 a0 c0 v e0 M- >I 6 co .T. 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Q O CO Q O D 2 C A U tx a D o a 7.1 a Co C E a E O E o o 2 E 0 a° , E E a 2 3 L i 0 a 0 0 0 a ° 0 0 STATE OF ALASKA AL 4 OIL AND GAS CONSERVATION COMML,—.ON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate LH Other U Tubing Velocity String Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory ❑ 212-078 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99504 50-133-10148-01 7.Property Designation(Lease Number): 8.Well Name and Number: A028406 Swanson River Unit(SRU)23B-22 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): 1 N/A Swanson River Field/Hemlock Oil 11.Present Well Condition Summary: Total Depth measured 11,741 feet Plugs measured N/A feet true vertical 10,902 feet Junk measured N/A feet .1 11 N ] (} 20 i Effective Depth measured 11,650 feet Packer measured 9,488 feet .AfR•��`"'"lC('� true vertical 11,860 feet true vertical 9,488 feet '+ Casing Length Size MD TVD Burst Collapse Structural Conductor 38' 22" 38' 38' Surface 3,001' 11-3/4" 3,001' 3,001' 3,070 psi 1,510 psi Intermediate 11,000' 7" 11,000' 11,000' 6,340 psi 3,830 psi Production Liner 2,222' 4-1/2" 11,741' 10,902' 8,430 psi 7,500 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 9,508'MD 9,508'TVD Arrowset Packers and SSSV(type,measured and true vertical depth) AS1-X Mech;N/A 9,488'MD 9,488'TVD N/A;N/A 12.Stimulation or cement summa squeeze : N/A q summary: 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: 38 0 123 1150 340 Subsequent to operation: 51 33 154 950 275 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C.O.Exempt: N/A Contact Stan Porhola Email sporhola pnhilcorp.Com Printed Name Stan Porhola Title Operations Engineer 1 Signature ��L "" Phone907-777-8412 Date60 1' ///L� 2,‘ 6.ei.iy- RBC S UN 17206 Form 10-404 Revised 10/2012 Wy Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 23B-22 50-133-10148-01 212-078 6/7/14 6/8/14 Daily Operations: 06/07/2014-Saturday RU equipment and lub, P.T. lub 250- 1,500. RIH with braided line to 10,862', could not work deeper, too high of deviation. POOH. RIH,tag X nipple 9,499' RKB. POOH. Pump 15 BBLS lease water, well on vacuum monitor pressure, no pressure build. SDFN. 06/08/2014-Sunday RU Crane, stab BOP's pump kill fluid, ensure well is dead. RU power tongs, wrong size tongs, remove tongs. RIH with 960' of 1.9" tbg with plug on bottom, set in X-nipple @ 9,499'. POOH, pump 8 bbls lease water to release tbg plug. RDMO and RTP. Soldotna Creek Unit/11/2012 • Well: SRU 23B-22 ACTUAL SCHEMATIC Completion Ran: 10 PTD:212-078 Hilcorp Alaska,LU API: 50-133-10148-01 Ground Elev:239'Above MSL KB-THF:19.00' '., 1 0 L CASING DETAIL 22 ! Size Type Wt Grade Conn. ID Top Btm f 22" Conductor - Surf 38' ., ih, 11-3/4" Surf.Csg 47 J-55 BTC 11.00" Surf 3,001' 29 N-80 BTC 6.184" Surf 114' 41 23 N-80 BTC 6.366" 114' 4,886' 2 11-3/4" le 7" Intermediate 26 N-80 BTC 6.276" 4,886' 6,781' �� 29 N-80 BTC 6.184" 6,781' 8,565' 29 P-110 BTC 6.184" 8,565' 9,720' 3 SIR ' i 4-1/2" Prod Lnr 12.6 N-80 IBT 3.958" 9,512' 11,982' i I 1 TUBING DETAIL ' 3-1/2" Production 9.3 L-80 8RD 2.992" Surf 9,508' ,I 4 °tl 1.900" V-String 2.75 L-80 10RD 1.610" 9,502' 10,462' JEWELRY DETAIL No. Depth ID OD Item 5 ISE 1 ")i ,4t, 1 19' 2.992" Tubing Hanger 2 2,704' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD 9. ' 3 5,004' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD 6 4 6,831' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD 1 F! 5 7,986' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD ip 6 8,920' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD 7 9,474' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD ' C7 i 't8 9,487' 2.813" 5.875" On/Off Tool w/X-Nipple pV I. l 9 9,488' 2.992" 5.875" Arrowset AS1-X Mechanical Packer y 10 9,502' 2.813" 3.900" X-Nipple yt 8 • 11 9,507' 3.000" 4.125" WL Entry Guide S A 9,502' 1.600" 2.850" Profile Hanger Sub Nit I,II I . l "'� 8 10,462' 1.135" 1.900" XN-Nipple(1.250"X;1.135"XN) 9 1 ` : 1 v4 10 A t,1 Velocity String Installed 6/08/14 I ' 1.900" 48 jts of 1.900"2.75#NU LORD(20'jts;string wt 5,200#) ;'a 11 I Top of Liner Top Bottom Hanger @ 9,512' MD 9,502' 10,462' II TVD 9,502' 10,382' Dr 7" 1 i c B PERFORATION DETAIL l' • L'", Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 7.1 '7",( 7/19/13 G-2 11,242' 11,277' 10,732' 10,743' 6 35 60 2"HC r 4 10/10/12 G-2 11,433' 11,440' 10,795' 10,797' 6 7 60 2-3/4"TCP HMX 1,,, 10/30/13 H-1 11,465' 11,482' 10,806' 10,812' 6 17 60 2-1/2"HC 9 7 G-2 10/30/13 H-2 11,482' 11,485' 10,812' 10,813' 6 3 60 2-1/2"HC ,,'14 ,) 10/10/12 H-2 11,482' 11,507' 10,812' 10,820' 6 25 60 2-3/4"TCP HMX .4.,_ G-2 10/10/12 H-3 11,534' 11,569' 10,830' 10,842' 6 35 60 2-3/4"TCP HMX P 10/10/12 H-3 11,595' 11,618' 10,851' 10,859' 6 23 60 2-3/4"TCP HMX H-1 tit __t_ H-2 H-3 'i i `r s H-3 X. '' • 'S V 4-1/2" t, 6"hole PBTD=11,654'MD/10,871'ND TD=11,741'MD/10,902'ND Max Deviation 72°@ 11,182' Max Dogleg 8.8°/100'@ 9,926' Downhole Revised:6/08/14 Updated by STP 6/13/14 STATE OF ALASKA EIVED AL 1 OIL AND GAS CONSERVATION COMM, JN EC • REPORT OF SUNDRY WELL OPERATIONS NOV 2 6 2013 1.Operations Abandon LI Repair Well U Plug Perforations U Perforate U• Other U AOGCC Performed: Alter Casing ❑ Pull Tubing El Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑., Exploratory ❑ 212-078 . 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99504 50-133-10148-01 ' 7.Property Designation(Lease Number): 8.Well Name and Number: A028406 • Swanson River Unit(SRU)23B-22 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Hemlock Oil • 11.Present Well Condition Summary: Total Depth measured 11,741 feet Plugs measured N/A feet true vertical 10,902 feet Junk measured N/A feet Effective Depth measured 11,650 feet Packer measured 9,488 feet true vertical 11,860 feet true vertical 9,488 feet Casing Length Size MD ND Burst Collapse Structural Conductor 38' 22" 38' 38' Surface 3,001' 11-3/4" 3,001' 3,001' 3,070 psi 1,510 psi Intermediate 11,000' 7" 11,000' 11,000' 6,340 psi 3,830 psi Production Liner 2,222' 4-1/2" 11,741' 10,902' 8,430 psi 7,500 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 9,508'MD 9,508'ND Arrowset Packers and SSSV(type,measured and true vertical depth) ASI-X Mech;N/A 9,488'MD 9,488'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: 86 255 129 1050 320 Subsequent to operation: 59 238 126 1080 320 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development❑., ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil I=1., Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-561 Contact Stan Porhola Email sporholaahilcorp.com Printed Name / / Stan Porhola Title Operations Engineer Signature i,�, /04.1,.1\_ Phone 907-777-8412 Date j 12_5- f 3 1 74, L4.12 ;Br ,QC' DEC 13A Form 10-404 Revised 10/2012 0r_ /`ji%7 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 23B-22 50-133-10148-01 212-078 10/29/13 10/30/13 Daily Operations: 10/29/2013 -Tuesday Mobe to location. Rig up Pollard E-line lubricator, pressure test to 250 psi low and 3000 psi high. Ran in hole with 2-1/2" x 20' HC, 6 spf, 60 deg perf gun down to 11,390'. Could not go any further. Had roller boogies on tools. POOH and switch boogies around and added wt. RIH to same depth and same thing. Consulted with team and decided to get hot oiler out in the morning. 10/30/2013 -Wednesday Mobe to location. Rig up Pollard E-line lubricator, pressure test to 250 psi low and 3000 psi high. Ran in hole with 2-1/2" x 20' HC, 6 spf, 60 deg perf gun w/roller boogies. Rigged up Hot oiler to well. Pumped 12 bbls KCL and well went on vacuum. Got tools to fall to 11,490'. Spotted perf gun from 11,485'to 11,465'tied into Pollard CCL/GR log dated 9-OCT-12. Tubing pressure was 0 psi. Fired gun and saw no increase. Fluid level was around 3,000' before well going on vacuum. Rig down lubricator and move to SRU 12-15. Soldotna Creek Unit Well: SRU 23B 22 ACTUAL SCHEMATIC Completion Ran: 10/11/2012 PTD:212-078 Ha,.,,„ %I,&,.i.i.c API: 50-133-10148-01 Ground Elev:239'Above MSL KB-THF: 19.00' 1 CASING DETAIL 22" Size Type Wt Grade Conn. ID Top Btm 22" Conductor - - - Surf 38' .. [ 11-3/4" Surf.Csg 47 J-55 BTC 11.00" Surf 3,001' 29 N-80 BTC 6.184" Surf 114' 23 N-80 BTC 6.366" 114' 4,886' 11-3/4" 2 7" Intermediate 26 N-80 BTC 6.276" 4,886' 6,781' 29 N-80 BTC 6.184" 6,781' 8,565' 29 P-110 BTC 6.184" 8,565' 9,720' 3) fU 4-1/2" Prod Lnr 12.6 N-80 IBT 3.958" 9,512' 11,982' TUBING DETAIL 3-1/2" Production 9.3 L-80 8RD 2.992" Surf 9,508' 4n—I JEWELRY DETAIL S) t>r No. Depth ID OD Item 1 19' 2.992" - Tubing Hanger 2 2,704' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD 3 5,004' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD 64 6,831' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD r ill 5 7,986' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD • 6 8,920' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD 7 9,474' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD 7 i 8 9,487' 2.813" 5.875" On/Off Tool w/X-Nipple 9 9,488' 2.992" 5.875" Arrowset AS1-X Mechanical Packer 10 9,502' 2.660" 3.900" XN-Nipple 11 9,507' 3.000" 4.125" WL Entry Guide 8 / ,, , 9 i a 10 XN 11 Top of Liner ® Hanger @ 9,512' 7„ L • PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 7/19/13 G-2 11,242' 11,277' 10,732' 10,743' 6 35 60 2"HC 10/10/12 G-2 11,433' 11,440' 10,795' 10,797' 6 7 60 2-3/4"TCP HMX G-2 ✓10/30/13 H-1 11,465' 11,482' 10,806' 10,812' 6 17 60 2-1/2"HC A0/30/13 H-2 11,482' 11,485' 10,812' 10,813' 6 3 60 2-1/2"HC 10/10/12 H-2 11,482' 11,507' 10,812' 10,820' 6 25 60 2-3/4"TCP HMX G-2 10/10/12 H-3 11,534' 11,569' 10,830' 10,842' 6 35 60 2-3/4"TCP HMX 10/10/12 H-3 11,595' 11,618' 10,851' 10,859' 6 23 60 2-3/4"TCP HMX H-1 • H-2 • r i Z H-3 r H-3 q , 4-1/2"4 ... , 6"hole PBTD=11,654'MD/10,871'ND TD=11,741'MD/10,902'ND Max Deviation 72°@ 11,182' Max Dogleg 8.8°/100'@ 9,926' Downhole Revised:10/30/13 Updated by STP 11/19/13 •ioug •£10Z `zagoiop 3o sup u J vQ zauotssturtuoD `.4u4D zalszaod • Stpup `1Ciazaou!S •puaNaam.10 Supgou u uo siie3 /Cup Pz£Z alp It 'uP 2uDizom lxau alp .10 `za ai stti1 Io am) alp 2utmoiloi Sup Pz£Z alp uo L\id 0£:t (q paniaoaz st 1.t Ii Xiatup paiapisuoo st uopuzaptsuooaz zoj lsanbaz v •uouezapisuooaz zoj uot1uotidde uu XJDOV alp gum aitd Sm pt Xq papally uoszad u `umocis asneo pool zoJ D i oov alp sr Ow zatiyinl dons zo `uotstoap Siq to aotlou uaUnzm .Ingle si ep OZ uttiltm 080'SO'I£ SFS ut paptnozd sy •tuzol pasoioua alp ut ;no las ienozdde to suompuoo alp a1ou asuaid 'iiam paouazalaz anoqu 042 01 2upuiaz iunozddd Xzpung zol uouuogddd panozdde oq st pasoioug :uiotizod 'JAI zu0Q 19S-£I£ :zaqulnm czpunS ZZ-S£Z I12IS `iood II0 )iooituaH `piatd Ian!) uosuumS :02I £OS66 ?Id `02uzotioud 00I awns `0Apci lutodzaluaJ 008£ DTI `uNsui`d dzooMMH zaaut2ug suoTTezadp uiotizod ue1S 6tiSL'9L6L06 :xoJ £E41'6L .L06 :u!oW LST-10S66 oisoly 'aboJogauy �0.9V7V4.0 GflUGAV y}uanaS S M EEE 'I'IINM`dd NVHS 1ON 1 AOD _ • o 1 )JSV IVfo SPD pug P0 mspIV HIV's 'e.4'; '/&� e gdna u!s4uewy0eUVI� •Ioxdde;o e;ep 041 11104 sq; wIN i I II a eddy (ZIoZ/Ol Pes!neel)£0 4-0 L u0od pue'mod mums �l $i'h Z'v g7- C :oleo L,K NOISSI111103 3HI 213NOISSI111100 :icq panolddy / A8 O3AO2IddV 7411 ( 11 Q/— 0/ :paiinbaa wJoj luenbasgng n oN ❑ saA LpaJ!nbaa uo!;deox3 6u!oeds `L T - AON SINCIEnd :•10410 ❑ aaututa13 uo!;eool ❑ ;se'A;u6a1ul!eo!ueyoayy ❑ ;sal dOH ❑ R;u6a;u1 60Id l)s -' ..19-. :JagwnN tipunS ssau;!m Aew an!leluasaidai a;ey;os uo!ss!wwo3 A1!;0N :lenadde 10 suo!;!pu00 A1N0 3Sn NOISSIWWO3 )/,. /C)) a10O Z148-LLL-L06 auoyd --••-\27_-�„ ,G'/ ain;eu6!S Jaau!6u3 suo!;BJad0 a!;!1 eloyJod ue;S aweN pa;uud Woo•aoollyoeloyloas I!ew3 Z148-LLL-L06 :auoyd e!ou;ad uelS Pe;uo3 •e6peimoul Aw lo;sag ay;o;loaJJoO pue ani;s!6u!o6aio1 ay;law Appao Agway I'Ll ❑ OflldS ❑ HOISO :eAge;ueseidaa uo!ss!wwoo ❑ peuopuegy ❑ DVM ❑ INIO ❑ fNIM :elBa :lenoJddv leg-19n'91. ❑ papuadsn9 ❑ IdSOM ❑ Seo •Q I!O :suolleJedo 6u!ouewwo3 E1/9Z/0L :)Uom pasadad nue sn;els IIaM.5l Jo;a;ea pa;ew!ls3'4l U e3uues_ U;uawdo!anaa UWide/6ge1u; U fuo;eJo!dx3 U 40101IS d09 U weJ6oid suo!;BJed0 pope;aa :)Isompes.doidnue ssel3Ham'El ❑ lesodoid1otiewwnSuo!lduosaa :sluawy3e1IV'ZI. 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Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 67 298 118 1050 260 Subsequent to operation: 64 13 123 970 200 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development❑� Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ p 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: 313-371 Contact Stan Porhola Email sporholaahilcorp.com Printed Name 47k/0-1,4- Stan Porhola Title Operations Engineer Signature Phone 907-777-8412 Date 73( /3 c f.11.0 z RBDMS AUG - 5 .- Form 10-404 Revised 10/2012 p r ff,g- ; Submit Original Only I Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 23B-22 50-133-10148-01-00 212-078 7/19/13 7/19/13 Daily Operations: 07/19/2013-Friday Held JSA, MIRU EL. MU Gamma ray/CCL, roller bogies and 20'x 2" RTG gun. RIH to 11,490'(could not RIH deeper). PU logging correlation pass. RIH. PU and shot gun 11,257'-11,277'. POOH. MU 15'x 2" RTG gun. RIH on depth and gun did not fire. POOH. Changed PX-1 and firing head. RIH to 11,370'(could not go deeper). PU on depth and fired gun and perf 11,242'-11,257'. POOH. RDMO EL. Page 1 of 1 ° Soldotna Creek Unit Well: SRU 23B-22 ACTUAL SCHEMATIC 112-0788-210/11/2012 PTD: Hilrora Alaska,1.1.c API: 50-133-10148-01 Ground Elev:239'Above MSL KB-THF:19.00' 22 aJ 41 1 L CASING DETAIL Size Type Wt Grade Conn. ID Top Btm i,'" 4v 22" Conductor _ - - - Surf 38' r 11-3/4" _ Surf.Csg 47 J-55 BTC 11.00" Surf 3,001' 29 N-80 BTC 6.184" Surf 114' 23 N-80 BTC 6.366" 114' 4,886' 2 lit i Ai, 7" Intermediate 26 N-80 BTC 6.276" 4,886' 6,781' 29 N-80 BTC 6.184" 6,781' 8,565' !# 29 P-110 BTC 6.184" 8,565' 9,720' 1,4 3 III i 4 4-1/2" Prod Lnr 12.6 N-80 IBT 3.958" 9,512' 11,982' s,' TUBING DETAIL 3-1/2" Production 9.3 L-80 8RD 2.992" Surf 9,508' 4 SO 1 JEWELRY DETAIL No. Depth ID OD Item 81 5 1 19' 2.992" - Tubing Hanger log ,.w, 2 2,704' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD Of 3 5,004' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD 4 6,831' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD To 6 h1 5 7,986' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD *`� 6 8,920' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD 111 I 04 7 9,474' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD 40'4 7 Mk i' r 8 9,487' 2.813" 5.875" On/Off Tool w/X-Nipple 9 9,488' 2.992" 5.875" Arrowset A51-X Mechanical Packer ti� 10 9,502' 2.660" 3.900" XN-Nipple 11 11 9,507' 3.000" 4.125" WL Entry Guide 8 I 4LI Mk I *r, 9 u * ►r' at to !1 IF a 44 11 Top of Liner Hanger @ 9,512' NIP 7,, 4 k, t 464 PERFORATION DETAIL V treDate Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments tf! t 7/19/13 G-2 11,242' 11,277' 10,732' 10,743' 6 35 60 2"HC 10/10/12 G-2 11,433' 11,440' 10,795' 10,797' 6 7 60 2-3/4"TCP HMX *t 2 10/10/12 H-2 11,482' 11,507' 10,812' 10,820' 6 25 60 2-3/4"TCP HMX So 5, 1, 10/10/12 H-3 11,534' 11,569' 10,830' 10,842' 6 35 60 2-3/4"TCP HMX : 4 10/10/12 H-3 11,595' 11,618' 10,851' 10,859' 6 23 60 2-3/4"TCP HMX 4 A G2 ,, r t) t H-2 V -'4-edti H-3 4 H-3 X0 Ilizia4-1/2" i+� 6"hole PBTD=11,654'MD/10,871'TVD TD=11,741'MD/10,902'ND Max Deviation 72°@ 11,182' Max Dogleg 8.8°/100'@ 9,926' Downhole Revised:7/19/2013 Updated by STP 7/29/2013 43C, 1'/%%s, THE STATE Alaska Oil and Gas °ALAS+,�` M o c r �.;osel vai�ioll ©1iYlIril1SS)iOn wR GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF y�P Anchorage, Alaska 99501-3572 -ALASMain: 907 279.1433 Fax: 907 276.7542 Stan Porhola Operations Engineer Hilcorp Alaska, LLC c G ai— Q /7 3800 Centerpoint Drive, Suite 100 l Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SRU 23B-22 Sundry Number: 313-3 71 Dear Mr. Porhola: 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 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, Ir.., ;0/...4.02(110..... ...' Cathy P. 'oerster Chair DATED this / day of July, 2013. Encl. ',k'I RECEIVED STATE OF ALASKA A JUL 15013 ALASKA OIL AND GAS CONSERVATION COMMISSION ,7—.f 7/!ci/ 43 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair Well Change Approved Program❑ Suspend❑ Plug Perforations ❑ Perforate Q • Pull Tubing❑ Time Extension❑ Operations Shutdowi❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing Other. ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill l Number Exploratory ❑ Development ❑✓ .. 212-078 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service CI 6.API Number. Anchorage,Alaska 99503 50-133-10148-01 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123A Swanson River Unit(SRU)23&22 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): A028406 • Swanson River Field/Hemlock Oil ' 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): 11,741 10,902 • 11,650 10,860 WA N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 38' 22" 38' Surface 3,001' 11-3/4" 3,001' 3,001' 3,070 psi 1,510 psi Intermediate 11,000' 7" 11,000' 11,000' 6,340 psi 3,830 psi Production Liner 2,222' 4-1/2" 11,741' 10,902 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/L-80 9,508' Packers and SSSV Type: Packers and SSSV MD(t)and ND(ft): Arrowset AS1-X Mech;N/A 9,488'MD/9,488'ND;N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after prop.sed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphicn Development n Service n 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 07/17/13 Oil Q Gas ❑ WDSPL ❑ Suspended Ei 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG El — 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email sDorhola ahilcorD.corrm Printed Name Stan Porhola Title Operations Engineer / Signature i4��p' �.�-- Phone 907-777-8412 Date 7 [ S f 3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 31 3.31 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test El Location Clearance ❑ /h Other: RBDMS JUL 2 3 201S� Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: / p —Lr Q(4 APPROVED BY Approved by:Alp 9,44,1_,„._ COMMISSIONER THE COMMISSION Date: 7 /9 .� 3 7,7,3 Submit Form and � All)Farm 10-403(Rsed 10/2012) Approved applicatiCis RIG2INALe date of app vol. Atachments in e ki ' A Well Prognosis Well: SRU 23B-22 Hilcorp Alaska,LL Date:7/15/2013 Well Name: SRU 23B-22 API Number: 50-133-10148-01 Current Status: Gaslifted Oil Producer Leg: N/A Estimated Start Date: July 17th, 2013 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 212-078 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: —2,123 psi @ 10,859' TVD (Static survey April 2013 below bottom zone 11,618' MD) Maximum Expected BHP: —2,123 psi @ 10,859' TVD (Static survey April 2013 below bottom zone 11,618' MD) Max. Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) will balance reservoir pressure at 5,345 ft. TVD. Brief Well Summary This well was drilled with the Doyon Arctic Fox in August 2012 to October 2012 as a sidetrack of the original • wellbore SRU 14-22. The completion was ran with the Williams Rig#405 in October 2012. Notes Regarding Wellbore Condition • The well was sidetracked from vertical at 9,718' MD. Maximum dogleg is 8.8° per 100'. • Wellbore deviation at the perforations is approximately 70 degrees. Maximum deviation is 72 degrees. OBJECTIVE OF WORKOVER Add new perfs in the Tyonek G-2 (existing perfs are in the Hemlock H-2, H-3 and Tyonek G-2). J E-line procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU 2.125" 6 spf HC r line guns. 3. RIH and perforat terval from 11,242'-11,277' (35'). 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. 4. RD E-line. 5. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic • Soldo Well: SRtna UCreek 23B-22Unit .ii ACTUAL SCHEMATIC Completion Ran: 10/11/2012 PTD: 212-078 na."" .1:..1"'1.1.1, API: 50-133-10148-01 Ground Elev:239'Above MSL KB-THF: 19.00' 1 CASING DETAIL 22" Size Type Wt Grade Conn. ID Top Btm 22" Conductor - - - Surf 38' • 11-3/4" Surf.Csg 47 1-55 BTC 11.00" Surf 3,001' ' 29 N-80 BTC 6.184" Surf 114' 2 23 N-80 BTC 6.366" 114' 4,886' 11-3/4" 7" Intermediate 26 N-80 BTC 6.276" 4,886' 6,781' 29 N-80 BTC 6.184" 6,781' 8,565' 29 P-110 BTC 6.184" 8,565' 9,720' 3 F 111 4-1/2" Prod Lnr 12.6 N-80 IBT 3.958" 9,512' 11,982' TUBING DETAIL 3-1/2" Production 9.3 L-80 8RD 2.992" Surf 9,508' 4) hl JEWELRY DETAIL �) No. Depth ID OD _ Item 111 1 19' 2.992" - Tubing Hanger 2 2,704' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD 3 5,004' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD f , 4 6,831' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD � 5 7,986' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD 6 8,920' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD h 7 9,474' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD k 7 I' iii 4 8 9,487' 2.813" 5.875" On/Off Tool w/X-Nipple V I '~ 9 9,488' 2.992" 5.875" Arrowset AS1-X Mechanical Packer 10 9,502' 2.660" 3.900" XN-Nipple H ,. �' 11 9,507' 3.000" 4.125" WL Entry Guide 9 al 1 4: IO E 11 Top of Liner +. Hanger @ 9,512' 7" i , : S PERFORATION DETAIL - Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 10/10/12 G-2 11,433' 11,440' 10,795' 10,797' 6 7 60 2-3/4"TCP HMX I, 10/10/12 H-2 11,482' 11,507' 10,812' 10,820' 6 25 " 60 2-3/4"TCP HMX 10/10/12 H-3 11,534' 11,569' 10,830' 10,842' 6 35 . 60 2-3/4"TCP HMX 10/10/12 H-3 11,595' 11,618' 10,851' 10,859' 6 23 60 2-3/4"TCP HMX G-2 id 6 k. H-2 I. = H-3 1_ h S H-3 kA - •rr 4-1/2"4 ' , 'IN, 6"hole PBTD=11,654'MD/10,871'ND TD=11,741'MD/10,902'ND Max Deviation 72°@ 11,182' Max Dogleg 8.8°/100'@ 9,926' Downhole Revised:10/11/2012 Updated by STP 7/15/2013 • Soldotna Creek Unit Well: SRU 23B-22 Proposed Completion PROPOSED S C H E M AT I C PTD:212-078 H'i`"'p Alaxha,LLC API: 50-133-10148-01 Ground Elev:239'Above MSL J KB-THF:19.00' 22" a 1 L CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 22" Conductor - - - Surf 38' '. 11-3/4" Surf.Csg 47 J-55 BTC 11.00" Surf 3,001' q 29 N-80 BTC 6.184" Surf 114' ,6 '• 23 N-80 BTC 6.366" 114' 4,886' 2 7" Intermediate 26 N-80 BTC 6.276" 4,886' 6,781' 11-3/4" i 29 N-80 BTC 6.184" 6,781' 8,565' 29 P-110 BTC 6.184" 8,565' 9,720' o 30:31) 4 4-1/2" Prod Lnr 12.6 N-80 IBT 3.958" 9,512' 11,982' TUBING DETAIL C 3-1/2" Production 9.3 L-80 8RD 2.992" Surf 9,508' 4 IMO JEWELRY DETAIL 1 55 No. Depth ID OD Item 1 19' 2.992" - Tubing Hanger L« ., 2 2,704' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD 4" ` 3 5,004' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD 1 4 6,831' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD 6ircz5 7,986' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD 6 8,920' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD 7 9,474' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD 7 Mk ; (( 8 9,487' 2.813" 5.875" On/Off Tool w/X-Nipple 9 9,488' 2.992" 5.875" Arrowset AS1-X Mechanical Packer r' 10 9,502' 2.660" 3.900" XN-Nipple 11 8 11 9,507' 3.000" 4.125" WL Entry Guide It' 61 9 y, 1 1 gi'41 7 ! —�t 4 10 a7! g MI Ni l 11 _ Top of Liner MO Hanger @ 9,512' r 7" 4 i, �� 7 PERFORATION DETAIL I.` `, Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments tt; Proposed G-2 11,242' 11,277' 10,732' 10,743' 6 35 60 2-1/8"HC it 4,1 10/10/12 G-2 11,433' 11,440' 10,795' 10,797' 6 7 60 2-3/4"TCP HMX G-2 10/10/12 H-2 11,482' 11,507' 10,812' 10,820' 6 25 60 2-3/4"TCP HMX 9; 10/10/12 H-3 11,534' 11,569' 10,830' 10,842' 6 35 60 2-3/4"TCP HMX �l 4 10/10/12 H-3 11,595' 11,618' 10,851' 10,859' 6 23 60 2-3/4"TCP HMX G-2 4 H-2 P 6 H-3 if *S !1 H-3 o w 4-1/2" . ,. 6"hole PBTD=11,654'MD/10,871'ND TD=11,741'MD/10,902'ND Max Deviation 72'@ 11,182' Max Dogleg 8.8°/100'@ 9,926' Downhole Proposed Updated by STP 7/15/2013 Gee Te r•�w¢�eaau Hilcorp Alaska, LLC Geo Tech I[ 3800 Centerpoint Drive, Suite 100 .1111 RECEIVED Anchorage, AK 99503 Tele: 907 777-8337 MAY 1 3 2013 Ililcnrp Mao131,HA; Fax: 907 777 8510 E-mail: doudean@hilcorp.com /kQ3CC 2.