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ϵϱϬůďƐ͘ĨƚĞƌƐĞƚǁĞŝŐŚƚĚƌŽƉƉĞĚƚŽϴϴϱůďƐ͘tĂŝƚϱŵŝŶƵƚĞƐƉŝĐŬƵƉĐůĞĂŶ͘ZŝŚĂŶĚƚĂŐƐĞƚƉůƵŐ͘WKK,ƚŽƐƵƌĨĂĐĞ͘DĂŬĞ ƵƉϭϬΖŽĨϭͲϭϭͬϭϲΗĚƵŵƉďĂŝůĞƌ͘>ŽĂĚǁŝƚŚϭ͘ϴϯŐĂůůŽŶƐŽĨďĞĂĚƐ͘Z/,͘>ŽŐƐƚƌŝƉƚŽĐŽƌƌĞůĂƚĞ͘dŽƉŽĨƐƉŝƌĂůƉůƵŐĂƚϳ͕ϴϯϬΖ͘ dĂŐƉůƵŐƉŝĐŬƵƉϭΖĂŶĚĚƵŵƉďĞĂĚƐŽŶƉůƵŐ͘WKK,ƚŽƐƵƌĨĂĐĞ͘DĂŬĞƵƉϮϬΖϭͲϭϭͬϭϲΗĚƵŵƉďĂŝůĞƌďĂƌƌĞůĞǆƚĞŶƐŝŽŶƐ