- t DATE 5/13/2013 To: AOGCC Makana Bender 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL SRU 23B-22 Prints/CD Hilcorp_SRU 236-22 FieldSurvey_9700-11741.pdf 7 Hilcorp_SRU 236-22 Surveys_9700-11741.txt Hilcorp_SRU 23B-22_2MD 4MPR_TC_9732-.11741.PDF Hilcorp_SRU 2313-22_2TVD 4MPR._TC_9732-1:174:L.PDF Hilcorp_SRU 238-22_4MPR_TC_9732-l:1741.Ias Hilcorp_SRU 23B-22_5MD_4MPR_TC_9732-11741.PDF Hilcorp_SRU 238-22_5ND 4MPR_TC_9732-11741.PDF Ottirri Hilcorp_SRU 236-22_Time Pressure Log_09062012_09222012.PDF Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: , .1 • Date: w 'Ari STATE OF ALASKA — ALASr'A OIL AND GAS CONSERVATION COMMIJjION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil 0 Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25.105 20AAc 25.110 Development 0 . Exploratory❑ GINJ ❑ WINJ❑ WAG ❑ WDSPL❑ No.of Completions: 1 'a M l 113 Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: Hilcorp Alaska, LLC Comp. 104/2012 212078 3.Address: 6. Date Spudd : 2 i m,<3 13.API Number: 3800 Centerpoint Drive,Suite 100 Anchorage,AK 99503 *13 t L012 50-133-10148-01-00 • 4a. Location of Well(Governmental Section): 7. Date TD Reached: z �z.,14.Well Name and Number: Surface: 738'FSL,637'FWL,Sec 22,T8N, R9W,SM • `J.Z�` I2 rU Swanson River Unit(SRU)23B-22 • Top of Productive Horizon: 8. KB(ft above MSL): 259 15. Field/Pool(s): 1,440'FSL, 1,345'FWL,Sec 22,T8N, R9W,SM GL(ft above MSL): 239 Total Depth: 9. Plug Back Depth(MD+TVD): Swanson River Field Hemlock Oil • 1,764'FSL, 1,679'FW_,Sec 22,TON, R9W,SM • 11,654'/10,871' • 4b. Location of Well(State Base Plane Coordinates, NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 348436.9 • y- 2472450.3 t Zone- 4 • 11,741 /10,902 • FED A028406 Swanson River Unit TPI: x- 349114.6 y- 2473135.6 Zone- 4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth: x- 349448.7 y- 2473479.6 Zone- 4 N/A N/A 18. Directional Survey: Yes 0 No ❑ Definitive MWD Survey 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 MC 25.050) N/A (ft MSL) N/A 1. Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-dnlVLateral Top Window MD/TVD: Formation Log MD&TVD, LWD Combo Log MD&TVD,Gas Ratio Log MD&TVD,Drilling Dynamics Log MD&TVD, 9,718'/9,718' )FTII Loq MD 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT (:ASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 11-3/4" 47 J-55 Surface ' 3,001' Surface 3,001' _ 7" 29 N-80-P110 Surface .1-00ff 171,0' Surface J1-,-e ` W1KJ7.+- - 172-o tiPtc, i•S•!c . 4.5" 12.6# L-80 9,519' 11,741' 9,519' 10,902' 6" 52 bbls Class B 15.6 ppg N/A 24.Open to production or injection? Yes 0 No ❑ 25. TUBING RECORD If Yes, list each interval open(MD+TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3-1/2" 9,508' 9,488'/9,188' Please see attached well schematic. 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes❑ No 0 w J DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED i .47RECEIVED -, NOV 0 9 201? :7 PRODUCTION TEST ''gate First Production: Method of Operation(Flowing,gas lift,etc.): Q OGCC 10_/13/2012 Flowing _ /1 Date of Test: Hours Tested: Production for Oil-Bbl• Gas-MCF. Water-Bbl: 'Choke Size: Gas-Oil Ratio: 0/15/2012 3 hours Test Period ..p..43.5 307 9 3 7,049 ;low Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 340 700 24-Hour Rate 349 2,460 71 42.7 CORE DATA Conventional Core(s)Acquired? Yes❑ No 0 Sidewall Cores Acquired? Yes❑ No 0 it Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. RBDMS NOV 13 2012(_S\W1, Form 10-407 Revised 10/2012 CONTINUEDON REVERSE� Q� Submit original only v,J',` 1.3•/5 Ay) ,z_. c3 6 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑Yes L'10 If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, G1 ST 11,112 10,691 and submit detailed test information per 20 AAC 25.071. G2ST 11,241 10,731 HKT 11,460 10,804 H2ST 11,481 10,811 H3ST 11,533 10,829 H4ST 11,638 10,866 TD 11,741 10,902 Formation at total depth: 31. List of Attachments: Final Schematic,Daily Report Summary, Definitive Directional Survey,Casing Tally,Cementing Reports Days vs. Depth Graph,MW vs. Depth Graph 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Email: Ikeller@hilcorp.com Printed Name: Luke Keller Title: DrillingEngineer Signature: Phone: 907-74-8395 Date: 11/9/2012 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation' Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 II Swanson River Unit Well SRU 23B-22 Completed 10/5/12 x;icorp Alaska,u,c PTD#212-078 239'Above MSL CASING DETAIL I KB-THF:19' Size Type Wt Grade Conn. ID Top Btm 1 ® it 22" Conductor Surf 38' 22 11-3/4" Surf.Csg 47 J-55 Buttress 11" Surf 3,001' µ 29 N-80 Buttress 6.184" Surf 114' L-, Pt, 23 N-80 Buttress 6.366" 114' 4,886' 2 7" Intermediate 26 N-80 Buttress 6.276" 4,886' 6,781' 11-3/4" 29 N-80 Buttress 6.184" 6,781' 8,565' lir 29 P-110 Buttress 6.184" 8,565' 9,720' 11 4-1/2" Prod Lnr 12.6 N-80 IBT IBT 3.958" 9,519' 11,741' 3 I TUBING DETAIL 3-1/2" Production 9.3 L-80 8RD 2.441 Surf 9,508' JEWELRY DETAIL 4 'Ilk i No. Depth ID OD Item ; 1 19' 2.99" - Tubing Hanger 1.1 1.1 § 2 2,700' 2.867" 5.313' 3-1/2"SFO-1 Mandrel 8RD 5 k I 3 5,000' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD 4 6,827' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD 5 7,981' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD 6 „ 6 8,915' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD I0" 7 9,469' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD a i Fi 7 P '2- l 8 9,486' 2.813" 5.875" T-2 On/Off Tool w/X Nipple 8 c1 K�8 9 9488' 3.0" 6.08" Arrowset ASi-X Mechanical Packer r I I I 10 9,508' 2.660" 3.90" XN Nipple 9 LL 11 9,508' 3.0" 4.125" WL Re-entry guide II t Liner Hanger 10 @ 9,519' 7-21,11! 11 Whip-stock @ I/ �, 9,720' PERFORATION DETAIL 1 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Detail �i G2 11,433' 11,440' 10,795' 10,797' 6 7' 2-3/4"TCP HMX H2 11,482' 11,507' 10,812' 10,820' 6 25' 2-3/4"TCP HMX � ' H3 11,534' 11,569' 10,830' 10,842' 6 35' 2-3/4"TCP HMX E 'r' H3 11,595' 11,618' 10,851' 10,859' 6 23' 2-3/4"TCP HMX i$ 6�ttl ist / S i., /6l/0/ i: tr 44,1 F G2 to H3 "t —fit I4-1/2" TD=11,741'/ND=10,902' Revised By LEK 11/8/12 IIHilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 23B-22(Sidetrack SRU 14-22) 50-133-10148-01-00 212078 7/22/12 Daily Operations: ' ' 08/29/2012-Wednesday Cont NU 11" BOP, spot Canrig unit, spot BHI unit, MU kill and choke lines. Install HandyBerm around entire footprint, spot foreman unit, build mud dock. Offload mud products, offload smart tools, install flow nipple and flow line. Function test BOP's, function test all surface equipment,wire in service shacks.RU floor and test equipment,MWD Rep RU transducer's,install katchkan drip pan,Shell test BOP, kill and choke lines,CO kill line HCR. 08/30/2012-Thursday Removed kill line HCR and replaced, 2nd HCR valve bad, remove HCR for rebuild. Rig crew travel to Soldotna for pre-spud meeting. Pre-spud toe with entire rig team. Install rebuilt HCR,function and psi test. Commence BOP test with state rep John Crisp BLM rep Thomas Zelenka, nd / BLM rep Justin Milller.All tests at 10 min intervals at 250/5,000 psi,and annular at 250/2500 psi.Test#1 annular.Test#2 upper variables,kill line and choke valves 5-9-14-15,test#3 kill HCR,choke valves 4-8-12-13. Test#4 manual kill valve,choke valves 3-7-11-10-6-2-1,choke HCR, manual choke.Lower 4"rams,TIW and dart valve. 08/31/2012-Friday RD test equipment, pull test plug, line up valves and choke manifold. Install shaker screens, set 6 5/16" ID wear bushing, RU hole fill pump, off load mud products,offload drill pipe,rack and tally DP in pipeshed,mix mud. Install BHI sensor on standpipe gooseneck,cont offload and racking DP.Remove choke line section,install shock hose, RU and test choke line 250/5,000 at 10 min each on chart, RD test equipment.Off load last trailer of HWDP, rack and tally same,strap BHA#1. Baker Rep on location, PJSM with crew on PU drill pipe. MU BHA#1 (cleanout assembly),PU and single in hole with_4"HWDP.andjars. 09/01/2012-Saturday Cont PU DP from pipeshed and single in hole from 1,930'to 5,856'with 6" bit and 6.059" upper mill for guage. Crew held BOP drill at 1,100 hrs.Tagged up at 5,856'with 10K max, pulled 20K over to get free.Up wt 110K. Rotated 40 rpm and eased down from 5,856'to 5,862', max torque 3,500 ft/lbs,max wt on bit 1K.Worked tight spot 4 times then increased to 55 rpm and worked thru 4 more times.Stopped rotation and worked thru tight spot 4 times no problem. Fixed hydraulic hose on topdrive,greased crown and drawworks. Cont single in hole and encountered tight spots 6,079'to 6,082',6,113'to 6,118',6,227'to 6,229',6,319'to 6,321',6,323'to 6,326',worked tight spots at 40 and;55 rpm then with no rotation, cont single in hole to 8,539'at 00:00 hrs. Cont single in hole from 8,539'to top of bridge plug at 9,736'.Tagged bridge plug, set 30K on bit and picked up so as not to set off jars. CBU 2 x at 210 gpm-800 psi and prep test pump/chart to test 7"casing. ._Zest 7°..S.asjng at2.100 psi for 30 rein on chart,staging up in 500 psi increments. \a•1 09/02/2012-Sunday Cont testing 7"casing at 2,100 psi on chart, stage psi up in 500 psi increments. Mix and pump 30 bbl hi-vis sweep at 210 gpm, LD 2 jnts DP and drop 2.4" drift. POOH from 9,673' to 7,784', up wt 136K, dwn wt 136K. PJSM with new crew. Cont POOH from 7,784'to BHA .Install MWD encoder and calibrate same. POOH LD jars and bit.; Stage new BHA tools on rig floor, PJSM on whipstock handling and running. MU BHA#2 window mills and whipstock,anchor screws set at 17K, bolt at 35K. RIH at 2 minutes per stand to 607', PJSM with new crew on tour. Cont RIH at 2 min per stand from 607'to 5,800',filling pipe every 30 stands. 09/03/2012-`,Monday Cont RIH with whipstock assembly from,5800'to 9,704'. MU topdrive,circ with water 1 1/2 DP volumes at 210 gpm-770 psi. Held PJSM, RU Pollard e-line and gyro data. RIH with e-line,orient whipstock ramp at 42 degrees, POOH with e-line. Set down on BP 17K and trip anchor. Overpull 5K and verify anchor set.Slack off 35K and shear bolt.Top of ramp at 9,718', bottom of wondow will be 9,732'. PU 5'above ramp and displace well to 9.2ppg 6%KCL/PHPA mud at 6 bpm-960 psi. Begin milling window from 9,718'to 9,734',7.7 bpm-1360 psi, up wt 156K, dwn wt 155K, rot wt 155K, 70 rpm, 5-9K on bott torque, 3-5K wob, increased rpm to 100. 5-9K on bott torque,5-10K wob, recovered 54# metal at 00:00hrs.Cont milling from 9,734'to 9,750',315 gpm-1,400 psi,100 rpm,3-6K on bott torque;12-15K wob. 09/04/2012-Tuesday Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 23B-22(Sidetrack SRU 14-22) 50-133-10148-01-00 212078 7/22/12 Daily Operations: Cont milling new formation from 9750'to 9756', 1600 psi at 315 gpm,81 rpm,; 3-6K on bott torque, 12-15K wob, ream through window 4 ✓/ times, work through ; window 4 times no rotation, no problems in and out of window. ; CBU 279 gpm, 1430 psi ; Rack back 1 stand, RU f 0 injection pump and cement hose,shut in and perform FIT; FIT to 12ppg EMW,1415 psi for 10 minutes. pumped 2.5 bbls,got 2,2 bbls back; I2dr5r when bled off. RD and blew down lines.; Monitor well,well is static.;MU topdrive,pumped dry job,blew down topdrive.;POOH from 9720' to 5000',checked for flow,filled trip tank.;Cont POOH from 5000',to HWDP, hole fill off by 1 bbl.;Monitor well for 30 minutes,well flowing .7 at 1.7 bbls per hour. ; Notified Drilling Manager, decision made to TIH and weight up from 9.2 to 9.4. ; RIH with same milling assembly to 4770'.;Fill pipe and circ surf to surf at 6 bpm,700 psi.;Cont RIH from 4770'to 9715'while increase mud wt in pits to 9.4; MU topdrive and circ 9.4 at 330 gpm-1400 psi.At bottoms up,gas increased;to 2900 units,closed annular and cont circ through choke at 124 gpm-660 psi; until good 9.4 in and 9.4 out. Shut down pumps. ; Monitor for flow from degasser, no flow, open bag and cont check for flow.; Well still flowing at 1 bbl per hour;Cont circ and increase mud wt to 9.6 in and out. Max gas at bottoms up 135 units;Shut in topdrive and monitor well.Well still flowing at 1 bbl per hour. Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 238-22(Sidetrack SRU 14-22) 50-133-10148-01-00 212078 7/22/12 Daily Operations: 09/05/2012-Wednesday CBU at 330 gpm-1690 psi,max gas at bottoms up 216 units,called out more barite.Close annular to monitor psi build.700 psi in two hours. Notified Drilling Manager. Decision made to bleed off, commence circulating and circulating while increasing mud weight in 2/10's increments.Bleed off well, break circ and CBU through choke, 124 gpm-440 psi,max gas 240 units at bottoms up,open annular and resume circ down flowline while increasing mud weight to 9.8 ppg.Monitor well,well flowing at 1 bbl per hour.Cont circ at 7 bph-1680 psi,85 units gas at bottoms up,cont increase mud weight to 10.0 ppg, perform flow check,flowing at.8 bph,cont circ and increase mud weight to 10.2 ppg,performed flow check,flowing at.5 bph, increase mud weight to 10.4 ppg, had 93 units gas at bottoms up,check for flow,well flowing at.5 bph,cont weight up to 10.6 ppg. Monitor well,flowing at.5 bph,shut in to obtain psi build,SIDPP 140 SICP 160,bled off with very little returns. Called Drilling Manager, decision made to CBU and POOH half way to surface and monitor well and trip sheet,cbu with 247 units gas at bottoms up. POOH on trip tank, hole did not take correct fluid to fill first 5 stands,calculated hole fill 1.7 bbls per 5 stands, hole now taking 1.8 bbls per stand. 09/06/2012-Thursday Cont POOH from 8000'to to HWDP,monitored well at 4,700',had flow in 30 minutes.Monitored well for 30 min,called Drilling Manager and cont POOH to test BOPE. Rig crew tested choke manifold while POOH.Pull wear bushing,set test plug, monitor wellbore via annulaus valve in cellar.Test all BOPE at 250/4000 psi at 5/5 min per test. AOGCC Rep Jim Regg waived witness of test.Tested annular at 250/2500 psi.Pull test plug,set wear bushing,service rig and topdrive.PJSM,MU BHA#3,upload MWD,load radioactive sources,cont MU BHA. 09/07/2012-Friday Cont MU BHA#3(directional)PU 30 jnts DP from pipeshed,then RIH from derrick.Fill pipe and pulse test at 2657'.Had proper displacement while RIH. Orient motor through window with no problem, and CBU, 2765 units gas at bott up. RU GyroData and Pollard, RIH and orient toolface to 41.8 degrees, POOH w/gyro. Wash and slide from 9,736'to 9,756'. Slide from 9,756' to 9,796', 208 gpm-1470 psi, up wt 160K, dwn wt 155K,8-10K wob.CBU 170 bbls.RU XO,pump in sub,packoff and RIH with GyroData to checkshot/orient toolface. 09/08/2012-Saturday M/U top drive, check shot survey, stand back 1 stand, rig up wire line. Run in hole and gyro, @ 9,732' latch up failed multiple times, consistant tool @ 36 deg, POH w/wire line, RIH 1 stand T/9,796',orient motor.Time drill and slide @ 6 ft/hr, F/9,796'T/9,812',209 gpm, 1550 psi,p/u 164K,s/o 167K,ADT 3.8 hr.Time drill F/9,812'T/9,970',p/u 157K,s/o 152,pump psi 1790,off bottom psi 1590,ADT 11.75, 09/09/2012-Sunday Rotate and slide F/9,89'4 T/10,022',209 gpm,1760 stp,P/u 172K,s/o 165K.ADT 5.0,AST 5.0,ART 1.0.Rotate and slide F/10,022'T/10,120' torq on bottom 3K,off bott 2K. P/U 173K, S/0 160K, RTW 162K,service top drive,and rig. Rotate and slide F/10,120'T/10,241'250 gpm, 2280 spp, 7/20k wob, 3K torq on bottom, 3K torq off bottom,ADT 11 hr,AST 7 hr,ART 4 hr. Rotate slide F/10,241'T/10,363'-122' @ 20 ft/hr,wob 15/20,gpm 247,torq 3.9 on bottom,2.5 off bottom,SPP 2260 on bottom,2090 off botom,60 rpm,rtw 168,p/u 175K,s/o 162K. 09/10/2012-Monday Rotate and slide F/10,383'T/10,407'-44' @ 11ft/hr, p/u 176K s/o 162K rtw 168K,torq on botto 4K,torq off bottom 2.5K, 247 gpm, 2250 spp.ADT 4 hr AST 2.6 hr,ART 1.4. Circulate bottoms up @ 10,407' @ 247 gpm, 2100 psi, 80 rpm,torq 2.5K monitor well,flowing.5 bbl hr. Trip out of hole F/10,407'T/,9672',fill pipe ever stand,monitor every 5 stands. Hole not taking proper hole fill. Monitor well f/30 min,well flowing.5 bbls hr.Trip in hole F/9,672'to 9,719',orient tool to get through window,TIH to 10,378',m/u top drive and wash down to 10,407'. Circulate bottoms up,3080 units gas @ bottoms up,build mud weight T/10.7.Get new slow pump rates.Trip out of hole F/10,407'T/9,672', no over pull, hole took 1.42 bbls under disp.Shut in well and monitor PSI, 58 on casing, 14 on drill pipe.Trip out of hole F/9,672'T/4,567'. Shut well in and record well bore pressure,annulas psi 88,Dp PSI 10.Continue trip out of hole. 09/11/2012-Tuesday Continue TOH F/4,567'T/806',cal disp 13.6 bbls,act 12bbls,1.6 bbls gain.Monitor well,slight flow observed.Continue TOH to 136'std back hwdp,jars 1NMFC. PJSM,remove raidoactive sources,LID NMFC,UBHO,&filter sub.Install nutron verifier,down load MWD,clean rig floo. Stand back smart tools in derrick,lay down bit, motor,short DC&stab. P/U new motor&new orient sub,orient mwd tools, make up BHA. PJSM w/ mwd, & load sources in tools. RIH W/BHA, shallow test mwd @ 440', contiune TIH. Fill pipe and calibrate mwd tools @ 2,374'. Continue TIH F/ 2,374' T/ 9,665', fill pipe every 25 stands. PJSM, slip and cut drilling line. Continue tripping in hole T/ 10,407'. Circulate bottoms up,3000 units gas @ bottoms up,0 mud gains in last 12hr. Page 3 of 7 • Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 23B-22(Sidetrack SRU 14-22) 50-133-10148-01-00 212078 7/22/12 Daily Operations: 09/12/2012-Wednesday Drill F/10,407'T/10,428'-21'@ 3.5 ft/hr,gpm 247, SPP 2020, rpm 30,torq 2.9WOB 15. Drill F/10,428'T/10,450' -22'@ 3.1 ft/hr, gpm 319, SPP 2995 on bot torq 3K on bot. Diff PSI w/rotating= 275,w/sliding 100, p/u 176K,s/o rpm 65, rtw 164. ADT 6.5hr, AST 4.5hr, ART 2hr. Circulate bottoms up @ 310 gpm,3,000 psi,monitor well F/30 min,wellbore flowing @1/2 bbl/hr.POOH F/10,450'T/9,546',filling every std, hole took 1/2 bbl over calcuted displace. Monitor well F/30 min,wellbore flowing @1/2 bbl/hr.Pump dry job and continue tripping out of hole to 4,500',taking proper hole fill.Monitor well for 30 min @4,500,well bore flowing 1/2 bbl/hr.Continue tripping out of hole F/4,500'T/ HWDP @805',hole taking proper hole fill.Continue trip out,stand back hwdp,jars&1 jt NMFC,hole tken 2 bbl.Over @301'. 09/13/2012-Thursday Continue tripping out of hole. Unload, radioactive sources, l/d NMFC,filter sub,down load MWD. Std back mwd, break bit and l/d motor, poney clr,and stab.Rig up to test BOP's,test BOP's-rams @ 250 psi low,4,000 psi high.Test hydrill @ 250 lo,2,500 hi,test choke manifold @ 250 lo,4,000 high. Rig down test equipment,install wear bushing, prep floor F/picking up BHA. Pick up motor, bit,stab and bha,orient BHA to MWD.PJSM,load source,continue tripping in w/BHA to 806'shallow test MWD.Trip in hole T/4,988't/9,809',filling pipe every 25 09/14/2012-Friday Continue trip in hole t/10,430'. M/u top drive wash down t/10,450', cbu, @ 247 gpm, 1,960 psi,3,194 units gas. Drill F/10,450 T/10,490- 40' @ 8.8 ft/hr,279 gpm,SPP 2260 psi,torq 4K,on. 2.5 off bottom, p/u 177K,s/o 163K,rtw, 170K,ADT 2.6 AST 2.5,ART.1. Drill F/10,490' T/10,603'-113' @ 18.8 ft/hr, P/U 174,S/0 162K, RT 165K.On bot torq 4.2,off bot 2.5 SPP 2940 psi,wob 20K, RPM 60. Rotate and slide F/ 10,603'T/10,681'-78' @ 13 ft/hr, p/u 178K,s/o 162K. ROT 165K,torq on bot 4.2,torq off 2.5,ART 1.5,AST 4.5. Rotate and slide F/10,681' T/10,836'-155'@ 25.8 ft/hr,SPP 2826 psi,wob 25. 09/15/2012-Saturday Rotate and slide F/10,836'T/10,900' -64' @ 10.6 ft/hr, p/u 181K,s/o 159K. ROT 170K,gpm 295,spp 3110 psi,torq on bottom 5.2,torq off 3.6,ADT 6 hr. AST 3.9,ART 2.1. Attempt to drill @ 10,900',pressure spike and blown pop off on pump.Reset pop off,attempt to drill,pump psi spiked anad blew pop off, attemp to drill pump PSI up, diff psi up. Monitor well F/ 30 min, well flowing .3 bbbl hr. Trip out of hole T/9,609', pulling 5/15 over pull F/10,900'T/10,618' & 10K over T/10,240', .7 bbl under calucated displacement. Monitor well,flowing @.3 bbl/hr.Pump dry job and trip out of hole to 4,500'well took 4 bbls under calcaluted dis.Monitor well flowing 1/2 bbl hr.Continue trippin out of hole T/806,flow check well, hole flowing.3 bph.Continue TOH to 350',remove nuke sources,and l/d flex collar,&down load MWD.L/D SDN&BCPM tools,POOH break bit,bit missing cones,l/d orient sub. I/d ontrak MWD and stand back motor assembly.Wait on Baker fishing tools. 09/16/2012-Sunday Wait on Baker fishing tools. Make up reverse junk basket BHA. RIH with hwdp and jars, BHA wt.15K.Trip in hole F/676'1/10,739',M/U top drive,p/u wt 175K,s/o 167K,rot 160K.Torq 2.5, PSI 1,520,gpm 247.Wash and ream F/10,739'T/10,864',droop ball&circulate ball down (991 stks). Continue to wash down to 11,900', pump psi 2,100 psi, rotate down to 10,902', pick up 5' and wash down to bottom. Monitor well for 30 min,well flowing.21 bbl/hr.Trip out of hole to window,and monitor well for 30 min.Continue tripping out of hle to 4,500'and monitor well,well static.Continue tripping out of hole to BA, monitor well,well static.Continue tripping out of hole, break off reverse junk basket,basket empty.Wear on outside nose of burning shoe,no wear on inside of shoe,minor scratchs inside bottom fingers. 09/17/2012-Monday Lay down reversing junk basket.Remove junk basket&pick up mill tools to floor.Make up 6" rod cone mill&boot baskets.Trip in hole with cone mill T/9,677'. M/U TIW valve and top drive.Cut and slip drilling line,service crown&blocks. Continue tripping in hole to 10,873'.M/U top drive, break circulation,obtain drilling parameters,p/u 180,s/o 157k,torq off bottom 2.9,SPP 760 psi.Wash F/9,677'T/10,902', mill on cones wob 5/15, 60 rpm,800 psi ;torq on bottom 2.9 to 7.5 -F/10,900 T/10,912. Monitor well, POH to window, monitor well, hole taking proper hole fill.Continue tripping out of hole 600'. 09/18/2012-Tuesday Continue POOH with BHA&L/D cone mill.Clear rig floor of Baker tools,service rig and clean floor.Make up drilling BHA,scribe motor,check float. Down load MWD tool.Orient motor w/orient sub, shallow test MWD.Continue p/u BHA and load sources in MWD. Run in hole with HWDP out of derrick.Pick up 24jts drill pipe,trip in hole to 9,719',orient dril string 1/4 turn to get thru window.Continue tripping in hole T/ 10,865'.Wash down F/10,865'T/10,910'@ 200 gpm,2,190 psi.Rotate and slide F/10,910'to 11,010'. Page 4 of 7 Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 23B-22(Sidetrack SRU 14-22) 50-133-10148-01-00 212078 7/22/12 Daily Operations: 09/19/2012-Wednesday Rotate and slide 1,1011'/11,106'-95'@15.8 ft/hr,wob 10/15 K,rpm 60,gpm 280.SPP 2350,off bottom PSI 2,240,p/u 182K,s/o 160k,rwt 155K,ADT 4.8. Rotate and slide F/11,106'T/11,162',wob 10/15, rpm 80,spp 3,000,torq on 4.8,torq off 3.5, p/u 185,s/o 150,rot wt 160. Continue drilling F/11,162'T 11,250',wob 10/18,rpm 80,spp 3,040 on bottom.Stand back 1 stand and circulate bottoms up. Monitor well, trip out of hole F/11,244'T/9,668',p/u 185,s/o 165k;well flowing 1/2 bbl/hr,no over pull tripping out of open hole.Monitor well F/30 min @ 9,668,well flowing.25 bbl/hr,pump dry job;Continue tripping out of hole. 09/20/2012 Thursday Trip out of hole to BHA,monitor well,well flowing 1/4 bbl/hr.Stand back hwdp,hold PJSM on unloading sources,p/u to source and unload. L/D filter sub,&monel collar,p/u&install verfier&down load MWD.Stand back mwd,break bit, gauge stab,lay down motor.Clean&clear rig floor of drilling tools.Rig up cellar to monitor well,pull wear bushing.Rig up to test bop's.Test bop's,test ann @ 250 lo,2,500 hi for 5 min, test rams @ 250 to/4,000 high.Test all choke valves @ 250 lo/4,000 high,perform accumlator draw down test,pull test plug,install wear bushing,r/d testing equip, blow down choke&kill. PJSM, pick up motor m/u bit,orient motor. PJSM,with MWD,on loading sources,load sources.Trip in hole to 803',conduct shallow hole test of mwd,continue tripping in,hole filling pipe every 40 stands 09/21/2012-Friday Trip in hole T/11,173',p/u 185,s/o 160k.Wash down F/11,173'T/11,250'@ 220 gpm,1950 SPP,10k wob,observed from 11,220'to 11,250' md. Rotate and slide F/11,250'T/11,367', rpm 85,torque on 5K,torque off 3.5,wob 15,gpm 250, PSI on 2,520, PSI off 2,380,p/u 185,s/o 157k, rwt 155,ADT 3.4,ART 2.5. AST.9 hr,jar hrs 88.6, bit hrs 3.4. Rotate and slide F/11,337'1/11,582', wob 15, rpm 85, SPP 2,750,off bottom 2,420 psi, torque on bottom 6k, torque off 4.7, gpm 250, ADT 11,ART 9, AST 2, p/u 187k, s/o 156, rtw162k. Rotate and slide F/ 11,582'T/11,657',rpm,85,wob 11k,SPP 2661,gpm,247.Bit hours,19 total,ART 12.25,AST 3.25hr. 09/22/2012-Saturday 160k,rwt 157,rpm 85,pump. 30 bbl nut plug sweep @ 11,706' md,ADT 10.4,ART 10.4. Rotate and slide F/11,707'T/11,741', PR @ 6bpm, 2,560 psi off bottom, 2760 on bottom, 55 rpm,4k torque off bottom, 6/7k on bottom, wob 15/18, p/u 170k, s/o 148 rot 155k. Survey @ 11,741'.Circulate&cond mud,pump sweep andcbu x 2@ 6bpm,2560,40rpm,torq 3.3k. Monitor well f/30 min,well flowing.6 bbl/hr,trip out of hole.Trip out of hole to window @ 9,719' and monitor well.Trip out of hole to 9,155', hole not taking proper hole fill, 8bbl gain. Monitor well,well flowing @ 3bbl/hr.Strap pits,trip in hole 10 stands, 1.4 bbls over calcuated displacement. Continue tripping in hole to bottom@ 11,741'. 09/23/2012-Sunday Continue circulating bottoms up, GPM 220, PSI 2,240, rpm 60, torq 4k. Monitor well, well flowing 4 bbl/min, circulate and increase mwt F/10.7 to 10.8 ppg,circulate @ 220 gpm,45 rpm,4k torq, 2230 psi. Flow check well,flowing @ 1.5 bbl/hr,circulate and increase MWT to 10.9,circulate @ 6 bbl/min,2400 psi,45/50 rpm,p/u 185k,s/o 158k,rwt 159k,tq 4k.Flow check well,well flowing @ 1/4 bbl/hr.Trip out of hole F/11,741'T/9,663',calcuated disp. 10.2 bbls, hole took 11.7 bb. Flow check well.Cut drilling line,trip out of hole to 4,500', monitor well,continue tripping out of hole to bha.Monitor well,lay down HWDP. 09/24/2012-Monday Lay down BHA,MWD tools,flex collars,mud motor,sdn,bcpm,clear drilling tools off rig floor.PJSM,rig up casing tools,P/u and run 4.5 L-80, 12.6#Hydril 521 liner,p/u 46k,s/o 44k,change out elevators,make up liner hanger.Rig down casing running tools.Pick spinner tongs,rig up rig tongs. Trip in hole w/4.5 liner on drill pipe.Trip in hole with 4.5 12.6#L-80 liner on drill pipe to 6,728'. 09/25/2012-Tuesday Make up cement head and stand back in derric.Continue running in hole with 4.5 liner to 9,708'. Circulate 3bbl/min,700 psi,p/u 140k,s/o 130k,rwt 136k,torque @ 15 rpm 1k,continue running 4.5 liner F/9,708'T/10,000'rotate and wash liner down,F/10,000T/10,928 p/u 152k, s/o 144k, rpm 15, 3 bbl/min @ 820 psi;wash and ream F/10,928'T/11,595', p/u 155k,s/o 145k, rwt 152k.Top drive not rotating,troubleN shoot problem, trouble shoot rotation. Continue washing down liner F/ 11,595' T/ 11,741'. Circulate and condition mud. Pre job safety 14th, meeting with Schlumberger, Baker on cementing.Cement 4.5 liner,test cement equip @ 4,500 psi, pump 22 bbls mud push,pump 52 bbls n class G cement,pump 5 bbls water drop kick out plug,displace with rig pump,latch up @ 2,047 stks,bump plug w/2757 stks, pressure up T/ { r 2,800 psi,slack off 75k,set hanger,bleed off and check floats. PSI up to 4,100&release running tool, p/u 10slack off w/rotating&shear, dog sub,psi up to 1,400 and release pack off,circulate out cement. Page 5 of 7 IIHilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 23B-22(Sidetrack SRU 14-22) 50-133-10148-01-00 212078 7/22/12 k" Daily Operations: - its,,, 09/26/2012-Wednesday Continue circ conditioning mud with Bicarb and Caustic to bring PH up for storage. RD cement lines, blow down cement hardline. POOH and LD DP from 9,491'to 8,045'. RIH with cement head, break and LD same, LD one single. Continue POOH racking in derrick, LD liner hanger running tool. Break off XO's on cement head,clear and clean rig floor. PU stack washer and flush BOP stack in prep for cleanout run, LD washing sub. Stage cleanout tools on rig floor, PJSM on PU 2-3/8"tubing, MU bit,XO's, PU casing scraper/magnet assembly for 4.5"casing, PU single in hole 65 joints 2-3/8". MU Baker TBR dress and polish mill, 1 joint 4" DP,casing scraper/brush assembly,RIH with 4" DP from derrick to 5,000'. 09/27/2012-Thursday Continue RIH on 4"DP from 5,000'to 6,683'and lost a slip die down hole.Drain BOP stack,check drip pan,look for slip die.Inform Drilling Engineer of lost slip die, POOH 4,500'to upper magnet and recovered slip die on upper magnet. Clean rig floor, prep to RIH. Cont RIH from 2,150' to 9,516' (top of liner), entered liner hanger no problem. Mud running over top of DP 30' above floor,attempt CBU, pump motors won't run.Troubleshoot rig pumps,found day tanks and filters full of water, drained water and changed filters. Fired up pumps and CBU at 3 bpm-1,100 psi.Continue to ease in hole,having to MU top drive to prevent mud running over top of DP.String taking weight at 11,551',start washing to bottom with 100 spm,2,400 psi. 09/28/2012-Friday Continue wash and ream 3 bpm-1,450 psi, 20 rpm to 11,610'. Polish liner hanger top at 9,516', 5 bpm, 2,512 psi, 50 rpm, 2K on bottom torque,CBU to condition mud for casing test.Pull 1 stand,RU and test casing at 2,100 psi for 30 min on chart.Good test,RD.RIH 1 stand, displace well to fresh water 2 circs, 108 spm-1,504 psi, up weight 165K. POOH 5,000'to upper brush, RIH to 11,600'. Circ surf to surf x2 with fresh water at 4 bpm-1,050 psi until return fluid clean.Build 50 bbl caustic pill,50 bbl hi vis pill and 50 bbl baraclean pill in pits.Pump pill train 117 spm-2,022 psi,followed with 6%KCL. 09/29/2012-Saturday Cont displace well to 6% KCL, NTU's at 100,fill trip tank, prep to POOH. POOH from 11,609', lay down 9,500' 4" DP and upper scraper, brush assemblies. RU Weatherford tubing tongs, rack back 2-3/8" tubing in derrick, LD polish mill and lower scraper/brush/magnet. Tested choke manifold and gas alarms while POOH. MU wear bushing tool and pull wear ring, prep to test ROPE. Test all BOPE at 25914,900 psi for 5min each,annular at 250/2,500 psi on chart.AOGCC Rep Jim Regg waived witness of testing at 12:00 hrs 9/28/12.R&T 09/30/2012-Sunday Cont testing BOPE at 250/4,000 psi, RD test equipment, install wear ring. PJSM, RU ExPro sheave and tools, test tools on surface, troubleshoot tools, RIH. Experienced tool failure, POOH and change out to backup tool, Warrior computer has failed, discuss with completionse engineer, decision made to wait on delivery of replacement Warrior computer. Rig hands cleaning and painting and performing maintenance while waiting on delivery.New computer on location at 03:00.Installed computer,tested tool and computer at surface,RIH at 06:00. 10/01/2012-Monday 2 RIH in hole with logging tool,stopped at 1,000',had tool failure,POOH.Change out backup tool to primary tool,test ok.RIH testing every 4t5 1,000' with no problems, tagged up at 11,688' WLM. Log while POOH at 30' per minute from 11,688'to 7,000',then POOH RD ExPro. u Clear rig floor,lay out guns,prep to PU TCP assembly,PJSM.MU 9 jnts(185')2-3/4"guns,firing head,ported sub,RA sub,RIH on 60 jnts; 2 3/8"tbg,XO,then single in hole with 3 1/2"tubing from pipe shed. 10/02/2012-Tuesday Continue single in hole with 3-1/2"tubing from pipeshed to 8,806',flowing over the top.Mix 9.7 ppg pill and pump 20 bbls down tubing. Continue single in hole with total 298 jnts 3-1/2"tubing plus 2 pups to 11,615', up wt 98K. MU 1 jnt tubing on top of pups, attempt to locate landing collar.String taking weight at 11,616'. LD jnt tubing, prep to RU for e-line,spot logging truck, rehead e-line, MU tools,MU lubricator and pump in sub. RIH with logging tool. At 10,850' had to pump tool down tagged at 11,436 wlm. Logged up hole to 9,950'. Discuss with engineer,decision made to POOH RD ExPro. Page 6 of 7 Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 23B-22(Sidetrack SRU 14-22) 50-133-10148-01-00 212078 7/22/12 Daily Operations: 10/03/2012-Wednesday Cont POOH with correlation tools.RD lubricator and pump in sub,RD Expro.RU and MU 1 jnt tbg,attempt to work string 5'deeper,lay down joint.Clean and clear rig floor,RD Weatherford tongs and handling equip.Offload tree and 3 1/2"joint,ship out Weatherford tong equip,prep to run RTTS.Shut in boiler,blow dwn all steam lines,prep for ND BOPE.MU Halliburton RTTS,RIH 1 jnt and set,MU wear bushing tool and pull bushing;MU RTTS running tool and engage packer,pull above table,LD RTTS.MU hanger with Cameron Rep,land hanger,up wt 102K,dwn wt 98K.Start ND BOP,drain degasser and rock washer,disconnect steam lines,remove choke and kill lines,prep degasser for lay down,RD mud lab,remove flowline. Install tree with Cameron Rep.Hang blocks,slip 13 wraps on drum,LD elevators and bales,remove saver sub,LD kelly hose,stage carrier for topdrive,unhook service loops,remove slide. 10/04/2012-Thursday Prep derrick for removal. 10/05/2012-Friday No Activity. 10/06/2012-Saturday See Operations Weekly Summary 10/07/2012-Sunday See Operations Weekly Summary 10/08/2012-Monday See Operations Weekly Summary 10/09/2012-Tuesday See Operations Weekly Summary Page 7of7 11 Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 23B-22 50-133-10148-01-00 212-078 Daily Operations: 10/03/2012-Wednesday Mobe rig. 10/04/2012-Thursday Mobe rig. 10/05/2012-Friday Mobe rig. Laid containment, MIRU WOR and equipment. 10/06/2012-Saturday ND tree, NU BOP's, RU test pump. Tested BOPE per AOGCC requirements. (250 psi low/3,000 psi high-witness waived by Jim Regg, AOGCC.) Pulled tbg hgr. TOOH w/90 stands of 3-1/2"8rd. Secured well and SDFN. 10/07/2012-Sunday TOOH w/148 stands of 3-1/2"and 30 stands of 2-2/3"and 1 single. LD TCP guns. PU 3.75"mill,2 DC and TIH w/61 Its of 2-3/8"and 294 jts of 3-1/2". Tag bottom at 11,623.5'. PU 1 jt and SDFN. 10/08/2012-Monday Started pumping 3.5 BPM. Drilled cement from 11,623.5'to 11,650'. Reamed and cir well clean. RD power swivel. POOH. LD mill and DC. PU TCP guns and RIH w/31 stands of 2-3/8 tbg. SDFN. 10/09/2012-Tuesday PU packer and RIH w/148 std of 3-1/2"tbg. Correlate depth. POOH. MIRU EL. RIH and log. RDMO EL. SDFN. Page 1 of 1 4. Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 23B-22 50-133-10148-01-00 212-078 Daily Operations: 10/10/2012-Wednesday RD eline and correlated TCP depth. POOH. RDMO Eline. PU TCP 1'. Pressured up well to 2,800 psis bleed off,gun fired after 5 mins. Monitored well for 1 hr. Fluid level stagnant at 960'. TOOH w/248 stands of 3-1/2"tbg. Set TIW. Secured well and SDFN. 10/11/2012-Thursday LD 62 jts of 2-3/8"tbg and TCP. PU WL RG,X-nipple(2.83)and packer. RIH w/WL RG,x-nipple(2.83), packer,6 GLM and 293 jts of 3-1/2" 8rd. Set packer @ 9,508'. Landed hanger. Dropped prong and test TGB/CSG. Set BPV, ND BOP, NU tree and tested to 5,000 psi. Pull BPV. MIRU SL. Pulled prong and test plug. RDMO. WOR. 10/12/2012-Friday No activity to report. 10/13/2012-Saturday No activity to report. 10/14/2012-Sunday No activity to report. 10/15/2012-Monday No activity to report. 10/16/2012-Tuesday No activity to report. 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JelloOTeold Z 1.'9991.L 1.9'017 L%9 I!aP' H 08 I #9.ZI. 917 If 6 178'17991.L 8Z L aelloa 6u!puel Z£'£1,91.L Z9'L17 6Z9 I!JPAH 08 1 #9.Z 6 9•j 89'91796 17L'1790Z 1.29 I!JPAH 08 I #9.Z I- 9.7 sw 09 09 01 L Sir 00'6L96 89.62 a06uey Jou!I dXZ aa>{e8 00.8 00'91.96 eoejns oT ed!d iiva 00•£ 00'8 09.81- 8)1 I a6ueId jo dol Jo 6uI11.S jo doi abed sdol q;6ua-I s;uawwoa pue uol;duosaa;uewd!nb3 IIaM s;uior JagwnN Tr q;daa i.#uoAoa :6ib ZI.OZ/5Z/6 :elea aaoqllee o; ;aadsa.r wpm unei WaiudInb3 Jo uogduasea ZZ-8EZ :IIaM die;aa 6uillua 210 6uignl 6ulsea ail `eMseiy daooliH Hilcorp Alaska, LLC CASING/TUBING TALLY PAGE: 1 of 3 WELL NUMBER: 23B-22 RIG: Doyon#1 TALLY-JOINT DESCRIPTION: DATE: 09/25/12 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No - Feet No Feet No Feet No Feet No Feet 1 41.48 26 41.51 51 41.44 76 101 126 151 176 2 39.70 27 41.46 52 41.49 77 102 127 152 177 3 39.74 28 41.47 53 41.45 78 103 128 153 178 4 41.50 29 41.48 54 41.04 79 104 129 154 179 5 41.47 30 39.78 55 41.48 80 105 130 155 180 6 41.49 31 41.46 56 41.49 81 106 131 156 181 7 39.76 32 41.47 57 41.48 82 107 132 157 182 8 41.47 33 41.45 58 40.94 83 108 133 158 183 9 41.50 34 41.46 59 40.81 84 109 134 159 184 10 41.47 35 41.48 60 41.52 85 110 135 160 185 11 41.51 36 41.47 61 86 111 136 161 186 12 41.50 37 41.12 62 87 112 137 162 1871 13 41.52 38 40.56 63 88 113 138 163 188 14 41.50 39 41.07 64 89 114 139 164 189 15 41.51 40 41.46 65 90 115 140 165 190 16 41.46 41 40.93 66 91 116 141 166 191 17 41.47 42 41.47 67 92 117 142 167 192 18 41.43 43 41.48 68 93 118 143 168 193 19 41.47 44 41.47 69 94 119 144 169 194 20 41.45 45 41.48 70 95 120 145 170 195 21 41.46 46 41.51 71 96 121 146 171 196 22 41.47 47 41.46 72 97 122 147 172 197 23 41.49 48 41.50 73 98 123 148 173 198 24 41.50 49 41.46 74 99 124 149 174 199 25 41.47 50 41.49 75 100 125 150 175 200 Tot 1031.79 Tot 1032.95 Tot 413.14 Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE= 2477.88 DIRECTIONS: TOTAL JOINTS THIS PAGE= 60 Hilcorp Alaska, LLC CASINGITUBING TALLY PAGE: 2 of 3 WELL NUMBER: 23B-22 RIG: Doyon#1 TALLY-JOINT DESCRIPTION: DATE: 09/25/12 Column 9 Column 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 201 226 251 276 301 326 351 376 202 227 252 277 302 327 352 377 203 228 253 278 303 328 353 378 204 229 254 279 304 329 354 379 205 230 255 280 305 330 355 380 206 231 256 281 306 331 356 381 207 232 257 282 307 332 357 382 208 233 258 283 308 333 358 383 209 234 259 284 309 334 359 384 210 235 260 285 310 335 360 385 211 236 261 286 311 336 361 386 212 237 262 287 312 337 362 387 213 238 263 288 313 338 363 388 214 239 264 289 314 339 364 389 215 240 265 290 315 340 365 390 216 241 266 291 _ 316 341 366 391 217 242 267 292 317 342 367 392 218 243 268 293 318 343 368 393 219 244 269 294 319 344 369 394 220 245 270 295 320 345 370 395 221 246 271 296 321 346 371 396 222 247 272 297 322 347 372 397 223 248 273 298 323 348 373 398 224 1249 274 299 324 349 374 399 225 250 275 300 325 350 375 400 Tot Tot Tot Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE= DIRECTIONS: TOTAL JOINTS THIS PAGE= . J11. CASING/TUBING TALLY PAGE: 3 of 3 WELL NUMBER: 23B-22 RIG: Doyon#1 TALLY-JOINT DESCRIPTION: DATE: 09/25/12 Column 9 Column 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 401 426 451 476 501 526 551 576 402 427 452 477 502 527 552 577 403 428 453 478 503 528 553 578 404 429 454 479 504 529 554 579 405 430 455 480 505 530 555 580 406 431 456 481 506 531 556 581 407 432 457 482 507 532 557 582 408 433 458 483 508 533 558 583 409 434 459 484 509 534 559 584 410 435 460 485 510 535 560 585 411 436 461 486 511 536 561 586 412 437 462 487 512 537 562 587 413 438 463 488 513 538 563 588 414 439 464 489 514 539 564 589 415 440 465 490 515 540 565 590 416 441 466 491 516 541 566 591 417 442 467 492 517 542 567 592 418 443 468 493 518 543 568 593 419 444 469 494 519 544 569 594 420 445 470 495 520 545 570 595 421 446 471 496 521 546 571 596 422 -M-0- 497 -®-M-®-M 423 448 473 498 523 548 573 598 424 449 474 499 524 549 574 599 425 450 475 500 525 550 575 600 Tot Tot Tot Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE= TOTAL LENGTH= 2477.88 DIRECTIONS: TOTAL JOINTS THIS PAGE TOTAL JOINTS= 60 AVERAGE JT= 41.30 2 3 Measured Depth(ft) - 1-, ._.0 A NJ O 00 Ql A NJ O O O 0 OO 0 O 0 0 O0 0 0 0 0 In N O N Cn v N N c H4 in N W CI co o NJ 13 N " M. N S LO O U.) v, o II I n c a) 3 U, ul tri _______.-- O Measured Depth(ft) 3 3 A N 0 CO Q1 A N O O O 0 0 O 0 O0 O O O 0 0 O O O 00 U1 to O N v w 03 m fD ' o — CS 00 I- O � r N O N o N N O 4. • Schlumberger Cementing Job Report CemCATy1.5 Well SRU 23B-22 Client Nilcorp Field Swanson River Unit SIR No. BVCN-00051 Engineer Lindy Byerly lob Type Liner Country United States lob Date 09-24-2012 Time r Rate ----Density Volume -- Treating Preacui Messages 20:58:34 start priming pump 21:24:00 21:49:00 ( Reset Total,Vol=44.83 bbl Rate Check Front Head,4hpm Reset Total,Vol=7.21 bbl Rate check rear head,4bpm Reset Total,Vol=0.55 bbl Reset Total,Vol u 4.83 bbl 22:14:00 Rate checks good Standing by for rig to TD and a 22:39:00 Rig circulating;4.6 hpm,1200• 23:04:00 Rig continuing circulation 23:29:00 23:04:00 00:19:00 00:44:00 I End PiSM Reset Total,Vol=11.13 bbl 01:09:00 4"liollierw1 Blow air down hardline Q i. Coming online 5 bbl fresh water Start pumping 5 bbl fresh water 5 his!away,Shut in on rig floor Shut in on rig,clear on floor p Clear on ground,dear on floor 01:34:00 Low Pr Trips tripped Low good,all dear High PT High Pr good,all dear on grounc Pressure bled,SLB pump Isola 01:59:00 Rig lining up to pump MP I Reset Total,Vol=4.93 bbl Rig pumping MPII 11 MA MP away r Start batching cement • Rig done pumping MP 02:24:00 -- Ce up to pump down dp Cement to weigh[,15.3 ppg Pumping cot swap abt bottle 18 bbl mix h2o away Swapped to back bottle 02:49:00 30 bbl mix 520 away,pumping 52 bpi cement away using mix / Drop Dart Tattletell Indicated dart was dm Rig start displacing,leave 01.5 o 03:09:25 , 516 washing up,stay rigged In lob complete,SLB rig down wast. I hh:rpm;so III(690 1.3 la 10 40 600 4.0 60 110 Ileo 400 11.0 36.0 !ia 740 0.00 1000 2000 arm Lea .noeua,..a _ _ ........,B/M — LB/G .. -BBL PSI 1 09/26/2012 14:14:23 4, 1 Schlumberger Cementing Service Report Customer !lob Number Hllcorp BVCN-00051 Web taxation(lewd) 9d.hHeberTer taotso., we Mat SRO 23B-22 238-22 Arctic Fox KENAI Sep/242012 Mstd Females Name/Type Berlatlon OR dna Well MD Wall TVD Swanson River Unit Clean-Sandstone 70 deg 6.0 in 11741.0 ft ft County Kenai gonia/PronMs AK BNP SHUT ONCT Pore Preop Gradient was Neter J API/UNI 5876 psi 187 degF 175 degF 7.50 Ib/gal � _-- P ig Name 0000. Drilled Far SVlace VM 008116/1.119r Arctic Fox 03 Land Depth,R Shot.In Wel6te,N■JR Grade Thread offshore Zone Well pass Well TO. 10100.0 7.0 26.0 Old Re-entry 11741.0 4.5 12.6 Drilling F1014 Type Mar.Dwlty Plad4e Vkwasfy TAM/9M Mos W9el d TM Dept/,R SIN,la WO"6/R Meda Tbread ....i.__ _- S ervice Line lob 0 p_ 0 9516.0 4.0 14.0 E-75 T Type Cementing Lina 0.0 0.0 0.0 Ma Mar.Allowed Tub.Ne Maas Allowed Ann.Press Val Calneetbll yhNel9tlevjOpen Note 5000 psi psi Tem It NYlaW.R Mat/ft Na.of Aoki TOY lserrl ■rlOsInie,.cttansR ft 0000....._._.......0000-__. ft Pumped 52.0 bid 15.3 ppg EasYBLOK cement - t R Obw1er R R M Treat Deem Displacement Pad...Type Packer Ogtb Dlill Pipe 136.0 bbl ft .__........___.............__.. 0000._ _.. Tubing vol Casing Vol. brander Vol. Opeb■la Val. hhi 34.0 hbl 15.0 bit 35.0 bit csaDv/7166r..Drama 0 111101.Veru cbolted polar*Caen ] Casing Touts Noumea ids Mt pxawa peri Ass Type Ilweeron Tybe MM Rotated LJ Pipe Nae400sted 0 Ase asplb 11741.0 ft Tod Ville N s.t7r9ragWe Tp Mae "Few.Nue. Blabs Tee Type Ted Della R Cema5 Meed Type Single Slave Tod Depth ft Tell Alpe AM In lob SchedY d Few A.eleed on LooYlae Leave taotlpn Cabe Type Toll MIM Depth ft Sap/24/2012 20:00 Sep/24/2012 15:30 Sep/25/2012 04:30 c.�_---- --- --�- ca.Ospcs 11892.0 ft Sqs Talml Vol. hbl DYe TInM Pressure Row MOny 0000 Rom _.-. PPeisnie 54.br PSI Hata Vol.... DaMlty dock 8/M Dbl. 10/6 ___- A --., 09/24/2012 20:55:34 36 0.1 0.0 -0.00 09)24/2012 ( 20:59:43 37. __..__..........._ 0.1 0.1 -0.00 Start priming pump 09/24/2012 21:01:54 37 0.0 0.1 0.00 ______............._. 09/24/2012 21:05:14 39 0.1 0.3 -0.00 09/24/2012 21:08:34 41 1.3 0.8 6.54 0912412012. 21:11:54 39 2.7 13.1 636 09/24/2012 21:15:14 39 0.2 20.e 8.36 09/24/2012 21:18:34 40 2.7 25.5 0.36 0000 09/24/2012 21:21:54 42 0.0 29.1 8.36 09/24/2012 21:25:14 41 0.0 29.1 0.36 09/24/2012 21:28:34 43 0.0 29.9 9.36 09/24/2012 21:31:54 42 0.0 29.9 8.36 09/24/2012 21:35:14 41 0.0 29.9 5.36 09/24/2012 21:38:34 42 0.0 33.2 835 09/24/2012 21:41:54 43 2.4 33.2 8.36 i 09/24/2012 21:45:14 43 0.0 40.5 8.37 __.0000..............._ 09/24/2012 21:48:32 43 0.0 44.8 8.37 Reset Total,Vol=4-4.83 bit 09/2412012 21:48:34 43 0.0 0.0 8.37 T 09/24/2012 21:48:52 43 0.0 0.0 8.38 .Rate Check Front Had,4bpm _ _ 0 000 ' 09/24/2012 21:51:52 1 43 ! 0.0 I 7.2 838 Reset Total,Vol.7.21 881 09/24/2012 2I:51:54 43 I 0.0 t D.0 ( 5.38 ° I' _ _ 0000_. 0000 Page 1614 J. i Ivrea nod ob Start C.tornar Tipb DIUmber SRU 2313-22 230-22 Swanson River UnitLSep/24/7012 teirorp I BYCN-00051 Date 7bna Pressure Flow 8sny Merry message 244w PS0 usts Polions nessItY /deo 8/M mi. 1.8/8 09/24/2012 21:52:27 43 I 4.0 0.6 • 8.37 Reset Total,Vol-.=0.55 bbl 09/24/2012 21:54:03 43 0.0 4.8 8.3B Reset Total,Vol.=4.83 bb! 09/24/2012 21:55:14 42 0.0 0.0 8.38 09/24/2012 21:55:20 43 0.0 0.0 8.38 Rate checks gond 09/24/2012 21:55:34 42 0.0 0.0 8.38 Standing by for rig to TO and assemble ant head 09/24/2012 21:58:34 43 0.0 0.0 837 09/34/2012 22:01:54 43 0.0 0.0 8.37 09/24/2012 22:05:14 42 0.0 0.0 8.37 09/24/2012 22:08:34 43 0.0 0.0 8.37 -- 09/2412012 22:11:54 43 0.0 0.0 8.37 09/24/2012 22:15:14 43 0.0 CO 6.37 09/24/2012 22:18:34 43 0.0 0.0 8..37 09/24/2012 22:21:54 44 0.0 0.0 8.37 09/24/2012 22:25:14 43 0.0 0.0 8.37 09,24/2012 2228:34 42 0.0 0.0 8.37 09/24/2012 22:31:54 42 0.0 0.0 8.37 .. 09/24/2012 22:35:14 43 0.0 0.0 8-17 09/2412011 22:38:34 43 0.0 0.0 8.37 09/24/2012 22:41:54 43 0.0 0.0 8.37 09/2412012 22:45:14 43 0.0 0.0 8.37 09/24/2012 22:48:34 43 0.0 0.0 9.37 - 09/24/2012 22:51:54 43 0.0 0.0 8.37 09/24/2012 22:54:29 43 0.0 0.0 8.37 Rig circulating;4.6 bpm,1200 re 09/24/20/2 22:55:14 43 0.0 0.0 8.37 D9/2412012 22:58:34 43 0.0 0.0 8.37 ......_,_._ 09/24/2012 23:01:54 42 0.0 0.0 8.37 09/24/2012 23:05:14 44 0.0 0.D L37 - 09/24/2012 13:08:34 43 0.0 0.0 8.37 09/24/1012 23:10:38 43 0.0 0.0 8.37 Rig continuing circulation 09/24/2012 23:11:54 43 0.0 0.0 8.37 09/24/2012 23:15:14 43 0.0 0.0 8.97 09/24/2012 231534 43 CO 0.0 0.37 09/24/2012 23:21:54 43 0.0 0.0 837 09/24/2012 23:25:14 43 0.0 0.0 8.37 09/24/2012 23:28:34 43 0.0 0.0 &37 09/24/2012 23131:54 43 0.0 0.0 838 -.1 09/24/2012 23:35:14 43 0.0 0.0 am 09/24/2012 23:38:34 42 0.0 0.0 8.38 09/24/2012 23:41:54 42 0.0 0.0 8.38 09/24/2011 234/5:14 43 0.0 0.0 8.38 ...., 09/24/2012 23:40:34 43 0.0 0.0 8.38 -, 09/24/2012 23:51:54 43 0.0 0.0 8.38 09/24/2012 23:55:14 43 0.0 0.0 gal •09/24/2012 23:58:34 43 0.0 0,9 8.38 --I 09/25/2012 00:01:54 43 0.0 0.0 838 09/25/2012 00:05:14 43 0.0 0.0 0.38 09/25/2012 00:08:34 43 0.0 0.0 8.38 09/25/2012 00:11:54 43 0.0 0.0 838 09/25/2012 00:15:14 43 0.0 0.0 8-15 09/25/2012 00:18:34 44 0.0 0.0 8.38 09/25/2012 00:21:54 42 0.0 0.0 11.39 0983/2012 00:25:14 43 0.0 0.0 8.38 09/25/2012 00:28:34 43 0.0 0.0 I 8.38 09/25/2012 00:31:54 43 0.0 0.0 8.38 , ......._ P.V•a 414 • Wei Fltldf..lob Storrs Outwear lob Number SRI 2313-22 238-22 Swanson River Unt Sep/24/2012 Hilearn BVCN-00051 Date Time Pressure Haw Slurry lorry , Neaupe 24-hr PSI Rare Volume Density dock B/14 8l. 18/e 09/25/2012 00:38:34 43 0.0 0.0 8.38 09/25/2012 00:41:54 43 5.5 3.9 8.36 09/25/2012 00:45:14 44 0.1 6.1 8.37 O 9/23/2012 00:48:34 43 0.0 6.3 8.37 09/25/2012 00:50:21 43 j 3.9 6.9 8.37 End P1SM 09/25/2012 00:51:25 43 0.2 11.1 8.35 Reset Total,Vol=11.13 bbl O 9/25/2012 00:51:54 44 0.2 0.0 8.36 09/25/2012 00:55:14 44 0.0 0.1. 8.37 09/25/2012 00:59:34 44 0.0 0.1 8.37 09/25/2012 01:01:54 45 0.0 0.1 8.37 09/25/2012 01:05:14 43 0.0 0.1 837 09/25/2012 01:07:42 : 52 0.0 0.1. 8.37 Blow dr down hardline 05/25/2012 01:08:04 123 0.1 0.1 8.37 Coring onloe 5 bol Oeste water 09/25/2012 01:08:34 418 0.8 0.5 8.36 99/25/2012 I 01:09:03 410 0.8 0.9 8.37 Start pumping S bbl fresh water ahead 09/25/2012 01:11:46 159 0.0 4.9 8.36 5 bbl away,shut In on rig floor 09/25/2012 01:11:54 150 0.0 4.9 8.36 09/25/2012 01:12:52 145 0.0 4.9 8.36 Shut In on rig,dear on floor 09/25/2012 01:14:00 1527 ,._ 0.0 4.9 6.37 Clear on ground,dear of floor 09/25/2012 01:14:06 1515 0.0 4.9 8.36 low PT 09/25/2012 01:14:21 1502 0.0 4.9 8.36 Trips hipped 09/25/2012 01:15:14 1482 0.0 4.9 8.37 O 9/25/2012 n 01:15:12 1942 0.1 4.9 837 Low good,a0 clear 09/25/2012 01:15:36 4419: 0.1 I 4.9 0.37 High PT 09/25/2012 01:17:53 4334 0.0 4.9 8.37 Nigh PT good,all dear on ground and rig 09/25/2012 01:18:34 57 0.0 4.9 8.37 09/25/2012 01:18:52 56 0.0 4.9 8.36 Pressure bled,SIB pump Isolated 09/25/2012 01:19:07 f 52 1 0.0 4.9 8.57 Rig lining up to pump MP 09/25/2012 01:19:39 54 0.0 4.9 8.37 I Reset Total,Vol=4.93 bd 09/25/2012 01:21:54 55 0.0 4.9 8.37 09/25/2012 01:23:14 55 0.0 , 4.9 8.36 Rig pumping MPII 09/25/2012 01:24:41 54 0.0 4.9 5.36 11 bbl MP away 09/258012 01:25:14 54 0.0 4.9 8.37 _. 09/25/2012 01:27:08 II 55 0.0 4.9 8.23 Stat brtdning cement 0985/2012 01:28:34 4 ^ 54 -_ 0.0 4.9 12.03 0985/2012 01:28:40 : 54 0.0 4.9 12.34 Rig dao pumping MP 09/25/2012 01:29:00 79 0.0 4.9 13.25 Lina up to pump dorm dp ^ 09/25/2012 01:31:54 66 0.0 4.9 15.25 09/25/2012 01:35:14 65 94 4.9 15.20 0985/2012 01:37:49 97 0.0 4.9 15.26 C.arfem to weight,15.3 PPS 09/25/2012 01:38:08 -....203 1.1 5.0 15.23 Purring rot 09/25/2012 01:38:34 412 1.4 5.4 15.41 09/25/2012 01:41:54 671 3.7 14.5 15.47 09/25/2012 01:42:59 167 4.5 16.2 14.91 Swap eat beetle 09/25/2012 01:45:14 554 3.0 22.2 15.22 09/25/2012 01:48:34 282 3.0 32.0 15.34 09/25/2012 01:51:54 260 3.1 42.1 15.26 09/25/2012 01:55:14 293 3.3 52.7 15.52 09/25/2012 ' 01:56:43 n 293 3.3 57.5 1 1531 1 18 lobi mix h2o away 09/25/2012 01:57:13 1 218 3.3 59.2 j 15.26 Swapped to bads bottle 09/25/2012 01:57:58 139 1.7 60.2 I 15.55 30 bbl mlic 1120 away,pumping down tub O 9/25/2012 01:58:34 185 2.4 61.3 15.72 09/252012 , 01:59:01 54 0.0 62.2 15.64 52 bbl commit away Nang nix water J - 09/25/2012 I 0159:371- 73 ltI 0.0 • 62.2 15.74 j Drop Dat I ...._ esee]oh4 f - - Wel I Reid Job Start Customer Job Nrmbor SRU 2311-22 236-22 Swanson River Unit 5eg124/2012 Hllcorp UCH-00051 Der 1 rine PressureRow berry Blurry Iteaape 24-hr !OIRets volume 0ananyty dock 5/M set tan 09/25/2012 02:04:34 176 0.0 66.1 9.06 TatUatdl indabed dart was dropped 09/25/2012 I 02:04:46 223 0.0 66.1 9.43 Rig start dlpladng,leave SLB open to monitor pressure 09/25/2012 02:05:14 152 0.0 66.1 10.66 09/25/2012 02:05:34 269 0.0 66.1 10.57 SLD washing up,stay rigged In 09/25/2012 02:09:34 1563 0.0 66.1 5.49 00/25/2012 02:11:54 1601 0.0 66.1 13.96 09/25/2012 02:15:14 1729 0.0 66.1 12.49 09/25/2012 02:19:34 904 0.0 66.1 0.49 09/25/2012 02:21:54 2040 0.0 66.1 7.64 09/25/2012 02125:14 2011 0.0 66.1 5.26 09/25/2012 02:25:34 2670 0.0 66.1 8.22 09/25/2012 02:31:54 2909 0.0 66.1 6.15^ 09/25/2012 02:35:14 59 0.0 66.1 2.42 09/25/2012 02:38:34. .3536 0.0 66.1 5.42 09/25/2012 02:41:54 2031 0.0 66.1 6.40 09/25/2012 02:45:14 59 0.0 66.1 1.41 09/25/201202:48:34 2702 0.0 66.1. &40 09/25/2012 02:51:54 55 0.0 66.1 9.36 09/25/2012 02:55:14 53 0.0 66.1 8.34 09/25/2012 02:58:34 2330 0.0 66.1 A� 09/25/2013 03:01:54 2257 _--- 0.0 66.1 6.34 09/25/2012 03:05:14 2214 0.0 66.1 8.34 00/25/2012 03:05:34 2434, 0.0 66.1 , 9.34 Post lob Summary Ibnge Peeve vara r bW/ t Voir a of PYId Loutltedr Or Awry Ml Stud i Semler=isle TOW llo,y sky !decor Ni 2.1 5.7 52.0 131.0 22.0 TreebnS Preoowe summery,pr lrwgieew irks Naske e e Play Avenge sump Plug to Breakdown Type 'Volume 0eledgr 4719 2417 355 3000 J bbl WO Avg.Na Percent Designed flurry Volume Weptecomrrt Water Temp Caret Cktrsd to SWUM/ 0 WI bbl 44 52.0 bid 136.0 bbl 1.14h: 75 0066 Tr.>+.es El io R Cunt:mew or Oetiorlood Representative _.. 5ddumbemer superoMor 4lrrdrls tela 0 3sb Completed CI ]irony Greco Undy 0yerly - - Vigo 4al4 • F i tv \�� 1/77s� THE STATE Alaska Oil and Gas �� OfALASI�:A - __A_ Conservation Commission �wo ., GOVERNOR SEAN PARNELL 333 West Seventh Avenue O !- Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Chad Helgeson Operations EngineerQ 7 Hilcorp Alaska, LLC 9.1 .--'-"-3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, Swanson River Unit 23B-22 Sundry Number: 312-367 Dear Mr. Helgeson: 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 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, -14;.L /9)(fe,c 1 Cathy P.7 . oerster Chair DATED this Zr day of October, 2012. Encl. , RECEIVED • iiik/.11/y S E 2 6 2012 ' /1 STATE OF ALASKA er AOGCC ` ALASKA OIL AND GAS CONSERVATION COMMISSION A C APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program 0 Suspend❑ Plug Perforations 0 Perforate Q • Pull Tubing 0 Time Extension 0 Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing ❑ Other. Complete I. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Development Q Exploratory ❑ 212-078 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 100,Anchorage,AK 99503 50-133-10148-01 • 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 CI No Q • Swanson River Unit(SRU)23B-22 , 9.Property Designation(Lease Number): 10.Field/Pool(s): A028406 ' Swanson River Field/Hemlock Oil • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 11,741 10,902 • 11,650 10,860 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 38' 22" 38' Surface 3,001' 11-3/4" 3,001' 3,001' 3,070 psi 1,510 psi Intermediate 9,720' 7" 9,720' 9,720' 6,340 psi 3,830 psi Production Liner 2,382' 4-1/2" 11,982 11,300' 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/L-80 9,550' Packers and SSSV Type: Arrowset Mechanical Pkr Packers and SSSV MD(ft)and ND(ft): 9,550'MD;9,550'ND N/A N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑✓ • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Operations: 9/27/2012 CommencingOil 2 Gas ❑ - ❑ WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned 0 Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chad Helgeson 777-8405 Printed Name Chad Helgeson Title Operations Engineer Signature lnnnjC Phone 777-8405 Date 9/25/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 12 3(151 Plug Integrity ❑ BOP Test Mechanical Integrity Tlest ❑ Location Clearance ❑ Other 7 CS t. /3 d/ / d 206 /1-11 T1 oL r (4 coo p5 i trTa >Gfir''' ) Subsequent Form Required: P - 46 �' APPROVED BY Approved by: ‘2.Wtki' �7 COMMISSIONER THE COMMISSION Date: ID - ( 7– fli Form 10-403 Revised 1/2010 ORIGIVAALS OCT 0 4 201 /`(/ .su mit in Duplicate • 1 � Well Prognosis Well: SRU 23B-22 Hilcorp Alaska,LLC Date:9/24/2012 Well Name: SRU 23B-22 API Number: 50-133-10148-01 Current Status: New Cased Oil Producer Leg: N/A Estimated Start Date: September 29, 2012 Rig: Williams 405 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 212-078 First Call Engineer: Chad Helgeson (907)777-8405 (0) (907)229-4824 (M) Second Call Engineer: Luke Saugier (907)777-8395 (0) AFE Number: 1211616 Current Bottom Hole Pressure: —3,117 psi @ 10,841' TVD (Based on reservoir modeling of known nearby reservoir pressures) Maximum Expected BHP: — 5,832 psi @ 10,800' TVD (Using max .54psi/ft gradient, possible max virgin pressure) Max. Allowable Surface Pressure: —609 psi (Based on 6% KCI brine left in the well 1 when perforating) Brief Well Summary This well was sidetracked with the Doyon Arctic Fox in September 2012. Completion will be run with the Arctic Fox rig. Notes Regarding Wellbore Condition • The well will be cased with 6%KCI brine left in the well. No open perforations. I Brief completion procedure: /30P to 4-voOps , 1. Cleanout and displace mud in well with PW and then sweep and chase with clean 6%KCI fluid. 2. Tag PBTD,ensure depth is at least 11,630'. 3. POOH LD 4" Drill Pipe 4. RU eline, RIH with Gamma-Ray/CCL and CBL and log from TD to 7,000ft with roller boogies. 5. PU TCP Equipment. a. Ensure a good strap/tally on all pipe and TCP equipment RIH. (no room for errors or mistakes in pipe tally) 6. Lay out all guns in order from the bottom to the top. 7. Run TCP completion, 2-3/4" TCP guns (90ft total perfs, 185ft overall length), Firing head, ported sub, 2 joints of 2-3/" tubing, RA Marker sub, 60 joints of 2-3/8" 8rd EUE workstring with pup joint every 20 joints,XO to 3-1/2" 8rd tubing, Run new 3-1/2"8rd EUE tubing to surface. 8. RU E-line to correlate the guns are on depth. 9. POH w/eline, RD eline. 10. Install kelly safety valve at surface with pump-in sub and pressure gauges 11. Close annular, pressure up tubing and fire guns 12. Monitor well for at least 30 min. Determine if the well is flowing, static or losing fluid, note any changes. 13. Circulate tubing with 6%KCL fluid or KWF if well has any pressure. 14. Ensure no gas and well is stable. 15. TOOH, rack back 3-1/2"tubing, LD 2-3/8"workstring, LD TCP guns, ensure all shots fired. , ll Well Prognosis Well: SRU 23B-22 Hilcorp Alaska,LLC Date:9/24/2012 16. RIH with 3-1/2" EUE 8rd tubing, GL mandrels(per design), and mechanical packer as described on attached diagram to 9,550ft. 17. Test casing to 2,500 PSI and tubing to 3,000 PSI, chart and record for 30 min. 18. Set BPV, ND BOP, RU Tree (test to 5000 psi) 19. RDMO rig and equipment. 20. Turn well over to production. Attachments: 1. Proposed Schematic Swanson River Unit II Well SRU 23B-22 PROPOSED Future Hileorp Aleeka,LL( PTD#212-078 239'Above MSL CASING DETAIL KB THF:20' Size Type Wt Grade Conn. ID Top Btm 1 I�dN 1 l 22" Conductor - - - Surf 38' 22" 2 a y 1 � D 11-3/4" Surf.Csg 47 J-55 Buttress 11" Surf 3,001' 1" r ;,0 2 4 I' 29 N-80 Buttress 6.184" Surf 114' II: I lj 23 N-80 Buttress 6.366" 114' 4,886' rol 3 t. 7" Intermediate 26 N-80 Buttress 6.276" 4,886' 6,781' 11-3/4"41 s' 29 N-80 Buttress 6.184" 6,781' 8,565' M 29 P-110 Buttress 6.184" 8,565' 9,720' 1,4 4 4111D i IA, 4-1/2" Prod Lnr 12.6 N-80 IBT IBT 3.958" 9,600' 11,982' t1' tiw ,N TUBING DETAIL 3-1/2" Production 9.3 L-80 8RD 2.441 Surf 9,550' 5 i JEWELRY DETAIL No. Depth ID OD Item 61 6 4 b 1 20' 2.99" - Tubing Hanger 1, i+' 2 2,300' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD 4 44 3 3,400' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD t4d 7 e11 1 4 4,500' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD I5 5,600' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD 8 " 14. 6 7,200' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD 7 8,200' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD 1, 8 8,900' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD 174 9 4.14- i °a M 9 9,400' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD ke' 10 . r:, I.' I ,,. I 4'y 10 9,545' 2.813" 5.75" On/Off Tool w/X Nipple _ 11 9,550' 3.0" 6.08" Arrowset Mechanical Packer •11 12 9,560' 2.813" 4.0" WL Entry Guide w/X Nipple 7„ ' 12 Tr, Whip-stock @ 9 720 PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Detail G2 11,433' 11,440' 10,795' 10,797' 6 7' 2-3/4"TCP HMX • 0' H2 11,482' 11,507' 10,812' 10,820' 6 25' 2-3/4"TCP HMX �' H3 11,534' 11,569' 10,830' 10,842' 6 35' 2-3/4"TCP HMX 11 H3 11,595' 11,618' 10,851' 10,859' 6 23' 2-3/4"TCP HMX ;,f r l fg P 4 i G2 to H3 4-1/2"k'"" 70.2'Deviation,6 deg TD=11,741'/ND=10,902' build starts at 9,800' PBTD= Revised By CAH 9/25/2012 Ferguson, Victoria L (DOA) From: Ferguson, Victoria L(DOA) Sent: Friday, September 28, 2012 11:03 AM To: 'Chad Helgeson' Cc: Schwartz, Guy L(DOA) Subject: SRU 23B-22(PTD 212-078, Sundry 312-367) Chad, You have verbal approval to proceed with this sundry. Please note the BOPs must be tested to 4000 psi and the AOGCC must be notified in advance. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria ferquson analaska qov 1 • • °F 7.1 / THE STATE Alaska Oil and Gas ALASKA � _ :_�,;_ Conservation Commission Witt ^ti GOVERNOR SEAN PARNELL 333 West Seventh Avenue 9°' L Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Chad Helgeson Operations Engineer Hilcorp Alaska, LLC 1 1 3800 Centerpoint Drive, Suite 100 d� Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SRU 23B-22 Sundry Number: 312-378 Dear Mr. Helgeson: 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 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, (2:4 Cathy v Foerster Chair DATED this S day of October, 2012. Encl. IV Jo is STATE OF ALASKA V RECEIVED o OCT 03 2012 Z ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations ❑ Perforate❑✓ Pull Tubing❑✓ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other: Complete ❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development Q Exploratory ❑ _ 212-078 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 100,Anchorage,AK 99503 50-133-10148-01 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 CI No 2Swenson River Unit(SRU)23B-22 9.Property Designation(Lease Number): 10.Field/Pool(s): A028406 Swanson River Field/Hemlock ON 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): 'Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11,741 10,902 11,650 10,860 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 38' 22" 38' Surface 3,001' 11-3/4" 3,001' 3,001' 3,070 psi 1,510 psi Intermediate 9,720' 7" 9,720' 9,720' 6,340 psi 3,830 psi Production Liner 2,382' 4-1/2" 11,982 11,300' 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: 2-3/8" Tubing Grade: 6.4#/L-80 Tubing MD(ft): 11,364 See Attached Schematic See Attached Schematic 3-1/2" 9.3#/L-80 9,415 Packers and SSSV Type: N/A Packers and SSSV MD(t)and TVD(ft): N/A N/A N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Development ❑✓ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 10/5/2012 Commencing Operations: Oil ❑✓ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A /plsl/Z WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: SaA-- GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is trrle and correct to the best of my knowledge. Contact Chad Helgeson 777-8405 Printed Name Chad'HHeeelgeesson Title Operations Engineer Signature ��r% Phone 777-8405 Date 1W3/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: l/-12,_. 3-.)?' Plug Integrity ❑ BOP Test [ Mechanical Integrity Test ❑ Location Clearance ❑ Other: /frt.'f't 4.,e S o/ -7--.1--- [ 5ve ,a$ " / ( .6Subsequent Form Required: /6 - zip 7 / Will era) APPROVED BY Approved by: L6 t�j ` �SF�-� COMMISSIONER TH OMMISSION Date: l`)- S- /a_ Form 10-403 evised 1/2010 Submit in Dplicate Well Prognosis Rev 1 Well: SRU 23B-22 Hilcora Alaska,LLC Date:10/3/2012 Well Name: SRU 23B-22 API Number: 50-133-10148-01 Current Status: New Cased Oil Producer Leg: N/A Estimated Start Date: October 5th,2012 Rig: Williams 405 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 212-078 First Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824 (M) Second Call Engineer: Luke Saugier (907)777-8395 (0) AFE Number: 1211616 Current Bottom Hole Pressure: —3,117 psi @ 10,841' ND (Based on reservoir modeling of known nearby reservoir pressures) Maximum Expected BHP: —5,832 psi @ 10,800' TVD (Using max .54psi/ft gradient, possible max virgin pressure) Max. Allowable Surface Pressure: —609 psi (Based on 6% KCI brine left in the well when perforating) Brief Well Summary This well was sidetracked with the Doyon Arctic Fox in September 2012. There were problems getting TCP guns to bottom with the Arctic Fox Rig and it was decided for maximum efficiency of the drilling and completion rigs to move the Doyon Rig to drilling its next well and the completion will be run with the Williams Rig 405. Notes Regarding Wellbore Condition The well is cased with 6% KCI brine, 9,457'of 3-1/2"tubing, 1,914' of 2-3/8" with 231' of TCP assembly (90ft of live guns- pressure activated). No open perforations. ✓ Completion procedure: 1. Monitor pressure on tree(2-3 times/day), Bleed any pressure that has built up, notify engineer if 1,000 psi is observed. 2. MIRU Williams 405 workover rig. 3. Set TWC. ND Tree, NU 7" BOP stack and test with the following guidelines(notify AOGCC& BLM 24hr in advance of test) a. Test BOP's to 1500 psi on pipe and shear rams, choke and manifold equipment to 300CLasi. b. Leave casing valve open during test to ensure that pressure does not build on TCP guns (guns fire at a minimum pressure of 2,100 psi). 4. Pull BPV, Pull 3-1/2"tubing and 2-3/8"tubing and LD Halliburton TCP guns. 5. Test BOP(blind rams and shear rams) (notify AOGCC 24hrs in advance)to 3,000 psi. 6. PU cleanout BHA, 3.75 4-blade bit and mud motor. (RIH w/72 joints of 2-3/8"tubing and approximately 298 joints of 3-1/2"tubing to surface) 7. RIH and clean to bottom 11,650', (Liner hanger at 9,512'). 8. Circulate and filter 6%KCI fluid. (filter to 10 micron filters) 9. PU TCP completion a. Ensure a good strap/tally on all pipe and TCP equipment RIH. b. Lay out all guns in order from the bottom to the top. Well Prognosis Rev 1 Well: SRU 23B-22 Hilcorp Alaska,LLC Date:10/3/2012 10. Run TCP completion, 2-3/4" TCP guns (90ft total perfs, 185ft overall length), Firing head, ported sub, 2 joints of 2-3/8" tubing, RA Marker sub, 62 joints of 2-3/8" 8rd EUE workstring with pup joint every 20 joints,XO to 3-1/2"8rd tubing, Run 3-1/2" 8rd EUE tubing to surface. 11. RIH correlate w/eline,spot gun on depth 12. Install kelly safety valve at surface with pump-in sub and pressure gauges 13. Close annular, pressure up tubing and fire guns a. Pressure activated firing head (minimum -2100 psi, Maximum 2,800 psi) b. 6 min delay timer on firing head c. Bleed pressure on tubing and casing to zero after activating guns. 14. Monitor well for 30 min, a. If fluid level drops,obtain fluid level measurement every 10 min until stagnant, note fluid levels. b. Fill hole and circulate BU. c. If well makes fluid,weight up and circulate KW brine so well is stable. 15. Assuming no flow,TOH, laydown 2-3/8"tubing and TCP assembly a. Ensure all guns fired 16. RIH w/completion on 3-1/2"tubing(mechanical packer and gas lift valves as shown on diagram), set at approx. 9,550ft. 17. Set packer, drop RHCP spear and test tubing and chart for 30 min, (3,000 psi on tubing and 2,500 psi on casing) 18. Set BPV, ND BOP, NU Tree test(5,000 psi). 19. RDMO rig and equipment. 20. Turn well over to production. 21. RU Gas lift, unload fluid with gas lift 22. RU Slickline, RIH and pull plug and prong from XN-nipple. 23. Flow well to production Attachments: 1. Existing Well Schematic(As left by Doyon work) 2. Proposed Schematic 3. Williams BOP Schematic , . . . , 11 Current Well Diagram Swanson River Unit Well SRU 23B-22 Post Doyon Arctic Fox Work mk•orp nidgka.LL(: PTD#212-078 239'Above MSL CASING DETAIL KB THF:20' Size Type Wt Grade Conn. ID Top Btm +A 1 ;d 22" Conductor - - - Surf 38' 22" V+ '•' � 11-3/4" Surf.Csg 47 J-55 Buttress 11" Surf 3,001' ,* i,; 29 N-80 Buttress 6.184" Surf 114' vi , 23 N-80 Buttress 6.366" 114' 4,886' 11-3/4" -- ,*, 7" Intermediate 26 N-80 Buttress 6.276" 4,886' 6,781' a 1 29 N-80 Buttress 6.184" 6,781' 8,565' Y el29 P-110 Buttress 6.184" 8,565' 9,720' :i ;f! 4-1/2" Prod Lnr 12.6 N-80 IBT 3.958" 9,512' 11,982' e IBT +ie ��+ TUBING DETAIL 11 3-1/2" Production 9.3 L-80 8RD 2.933 Surf 9,415' 'j Ai 2-3/8" Production 6.4 L-80 8RD 1.995 9,415' 11,364' JEWELRY DETAIL 04 iso No. Depth ID OD Item y 1 20' 2.99" - Tubing Hanger .P 2 9,415' 1.99" 4.0 3-1/2"box X 2-3/8"pin XO 3 11,330' 1.99 3.0 RA Marker Sub t' r• 4 11,364' 1.5 3.0 Ported Sub w/XO ^; �� Firing Head w/DCL Sub 5 1113 _ 560'NA 2.75 2.75"TCP gun assembly +54, 90ft of guns,OAL 195ft • 'M+ 1 x r ,; Y 2 _ Ai Liner Hanger ,�, � @ 9,512' 7" �iWhip-stock @ ' 44. 9,720' VI a Y 4 1 L. %. I S` 7' 1 .? .A -A l it J.: I i ;, ! 3 NV 111 cy „ r, F4 r5i 4, !*, b+ x' _ . ice; 4-1/2"k' "-e6 70.2'Deviation,6 deg build TD=11,741'/ND=10,902' starts at 9,800' PBTD=11,650'/ND=10,860' Revised By TDF 10/3/2012 Swanson River Unit Well SRU 23B-22 PROPOSED Future Hilrorp AlaAka,IAA: PTD#212-078 239'Above MSL CASING DETAIL KB-THF:20' Size Type Wt Grade Conn. ID Top Btm J t,, 1 iilD 22" Conductor - - - Surf 38' 10 22 a � 11-3/4" Surf.Csg 47 J-55 Buttress 11" Surf 3,001' - 29 N-80 Buttress 6.184" Surf 114' , 1 1 23 N-80 Buttress 6.366" 114' 4,886' "' 2 INK ,, 7" Intermediate 26 N-80 Buttress 6.276" 4,886' 6,781' 11-3/4" ,r, 29 N-80 Buttress 6.184" 6,781' 8,565' )+ 29 P-110 Buttress 6.184" 8,565' 9,720' x '•1' 4-1/2" Prod Lnr 12.6 N-80 IBT IBT 3.958" 9,512' 11,982' 3 MIN i TUBING DETAIL 1 3-1/2" Production 9.3 L-80 8RD 2.441 Surf 9,510' tipiV JEWELRY DETAIL 1 4 MIN i' 04 No. Depth ID OD Item 1 20' 2.99" - Tubing Hanger Fs 2 2,700' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD 5 i ,r 3 5,000' 2.867" 5.313" 3-1/2"SFO-1 Mandrel 8RD qv 1 " 4 6,800' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD 5 8,000' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD %, 6 i. r" 6 8,900' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD 1,4 7 9,460' 2.867" 5.313" 3-1/2"SF0-1 Mandrel 8RD 'W °W e 8 9,490' 2.813" 5.75" On/Off Tool w/X Nipple 7 ^ f`i * 8 9 9,500' 3.0" 6.08" Arrowset Mechanical Packer 1 �•` 10 9,510' 2.813" 4.0" WL Entry Guide w/X Nipple , 1.1 a Liner Hanger 0, 9 �, @ 9,512' 7"2 '4 10 Whip-stock @ •'� 9 720 PERFORATION DETAIL IP Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Detail 1 G2 11,433' 11,440' 10,795' 10,797' 6 7' 2-3/4"TCP HMX 14 i4` i W H2 11,482' 11,507' 10,812' 10,820' 6 25' 2-3/4"TCP HMX H3 11,534' 11,569' 10,830 10,842' 6 35' 2-3/4"TCP HMX H3 11,595' 11,618' 10,851' 10,859' 6 23' 2-3/4"TCP HMX *4 y{ 1.i *il 4i 1 ii G2 to H3 J 4-1/2't1f .` 70.2°Deviation,6 deg TD=11,741'/TVD=10,902' build starts at 9,800' PBTD=11,650'/TVD=10,860' Revised By TDF 9/27/2012 Swanson River 2012 Williams Rig BOP 07/31/2012 01405 a 3.07' Hydr•11110i- GK 7 1/16-5000 lil Ill III rli lil _ UJJI!I = I1.11111 ciw u IIiS_: 3.68' _i�� 1. 4[ ��I 71/16-5000 hiD- ififtnfTh Eft Choke and Kill Valves 2 1/16 10M Ill [1 ti Ullt — t 1101I . 2.00' 71/16" �l(• ) !IIO.II0 _50_0 _ lel " Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, October 05, 2012 12:19 PM To: 'Chad Helgeson' Cc: Awhudgens75@yahoo.in Subject: RE: 2313-22 Sundry Approval (PTD 212-078) Attachments: SRU 23B-22 .pdf Chad , You have verbal approval to rig up Williams 405 and proceed with the completion as outlined in the attached sundry. Please forward this email and scanned sundry copy to the rig. A signed copy of the Sundry (#312-378)will be ready for pickup approx. Monday morning. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Chad Helgeson [mailto:chelgeson@hilcorp.com] Sent: Friday, October 05, 2012 11:59 AM To: Schwartz, Guy L (DOA) Cc: Awhudgens75@yahoo.in Subject: 23B-22 Sundry Approval Guy, Can we get a verbal approval on the Swanson River 23B-22 completion/pull TCP guns with the Williams rig? The Doyon rig will finish moving off location today and would like to start work tomorrow with the Williams rig. Thanks Chad Helgeson Operations Engineer Hilcorp Alaska, LLC Office: 907-777-8405 Mobile: 907-229-4824 10/5/2012 Page 1 of 3 Schwartz, Guy L (DOA) From: Chad Helgeson [chelgeson@hilcorp.com] Sent: Wednesday, October 03, 2012 10:05 AM To: Schwartz, Guy L (DOA) Subject: RE: Swanson Arctic Fox change We can do a TWC. I'll write that up and submit it to you. Chad From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, October 03, 2012 10:04 AM To: Chad Helgeson Cc: Luke Saugier; Luke Keller; Stan Golis; Paul Mazzolini; Kevin Eastham; Ferguson, Victoria L(DOA); Rance Pederson - (C); Mike Leslie Subject: RE: Swanson Arctic Fox change Chad, I agree with basic steps... question on number one below though regarding first BOP test. Why not a TWC instead of BPV? Monitor IA for leaking TWC during BOP test..... Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Chad Helgeson [mailto:chelgeson@hilcorp.com] Sent: Tuesday, October 02, 2012 3:12 PM To: Schwartz, Guy L (DOA) Cc: Luke Saugier; Luke Keller; Stan Golis; Paul Mazzolini; Kevin Eastham; Ferguson, Victoria L (DOA); Rance Pederson - (C); Mike Leslie Subject: RE: Swanson Arctic Fox change Guy, We have checked with Halliburton and these guns are set to fire with the current fluid in the well with a minimum pressure of 2100 psi at surface. The max pressure is 2,800 psi. I would like to request the following to ensure that we don't build pressure and accidently fire the guns before we pull them out of the well. 1. Test BOP's to 1500 psi on initial rig up, against a BPV. 2. Test BOP's to 3000 psi after TCP's are removed from the well, before running back in the well. 3. There is a flow sub on bottom that should allow us to monitor the casing pressure on the well, during BOP testing 4. We will leave the wellhead open with a gauge and can monitor the pressure multiple times a day to ensure that we do not build any pressure. Let me know if these items seem satisfactory to you and we will get the new 10-403 submitted tomorrow. Thanks Chad 10/5/2012 Page 2 of 3 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, October 02, 2012 1:34 PM To: Chad Helgeson Cc: Luke Saugier; Luke Keller; Stan Golis; Paul Mazzolini; Kevin Eastham; Ferguson, Victoria L (DOA) Subject: RE: Swanson Arctic Fox change Chad, In principle I don't think there are any issues except having live guns in the well. When Williams 405 arrives how will you test BOP's? I assume you will test against a test plug or TWC? If this leaks you could pressure up the tbg/casing ( not very likely but possible). You can monitor IA pressure with a gauge during BOP testing operations (if there is a communication pathway between tubing and IA below hanger). It would also be a good idea to keep an eye on the wellhead pressure (via inner annulus gauge) while you wait on 405 in case there are any thermal effects on pressure since you have a closed system. Please address this question and then submit a 403 sundry for the Williams rig operations you outline below.. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Chad Helgeson [mailto:chelgeson@hilcorp.com] Sent: Tuesday, October 02, 2012 11:29 AM To: Schwartz, Guy L (DOA) Cc: Luke Saugier; Luke Keller; Stan Golis; Paul Mazzolini; Kevin Eastham; Ferguson, Victoria L (DOA) Subject: Swanson Arctic Fox change Guy, We have had some issues with getting our TCP guns on bottom in the SRU 23B-22 sidetrack well (PTD#212- 078). Currently we have 9,457' of 3-1/2"tubing in the well and 1,914' of 2-3/8" with 231'of TCP assembly(90ft of guns). We would like to move forward with the following plan. - Lay down 4 joints of tubing(equivalent pipe depth of 11,494') - Stand back 4 joints of tubing(124ft) - Pickup an RTTS(storm) packer and set 124ft below rig floor. Pull the wear bushing. - Pull the RTTS packer, land the tubing hanger - ND BOP, NU Tree, set BPV—Do not pressure up on tubing,as pressure activated TCP guns are in the well - RD and Move Doyon Arctic Fox to SCU 44-33. - MIRU Williams#405 - ND Tree, NU 7" BOP stack and test - Pull BPV, Pull 3-1/2"tubing. Lay down 2-3/8"tubing and TCP guns with Halliburton - PU 2-7/8"workstring with 3.8" mill and collars - RIH and clean to bottom, or below 11,620'. - Circulate and filter 6% KCI fluid - PU TCP completion, RIH correlate w/eline and fire guns. - Monitor well,circulate BU. - Assuming no flow,TOH, laydown pipe 10/5/2012 Page 3 of 3 - PU 3-1/2" tubing, RIH w/completion (packer and gas lift valves) - Test tubing and casing - Set BPV, ND BOP, NU Tree test. - RD move off location Please let me know if you agree with this and we will create a new 10-403 for this work and start proceeding in this direction. If you have any questions, please let me know. Chad Helgeson Operations Engineer Hilcorp Alaska, LLC Office: 907-777-8405 Mobile: 907-229-4824 10/5/2012 Landon Ellison Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8337 HiIrorp Moan.,L A Fax: 907 777-8510 E-mail: doudean@hilcorp.com 12/20/12 To: AOGCC Makana Bender 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTA SRU 23B-22 Prints: SRU 23B-22 Formation Log MD 2"=100-' SRU 23B-22 Formation Log TVD 2"=1004- SRU "=100'SRU 23B-22 LWD Combo Log MD 2"=100 SRU 23B-22 LWD Combo Log ND 2"=100' SRU 23B-22 Gas Ratio Log MD 2"=100 SRU 23B-22 Gas Ratio Log ND 2"=100 r SRU 23B-22 Drilling Dynamics MD 2"=100 SRU 23B-22 Drilling Dynamics TVD 2"=100 SRU 23B-22 Final Well Report.doc CD: Final Well Data g C1 q `{ DAILY REPORTS See CD -- DML DATA See CD " FINAL WELL REPORT SRU 23B-22 Final Well Report.doc,- SRU 23B-22 Final Well Report.pdf LAS FILE SRU 23B-22.1as LOG PDF FILES SRU 23B-22 Formation Log MD.pdf SRU 23B-22 LWD Combo Log MD.pdf SRU 23B-22 Gas Ratio Log MD.pdf - SRU 23B-22 Drilling Dynamics MD.pdf ' CD: Final Survey D to See CD Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: 0114 Date: Z 33_jL Prb Zjz07Y0 Regg, James B (DOA) From: Rance Pederson -(C) [rpederson@hilcorp.com] Sent: Tuesday, September 04, 2012 8:23 PM j� TIC I( v To: DOA AOGCC Prudhoe Bay; Regg, James B (DOA) Cc: Paul Mazzolini; Luke Keller Subject: Reporting BOPE Use Gentlemen, As per the AOGCC Guidance Bulletin No. 10-003 I would like to report the use of our BOP. Date/Time of BOPE Use: 9/3/2012 and 9/4/2012 - Well/Location/PTD Number: Well 23B-22, Swanson River Field, PTD 2120780 Rig Name: Doyon Arctic Fox (rig#1) • Operator Contact: Rance Pederson at 907-398-4847 Operations Summary: On 9/3/2012 we had milled our window and 24' of new formation, performed an FIT, monitored well and POOH for BHA change. Upon nearing surface we noticed the well begin to flow. We ran the same milling BHA back to bottom in order to circulate from 9.2ppg to 9.4ppg in hopes to kill the well.As we were getting our initial bottoms up the gas units began to rise so we closed the annular at 22:00 hrs and continued circulating through an open choke so as not to have any fluid loss over the flow riser in the cellar, due to gas breaking out of the mud. Once the gas units dropped we opened the annular and continued circulating down the flowline. On 9/4/2012 at 07:00 we had increased our mud weight to 9.6ppg and still had approximately 1 bbl per hour flow. Decision was made to shut in the annular and monitor pressure build so as to determine kill weight mud needed. Once this was achieved we again opened the annular and circulated while increasing mud weight to 9.8ppg. BOPE Used: Annular Preventer, Kill Line HCR and Auto Choke — Reason for BOPE Use: Initially to prevent fluid from spilling over flow riser while circulating bottoms up, anticipating gas to surface. Secondly to obtain shut in pressures and determine kill weight needed. Actions Taken/To Be Taken: Notifications of closures were made to Hilcorp Drilling Manager and Drilling Engineer. BOPE was initially tested on 8/30/2012, and is again due for testing on 9/6/2012. Rance Pederson Hilcorp Drilling Foreman 907-398-4847 1 Swanson River Unit n ., , .... . , . Well SRU 23B-22 _. . , ASBUILT Last Completed Future Hilcorp nlimok.,1.1.c PTD:XXX-XXX ^7 1)7-1) 24Z —637 239'Above MSL Casing & Tubing KB-THF:20' Size Type Wt Grade Conn. ID Top Btm 22" a 1 I 1-7r I 22" Conductor - - - Surf 38' D 11-3/4" Surf.Csg 47 1-55 Buttress 11" Surf 3,001' & -26-12— , 21 jj 29 N-80 Buttress 6.184" Surf 114' 23 N-80 Buttress 6.366" 114' 4,886' 3•—.la 7" Intermediate 26 N-80 Buttress 6.276" 4,886' 6,781' 11-3/4" 29 N-80 Buttress 6.184" 6,781' 8,565' 29 P-110 Buttress 6.184" 8,565' 11,000' 4 t tj 4-1/2" Prod Lnr 12.6 N-80 IBT IBT 3.958" 7,900' 10,143' Tubing ' 3-1/2" Production 9.2 L-80 IBT IBT 2.441 Surf 7,900 sa l �, JEWELRY DETAIL '; r 6 No. Depth ID OD Item ,* , 1 20' 2.44" - Tubing Hanger 2 1,300' 2.44" 4.750" 3-1/2"SFO-1 Mandrel 8RD 12 port a •0 , 7 3 2,400' 2.44" 4.750" 3-1/2"SF0-1 Mandrel 8RD 12 port °' 4 3,500' 2.44" 4.750" 3-1/2"SF0-1 Mandrel 8RD 12 port - 5 4,600' 2.44" 4.750" 3-1/2"SFO-1 Mandrel 8RD 12 port i 8 S' ' 6 5,200' 2.44" 4.750" 3-1/2"SFO-1 Mandrel 8RD 12 port ... 7 6,200' 2.44" 4.750" 3-1/2"SF0-1 Mandrel 8RD 12 port y 9 '7 8 6,900' 2.44" 4.750" 3-1/2"SFO-1 Mandrel 8RD 12 port `4, lei It. ": 9 7,900' 2.44" 4.750" 3-1/2"SF0-1 Mandrel 8RD 12 port :' I I 10 9,860' 2.000" 6.5" On/Off Tool w/X Nipple MUM: - 11 9,880' 1.978" 4.140" Arrowset Mechanical Packer 11 _' 12 9,900' - - WL Entry Guide w/X Nipple � w. 7„2a 12 4-1/2"I. .. TD=11,982/TVD=11,300' SRU 23B-22 Proposed Well Schematic 6-20-2012.doc Updated by TDF 6/20/2012 f' `_' I N �' SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W 7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Paul Mazzolini Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive Anchorage, AK 99524 Re: Swanson River Field, Hemlock Oil Pool, SRU-23B-22 Hilcorp Alaska, LLC Permit No: 212-078 Surface Location: 738' FSL, 637' FWL, SEC. 22, T8N, R9W, SM Bottomhole Location: 1650' FSL, 1470' FWL, SEC. 22, T8N, R9W, SM Dear Mr. Mazzolini: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval 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. Sincerely, r Cathy P/Foerster Chair kek DATED this day of June, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department.of Environmental Conservation w/o encl. (via e-mail) ep' 6-tiZ"1" RECEIVED STATE OF ALASKA JUN 8 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 12. AOGCC 20 AAC 25.005 �iv tt, 1 a.Type of Work: ' lb.Proposed Well Class: Development-Oil 0 - Service- Winj ❑ Single Zone d l 1 c.Specify if well Is proposed for: Drill ❑ Redrill ❑� Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond:,pj Blanket ❑ Single Well ❑ 11.Wed Name and Number: W� SRU 238-22 Hilcorp Alaska,LLC Bond Z?r�3SZ��-�,2�35�1 . 3 Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Dr,Anchorage,AK,99524 MD: 11,982 - TVD: 11,300 Hemlock Oil Pool • 4a Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 738'FSL,637'FWL,Sec 22,T8N,R9W,S A028406 - Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1069'FSL,940'FWL,Sec 22,T8N,R9W,S N/A 8/1/2012 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1650'FSL,1470'FWL,Sec 22,T8N,R9W,S 2400 1000'east of adjoining lease A02877 4b Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL:259 feet 15.Distance to Nearest Well Open Surface: x-348436.9 y- 2472450.3 Zone-4 GL Elevation above MSL:239 feet to Same Pool: SRU 21-27(2,048') 16 Deviated wells: Kickoff depth: 10,100 feet ' 17.Maximum Anticipated Pressures In psig(see 20 AAC 25.035) Maximum Hole Angle: 69 degrees . Downhole: 3424 psig ' Surface: 2294 pSig • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Conn Length MD TVD MD TVD (including stage data) 6" 4-1/2" 12.6 L-80 Hydril 521 2082' 9900' 9900' 11,982 11,300 234 ft3(Single stage) 19 PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface 3001 11-3/4" 1920 sx 3001 3001 Intermediate Production 11,000' 7' 1500 ax 11,000' 3,001' Liner Perforation Depth MD(ft): 10,828'to 10,850', 10,859'to 10,863' Perforation Depth TVD(ft): 10,828'to 10,850•, 10,859'to 10,863' 20 Attachments: Property Plat Q BOP Sketch Q Drilling Program Q Time v.Depth Plot Q Shallow Hazard Analysis❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑� 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22 I hereby certify that the foregoing is true and correct. Contact Printed Name PP AA- !"(l4Z101-IiJ( 1 Title 12,1L.Lfu„1G Mielave}6.6,t' Signature �C.c-A-e.. / Phone '?67-777-836q Date 0447120 i� ` Commission Use Only Permit to Drill API Number: /3 -/O/(7/ Permit A lov, I ^ I See cover letter for other Number: �� 50-l� �/�}/� `ii Date: p1 1)�Z'/ ,1 I requirements. Conditions of approval: If box is checked,well may not beySused to explore for,test,or produce coalbed methane, s hydrates,or gas contained in shales: 27 Other: , 5a0 r.` „*„E iJ 15c9P /e � Samples req'd: Yes❑ No[. Mud log req'd: Yes ❑ No[]K ('i l�o S - /- c.- � E 'C 7:75.- �, H2S measures: Yes❑ No 2 Directional svy req'd: Yes "No EDz bd QS, /T hn`"-�.-r (LS� � — s� Cc .ti:r� 614 Ce. 4....i-ii, � Z4-...r"' A Y7 oi...(6 , AP ROVED BY THE COMMISSION DATE: 6 _ ,. .,a --/„.2._ i��/-y/�"�� ,COMMISSIONER / 1� ORIGINAL" ,,9. 02 Tvi; Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Duplicate q/(.., 6 '2z-'l7.-- 14 Hilcorp Paul Mazzolini Hilcorp Alaska,LLC Lam Comm Drilling Manager P.O. Box 244027 Anchorage,AK 99524-4027 6/6/2012 Tel 907 777 8369 Email pmazzolini@hilcorp.com Commissioner Alaska Oil & Gas Conservation Commission RECEIVED 333 W. 7th Avenue Anchorage, Alaska 99501 JUN 0 8 2012 Re: Swanson River Unit 23B-22 AOGCC Dear Commissioner, Enclosed for review and approval is the application for the Permit to Drill the Swanson River Unit 236- 22 SRU 23B-22 is a development oil well planned to be re-drilled in a NE direction from the parent wellbore SRU 14-22 utilizing the existing casing program down to 10,100'MD/TVD. - SRU 14-22 has been plugged and abandoned to a depth of 10,370'MD/TVD. The original perforations were in the Hemlock formation from 10,828'to 10,850'and from 10,859'to 10,863'. - At 10,100'MD/TVD,the parent wellbore will be sidetracked and a 6"x 1882' hole section drilled to a - total depth of 11,982'MD/11,300'TVD. SRU 23B-22 is a"Build&Hold"wellbore reaching a maximum of 70 deg inclination. - Drilling operations are expected to commence approximately Aug 1st, 2012 depending on the progress of other ongoing projects and the availability of Doyon's Arctic Fox. • %x I' A,eLT1 C- I Prior to the commencement of drilling operations, the AWS Rig #1 will be mobilized and conduct wellbore preparation operations for the sidetrack operation. A 10-403 will be submitted for this operation which includes: 1. Removing the existing production tree. '/o�Y Awry,a 2. Cutting and pulling the existing 2-7/8"tubing. - /v s- , nom, 7 - 4.s_ P 3. Cleaning out wellbore. I 4. Set a CIBP @ 10,120'&test casing to 3000 psi/30 mina 11 Pursuant to 20 AAC 25.055(a)(3),a spacing exception is NOT required: 1. SRU 23B-22 does not fall within 500 ft of a property line where ownership or • landownership changes. 2. It is not a gas well. • 3. It is the only well to be completed within the SW quarter section of Section 22, and is more than 1000'from any other well capable of producing from the same pool. Pursuant to 20 AAC 25.005(c)&(d),the following is included: 1. Plat identifying the property on which the well will be drilled. • 2. Diagram&description of blowout prevention equipment. 3. Information on drilling hazards. . Hilcorp Alaska,LLC Page 1 of 2 a. The Hemlock is potentially hydrocarbon bearing throughout the section. . MASP calculations are attached per 20 MC 25.005(c)(4)(A) • b. Potential target reservoirs and their predicted pore pressures are indicated in attached Well Design Summary. 4. Formation integrity test procedure. 5. Planned casing&cement program (Well Design Summary) 6. Diverter system will not be used. An 11" 5M BOP(3 ram &annular)will be used while drilling and completing 23B-22. BOP schematic is attached. 7. Drilling fluid program 8. Tabulation of predicted depths with equivalent formation pressures. 9. Requirements of 20 AAC 25.025 have been met. a. Blanket bond issued for Swanson River, bond no.22035257 • 10. Copy of drilling design summary. 11. General description of waste disposal. Operator does not wish to request authorization under 20 MC 25.080 for an annular disposal operation in the well. ' a. Drilling waste (cuttings and water based drilling fluids)will be contained at the drill site and hauled off to Emerald Services, Inc for inerting and subsequent • disposal. 12. Requirements of 20 AAC 25.050(b) have been met. a. Plat showing path of proposed wellbore including all adjacent wellbores ' within 200'is attached. b. All wellbores within 200'of proposed wellbore are owned by Hilcorp. • If you have any questions, please don't hesitate to contact myself at 777-8369 or Luke Keller at 777- 8395. Sincerely, Paul Mazzolini Drilling Manager Hilcorp Alaska,LLC Page 2 of 2 Swanson River Well SRU 23B-22 Hilcorp Well Design Summary SRU 23B-22 Well Design Summary SRU 23B-22 is a development oil well planned to be sidetracked out of 7" • production casing in the existing SRU 14-22 wellbore. A 6" x 1882' open hole section is planned from 10,100' MD / 10,100' TVD to 11,982' MD / 11,300' TVD. Integrated subsurface and 3-D geological interpretations, in conjunction with previous production data indicates that stranded oil reserves remain in the Hemlock 1-3 benches between the G and H faults. High on structure, . H4-10 benches are also prospective. Reserves aren't recoverable in existing wellbores due to lack of takepoints or mechanical condition of other existing wellbores in the fault block. • SRU 23B-22 is a deviated, "Build & Hold" wellbore reaching 70 degrees • inclination in the tangent section and a total depth of 11,982' MD / 11,300' - TVD. The well will be completed with a 4-1/2" production liner & 3-1/2" gas lift " assy. Well is planned to be drilled by Doyorfax. The Arctic Fox is a winterized, multi-module drilling unit, with a 400k telescoping double mast. Basic Well Information Well Name: SRU 23B-22 Estimated Spud Date: 8/1/2012 Field: Swanson River Productive Horizon: Hemlock Total Depth: 11,982 MD, 11,300' TVD Surface Location: 738' FSL, 637' FWL, Sec 22, T8N, R9W, S • X=348436.9, Y=2472450.3, NAD27, ASP, Zone 4 Top of Prod Horizon: 1069' FSL, 940' FWL, Sec 22, T8N, R9W, S X= 348760.8, Y= 2472777.6, NAD27, ASP, Zone 4 Planned BHL: 1650' FSL, 1470' FWL, Sec 22, T8N, R9W, S X= 349328.5, Y= 2473351.4, NAD27, ASP, Zone 4 Ground Elevation: 239' AMSL • KB elevation: 20' • 6/6/2012 Page 1 of 7 11 Swanson River Well SRU 23B-22 Hilcorp Well Design Summary Existing SRU 14B-22 Casing Design Soe O.D.le Weight Grade Conn Length Top MD/TVD Btm MD/TVD (in) (in) (lbs / ft) (ft) (ft) (ft) - 11-3/4 47 J-55 BTC 3001 WH 3001 7 29 N-80 BTC 114.6 WH 114.6 - 7 23 L-80 BTC 4772 114.6 4886.3 7 26 L-80 BTC 1895.1 4886.3 6781.4 - 7 29 L-80 BTC 1783.6 6781.4 8565 7 29 P-110 BTC 2435 8565 11000 Planned SRU 23B-22 Casing & Tubing Design 1 S�e O.D.le Weight Grade Conn Length MD/TVDTop Btm MD/TVD (in) (in) (lbs / ft) (ft) (ft) (ft) 6 4-1/2" 12.6 L-80 Hydril 2082 9900 11,982' / 521 11,300' Tbg 3-1/2" 9.3 L-80 EUE 9800 WH 9800 Tbg 2-3/8" 4.6 L-80 EUE 1000 9800 10800 i Well Control Summary Hole Section Equipment Test Pressure (psi) • 1 1" 5M Hydril GK Annular BOP Initial Test: • 11" 5M Hydril Double ram (fixed pipe 250/5000 rams in top cavity, blind rams in bottom (Annular 250/2500 psi) 6" cavity) Subsequent • 11" 5M drilling spool (3-1/8" outlets) Tests: • 11" 5M Hydril Single ram (Casing rams in 250/4000 ram cavity) (Annular 250/2500 psi) Schematics of the well control equipment are attached for reference. Well control equipment will be tested every 7 days,per AOGCC. 6/6/2012 Page 2 of 7 Swanson River Well SRU 23B-22 Hilcorp Well Design Summary eewv c�r•v Anti-Collision Evaluation Summary k•D'�✓too ,.ese.,1u 1 SRU 23B-22 will be sidetracked from the parent wellbore SRU 14-22 at 10,100'. • Other than the existing wellbore, there are no anti-collision issues with offset wellbores (SF > 1.3). SRI] 93-22 is the closest adjacent wellbore to the planned SRU 23B-22 wellbore. • Lowest EOU separation factor occurs at TD (1 .3). This still results in 185' between the two ellipses given the uncertainties that correspond with survey instruments used for each wellbore. SRU 23B-22 will be drilled using a mud motor and MWD. Surveys will be taken every 95' while drilling. Formation Integrity Testing Test Point, Projected Test Fluid Density Projected Projected 20' Below... Depth (TVD) Type Used for Test Test (EMW Surface ppg) Pressure 6" window 10,100 FIT 9.5 12 / 1313 psi Note:Anticipated fracture gradient at the 7"window depth(10,100'TVD)is expected to be.728 psi/ft based on offset field test data. An FIT of 12 ppg was chosen to allow for a(2.5)ppg(or 1313 psi)kick margin while drilling with a 9.5 ppg fluid density. Casing Testing Fluid Density in Test String Casing Pressure Test Duration Casing Burst (PSI) 7" Casing 9.5 ppg 3000 ✓ 30 min 6340 psi 4-1/2" Liner 9.5 ppg 3000 30 min 7500 psi 6/6/2012 Page 3 of 7 Swanson River Well SRU 23B-22 Hilcorp Well Design Summary Mud Program Summary Production Hole Section (6" hole, 4-1/2" liner to 11,982' MD) System Type: 6% KCI, PHPA Properties: Depths Density Viscosity Plastic Viscosity Yield Point API FL pH 10,100- 9.5- 10- 40-53 10-24 18-26 <5 8.5-9.5 11,982' System Formulation: 6% KCI / PHPA Product Concentration Water 0.905 bbl KCI 22 ppb Caustic 0.2 ppb (9 pH) BARAZAN D+ 1.1 ppb (as required 18+YP) DEXTRID LT 1-2 ppb EZ MUD DP 0.5 ppb (initial.15 ppb) ALDACIDE G 0.1 ppb BAROID 41 208 ppb (as needed to 12.5) Completion (3-1/2" x 2-3/8" Tubing to 11,000' MD1 System Type: 3% KCI Brine Properties: Density-8.4 ppg, Chlorides-25,000 ppm 6/6/2012 Page 4 of 7 Swanson River Well SRU 23B-22 Hilcorp Well Design Summary EnemyEneCompaq'Cementing Summary Production Hole Section (6" hole, 4-1/2" liner to 11,982' MD) . Cement volume based on annular volume + 30% open hole excess. Job will be a single slurry design. Cement from shoe to TOL. Estimated total volume is as follows: Section Formula Volume 7"x 4-1/2" overlap: (200') x 0.017 = 3.5 bbls 6" x 4-1/2" OH annulus: 1882' x 0.015 x 1 .3 = 36.7 bbls 4-1/2" Shoe Track: 90' x .0152 = 1.4 bbls Total Volume (bbls): 3.5 + 36.7 + 1 .4 = 41.6 bbls ✓ II Slurry Information: Stage EasyBLOK Production Blend System Conventional Density 15.3 Ib/gal Yield 1.35 ft3/sk Mixed Water 5.912 gal/sk Mixed Fluid 5.962 gal/sk Total Volume 41.6 bbl=233 ft3= 173 sx ✓ Expected 100 Bc at 05:24 hr:mn Thickening Expected ISO/API 13 mL in 30.0 min Fluid Loss Code Description Concentration G Cement 94 lb/sk WBWOB Dl 10 Retarder 0.05 gal/sk VBWOC Additives D046 Anti Foam 0.2%BWOB D202 Dispersant 1.5%BWOB D400 Gas Control Agent 0.8%BWOB D154 Extender 8.0%BWOB D174 Expanding Agent 1.5%BWOB 6/6/2012 Page 5 of 7 II Swanson River Well SRU 23B-22 Hilcorp Well Design Summary Email•c.,,, , Anticipated Formation Tops and Geohazards Top Name Formation Expected Fluid TVD Est Press PPG Kick Off Pt 10,100 Normal 8.5 • HKT Top Hemlock Oil OIL/GAS 10,747 2800-3200 4.6 - 5.8 . H2 Hemlock Oil OIL/GAS 10,772 2800-3200 4.6 - 5.7 , �(so H3 Hemlock Oil OIL/GAS 10,799 2800-3200 4.6 - 5.7 -')'e H4 Hemlock Oil OIL/GAS10,841 2800-3200 4.6 — 5.7 1 w H5 Hemlock Oil Wet/OIL 10,874 2800-3200 4.5 - 5.7 �(c v- y H7 Hemlock Oil Wet 10,923 2800-3200 4.5 - 5.7 ,� H10 Lower Hemlock Wet/OIL 11,057 2800-3200 4.5 - 5.6 •`, ke-aim TD 11,300 a "F LI/ AV Formation Evaluation Summary Interval Evaluation Method Comments 10,100' - 11,982' LWD Anadril Dual Gamma Ray + Electro- Magnetic Wave Resistivity + Azimuthal Density + Compensated Neutron Porosity 6/6/2012 Page 6 of 7 Swanson River Well SRU 23B-22 Hilcorp Well Design Summary beery Camping, SRU 23B-22 Drilling & Completion Summary 1 Prior to Mobilization of Doyon Arctic Fox to wellsite: a. MOB AWS #1 to wellsite. b. N/D Tree, N/U and test BOP. c. Cut and pull 2-7/8" prod tubing. d. Set CIBP @ 10,120'. e. Install & test new tubing head 1�_2l f. Install & test dry-hole tree. P g. Prep and level location for drlg rig. / 51 • fa S 2 Mobilize Doyon Arctic Fox to wellsite. 3 Make csg scraper trip to top of CIBP. Test csg to 3000 psi / 30 min. 4 Displace well to 9.5 ppg WBM. 5 Set whipstock and mill 6" window from 10,100' to 10,116'. Drill 20' new formation below window. 6 Conduct FIT to 12 ppg EMW. - 7 TOH with milling assy, M/U and TIH w/ 6" directional assy. 8 Drill 6" hole using mud motor/ MWD / LWD assy (GR + Res + Density + Porosity) to TD at 11,982' MD / 11,300' TVD. • 9 Clean up hole as necessary, pull wiper trip to window. 10 TOH, L/D directional assy. 11 Run 4-1/2" liner to 11,982'. Pump primary cement job, cmt from 4-1/2" I T° liner shoe to TOL at 9900'. 12 Set liner top packer. Test to 1500 psi / 5 min. 13 Circ out cmt, TOH. 14 M/U clean out string, clean out to float collar, polish PBR, scrape 7" casing. 15 Test 4-1/2" liner + 7" prod casing to 3000 psi / 30 min. 16 Displace well to 3% KCI completion fluid. 17 TOH, LDDP 18 N/D BOP, N/U dry hole tree. 19 RDMO Doyon Arctic Fox. 20 Mob AWS rig #1 to wellsite a. Perforate well via TCP assy b. Run 3-1/2" x 2-7/8" prod tubing assy. ✓ w/601 c. Install production tree. 6/6/2012 Page 7 of 7 SRU 23B-22 Days Vs Depth 10000 — — • • • • • • 10500 11000 L 0-+ a OJ a) v v 11500 12000 • • • • • • 12500 — 0 2 4 6 8 10 12 14 16 18 20 Days Uidianierier H IIco 23B-22(P2)Proposal Report (Def Plan) Report Date May 17,2012-0351 PM Survey/OLS Computation Minimum Curvature/Lubmski a Client H Acorn Energy Comp.ny Vertical Section Azimuth 43957•(True North) Field Swanson liner Unit Vertical Section Origin 0000 ft,0 000 6 Structure/Slot Swanson Ram/SRU 14.22 TV0 Reference Oahan RNB Well 14-22/239-22 5 TVD Reference Elevation 210000 ft above MSL Borehole 239-22 Seabed l Ground Elevation 170 000 n above MSL UWI/APIS Unknown/Unknown Magnetic Declination 17671' Survey Name 238-22(P2) Total Field Strength 55561 268 nT Survey Date May 04,2012 Magnetic Dip Angle 73735' Tort/AHD(DDI l ERD Ratio 69712'/1287744ft/4972/0112 Declination Date July 21,2012 Coordinate Reference System NAD27 Alaska State Plane,Zone 04 US Feet a Magnetic Decimation Madel BGGM 2011 Location Lat/Long N 60.45'53 28012.,W 150.50 51 36050' North Reference True North Location Grid N/E Y0( N 2472450 300 BUS,E 346436 900 BUS Grid Convergence Used 0000' CRS Grid Convergence Angle -073664762' Total Corr Mag North>True North 17677' Grief Scale Factor 099992614 Lout Cocrd Referenced To Well Head MD Incl Mom True TVDSS TVD VBEC NS EW TF DLS Directional Zoneonal Exclusion Zone Northing Eastln9 Comments (6) (•1 Cl (6) (6) (8) (6) no (1 ('/1006)011601417 Index Alert Angle lt (605) (605) Projected-Up 000 000 000 -21000 000 000 000 000 OM N/A 000 1626 247245030 348436% Proiected-Up 4000 000 000 -1700D 4000 000 000 000 43%M 000 000 1828 247245030 34843690 10000 000 43% -11000 10000 000 000 000 436661 000 000 1828 247245030 34843690 20000 000 4396 -1000 20000 000 000 000 4396M 000 000 1626 247245030 346436% 30000 000 43% 9000 30000 000 000 000 4396M 000 000 1626 247245030 34843690 40000 000 43% 1%00 40000 000 000 000 43%M 000 000 1826 247245030 34843690 50000 000 43% 29000 50000 000 000 000 4396M 000 000 1626 247245030 346436% 00000 0% 4366 39000 60000 000 000 000 4396M 000 000 1626 247245030 34843690 70000 000 4366 49000 70000 000 000 000 439681 000 000 1826 247245030 34843690 80000 000 4316 5%00 60000 000 000 000 4396M 000 000 1828 247245030 34843690 90000 000 4366 6%00 60000 000 000 000 43960 000 000 1626 247245030 34443690 100000 000 4396 79000 100000 000 000 000 439611 000 000 1628 247245030 34643690 110000 000 43% 89000 110000 000 000 000 439611 000 000 1626 247245030 34943690 120000 000 4396 99000 120000 000 000 000 439444 000 000 1626 247245030 34643690 130000 000 43% 106000 130000 000 000 000 439661 000 000 1626 247245030 34443640 140000 000 4396 119000 140000 000 000 000 439661 000 000 1626 247245030 34443690 150000 000 43% 129000 150000 000 000 000 4396M 000 000 1626 247245030 34443610 160000 000 4396 139000 160000 000 000 000 43%M 000 000 1626 247245030 34643690 170000 000 4396 149000 170000 000 000 000 43%M 000 000 1626 247245030 34643690 160000 000 4396 159000 180000 000 000 000 43%M 000 000 1626 247245030 34443890 190000 000 4396 169000 190000 000 000 000 43%M 000 000 1626 247245030 34843890 200000 000 4396 179000 200000 000 000 000 43%M 000 000 1626 247245030 34843690 210000 000 43% 189000 210000 000 000 000 4396M 000 000 1627 24724530 34843690 220000 000 4396 199000 220000 000 000 000 43%M 000 000 1627 247245030 34443690 230000 000 4396 209000 230000 000 000 000 43%M 000 000 1627 247245030 348436% 240000 000 4396 219000 240000 000 000 000 4398M 000 000 1627 247245030 34643690 250000 000 4396 229000 250000 000 000 000 43%M 000 000 1627 247245030 348436% 260000 000 4396 239000 2%000 000 000 000 43%M 000 000 1627 24724%% 34643690 270000 000 1096 249000 270000 000 000 000 43%M 000 000 1627 24724%30 34643690 240000 000 4396 256000 260000 000 000 000 43 46M 000 000 1627 247245030 34643690 290000 000 43% 26%00 290000 000 000 000 436661 000 000 1627 24724%% 34643690 300000 000 4396 279000 300000 000 000 000 43 66M 000 000 1627 24724%% 34843690 310000 000 4396 269000 310000 000 000 000 43%0 000 000 1627 247245030 34643690 320000 000 4396 299000 320000 000 000 000 43460 000 000 1627 247245030 346436% 330000 000 43% 3090% 330000 000 000 000 4396M 000 000 1827 247245030 34843690 340000 000 13% 319000 340000 000 000 000 43%M 000 000 1627 247245030 348436% 350000 000 13% 329000 350000 000 000 000 43%M 000 000 1627 24724%30 346136% 360000 000 4396 3390% 36%00 000 000 000 43%M 000 000 1627 247245030 34843690 370000 000 4396 349000 370000 000 000 000 43%M 000 000 1627 24724%30 34443690 340000 000 4396 359000 34%00 000 000 000 439661 000 000 1627 247245030 34443690 390000 000 4346 369000 390000 000 000 000 4396M 000 000 1627 247245030 34443660 400000 000 4396 379000 100000 000 000 000 4398M 000 000 1627 247245030 34843690 410000 000 4366 349000 410000 000 000 000 4396M 000 000 1627 24724530 34443660 420000 000 4346 39%00 420000 000 000 000 43%61 000 000 1127 247245030 34843690 430000 0% 4366 409000 430000 000 000 000 4396M 000 000 1627 24724%30 34443690 440000 000 4398 419000 440000 000 000 000 439661 000 000 1627 247245030 34443690 450000 000 4396 429000 450000 000 000 000 439611 000 000 1627 247245030 34443660 460000 000 4366 439000 460000 000 000 000 4396M 000 000 1627 247245030 34613610 470000 000 4366 449000 470000 000 000 000 4396M 0D0 000 1627 247245030 34643690 460000 000 4356 459000 440000 000 000 000 4396M 000 000 1627 247245030 94845690 490000 000 4356 46%% 4900% 000 000 000 439644 000 000 1627 247245030 94449690 500000 000 4396 479000 500000 000 000 000 4396M 000 000 1627 247245030 34643610 510000 000 4366 48%00 510000 000 000 000 439661 000 000 1627 247245030 34843690 520000 000 4366 499000 520000 000 000 000 43%M 000 000 1627 247245030 344436% 530000 000 4396 509000 530000 000 000 000 43%44 000 000 1627 247245330 34643690 540000 000 43% 519000 5400% 000 000 000 4396M 000 000 1627 247245030 34643690 550000 000 4396 529000 550000 000 000 000 439661 000 000 1627 247245030 34643691 560000 000 4396 539000 560000 000 000 000 439694 000 000 1627 247245030 346436% 570000 000 4396 549000 570000 000 000 000 4396M 000 000 1627 2/7245030 11411691 580000 000 4396 559000 560000 000 000 000 439611 000 000 1627 247245030 344436% 590000 000 4396 569000 590000 000 000 000 4396M 000 000 1627 247245030 34443690 100000 000 4396 579000 %0000 000 000 000 43%M 000 000 1627 247245030 14841890 610000 000 4366 549000 610000 000 000 000 4396/0 000 000 1627 247245030 34443690 620000 000 4366 599000 820000 000 000 000 4396M 000 000 1627 247245030 34443690 630000 000 4316 %%00 630000 000 000 000 439684 000 000 1627 247245030 14045890 640000 000 4396 819000 640000 000 000 000 43%M 000 000 1627 247245030 94641690 150000 000 4368 629000 650000 000 000 000 43%M 000 000 1627 247245030 34443690 660000 000 4366 639000 660000 000 000 000 43%M 000 000 1627 247245030 34443690 670000 000 4398 649000 670000 000 000 000 4396M 000 000 1627 247245030 31843690 650000 000 4398 659000 680000 000 000 000 43%M 000 000 1627 247245030 1441690 690000 000 4366 669000 890000 000 000 000 4396M 000 000 1627 247245030 34443690 700000 000 4366 679000 700000 000 000 000 4394M 000 000 1627 247245030 34843890 710000 000 4396 689000 710000 000 000 000 4396M 000 000 1627 247245030 34443690 720000 000 4366 699000 720000 000 000 000 4396M 000 000 1627 247245030 34443690 730000 000 4366 709000 730000 000 000 000 439aM 000 000 1627 247245030 34643690 740000 000 4366 719000 740000 000 000 000 43%M 000 000 1627 247245030 34443690 750000 000 43% 729000 750000 000 000 000 43%M 000 000 1627 247245030 34843690 ' 760000 000 4366 73%00 760000 000 000 000 4396M 000 000 1627 247245030 34643690 770000 000 4366 74%03 770000 000 000 000 439661 000 000 1627 247245030 34843690 750000 000 4396 759000 780000 000 000 000 439444 000 000 1627 247245030 34643690 790000 000 4366 769000 790000 000 000 000 4396M 000 000 1627 247245030 344436% 400000 000 4346 77%00 600000 000 000 000 4396M 000 000 1627 247245030 34443890 410000 000 4396 710%00 610000 000 000 000 439661 000 000 1627 247245030 34843690 820000 000 4396 799000 520000 000 000 000 439444 000 000 1627 247245030 34443610 1130300 000 4396 809000 830000 000 000 000 439644 000 000 1627 247245030 34443690 840000 000 4391 61%00 640000 000 000 000 43%44 000 000 1627 247245030 34643610 45000 000 4496 529000 650000 000 000 000 4396M 000 000 1627 247245030 34443690 860000 000 4396 639000 660000 000 000 000 4396M 000 000 1627 247245030 34643690 470000 000 4396 649000 8703 Co 000 000 000 439644 000 000 1627 247245030 34443690 460000 000 43% 659000 660000 000 000 000 4396M 000 000 1627 247245030 344436% 490000 000 4396 869000 890000 000 000 000 4396M 000 000 1627 247245030 344436% 600000 000 43% 1179000 900000 000 000 000 43%M 000 000 1627 247245030 34643610 110000 000 1396 809000 910000 000 000 000 4396M 000 000 1627 247245030 34643691 920000 000 4396 849000 920000 000 000 000 439664 000 000 1427 247245030 34843690 930000 000 43% 909000 930000 000 000 000 43%M 000 000 1627 247245030 344436% 640000 000 4396 919000 940000 000 000 000 43%M 000 000 1627 247245030 34643690 950000 000 4396 929000 %0000 000 000 000 4396M 000 000 1627 247245030 34443690 160000 000 4496 %%00 960000 000 000 000 43%M 000 000 1627 247245030 34443690 170000 000 4396 94%00 970000 000 000 000 4396M 000 000 1627 247245030 346436% 650000 000 4396 959000 980000 000 000 000 43%M 000 000 1627 247245030 34443690 990000 000 4396 %%00 990000 000 000 000 43%M 000 000 1627 247245030 344436% Dnlling Office 2.5.1100 0 Swanson River Unit\Swanson River\14-22/23B-22\23B-22\23B-22(P2) 6/7/2012 7:07 AM Page 1 of 2 MD 1001 Azim 0.5 True TV5 TVD VSEC NS EW TF 131-.5D.MExcluslonZone ronal Eicluson Zone Northing EasOng Comments (5) C) C) (B) (6) (N) (8) (6) (9 (mom DiMcuhy Index Alen Angle In (nus) (nus) 1000000 000 419E 579000 1000000 000 000 000 4396M 000 000 1627 247245030 34643690 To-In Pt 1005500 000 439E 586500 1009500 000 000 000 4396M 000 000 1627 247245030 34843690 Top Whipstock 1010000 300 439E 989000 1010000 013 009 004 4396M 6000 000 1364 247245039 34643699 Base Whipstock 1011600 492 4396 990596 1011556 124 089 066 4396M 1200 078 1205 247245118 34843777 COO 9100 1013100 492 4396 992090 1013010 252 182 175 43 96M 000 109 1205 247245209 34643667 1020000 037 4396 996943 1019943 1051 756 729 HS 500 194 149 247245777 34644429 1030000 1337 4396 008760 1029760 2936 2113 2036 HS 500 259 724 2472471 17 34645755 1040000 1637 439E 018376 1039376 5669 4081 3935 85 500 302 602 247249060 34647677 10`0000 2337 4396 027717 1046717 1231 8645 6407 HS 500 333 1123 247251591 31150162 1060000 2037 4396 036712 1057712 13513 9785 9435 HS 500 359 1542 247254691 34053250 1070000 3337 4316 045293 1066293 16722 13477 12995 HS 500 380 1997 247256337 34156557 1060000 3637 4306 053391 1074391 24560 17694 17061 HS 500 384 2470 247262501 34590977 1050000 4337 4306 060853 1061553 31121 22403 21602 HS 500 413 2950 247267150 3u65677 1100000 4837 4356 067514 1085514 36296 27565 26512 HS 500 427 3437 247272251 31870024 1110000 5337 4316 074223 1055223 46057 33150 31965 HS 500 440 3926 247277762 34876078 1120000 5537 4396 079632 1100132 54326 39107 37709 HS 500 451 4417 247263644 34651696 1130000 6337 4356 00169e 1105696 63055 45313 43770 HS 500 461 4910 247285551 34866035 1140000 6837 4396 086785 1109715 72182 51961 50103 HS 500 470 5403 247291336 34854455 End COO 1142684 6971 4396 089745 1110745 74686 53765 51842 HS 500 473 5536 247298117 34896215 1150000 6971 439E 092262 1113262 51550 58705 56605 HS 000 477 553E 247302995 34901044 1160000 6971 4396 015749 1116749 90830 66457 63116 HS 000 482 5536 247309612 34907641 1170000 6971 4396 099217 1120217 100310 72206 69626 HS 000 486 5536 247316329 34914237 111300 00 6971 43 96 102684 11236 61 1096 59 78961 761 37 HS 000 490 55 36 247322996 349200 34 1190000 6971 4396 1061 51 11271 51 119069 85713 02647 HS 000 494 5536 247329663 34927431 TD 1191215 6971 4396 109000 1130000 126774 91280 e7896 000 497 5536 247335140 34132850 Survey Error Model ISCW SA Rev 0"'3-13 95 030%Confidence 2 7955 soma Survey Program De.aiphon MD From MD To EOU Freq Survey Tool Type Borehole l Survey 181 DU 161 0000 40000 1/40000 SLB_CNSG.CASING-Depth Only 142211422 vertical no surveys(ProleoNd-Up) 40000 10095000 1/100000 SLBCNSG•CASING 14-22/1422 vemul no surreys 10095000 11962154 1/100000 61_6_MWDS10 23E1-22123622(82) Drilling Office 2 5.1100 0 Swanson River Unit\Swanson River\14-22/23B-22\23B-22\23B-22(P2) 6/7/2012 7:07 AM Page 2 of 2 H Schlumberger Hilcorp etr.ey COM WELL FIELD STRUCTURE 23B-22 (P2) Swanson River Unit Swanson River Magnetic Parameters Surface Location NAD27 Alaska Stale Plane.Zone 04.US Feet Miscellaneous Model: BGGM 2011 DO 73.735' Da.. July 21,2012 Lal'. N 604553.280 Northing: 247245030 HUS Grid Cow:-0.7396476r Slot'. SRU 14-22 TVD Ref: R515(2106 above MSL) Mag Dec: 17677' FS'. 55.93nT Lon'. W1..51360 Easling3484.90 BUS Scale Fact:099992814 Plan: 23B-22(P2) Srvy Dale:May 04.2012 0 200 400 600 800 1 N TD ' 3&22(P2) 800 800 A 600 600 A Z F O End Cry O N II s 400 8 400 U Cr)cn V V V 200 200 Cry 51100 Base Whipstock Top Whipstock Tie-In Pt 0 Tie-In ._4-22 vertical no surveys 0 0 200 400 600 800 «< W Scale=1:200(ft) E »> Schlumberger Hilcorp Ymmy CemPe, WELL FIELD STRUCTURE 23B-22 (P2) Swanson River Unit Swanson River Magnetic Parameters Surface Location NAM)Alaska Slate Plane,Zone 04,US Feel Mrscellaneous 07031 BOOM 2011 Dip: 73 735. Dale'. Ju121.2012 Lal: N 604553.280 Northing. 247245030 PUS Grkl Cony:-073964762• Set SRU 14-22 IVO Ref: RH612106 above MSL) Man Dec 1]67] F5: 55569.3nT Lon: W1505051.360 Easting. 346436.90(WS Scale Fact:099992614 Plan. Z39-22(P2) Srvy Dale:May 04,2012 -2000 0 2000 00 Tie-In • 2000 2000 4000 4000 • 6000 6000 • • 0 0 N II 8000 8000 U i rn V/ Tie-In Pt Top Whipstock 10000 - 10000 Base Whipstock Cry 5/100 3B-22(PZ End Cry TD 12000 12000 14000 14000 14-22 vertical no surveys -2000 0 2000 Vertical Section(ft)Azim=43.96°Scale=1:2000(ft) Origin=0 N/-S,0 E/-V SRU 34-16 -------- SRU --_ s U 14-15 S008N009W15 A028384 S008N009W16 SRU 21-22 SRU 23-22 SRU 32-22 A0807 SRU 412-22 ; S008N009W21 S008N009W22 i A028406 • B H L • A. / Top of • Production Horizon+' SRU 23B-22 f •SRU 14-22(09) Surface Location _ _ _ SRU 331-27 SI SRU 41-28 SRU 21-27 • Legend S008N009W28 j SRU 23B-22 • Surface Location A028399 S008N009W27 Top of Production Horizon /// • Bottom Hole Location / N KGSF2 / ' g �` • Other Surface Locations SRU 12-?1i'RU 314-27 + Other Bottom Hole Locations / SRU 212-27 Well Tracks /; Township-Range-Sections Well Name: SRU 14-22 PTD Z- 3q Field: Swanson River >> _ Existing Wellbore Hilcorp � S�c.a .P Conductor:22"@ 38' Surface Location: Swanson River 239'Above MSL X:348436.9 Y:2472450.3 11-3/4"47#,J-55,Shoe,3001' 1 TOC @ 10,370' Cmt Retainer @ 10,370'... Intermediate Csq: 0-114':7"29#N-80 Tbg Punch @ 10,542' 114-4886:7"234 N-80 \\\ 4886-6781':7"26#N-80 \\\ 6781'-8565':7 29#N-80 8565'-11000':7"29#P-110 Cmt Retainer @ 10,790' -_-- Pkr @ 10,813 H-1&H-2 Perfs 10 828';10 850'_, ,_--__ ___ Pkr @10,852___ --- --_-- -. H-4 Perfs:10,859'-10,863' III TD=11,000'MD/11,000'TVD Well Name: SRU 23B-22 (SRU 14-22 ST) 11 Field: Swanson River Planned Wellbore Hilcor Energy Compaq II Conductor:22"@ 38' Surface Location: Swanson River AboveMSL X:348436.9 Y:2472450.3 11-3/4"47#,J-55,Shoe,3001' X: TOL @ 9900' Whipstock @ 10,100' CIBP @ 10,120 O• TOC @ 10,370' \\ 41 111\\ Production Hole: Intermediate Csg: 6"hole,9.5 ppg WBM 0-114':7"29#N-80 ` 4-1/2",12.6 ppf,N-80,Hydril 521 to 114-4886:7"23#N-80 11,982'MD/11,300'TVD 4886-6781':7"26#N-80 Cmt to TOL @ 9,900'MD/TVD' 6781'-8565':7"29#N-80 8565'-11000':7"29#P-110 N 0.4- \\ c0 N EE \\ r r IID=11,982'MD/11,300'TVD TD=11,000'MD/11,000'TVD I - ANTICIPATED FORMATION TOPS&GEOHAZARDS TOP NAME FORMATION FLUID TVD(FT) TVDSS(FT) Est.Pressure KICK OFF POINT 6,000 -5,741 64-1 CT Tyonek Coal Gas/Water 6,385 -6,126 71-8CT Tyonek Coal Gas/Water 7,237 -6,978 77-3ST Tyonek Shale None 7,730 -7,471 E10 Tyonek Shale None 8,718 -8,459 HKT Top Hemlock Oil OIL/GAS 10,747 -10,488 2600-3000 psi H2 Hemlock Oil OIL/GAS 10,772 -10,513 2600-3000 psi • H3 Hemlock Oil OIL/GAS 10,799 -10,540 2600-3000 psi H4 Hemlock Oil OIL/GAS 10,841 -10,582 2600-3000 psi H5 Hemlock Oil Wet/OIL 10,874 -10,615 2600-3000 psi H7 Hemlock Oil Wet 10,923 -10,664 2600-3000 psi H10 Lower Hemlock Wet/OIL 11,057 -10,798 2600-3000 psi TD 11,300 -11,041 Maximum Anticipated Surface Pressure Calculation H;iico Swanson River Unit 23B-22 • Kenai Peninsula,Alaska Offset Information Well Date Hemlock Pressure TVD Grad SRU 331-27 March,2012 3140 10600 0.296 • Assumptions: 1. Based on offset drilling&well test data, Hemlock pore pressure is anticipated at 3100-3500 psi. , fu ./((Sd L. 2. Reservoir fluid gradient is anticipatgd at 7.7 ppg) C' iZLL . 3. Pressure gradient at 11,300' is calcul ted--as:-3140 psi+(700')*(.052)*(7.7)=3424 psi=0.303 psi/ft • I' J 4. Fracture gradient at 10,100' is estimated at 0.728 psi/ft based on field test data.• � Iia,,4Ad 5 arv- Fracture Pressure at 7"window considering a full column of gas from window to surface: J For 7"window at 10,100'TVD: Aft' /Z 10,100(ft)x 0.728(psi/ft)= 7352 psi 7352(psi)-[0.1(psi/ft)*10,100(ft)]= 6342 psi MASP from pore pressure Max pore pressure at TD (11,300'TVD) . f MASP (Wellbore evacuated to gas column) �✓ 11,300(ft)x 0.303(psi/ft)= 3424 psi • SIBHP-gas gradient to surface: 3424(psi)- [0.1(psi/ft)*11300(ft)]= 2294 psi Summary: 1. MASP while drilling 6" production hole is governed by SIBHP-gas gradient to surface. 2. MASP during production life is governed by SIBHP-gas gradient to surface. I-Dm /U) w , \§ / km i• )} § MI o 0 §�3 2 g� - a) k\ § § Vf ji ii Y / \\ m 06 SE§ 03 .4? CO §k, a) ej, , z 0�" — ` \/ R(2a� a - Mz=�, @ 2»5®~ — = gree ) ft(=o r O » ®0 w"w N \� M- CI �} ?u=a r \( _ co.c ` ! 2\\» § CD ID O )k \ e k>�cq ~ 06 _ w _ & 2 \ _ /. 5 /k o. )m , !( / j , 3 «'- ` J 2 )174 \ )§7 0 �'11>i � k• k ° $§ ) m 0 § § E o (\ } )\ \ oz kk26 2 0 /002/ ' N §00N0 _ / 7 ƒ §�\\} § B \\k )\ 0NO o ` � \ \ 0 c, /)ƒ co . : ! Swanson River SRU 23B-22 06/04/2012 I l: V,, , I,i Swanson River SRU 23B-22 Doyon BOP 2012 I , at,ittift lull A i Ary_fi C- 1--.6 • ' Hydril GK 11"-5000 Iii Til III hili) a'' -'l Hydril V o = - ®Ilii 11"-5000 _ _ . 11.85' i_il I I 111 Mud cross 1i-0 �I �' � 11 5M FE X11 5M FE 1N'_,1►1 i� [14M� N.w131/85MEFO - ir-- r? `ly I21 III Ii1Ili 111' ��' - H dril Y o� i it Crossover spool 1 U411 t-li Li, TBD 11"5M X 7 1/16'5M IIMITi1ftir11 -� Grade Level III I r.) IT o(o u1( •• Ic? 0)!11 11•i. 11 III ail III — i ff { 1 •1 LEDGEND DV17AKITA JV �� White Handle Valves Normally Open (/ Red Handle Valves tNormally Closed To FLARE 8 PITS I/ OP STACK FROM B ,.eF 4 1 5 6 (0- + 12)\'' To FLARE 1 PITS q -- " 10 B II (1$10 To DeGASSER MATERIAL LIST Item Description A 3-1/16"10M Remote Operated Hydraulic Choke / B 3-1/8"5M Adjustable Choke ✓ 1 2-1/16"5M Manual Gate Valve 1 ;,,,,,..14. 2-14 .3-1/8"5M Manual Gate Valve ,ARC71C FOX 111 Swanson River SRU 23B-22 06/04/2012 161.,.,1,1Iu.4...111 Swanson River SRU 23B-22 Tubing hanger,Seaboard 11 3/4 X 7 X 3 1/2 or 2 7/8 SC-E-CL,7X3Y%EUE8rd Lift and susp,3"Type H BPV profile,3/8 control line prep, dovetail body seals BHTA,Bowen,3 1/8 5M FE II I. I.l Valve,swab,VG-M, 3 1/8 5M FE, HWO A <d Valve,Wing,VG-M, Valve,Wing,SSV, 1 Q 3 1/8 5M FE,HWO VG-M,3 1/8 5M FE c'� O Qty 2 w/Halliburton ® Hydraulic operator 1,4611 1 1 1. Valve,Wing,VG-M, o! :, O C? © > i 2 1/16 5M FE, HWO ( JC 0 O` © I [�� OII I(( O 111 © . O ! \ �, ✓ IR r Valve,upper master, OoatrO 16)1 '/aTc1E- " , VG-M,31/85M FE, ‘es HWO I. A/ Valve,master,VG-M, 0 0 3 1/8 5M FE, HWO ,y,l 10 Adapter,Seaboard SM-E-CLN ©w' " 7 1/16 5M stdd X 3 1/8 5M stdd ui top,w/'/2 npt control line exit ■ _ Tbg head,Seaboard,S-8, _ Ground level 13 5/8 3M X 7 1/16"5M, "'� �=� w/2-2 1/16 5M SSO 111 Ii1 I ��1IE �o�I �� 't),,1 h''b`, Valve,Seaboard, p o .® 2 1/16 5M FE,HWO,Qty 2 1 Viii s 1 an " 1■1 1 00(:)-4121.i... Valve,Seaboard,2"LPO IMIIMME. or _i 1 Surface Use Plan Swanson River Unit Well SRU 23B-22 Surface Location: 738' FSL, 637' FWL, Sec 22,T8N, R9W, S Existing Road: The proposed SRU 23B-22 is within the unit boundaries of the Swanson River Field. The roads in the field are suitable for transportation of the drilling rig and support equipment. The road leading into Swanson Field is within the boundaries of the Kenai National Wildlife Refuge and is also suitable for rig transport. Sterling, Alaska is the nearest town to the site and is approximately 25 miles south of the well site. A map showing the location of the proposed well site and access route to the site is included in Figure 1. New or Constructed Access Roads: There will be no new roads required for the drilling of this well. Road upgrades may be required pending the size and configuration of the drilling rig. A separate sundry notice for surface use disturbance will be submitted at a later date if needed. Location of Existing Wells: SRU 23B-22 will be sidetracked from the existing SRU 14-22 wellbore on the 14-22 Pad. A map showing all known wells within a one-mile radius of the proposed SRU 23B-22 is included in Figure 2. Location of Existing and/or Proposed Production Facilities: New well 23B-22 will be connected to existing production facilities. An abandoned flowline will be reconnected, hydrotested, and placed back in service to support production from the new well. A gas lift heater will also be installed. A separate sundry notice for surface use disturbance will be submitted at a later date if needed. Location and Types of Water Supply: Existing water sources in Swanson River Field will be utilized. Available sources include permitted water wells at 14-22 and TS 1-33. All water use will be tracked in compliance with applicable permits. Water will be transported via vacuum truck from water wells to the rig location. Construction Materials: Road upgrades may be required to allow rig access to the pad. Stockpiled clean gravel picked up from roads within Swanson River Field will be used to level the pad if needed. Methods for Handling Waste: Drilling muds and cuttings: Excess mud and cuttings will be hauled from the rig pit system or storage tanks to off-site contractor Emerald for disposal. A • temporary waste storage permit will be obtained for any interim drilling fluid storage at Swanson. Brines& Completion Fluids: Eligible fluids will be hauled to a permitted Class II disposal well in • Swanson River Field for disposal. Garbage: All household and approved industrial garbage will be segregated and transported to the Kenai Borough Central Peninsula Landfill for disposal. • Chemicals: Unused chemicals will be returned to vendors or utilized in future operations. Sewage: All sanitary waste will be contained on-site and hauled off-site by a designated contractor. Ancillary Facilities: A trailer will be staged on the pad to house various supervisory and a minimum number of support personnel. The remainder of the drilling crew will be housed at a temporary camp adjacent to the main Swanson River Field office, noted on Figure 1. Well Site Layout: Attached Figure 3 shows the existing pad, the access road to the location and the proposed well location. New well 23B-22 will be sidetracked from the existing 14-22 wellbore. There will be no reserve pit on location. Proposed orientation of the drilling rig will be provided when a rig is identified. Plans for Surface Reclamation: No surface disturbances are required for drilling this well. Access will be on existing roads within Swanson River Field, and the well will be drilled from an existing pad. No pad or road expansion will be required. Approval for final abandonment of the well and location will be obtained from the BLM and U.S. Fish and Wildlife Service prior to any reclamation work. Surface Ownership: The surface lands of the Swanson River Field and the roads leading into the field are within the Kenai National Wildlife Refuge, and are managed by the U.S. Fish and Wildlife Service. Other Information: Additional information about the drilling rig will be provided when a rig is identified. a_ 3 2 SRU 212-10 d Pa 7 8 9 I 10 11 12 1st Ave SRU 14.09 Pad + SRU 34.10 Pad "'."""....., SRUa115P a sau v-ls Pad- O SRU 41.15 Pad I I I 2,1s ` 1 SRU 32.15 Pad—12. 15 17 10" 18 14 1 i.-SRU 23-15 Pad! SRU 43-15 Pad 1 SRU 234 15 Pad SFU 34-14 Pad f SRU 2132 Pad aa- Zft Pad 2-22 SRU 3232 Pad U2'23 SRU Pad a/ S108NO1OW S008N009W ? 21 sst �SRU332-21 Pad 22 23 21 19 20 SRU 23B-22 I Proposed,.\ SRU vi n t \FL 1st Ave SRU 14-22 Pad Paa` 717 SRU 41-28 Pad scum 28 Paa --^—./ SRU 21.2Pad SRU 12.20 Pad 2: 30 29 28 sRu.335 Paa 27 SRU 32 22 Pad 26 2,. SRU 34.28 Pad l_RF4111pad U2134Pad 1>; SRU 2133Pad j M.P./ S.32 SRU 1z34Pad- 16 i 31 32 33 34 35 '•.../ 3F SPU 23-33 Pad SCU 3333 Pa R 5 433 1st Aver'"u 3u1u,Pad scu 3433 Pad \ i Proposed Camp seu:1-o4 Pad n scu 41.04 Pad i. Location scu 2.3 P. SCU33.05 Pact 231d Ave s FlE� scU 12-v Pad SCu l4/ -12 1 6 5 3o a Pa� 3 s.23-03 Pad .43.05 CU 43.04 Pad_ scu 243.04 Pad S.34.0s Pad scu 34.04 Paas, 1scu 1,.03 Pad scu 14.04 Pad s U41.0ePad ¢011 scu 3100 Paa1 BSfu21 09 Pad scu 4109 Pad S007N009W SGU320aPad 12...Pa, 09 Pad R5 7 8 �u43.0SPads0u23a9Pad � 1c 11 12 SCU24308Pad ii,,,,4 1SOMRSCU 4Yin9Pad 9 A St sCU 1409 Pad34.09 Pad scu 34.0 I u e Pae ro k .�'+CH::2 sc Pad U // I, 1S 17 U1�e 1fi,.15 Pad 15 14 13 II N Swanson River Field9 n Figure 1 0 Map Scale 1:32,000 Alaska State Plane 4 NAD 19271 /� 2 !Moore 11aaka,ILI: _- Miles 0?141 P7,1 cnn gcr..-rri rrg Prrr t;'.f:1717 JV,<;rwr,frrrri,,,,, Prrrr Pri<-7.0 Fr.r: [TIT rrfrrrrf Piff17-017-' Prrr rrir giltr Mirg Frr_ Przff Mfr.,Frrr fTti SRU 23B-22 Proposed gr:Trir,i Fry': A.;'-grrr Cfli2-\":37.71'crf / rriT P711:1,-;;T:Pry: Mff Vrr.Tr itbFFrf En crst F34:^1P7 ITU )7j1=11- MI-111 4 - Frrf - - • ="1 ' SR 3428 Pad SRF Field Overview Proje - Area 4*Frr SRUgra 04/ - , €041177." P7tTek'rer: Legend SRU 23B-22 - c One Mile Radius 1 inch=1,083 feet A Proposed Well Surface Wells Figure 2 Feet1,500 3,000 Map Date 5/23/20120 0 SRU 14-22 Proposed Location .., .„., •0„:1,,,,--,.. :,..-,,;:-„,..ti . t 1r ? tion4 ,.:,...„ ' •..t%: ;.,,...„,. ...N ...4,. • r. ''''. '.'''Xr,, ',I'O'':,04;1?!;‘:.:::17:'''71:1'.' '''',1'''''''';t'74''!';:*" ''''''''' ' *e'.''' ' ifi''''t*''' ''' 1,0,44,4404,:) , .-':'4AV .' ' ' .':. ' ''' ' ',''''' l'''$...'a' -1,- ' "i0r, 1:-e., c`,' . '-,,,,,,,...-4'• ' 44.5e,'""' ' ' ' ' . :'w_�. ,,+ , mm " o' h ° v4t.l� " �� .a 4'1.; .1 ,r 4tis, lier 1,4 e. . .. �. • .' ' ,max ..2,...,2„ +'Y.. ,a, - ti111 114' t� C7 e < ' nab ., ' -'+•« �� SRU 14-22 sad A� �� 7 .� " SRU 14-22 Pad "aw.� s,'� ie Asn.;,$ . a a t t.. '''''C -';':.'1.' '' ' . ' - ' 4'°;." p, ''.4*.,,--.71;1.-:;;;-'4--i.',..,4,:- .1,--.,-:.*.",':: '---',...::;:t...fr' .. ... - ... ,--ilit, l'i. 214-, . vi,,,i,,,-.-4,-..-.,-*-4.1,,,,--i4,-....._.. . --* -Attik,.,- - - ---- ,7:,,,,,, ,..„.„ ,.,,, -,1, -,,,,,.-,.‘,,, - rr ... it �;` 4r: SRF Field i‘t O aE overview a ':*.-. . ''''' -.., .„. -:-4 . '11111911 Legend SRU 23B 22 Proposed Well N Surface Wells SRU 14-22 Well Pad 1 inch7=5 50 feet A u 4.•Lit Figur 3 Feet m.p o.,esnaizos 0 SRU 14-22 Proposed Location g 0 75 150 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME ` _C L 2 9 PTD# C 7 V Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD:��v�'—mac- j1 �r c"—(� POOL: `1::/-4--1/1- Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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SWANSON RIVER UNIT 23B-22 Kenai Peninsula Borough, Alaska ADL #212078 FINAL WELL REPORT MUDLOGGING DATA Provided by: Approved by: Kevin Eastham Compiled by: Larry Resch Dan Grunwald Distribution: 10/03/2012 T.D. Date: 09/21/2012 Swanson River Unit 23B-22 2 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................ 3 1.1 Equipment Summary ...................................................................................................................... 3 1.2 Crew ................................................................................................................................................ 3 2 WELL DETAILS ..................................................................................................................................... 4 2.1 Well Summary ................................................................................................................................ 4 2.2 Hole Data ........................................................................................................................................ 4 2.3 Well Synopsis ................................................................................................................................. 4 2.4 Daily Activity Summary ................................................................................................................... 5 3 GEOLOGICAL DATA ............................................................................................................................. 9 3.1 Lithostratigraphy ............................................................................................................................. 9 3.2 Mudlog Summary .......................................................................................................................... 10 3.3 Lithologic Details ........................................................................................................................... 11 3.4 Connection Gases ........................................................................................................................ 15 3.5 Trip (Wiper) Gases ....................................................................................................................... 15 3.6 Sampling Program / Sample Dispatch .......................................................................................... 16 4 PRESSURE / FORMATION STRENGTH DATA ................................................................................. 17 4.1 Pore pressure evaluation .............................................................................................................. 17 5 DRILLING DATA .................................................................................................................................. 18 5.1 Survey Data .................................................................................................................................. 18 5.2 Bit Record ..................................................................................................................................... 19 5.3 Mud Record .................................................................................................................................. 20 6 DAILY REPORTS ................................................................................................................................ 21 7 SHOW REPORTS ............................................................................................................................... 22 Enclosures: 2”/100’ Formation Log (MD/TVD) 2”/100’ Drilling Dynamics Log (MD/TVD) 2”/100’ LWD / Lithology Log (MD/TVD) 2”/100’ Gas Ratio Log (MD/TVD) Final Data CD Swanson River Unit 23B-22 3 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Comments Ditch Gas QGM agitator (mounted in mud trough) Flame ionization total gas & chromatography. 0 Block Height / Depth Totco WITS Feed 0 Hookload / Weight on Bit Totco WITS Feed 0 Mud Flow In Derived from pump rates and output 0 Return Flow Totco WITS Feed 0 Mudlogging Unit Computer System HP Compaq Pentium 4 (x3: DML, RigWatch, and Sample Catcher) 0 Pit Volumes, Gain/Loss Totco WITS Feed 0 Pump Pressure Totco WITS Feed 0 Pump Strokes Totco WITS Feed 0 Rate of Penetration Derived from block height 0 RPM Totco WITS Feed 11 days RPM & torque not transmitted by Totco until Sept. 13th (10,500’+) Torque Totco WITS Feed 11 days 1.2 Crew Unit Type : Steel Arctic Unit Number : ML030 Mudloggers Years *1 Days *2 Sample Catchers Years Days *2 Technician Days Larry Resch 13 20 Daniel Hillegeist 1 20 Allen Williams 2 Daniel Grunwald 4 20 Jessiah Johnson 1 20 *1 Years experience as Mudlogger *2 Days at wellsite between spud and total depth of well Swanson River Unit 23B-22 4 2 WELL DETAILS 2.1 Well Summary Well: SRU 23B-22 API Index #: 50-133-10148-01-00 Field: Swanson River Unit Surface Co-Ordinates: 738’ FSL, 637’ FWL, Sec. 22, T8N R9W, SM Borough: Kenai Peninsula Borough Primary Target Depth: Hemlock Formation 11460’ MD / 10804’ TVD State: Alaska TD Depth: 11741’ MD / 10902’ TVD Rig Name / Type: Arctic Fox / Double Suspension Date: (N/A) Primary Target: Hemlock Formation License: ADL 389198 Spud Date: 9/02/2012 Ground Elevation: 239’ AMSL Completion Status: 4½” liner RT Elevation: 257.98’ AMSL Classification: Development Secondary Target: Depth: Lower Tyonek Formation 9736’ MD / 9736’ TVD TD Formation: Hemlock Formation TD Date: 9/21/2012 Days Drilling: 11 Days Testing: 0 2.2 Hole Data Hole Section Maximum Depth TD Formation Mud Weight (ppg) Dev. (oinc) Casing/ Liner Shoe Depth LOT (ppg) MD (ft) TVDSS (ft) MD (ft) TVDSS (ft) Cased hole, 7” casing 9736’ -9478 Tyonek 9.2 <1 o whipstock in 7” casing 9736 -9478 12.0 6” 11741’ -10644 Hemlock 10.9 70 o 4½” 11739 -10644 N/A 2.3 Well Synopsis SRU 23B-22 is a deviated well designed to target a fault block containing stranded oil in the Hemlock Formation. The well was sidetracked out of the suspended SRU 14-22 wellbore; a whipstock was seated at 9736’ MD inside existing 7” casing. Drilling commenced with a planned build of 6 o/100ft up to a 70 o inclination toward the northeast and holding 70 o to total depth. Anticipated exploitation includes running a 4½” liner and utilizing a 3½” gas lift completion. Upon milling out a window in the casing, the formation pressures were higher than anticipated. Trip gases were consistently high (>2000 units), and despite raising the mud weight several times, flow checks often revealed gas influx into the well. Drilling was otherwise typical of the ash-rich sediments of the Cook Inlet Basin, steady through the Tyonek and uppermost Hemlock Formations, then extremely slow in the conglomerates of the Hemlock Formation. The latter brought the well to an end prior to the planned total depth. Relatively modest oil shows were observed in the target beds of the Hemlock Formation, as well as a small show in the overlying Tyonek Formation. Swanson River Unit 23B-22 5 2.4 Daily Activity Summary September 2, 2012 Trip in hole with whipstock to 9703 ft; rig up wireline and run gyro survey. Orientate whipstock. Tag bridge plug and set whipstock at 9736 ft; top of whipstock is 9718 ft; displace well to 6% KCl/EZ-Mud; start milling window at 1810 hours. Currently milling window in 7" casing at report time. September 3, 2012 Continue to mill window in 7” casing per Baker rep from 9734 ft to 9756 ft with 12-15k wob, 100 rpm, 3-6k torque, 1600 psi, 315 gpm, 163k up, 161k down; ream window while rotating—no drag; work window without rotating—no drag; circulate bottoms up at 9715 ft with 1430 psi, 279 gpm; rack back 1 stand and perform FIT to 12.0 ppg EMW; pump 30 bbl 12.5 ppg dry job; blow down top drive; monitor well (static); pull out of hole on elevators with trip tank from 9715 ft to 5000 ft; monitor well 10 minutes (static); fill trip tank and continue to trip out of hole from 5000 ft to top of BHA; check well—well is flowing; rack back 3 stands HWDP in derrick; check flow—well flowing at 1.7 BPH; company man to run in hole with milling assembly to 4770 ft; fill pipe with 100 strokes to fill at 700 psi, 252 gpm, 31% return flow reading; circulate surface to surface; CANRIG records 20 units of gas maximum at 4770 ft depth; continue trip in hole from 4470 ft to 9715 ft. Currently preparing to circulate bottoms up at report time. September 4, 2012 Begin circulating bottoms up at 9715 ft at 1690 psi, 330 gpm; CANRIG observes 2900 units of gas with increased flow from 34% to 41%; shut down pumps and shut in well at 0038 hrs with ISICP of 20 psi building to 70 psi over 1 hour; PJSM to weight up active system from 9.2 to 9.4 ppg; continue to circulate through choke manifold at 124 gpm and 660 psi with 180 psi back pressure; shut down and monitor well through open choke, open annular preventer; monitor well (flowing); continue weight up to 9.6 ppg and circulate at 330 gpm, 1690 psi, flow 36%; monitor well (flowing .75 bph); close annular preventer and observe ISICP of 5 psi increasing to 45 psi in 6 minutes; open choke and bleed off pressure; open annular preventer; circulate bottoms up and observe 216 units gas; close annular preventer with ISICP 5 psi, SICP 670 psi, SIDPP 670 psi; bleed off pressure through choke; open annular preventer; circulate through open choke at 9715 ft with 124 gpm, 440 psi; weight up to 9.8 ppg; circulate bottoms up and observe 240 units of gas; continue circulating at 328 gpm with 1530 psi, 35% flow; increase mud weight to 9.8 ppg; monitor well at 1300 hrs for 30 minutes—well flowing at 1 bph; circulate bottoms up at 323 gpm with 1680 psi, 35% flow and observe 85 units of gas; weight up to 10.0 ppg; monitor well at 1615 hrs—well flowing at .8 bph; circulate bottoms up at 319 gpm, 1640 psi, 35% flow and observe 112 units of gas; begin adding 6.6 bph water; weight up to 10.2 ppg; monitor well at 1930 hrs—well flowing at .5 bph; circulate bottoms up at 315 gpm with 1650 psi, 35% flow and observe 83 units of gas; weight up to 10.4 ppg; monitor well at 2130 hrs—well flowing at .5 bph; circulate bottoms up at 323 gpm, 1800 psi, 35% flow and observe 93 units of gas. Currently circulating at 331 gpm, 1800 psi, 36% flow while building mud weight to 10.6 ppg at report time. September 5, 2012 Continue to weight up mud system to 10.60 ppg while circulating at 320 gpm, 1870 psi, flow 35%; monitor well (flowing); close annular preventer and monitor pressure for 90 minutes—SIDPP 140 psi, SICP 160 psi; bleed off pressure, open annular and monitor well—flowing at .5 bph; circulate bottoms up at 9710 ft at 320 gpm, 1870 psi, 35% flow and observe 247 units gas; obtain SPR’s; monitor well; pull 5 stands drill pipe without filling hole—observe hole fluid column dropping; fill hole with 1.8 bbl; pump 20 bbl 12.6 ppg dry job; pull out of hole on trip tank; check well every 5 stands from 9407 ft to 4685 ft—static; monitor well at 4685 ft—static for 15 minutes, then slight flow at 30 minutes; continue to pull out of hole from 4685 ft to 2479 ft; calculated fill 37.5 bbls, observed fill 39.3 bbls; monitor well for 30 minutes—well flowing at .25 bph; continue trip out of hole from 2479 ft to top of BHA; check flow at top of BHA—decision made to pull completely out of hole and test BOP’s; lay down mill assembly and rig up to test BOP’s; test BOP’s at 250 psi low, 4000 psi high, 2500 psi high on annular; all tests good; witness waived by AOGCC rep Jim Regg. Currently servicing rig at report time. Total gain in 24 hours is 4.5 bbls. Swanson River Unit 23B-22 6 September 6, 2012 Pick up and make up BHA #4 with re-run bit number 1 along with mud motor, MWD tools; load sources and pick up 1 stand HWDP; shallow test MWD tools at 275 gpm, 1060 psi, 75 rpm, .5k torque; run in hole with 2 stands HWDP from derrick, jars, 7 stands HWDP; pick up and run in hole with 21 joints drill pipe from pipe shed from 861 ft to 1467 ft; fill pipe and pulse test MWD tools at 247 gpm, 1240 psi; continue to run in hole picking up 15 joints drill pipe from pipe shed from 2657 ft to 3128 ft; continue to run in hole with drill pipe from derrick from 3128 ft to 9734 ft filling pipe every 30 stands; monitor drill pipe displacement on trip tank; orient motor through window per directional driller; no change in weight indicator observed; circulate bottoms up at 252 gpm, 1760 psi, 31% flow; CANRIG records 2765 units of gas at bottoms up; pressure increases to 1850 psi; run gyro equipment and orientate tool face to 41.8 degrees; pull out of hole with gyro; ream from 9736 ft to 9756 ft at 210 gpm, 1440 psi, 31% flow; tag bottom at 9756 ft; slide drill at 41.78 degree from 9756ft to 9768 ft. Currently drilling ahead at report time. September 7, 2012 Continue to slide drill ahead from 9768 ft to 9796 ft with 208 gpm, 1470 psi, 155k up, 160k down; circulate 170 bbls at 9796 ft with 211 gpm, 1570 psi; rig up side entry sub for Pollard wireline to orient tool face at 335 degrees; work gyro tool face set at 339 degrees; pull out of hole with wire line tools; check shot survey with MWD; rack back 1 stand to 9732 ft; run in hole with wireline gyro to orient tool face; after repeated seats failed to obtain consistent tool face reading---most consistent tool face was 35 degrees; pull wireline gyro tool out of hole; run in hole 1 stand to 9796 ft and orientate motor; control slide drill ahead from 9796 ft to 9905 ft at report time. September 8, 2012 Continue to slide drill ahead from 9905 ft to 10243 ft with 15-25k wob, 247 gpm, 2250 psi, flow 47%, 173k up, 162k down. CANRIG reports 25-35 units of connection gas above background (20-35 units) from 9850 to 10150 ft, increasing to 172 units at 10115 ft, 143 units at 10180 ft, and 229 units at 10235 ft. Currently drilling ahead with 20 units of background gas at 10243 ft hole depth at report time. September 9, 2012 Continue to slide drill ahead from 10243 ft to 10407 ft with 15-25k wob, 247 gpm, 2260 psi on/ 2090 psi off, 176k up/ 162k down; circulate bottoms up at 10407 ft; monitor well—well flowing at .5 bph; pull and rack back 5 stands in derrick to 10115 ft; hole fill calc = 1.5 bbl, observed 1 bbl; continue to pull out of hole from 10115 ft to 9672 ft filling every stand; monitor well every 5 stands—well not taking proper fill; monitor well—flowing; run in hole from 9672 ft to 9719 ft; orientate tool to get through window; continue run in hole from 9719 ft to 10378 ft; Kelly up and wash/ ream to bottom at 10407 ft; circulate bottoms up—CANRIG records 3087 units of wiper trip gas, arriving on time and decreasing to background of < 15 units; weight up mud from 10.6 to 10.7 ppg; monitor well—flowing; pull out of hole from 10407 ft to 9672 ft—hole took 1.5 bbls less than calculated; monitor well—flowing; Kelly up install TIW and line up on choke; shut in well—DPP = 12 psi, SICP = 57 psi; bleed off pressure; pump dry job; continue to pull out of hole from 9672 ft to 7451 ft at report time. September 10, 2012 Continue to pull out of hole from 7451 ft to 4763 ft—calculated displacement 13.6 bbls, hole took 12 bbls for a 1.6 bbl gain; monitor well — well flowing at .6 bph; continue to pull out of hole from 4763 ft to 4567 ft; monitor well — closed annular preventer at 0440 hrs with ISIDPP = 10 psi, ISICP = 0, changing to SIDPP = 10 psi, SICP = 89 psi; open choke and annular preventer at 0600 hrs; continue to pull out of hole from 4567 ft to top of HWDP at 806 ft—calculated displacement = 20.4 bbl, actual displacement = 20.7 bbls; monitor well—slight flow; continue to pull out of hole with BHA; unload nuclear sources, download MWD data; rack back smart tools in derrick; pick up new motor, new bit and orient same; run in hole to 440 ft and shallow hole test tools at 220 gpm, 600 psi; monitor well — static; continue to run in hole from 2374 ft with drill pipe, filling pipe every 25 stands. Currently tripping in hole at 7198 ft at report time. Swanson River Unit 23B-22 7 September 11, 2012 Continue to run in hole from 7198 ft to 9665 ft; function test MWD; slip and cut drill line, service rig, calibrate block height; continue to run in hole from 9665 ft to 10367 ft; Kelly up and wash down to10407 ft; circulate bottoms up at 247 gpm, 1810 psi, 50 rpm, 2.2k torque—observed 3000 units of trip gas from bottoms up; drill ahead from 10407 ft to 10453 ft 30 rpm, 2.9 torque; 247 gpm, 2020 psi, 169k rot, 176k up, 164k down; circulate and condition bottoms up at 310 gpm, 3000 psi; mix dry job; monitor well—static; pull out of hole for bit and BOP test from 10453 ft to 9546 ft, filling hole every stand; monitor well at 9546 ft—static; continue to pull out of hole from 9546 ft to 6652 ft at report time. September 12, 2012 Continue to pull out of hole from 6652 ft to 4507 ft; monitor well—flowing at .5 bph; continue to pull out of hole from 4507 ft to top of HWDP at 805 ft; monitor well—flowing at .5 bph; continue to pull out of hole; unload nuclear sources and download MWD; rig up to test BOP’s and test same; make up new bit. Currently running in hole at report time. September 13, 2012 Continue to run in hole to 10430 ft filling pipe every 25 stands; kelly up awas20 ft to bottom at 10453 ft; circulate bottoms up at 279 gpm, 2260 psi and record 3194 units of trip gas; slide/ rotary drill ahead from 10453 ft to10681 ft with 15-25k wob, 0/ 180 rpm, 12-19k torque, 302 gpm, 2910 psi, 178k up, 162k down, 164k rot. Currently drilling ahead at 10686 ft at report time. September 14, 2012 Continue to rotary drill/ slide from 10686 ft to 10900 ft with 15-18k wob, 0/ 180 rpm, 3.5-5.5k torque, 295 gpm, 3110 psi, 181k up/ 158k down/ 170k rot; attempt to drill from 10900 ft no good—pump pressure dropping from 2690 psi off bottom, 3200 psi on bottom;, flow 32%, differential pressure 450+ psi; monitor well—flowing .3 bph; pull out of hole wet from 10900 ft; pull 5-15k over to 10618 ft, 5-10k over to 10240 ft, no over pull to 9609 ft; well took .7 bbl under calculated; monitor well at 9609 ft—flowing at .3 bph while inspecting derrick; pump dry job; continue to pull out of hole from 9609 ft to 4510 ft; well took 4 bbl under calculated for pulling 100 stands 4” drill pipe; monitor well at 4510 ft—well flowing .6 bph (part of this may be due to dry job); continue to pull out of hole from 4510 ft to top of HWDP at 806 ft; monitor well—flowing at .3 bph. Currently pulling out of hole at report time. September 15, 2012 Continue to trip out of hole from 806 ft to 350 ft; unload nukes, download MWD data; continue to pull out of hole from 350 ft to bit; cones missing off bit; lay down OnTrak MWD and stand back motor assembly; service rig while waiting on Baker fishing tools; make up junk catcher and fishing BHA; run in hole to 9719 ft and monitor well—flowing .21 bph; continue trip in hole from 9719 ft to 10739 ft; wash from 10739 ft to 10864 ft at 247 gpm, 1520 psi; drop ball, ball seated at 991 strokes; continue to wash from 10739 ft to 10900 ft with 290 gpm, 2100 psi; CANRIG records 3249 units of trip gas (arrives early); cut 2 ft core; shut down pumps and monitor well—flowing at .21 bph; go back to bottom and put 10k weight on catcher; pump dry job; pull out of hole wet from 10902 ft to 9284 ft at report time. September 16, 2012 Continue to pull out of hole with fishing tools from 9284 ft to 4500 ft; monitor well for 15 minutes—static, hole taking proper fill; continue to pull out of hole from 4500 ft to 676 ft; monitor well prior to pulling BHA—well flowing, no gas breakout; continue to pull out of hole; lay down junk catcher and inspect—no fish but outer edge of mill worn; make up junk basket and mill BHA as instructed by Baker representative; trip in hole to 9677 ft; monitor well—static; make up TIW and topdrive; slip and cut drill line, service rig, grease crown; continue trip in hole from 9677 ft to 10873 ft; kelly up, fill pipe and circulate—hole gave .6 bbl over calculated; CANRIG records 2707 units of trip gas while washing from 10873 ft to 10902 ft; attempt to mill cones from 10902 ft with 5-15k wob; 80 rpm, 3-7.5k torque, 126 gpm, 800 psi—made 10 ft new hole to 10912 while milling; monitor well at 10912 ft—well flowing .5 bph; get slow pump rates and pull out of hole wet from 10912 ft to 9677 ft; hole taking proper fill, no overpull observed; pump dry job and continue to pull out of hole from 9677 ft to 9550 ft at report time. Swanson River Unit 23B-22 8 September 17, 2012 Continue to pull out of hole from 9550 ft to 684 ft—hole taking proper fill; monitor well at 684 ft; continue to pull out of hole; lay down junk basket BHA per Baker representative; clean floor, service rig, calibrate blocks; make up drilling assembly—scribe motor, check float, download MWD, orient motor with orientation sub per Baker MWD; shallow hole test MWD—good test; load nukes and continue to run in hole from 805 ft to 1180 ft with 24 joints of 4” drill pipe from pipe shed; continue to run in hole from 1180 ft to 9606 ft with pipe from derrick filling pipe every 25 stands; check calipers MWD; continue to run in hole from 9606 ft to 9719 ft, orient string ¼ turn right to drop through window; continue to run in hole to bit depth of 10000 ft at report time. September 18, 2012 Continue to run in hole from 10000 ft to 10865 ft; orient high side and wash down from 10865 ft to 10912 ft with 200 gpm, 2190 psi; drill ahead from 10912 ft to 11162 ft with 10-15k wob, 80 rpm, 3.5-4.5k torque, 280 gpm, 2350 psi, 182k up, 160k down, 155k rot; control drill from 11162 ft to 11250 ft; pull up to 11244 ft and circulate bottoms up. Currently preparing to pull out of hole to inspect bit and test BOP’s at report time. September 19, 2012 Prepare to pull out of hole for bit inspection and BOP tests; monitor well for 15 minutes—well flowing .5 bph; pull out of hole from 11244 ft to 9668 ft; monitor well at window; pump dry job and pull out of hole from 9668 ft to 4500 ft; monitor well—well flowing .25 bph; continue to pull out of hole from 4500 ft to top of BHA at 850 ft; monitor well—well flowing at .25 bph; continue to pull out of hole, download MWD tools and rack back; test annular preventer to 250 psi low, 2500 psi high; test all other rams and related equipment to 250 psi low, 4000 psi high for 5 minutes; perform draw down test, function test super choke and manual choke; make up new bit and motor—orient same; continue to pick up BHA to 803 ft, conduct shallow hole test MWD tools. Currently running in hole at report time. September 20, 2012 Continue to run in hole from 1818 ft to 8660 ft; calibrate Baker MWD crown height and check crown-o-matic; continue to run in hole from 8660 ft to 9666 ft; break circulation with 125 gpm, 900 psi; attempt to exit window—no good; rotate string ½ turn—second attempt good; continue to run in hole from window to 11173 ft; kelly up and wash from 11173 ft to 11250 ft w2ith 220 gpm, 1950 psi, 50 psi differential; 10k slack off observed from 11220 ft to 11250 ft; drill ahead from 11250 ft to 11582 ft with 2-20k wob, 80 rpm, 4-6k torque, 250 gpm, 2750 psi, flow 27%. Currently drilling ahead from 11582 ft at report time. September 21, 2012 Continue to drill ahead from 11582 ft to 11706 ft with 15k wob, 85 rpm, 4-6k torque, 247 gpm, 2720 psi, 188k up, 157k down, 160k rot; pump 30 bbl--10 ppg nut plug sweep at 11706 ft; drill ahead from 11706 ft to TD at 11741 ft; conduct surveys per DD; circulate and condition hole 2xm bottoms up; pump nut plug sweep— comes back on time indicating gauged hole; monitor well at 11741 ft—well flowing; pull out of hole from 11741 ft to 11430 ft, monitor well—well still flowing; note 50k overpull coming off bottom; continue to pull out of hole from 11430 ft to 11116 ft, monitor well—flowing. Continue to pull out of hole at report time. September 22, 2012 Continue to pull out of hole from 11116 ft to 9667 ft; monitor well for 10 minutes—static; pump 22 bbl dry job; continue to pull out of hole from 9667 ft to 9288 ft with 2.8 bbl gain; pull out of hole 1 stand from 9288 ft to 9225 ft with 6.7 bbl gain; install TIW and inform company man, shut down hole fill and monitor well—obtain flow back rate of 5 bph; strap all pits and empty trip tank; run in hole from 9225 ft to 11741 ft; circulate bottoms up and receive back 2520 units gas (8.8 hrs downtime); gas returns to < 20 units background gas; monitor well—flow back rate of 4-5 bph; continue to circulate at 220 gpm, 2230 psi, 45 rpm, 4k torque, flow 30%; weight up mud system from 10.70 ppg to 10.80 ppg; monitor well at 1400-1500 hrs—well flowing at 3 bph; circulate and condition mud to 10.90 ppg; monitor well from 1600-1700 hrs—well flowing at .25 bph; pull out of hole from 11741 ft to 9663 ft; slip and cut 125 ft drill line; flow check well on trip tank—static; adjust brakes and calibrate block travel on TOTCO; pump 25 bbl dry job; continue to trip out of hole from 9663 ft to 5763 ft at report time. Swanson River Unit 23B-22 9 3 GEOLOGICAL DATA 3.1 Lithostratigraphy Formation tops provided by Hilcorp geological staff. FORMATION PROGNOSED POST DRILL TOPS MD (ft) TVD (ft) SSTVD (ft) MD (ft) TVD (ft) TVD (ft) Kick-off Point 9,700 9,700 -9,441 9,736 9,736 -9,478 Tyonek G1 – – – 11,112 10,691 -10,433 Tyonek G2 11,072 10,678 -10,419 11,237 10,730 -10,472 Hemlock Formation 11,278 10,743 -10,484 11,460 10,804 -10,546 Hemlock H2 11,332 10,761 -10,502 11,495 10,816 -10,558 Hemlock H3 11,407 10,786 -10,527 11,534 10,830 -10,572 Hemlock H4 11,535 10,830 -10,571 11,637 10,866 -10,608 Hemlock H5 11,612 10,857 -10,598 – – – Hemlock H7 11,766 10,911 -10,652 – – – TD 12,021 11,001 -10,742 11,741 10,902 -10,644 Swanson River Unit 23B-22 10 3.2 Mudlog Summary Kick-Off Point to Tyonek G1 Horizon 9736’ to 11112' MD (-9478' to -10433' SSTVD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 225 9 74 1069 6 144 The portion of the Tyonek Formation encountered in this well above the G Horizon consists of. Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 3738 1069 146282 6077 6465 2999 3735 2092 2984 3784 456 71550 1555 1295 600 815 613 605 4207 460 68417 691 632 467 728 637 642 5839 155 21660 2065 1118 148 304 76 77 Hemlock Formation 6750’ to 6950' MD (5938' to 6115' SSTVD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 41 7 15 353 8 40 The upper portion of the Hemlock Formation encountered in this well consists of. Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 3738 1069 146282 6077 6465 2999 3735 2092 2984 3784 456 71550 1555 1295 600 815 613 605 4207 460 68417 691 632 467 728 637 642 5839 155 21660 2065 1118 148 304 76 77 Swanson River Unit 23B-22 11 3.3 Lithologic Details Sand, Conglomeratic Sand (9720'-9780') = unconsolidated; medium to lower coarse grain; angular to subangular, becoming medium grain, subangular to subrounded in part down section; subdiscoidal; moderate sorting; tuffaceous/ argillaceous in part as an arenaceous claystone; no evidence of consolidation or cementation; dominantly milky white, slightly translucent quartz, feldspars common; locally abundant white to very light gray clays; generally soft, mushy, occasionally well indurated, firm, subwaxy; note coal at 9749' = black; firm to hard; massive; blocky with birdseye fracture common; no outgassing bubbles. Tuffaceous Claystone (9780' - 9840') = amorphous, light gray, soft, pasty claystone with subordinate matrix supported sand in devitrified ash tuff; cuttings are brittle to crumbly when dry with an earthy luster; quartz sand and minor lithics are lower very fine- to lower medium-grained; abundant graphite mud additive. Tuffaceous Claystone/ Siltstone (9840'- 9930') = light gray to very light gray with slight yellowish brown hues; firm; moderate to well indurated; sectile, crumbly to pulverulent in part; generall y amorphous, note occasional extremely thin carbonaceous layering; dull to rarely earthy; occasionally subwaxy; very arenaceous in part with abundant well rounded to subrounded quartz; a tuffaceous sandstone in part with matrix supported grains, rare grain supported; poorly consolidated; noncalcareous; no visible porosity; trace coal = black; massive to blocky, tabular to irregular cuttings habit; occasionall y hackly displaying layered organic material; rare brownish black, earthy. Tuffaceous Siltstone (9930' - 9990') = light olive gray to yellowish brown, subblocky to wedge like cuttings of crumbly siltstone have a dull, waxy luster underlain by a smooth, silty texture; crushed material exhibits good cohesion but no plasticity; contains thin interbedded black shales. Tuffaceous Siltstone (9990' - 10020') = medium gray, pulverulent to crumbly siltstone; gritty to silty texture with earthy to dull luster; fair cohesion with no plasticity; tuffaceous sandstone is very fine-grained and matrix supported with poor visible porosity; trace coal. Tuffaceous Sandstone (10020' - 10080') = light gray to pale brown; very fine to medium grains, rounded with moderate sphericity; poorly sorted; very poorly consolidated; traces of calcite cement; grain supported with tuffaceous matrix; very poor visual porosity. Tuffaceous Sandstone (10080' - 10110') = very light gray to medium gray; moderately consolidated; quartz sand is very light gray; minor darker lithics; poorly sorted; very fine to lower coarse grains; subangular with low sphericity; grain supported; poor visual porosity; trace calcite cement; trace shales. Tuffaceous Sandstone (10110' - 10200') = very light gray to light gray, white; medium grain, upper fine grain common; subrounded to subangular; subdiscoidal; moderate to well sorted in part; poorly consolidated, often loose sand; non to slightly calcareous; tuffaceous, argillaceous matrix; equally grain supported and matrix supported; grades towards an arenaceous claystone; no visible porosity; dominantly translucent and transparent quartz with black, brownish black and yellowish green secondary lithics; note coal/ carbonaceous shale = grayish black, brownish black, dusky yellowish brown in part; friable to moderately hard; irregular to slightly splintery fracture; earthy in part; subplaty; no visible outgassing. Tuffaceous Claystone/ Siltstone (10200' - 12230') = very light gray to light gray, often with slight yellowish brown hues; firm to soft; poor to moderate induration; pulverulent, rarely crumbly; no definable fracture or cuttings habit; slightly gritty and abrasive; dull. Swanson River Unit 23B-22 12 Sand/ Tuffaceous Sandstone (10230' - 10320') = generally loose sand; locally consolidated; light gray to very light gray; subrounded to subangular, subdiscoidal; moderate to good sorting; sandstone varies from matrix supported to grain supported in part; no visible porosity; moderately calcareous; translucent to transparent quartz dominates; abundant well rounded volcanic glass; rare very fine glass shards, muscovite; minor grayish black and very dark green secondary lithics; no stain or fluoresce. Tuffaceous Siltstone (10320' - 10410') = brownish gray wedge like to tabular cuttings of crumbly siltstone with minor clay and trace microscopic laminae of black shale; a dull, earthy luster is underlain by a smooth, silty texture; crushed material exhibits fair cohesion but no plasticity; transition at base to well sorted, partly matrix supported, very fine- to fine-grained quartz sandstone with minor lithics in a soft, pale devitrified ash; no oil indicators. Sandstone (10410' - 10453') = light gray well sorted, fine to very fine lapillae-lithic-quartz sandstone, with brittle silica cement and minor calcite cement. Tuffaceous Sandstone (10453' - 10590') = delicate, very light gray matrix supported sandstone; very poorly sorted sand ranges from very fine- to coarse- grained; the bulk of the sand consists of very light gray translucent quartz; trace to minor black and pale green siliceous lithics and flakes of black shale comprise the remainder of the sand; all are in a soft, white matrix of devitrified ash; visible porosity is negligible; quartz and shale grains are subangular to subrounded with moderate sphericity, while the siliceous lithics are subrounded to rounded with good sphericity; quartz grain surfaces are etched and pitted; contains sporadic, thin, interbedded black shales and abundant lenses and laminae of loose sand or brittle silica cemented sand and silt; abundant graphite mud additive in samples; no oil stain, odor, fluorescence, nor cut. Tuffaceous Claystone (10590' -10680') = light gray to very light gray, light brownish gray; firm to soft; good cohesion, poor adhesion; moderate to fair induration; malleable in part; no definable fracture or cuttings habit; dull to earthy, slightly subwaxy in part; generally smooth, nonabrasive; silty in part, rarely sandy; noncalcareous; no visible bedding; with interbedded coal = black; moderately hard to hard; irregular, hackly to slightly splintery; occasional birdseye fracture; vitreous, occasionally dull; rare fissile structure; no stain, odor, fluorescence, or cut. Tuffaceous Sandstone (10680' - 10770') = very light gray to light gray, grayish white, yellowish gray in part; upper fine to lower medium grain; subangular to subrounded; subdiscoidal; moderate to poor sorting; friable, occasionally moderate consolidation; noncalcareous; generally matrix supported with abundant clay/ ash, rare grain supported cuttings; no visible porosity; slightly silty in part; often grades towards an arenaceous claystone; dominantly milky white, matte quartz, locally abundant volcanic glass clasts; no stain, odor, fluorescence or cut. Tuffaceous Sandstone / Sand (10770' - 10890') = samples consist of loose sand sprinkled with soft amorphous cuttings of tuffaceous sandstone; the sand is moderately sorted, ranging from lower very fine- to upper medium-grained along with scattered coarse grains; grains primarily consist of translucent, very light gray to greenish gray subangular quartz with minor flakes of black shale, as well as trace pale green and dark gray rounded siliceous lithics; sphericity is moderate overall; quartz grain surfaces are etched and pitted; the intact sandstone is matrix supported in a pale devitrified ash; sporadic white to very pale orange cuttings of ash tuff can be seen in the samples; NO OIL STAIN IS EVIDENT, BUT A FAINT ODOR IS PERCEPTIBLE; 5% TO 10% OF THE SAMPLES FLUORESCE A LIGHT YELLOW, AND A FAINT BROWN CUT FLUORESCES A TRANSLUCENT YELLOW TO WHITE; A LIGHT CUT RESIDUE FLUORESCES A DULL YELLOW. Swanson River Unit 23B-22 13 Sand, Sandstone (10890' - 11010') = interval contains locally abundant upper very fine to lower fine grain loose sand; well rounded to subrounded; subdiscoidal; well sorted; dominantly translucent to transparent quartz; sandstone is very light gray; upper very fine, lower very fine grain common; well rounded to subrounded in part; subdiscoidal to spherical in part; well sorted; grain supported; tight; noncalcareous; quartz dominant with very fine scale-like carbonaceous detritus; NO VISIBLE OIL STAIN OR ODOR; UP TO 60% VERY FAINT PALE STRAW YELLOW FLUORESCENCE; IMMEDIATE WHITE TO BLUISH WHITE FLUORESCENT CUT, BECOMING YELLOWISH WHITE WITH FLUORESCENT DULL ORANGE RING; BROWN VISIBLE RESIDUE RING FLUORESCES YELLOW GOLD. Tuffaceous Sandstone (11010' - 11080') = olive gray slurry of disaggregated, well sorted, lower fine to very fine quartz sand with minor dark gray and pale green siliceous lithics and black flakes of shale; grains are subrounded with good sphericity; scattered soft ash matrix sandstone and lesser brittle to dense silica cemented sandstone and siltstone; NO OIL STAIN, WEAK ODOR; VERY DULL YELLOW FLUORESCENCE FROM RESIDUAL FLUID IN SAMPLES DIMINISHES WITH DEPTH; A WEAK STREAMING CUT FLUORESCES DULL YELLOW. Tuffaceous Siltstone (11080' - 11180') = crumbly to crunchy olive gray siltstone; wedge like to slightly tabular cuttings display a dull, earthy to waxy luster underlain by a smooth, silty texture; bulk material exhibits excellent cohesion but negligible plasticity; trace microscopic laminae of black shale are aligned along bedding, and a bed of gas-charged black shale occurs lower in this interval; lenses and laminae of firm siltstone and sandstone near the shale are cemented by silica; abundant graphite mud additive is present in the samples; NO OIL STAIN, ODOR, NOR FLUORESCENCE; A WEAK STREAMING CUT FLUORESCES YELLOW TO MILKY WHITE. Tuffaceous Siltstone (11080' - 11180') = crumbly to crunchy olive gray siltstone; wedge like to slightly tabular cuttings display a dull, earthy to waxy luster underlain by a smooth, silty texture; bulk material exhibits excellent cohesion but negligible plasticity; trace microscopic laminae of black shale are aligned along bedding, and a bed of gas-charged black shale occurs lower in this interval; lenses and laminae of firm siltstone and sandstone near the shale are cemented by silica; abundant graphite mud additive is present in the samples; NO OIL STAIN, ODOR, OR FLUORESCENCE; A WEAK STREAMING CUT FLUORESCES YELLOW TO MILKY WHITE. Tuffaceous Sandstone/ Siltstone/ Claystone (11180' - 11250') = very light gray to grayish white, light gray, occasional brownish hues; extremely fine to very fine grain; well rounded to subrounded; good sphericity; well to moderate sorting; very soft to poorly consolidated, rarely hard, well cemented noncalcareous; abundant ash/ clay matrix; no visible porosity; note locally abundant loose sand; interval varies from an argillaceous and silty sandstone to an arenaceous tuffaceous claystone; NO STAIN, ODOR, FLUORESCENCE, WITH RARE YELLOW CUT FLUORESCENCE. Sand/Sandstone (11250' - 11380') = samples consist of an olive gray slurry of mushy ash-matrix sandstone and disaggregated sand with minor lenses of silica cemented sandstone and siltstone; moderately sorted sand ranges from lower very fine- to lower medium-grained; translucent very light gray to yellowish gray quartz is peppered with flakes of black shale, along with dark gray and pale green siliceous lithics; sand is 50% to 75% matrix supported in soft, pale devitrified ash; subrounded to subangular grains display moderate sphericity; quartz grain surfaces are etched and pitted; CRUSHING TUFFACEOUS SANDSTONES LIBERATES TRACES OF FREE OIL, THOUGH NO ODOR IS NOTICEABLE; 10% TO 30% OF SAMPLES FLUORESCE A MODERATE YELLOW, AND A STREAMING BROWN CUT AND PALE CUT RESIDUE FLUORESCE MODERATE YELLOW. Swanson River Unit 23B-22 14 Tuffaceous Sandstone (11380' - 11450') = light olive gray to medium light gray sandstone with interspersed traces of moderately silicified sandstone; moderately sorted, very fine to upper fine grains; subangular to subrounded with low to moderate sphericity; matrix supported; 3% to 5% siltstone, brownish gray to dark gray, dense to crunchy; TRACE OIL IN SANDSTONE EXHIBITS DULL WHITE TO YELLOW FLUORESCENCE, AND A STREAMING VISIBLE CUT FLUORESCES MODERATE YELLOW. Tuffaceous Sandstone (11450' - 11550') = very light gray to light gray, grayish white; very fine to fine grain in part; well rounded to subrounded with good sphericity; well to moderate sorting; very poorly consolidated, with quartz grains and carbonaceous clasts/ detritus supported in a devitrified ash matrix; very fine loose quartz grains locally abundant; occasionally appears medium grain; grain supported; moderately hard to hard; noncalcareous; trace to poor visible porosity; NO VISIBLE OIL STAIN OR ODOR; INTERVAL VARIES FROM 40-70% BRIGHT YELLOW TO YELLOW ORANGE FLUORESCENCE; IMMEDIATE YELLOW WHITE FLUORESCENT CUT WITH SLOW TO DEVELOP BLUISH WHITE STREAMERS; NO VISIBLE RESIDUE RING. Sandstone/ Sand/ Tuffaceous Sand (11550' - 11650') = note significant increase of loose sand through interval; very fine well rounded grains with good sphericity; consolidated sand is hard to very hard; grain supported with very little matrix; calcareous; poor to fair visual porosity; NOTE INDICATIONS OF PLANAR/ PARALLEL BEDDING OF BLACK, NON-FLUORESCENT OR REACTIVE ORGANIC MATERIAL; INCREASED TUFFACEOUS COMPONENT DOWN SECTION THAT FLUORESCES DULL YELLOW ORANGE; IMMEDIATE BRIGHT BLUISH YELLOW SOLVENT REACTION WITH SLOW WHITE BLUE TO YELLOW WHITE STREAM CUT; NO CUT RESIDUE. Tuffaceous Sandstone (11650' - 11690') = yellowish gray, crumbly sandstone consists of moderately sorted quartz with minor darker lithics loosely bound in pale devitrified ash; very fine to medium grains are subangular to angular with moderate to poor sphericity; 10% TO 20% DULL YELLOW FLUORESCENCE; A DARK BROWN CUT FLUORESCES YELLOW TO WHITE. Sand/ Conglomeratic Sand (10690' - 10741') = loose quartz sand contains angular quartz and lithic pebble chips to one tenth inch; 15% MODERATE TO DULL YELLOW FLUORESCENCE; LIGHT BROWN CUT EMITS A MODERATE YELLOW FLUORESCENCE; NO CUT RESIDUE. Swanson River Unit 23B-22 15 3.4 Connection Gases 1 unit = 0.02% Methane Equivalent Measured Depth (feet) Subsea Total Vertical Depth (feet) Gas over background (units) Measured Depth (feet) Subsea Total Vertical Depth (feet) Gas over background (units) 9858 -9600 35 10742 -10297 59 9921 -9662 20 10805 -10326 57 9985 -9724 25 10867 -10352 65 10050 -9786 35 10988 -10392 35 10115 -9846 172 11051 -10413 40 10176 -9901 143 11115 -10434 60 10238 -9954 229 11177 -10453 47 10300 -10006 143 11241 -10473 57 10365 -10057 169 11302 -10493 51 10428 -10105 69 11365 -10514 25 10490 -10148 43 11428 -10535 39 10555 -10190 67 11492 -10557 70 10617 -10229 47 11555 -10579 46 10625 -10233 26 11616 -10600 36 10679 -10265 91 11679 -10623 15 3.5 Trip (Wiper) Gases 50 units = 1% Methane Equivalent Measured Depth (feet) Trip to (feet) Gas (units) Hours Off Bottom 9756 surface 2900 16 9756 surface 2765 36 10407 9595 3087 22½ 10407 surface 2995 36 10453 surface 3194 35 10900 surface 3249 25 10902 surface 2707 20 10912 surface 2887 27 11250 surface 3265 31 11741 9111 2520 8 11741 surface 3050 48 Swanson River Unit 23B-22 16 3.6 Sampling Program / Sample Dispatch Set Type / Purpose Frequency* Interval Dispatched to A Washed and dried reference samples 30 ft 10 ft 9750’ to 10,890’ 10,890’ to 11,741’ Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite #1000 Anchorage, AK 99508 Attn.: Debra Oudean (907) 777-8337 B Washed and dried reference samples 30 ft 10 ft 9750’ to 10,890’ 10,890’ to 11,741’ Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite #1000 Anchorage, AK 99508 Attn.: Debra Oudean (907) 777-8337 * Sample frequency was locally altered according to drill rate constraints and zones of interest. Sw a n s o n R i v e r U n i t 2 3 B - 2 2 17 4 P R E S S U R E / F O R M A T I O N S T R E N G T H D A T A Co n n e c t i o n g a s o c c u r r e d t h r o u g h m o s t o f t h e d r i l l i n g, b u t p e a k s w e r e c o n s i s t e n t l y s h a r p a n d d r o p p e d o f f q u i c k l y , i n d i c a t i n g p o r e p r e s s u r e r e m a i n e d be l o w m u d w e i g h t t h r o u g h o u t . Co n n e c t i o n g a s w a s e n c o u n t e r e d f r o m t h e s t a r t o f t h e w e l l w h i l e d r i l l i n g w i t h a 9 . 7 p p g m u d , b u t e v e n t ua l l y d r o p p e d o u t a s m u d w e i g h t w a s in c r e a s e d t o 1 0 . 4 p p g a t 5 6 5 7 ’ . T h e r e f o r e , p o r e p r e ss u r e i s e s t i m a t e d t o h a v e v a r i e d f r o m 9 . 4 t o 1 0 . 0 fr o m c a s i n g p o i n t t o t h e H R Z , r e m a i n i n g j u s t be l o w t h e m u d w e i g h t u n t i l m u d w e i g h t r e a c h e d 1 0 . 4 . Hi g h c o n n e c t i o n g a s w i t h a n 1 1 . 0 p p g m u d a t t h e t o p o f t h e H R Z i n d i c a t e s a s h a r p p r e s s u r e i n c r e a s e , a n d c o n t i n u e d h i g h c o n n e c t i o n a n d t r i p ga s e s t o t o t a l d e p t h i n d i c a t e p o r e p r e s s u r e p r o b a b l y r e m a i n e d j u s t u n d e r m u d w e i g h t , w h i c h v a r i e d f r o m 1 1 t o 1 1 . 3 + , a n d p o r e p r e s s u r e p e r h a p s 10 . 7 t o 1 1 . 1 p p g . 4. 1 P o r e p r e s s u r e e v a l u a t i o n Fo r m a t i o n In t e r v a l Pr i m a r y Li t h o l o g y (% ) Se c o n d a r y Li t h o l o g y (% ) In t e r v a l T o p s P o r e P r e s s u r e ( E M W ) Trend In d i c a t o r s MD (f t ) SS T V D (f t ) Mi n (p p g ) Ma x (p p g ) Tr e n d Ty o n e k (b e l o w - 9 4 7 8 ’ S S T V D ) 50 % Sa n d / S n d s t 25 % S l t s t , 20 % C l y s t 97 3 6 - 9 4 7 8 1 0 . 7 I N C R C G , T G , M W He m l o c k NO T E : C l y s t = C l a y s t o n e / C l a y ; S a n d = U n c o n s o l i d a t e d S a n d ; S l t s t = S i l t s t o n e ; S h = S h a l e ; S n d s t = S a n d s to n e ; A s h = A s h T u f f Swanson River Unit 23B-22 18 5 DRILLING DATA 5.1 Survey Data Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Northing (ft) Easting (ft) Vertical Section (ft) Dogleg Rate (o/100ft) T 9700 0.19 98.38 9699.84 3.11 9.33 0.00 9719 0.18 104.18 9718.84 3.10 9.39 8.74 0.11 9800 4.08 334.69 9799.77 5.67 8.28 9.83 5.18 9863 7.92 359.97 9862.43 12.04 7.32 13.75 7.26 9926 12.60 17.40 9924.42 22.95 9.37 23.04 8.83 9990 16.55 32.75 9986.37 37.29 16.40 38.24 8.58 10053 19.42 45.69 10046.31 52.16 28.75 57.52 7.78 10117 24.16 48.14 10105.72 68.34 46.13 81.23 7.54 10180 28.22 49.95 10162.24 86.54 67.15 108.91 6.57 10242 32.00 52.11 10215.86 106.07 91.34 139.76 6.34 10306 35.95 55.10 10268.93 127.24 120.14 174.99 6.70 10364 40.25 53.97 10314.56 148.01 149.28 210.16 7.51 10428 44.16 50.29 10361.97 174.43 183.16 252.69 7.23 10491 47.27 46.22 10405.96 204.47 216.77 297.64 6.76 10555 49.73 41.86 10448.38 238.94 250.05 245.55 6.39 10617 53.33 41.80 10486.94 275.10 282.42 394.05 5.80 10680 56.18 42.93 10523.29 313.11 317.09 445.48 4.75 10754 62.09 41.88 10561.24 360.00 359.89 508.95 8.08 10805 65.27 41.66 10583.85 394.09 390.34 554.62 6.25 10865 68.67 41.91 10607.32 435.26 427.12 609.79 5.67 10930 69.55 41.98 10630.50 480.42 467.71 670.48 1.37 10994 70.26 43.92 10652.49 524.41 508.67 730.58 3.04 11056 71.07 43.82 10673.02 566.59 549.21 789.08 1.31 11117 71.94 44.42 10692.37 608.12 589.48 846.93 1.71 11182 71.96 42.99 10712.51 652.79 632.18 908.72 2.08 11243 71.47 43.76 10731.65 694.89 671.96 966.64 1.44 11304 70.32 42.79 10751.61 736.86 711.47 1024.28 2.41 11366 70.68 42.88 10772.31 779.71 751.21 1082.71 0.60 11427 69.93 43.14 1792.87 821.71 790.38 1140.14 1.30 11491 70.09 43.45 10814.75 865.48 831.63 1200.27 0.51 11555 69.40 43.52 10836.91 909.05 872.94 1260.31 1.07 11619 69.24 42.68 10859.51 952.77 913.85 1320.18 1.26 11677 69.53 43.45 10879.93 992.40 950.95 1374.46 1.48 P 11741 69.53 43.45 10902.32 1035.86 992.25 1434.42 0.00 T tie-in point P projected Sw a n s o n R i v e r U n i t 2 3 B - 2 2 19 5. 2 B i t R e c o r d Bi t S i z e M a k e Ty p e / SN Je t s / TF A De p t h In De p t h Ou t Fo o t a g e Dr i l l e d Bi t Ho u r s Av g . RO P (f t / h r ) Av g . WO B (k l b s ) Av g . RP M Avg. PP (p s i ) Grade 1* 6 ” H C C In s e r t MX - 1 8 H D X / 52 1 0 1 1 3 3x 1 4 / 0. 4 5 1 97 3 6 ’ 9 7 3 6 ’ 0 ’ N / A - - - - - - - - 0 - 0 - N O - A - E - I - N O - B H A (m i l l ) 6 ” H C C Ca s i n g Cu t t e r / 10 1 2 7 2 3 1 4x 1 4 / 0. 6 0 1 97 3 6 ’ 9 7 5 6 ’ 2 0 ’ 1 1 . 9 4 2 4 0 1 5 9 6 N o t G r a d e d RR 1 6 ” H C C In s e r t MX - 1 8 H D X / 52 1 0 1 1 3 3x 1 4 / 0. 4 5 1 97 5 6 ’ 1 0 4 0 7 ’ 6 5 1 ’ 3 9 . 0 2 8 2 6 0 1 9 5 7 3 - 4 - W T - A - E - I - R G -HR 2 6 ” H C C PD C Q5 0 5 F X / 70 2 0 3 3 4 7x 1 7 / 1. 5 5 1 6 10 4 0 7 ’ 1 0 4 5 3 ’ 4 6 ’ 6 . 8 9 3 9 1 3 2 5 4 3 0 - 0 - B U - C - X - I - P N - PR 3 6 ” S E C In s e r t Q2 0 R 11 5 8 2 1 6 0 3x 1 4 / 0. 4 5 1 0 10 4 5 3 ’ 1 0 9 0 0 ’ 5 4 7 ’ 1 6 . 3 3 4 3 7 2 8 2 8 9 2 8 - 8 - L C - A - F - 3 / 16-CR-PR (m i l l ) 6” B a k e r F i s h i n g T o o l N / A 1 0 9 0 0 ’ 1 0 9 1 2 ’ 1 2 ’ 2 . 3 5 . 2 2 2 7 3 1 1 3 8 N o t G r a d e d 4 6 ” H C C Mi l l T o o t h MX - 1 8 H D X 51 9 4 2 6 0 3x 1 4 / 0. 4 5 1 0 10 9 1 2 ’ 1 1 2 5 0 ’ 3 3 8 ’ 1 6 . 9 2 0 1 3 6 0 2 6 4 3 3 - 3 - W T - A - X - I N -LT-HR 5 6 ” H C C In s e r t MX - 1 8 H D X 52 1 0 1 1 4 3x 1 4 / 0. 4 5 1 0 11 2 5 0 ’ 1 1 7 4 1 ’ 4 9 1 ’ 2 8 . 5 3 3 1 4 7 5 2 6 7 9 3 - 4 - W T - A - E - I N -RG-TD *b i t # 1 u s e d f o r c l e a n - o u t r u n Sw a n s o n R i v e r U n i t 2 3 B - 2 2 20 5. 3 M u d R e c o r d Co n t r a c t o r : B a r o i d Mu d T y p e : 6 % K C l P o l y m e r Da t e De p t h (f t ) MW (p p g ) VI S (s / q t ) PV Y P G e l s FL (c c ) FC So l s (% ) O/ W Ra t i o Sd (% ) pH Cl (mg/L) Ca (mg/L) 9/ 0 1 / 1 2 9 9 5 0 9 . 2 5 4 1 0 1 7 7 / 1 2 / 1 4 8 . 6 1 / 0 2 . 4 0 . 5 / 9 4. 5 - 9 . 0 3 1 0 0 0 4 0 9/ 0 2 / 1 2 9 7 3 6 9 . 2 5 5 1 1 1 7 7 / 1 1 / 1 3 8 . 2 1 / 0 2 . 5 0 . 5 / 9 4. 5 - 1 0 . 1 3 0 0 0 0 4 0 0 9/ 0 3 / 1 2 9 7 4 6 9 . 2 4 6 9 2 2 8 / 1 1 / 1 3 8 . 0 1 / 0 2 . 6 0 . 5 / 9 4 .5 - 1 0 . 4 2 9 0 0 0 4 0 0 9/ 0 4 / 1 2 9 7 5 6 9 . 4 5 6 1 2 2 5 1 1 / 1 4 / 1 6 6 . 2 1 / 0 3 . 3 0 . 5 / 93 . 7 - 1 0 . 0 3 0 0 0 0 4 0 0 9/ 0 5 / 1 2 9 7 5 6 1 0 . 4 5 4 8 1 1 2 5 1 1 / 1 4 / 1 7 5 . 0 1 / 0 7 . 2 0 . 5/ 8 9 . 9 - 9 . 0 3 1 0 0 0 3 6 0 9/ 0 6 / 1 2 9 7 5 6 1 0 . 6 5 4 8 1 2 2 7 1 1 / 1 4 / 4 9 5 . 0 1 / 0 8 . 2 0 . 5/ 8 9 . 0 - 9 . 0 2 9 5 0 0 3 6 0 9/ 0 7 / 1 2 9 8 0 2 1 0 . 6 4 7 1 1 2 4 9 / 1 1 / 1 2 4 . 4 1 / 0 7 . 8 0 . 3 / 89 . 6 - 9 . 0 3 0 5 0 0 3 6 0 9/ 0 8 / 1 2 1 0 0 1 9 1 0 . 6 5 2 1 5 2 8 9 / 1 3 / 1 5 3 . 6 1 / 2 7 . 8 0 . 3 /8 9 . 6 - 9 . 2 2 9 5 0 0 3 6 0 9/ 0 9 / 1 2 1 0 3 9 1 1 0 . 6 5 0 1 5 2 6 9 / 1 2 / 1 5 3 . 8 1 / 2 8 . 1 0 . 3 /8 9 . 2 - 9 . 0 3 2 0 0 0 3 6 0 9/ 1 0 / 1 2 1 0 4 0 7 1 0 . 7 4 9 1 4 2 7 9 / 1 2 / 1 4 4 . 0 1 / 2 8 . 4 0 . 3 /8 9 . 0 - 8 . 9 3 0 5 0 0 3 6 0 9/ 1 1 / 1 2 1 0 4 5 0 1 0 . 7 4 6 1 4 2 6 9 / 1 1 / 1 3 4 . 2 1 / 2 8 . 3 0 . 0 /8 8 . 8 0 . 1 5 9 . 2 3 1 0 0 0 3 2 0 9/ 1 2 / 1 2 1 0 4 5 3 1 0 . 7 4 8 1 3 2 7 9 / 1 1 / 1 3 4 . 2 1 / 2 8 . 6 0 . 3 /8 8 . 8 0 . 1 5 9 . 0 3 1 0 0 0 3 2 0 9/ 1 3 / 1 2 1 0 4 5 3 1 0 . 7 5 1 1 3 2 5 7 / 1 0 / 1 1 3 . 8 1 / 2 8 . 4 0 . 3 /8 9 . 0 0 . 1 5 9 . 7 3 0 5 0 0 3 6 0 9/ 1 4 / 1 2 1 0 9 0 0 1 0 . 7 5 0 1 7 2 8 7 / 9 / 1 2 3 . 8 1 / 2 8 . 6 0 . 5 / 88 . 5 0 . 2 5 9 . 6 3 1 0 0 0 3 2 0 9/ 1 5 / 1 2 1 0 9 0 2 1 0 . 7 5 0 1 7 2 8 8 / 1 0 / 1 1 3 . 4 1 / 2 8 . 6 0 . 5 /8 8 . 5 0 . 2 5 9 . 7 3 1 0 0 0 3 2 0 9/ 1 6 / 1 2 1 0 9 1 2 1 0 . 7 5 0 1 3 2 7 8 / 9 / 1 1 3 . 8 1 / 2 9 . 2 0 . 5 / 88 . 5 0 . 2 5 9 . 7 2 9 0 0 0 2 8 0 9/ 1 7 / 1 2 1 0 9 1 2 1 0 . 7 5 0 1 5 2 6 7 / 8 / 1 0 3 . 8 1 / 2 8 . 8 0 . 5 / 88 . 5 0 . 2 5 9 . 1 2 9 0 0 0 2 4 0 9/ 1 8 / 1 2 1 1 2 5 0 1 0 . 7 5 0 1 9 3 1 7 / 8 / 1 0 3 . 8 1 / 2 8 . 5 0 . 5 / 88 . 5 0 . 2 5 9 . 8 3 2 0 0 0 2 8 0 9/ 1 9 / 1 2 1 1 2 5 0 1 0 . 7 5 0 1 8 3 0 8 / 1 0 / 1 2 3 . 6 1 / 2 8 . 8 0 . 5 /8 8 . 5 0 . 2 5 9 . 8 2 9 0 0 0 2 0 0 9/ 2 0 / 1 2 1 1 5 6 1 1 0 . 7 5 3 1 9 2 9 7 / 1 0 / 1 2 3 . 6 1 / 2 8 . 8 0 . 5 /8 8 . 5 0 . 2 5 9 . 7 2 9 0 0 0 8 0 9/ 2 1 / 1 2 1 1 7 4 1 1 0 . 7 5 3 2 0 2 7 7 / 1 0 / 1 2 3 . 4 1 / 2 8 . 8 0 . 5 /8 8 . 5 0 . 2 5 9 . 7 2 8 0 0 0 4 0 9/ 2 2 / 1 2 1 1 7 4 1 1 0 . 9 2 1 1 9 2 6 6 / 8 / 9 3 . 6 1 / 2 9 . 0 0 . 3 / 8 8. 5 0 . 2 5 9 . 5 2 9 0 0 0 8 0 9/ 2 3 / 1 2 1 1 7 4 1 1 0 . 9 5 0 1 8 2 7 6 / 8 / 9 3 . 4 1 / 2 9 . 0 0 . 3 / 8 8. 5 0 . 2 5 9 . 5 2 9 0 0 0 8 0 9/ 2 4 / 1 2 1 1 7 4 1 1 0 . 9 4 7 1 8 2 5 6 / 8 / 9 3 . 4 1 / 2 9 . 0 0 . 3 / 8 8. 5 0 . 2 5 9 . 5 2 9 0 0 0 8 0 Ab b r e v i a t i o n s MW = M u d W e i g h t V I S = F u n n e l V i s c o s i t y P V = P l a s ti c V i s c o s i t y Y P = Y i e l d P o i n t Ge l s = G e l S t r e n g t h F L = F i l t r a t e L o s s F C = F i l t e r C a k e S o l s = S o l i d s O/ W = O i l t o W a t e r r a t i o S d = S a n d c o n t e n t C l = Ch l o r i d e s C a = H a r d n e s s 21 6 DAILY REPORTS 22 7 SHOW REPORTS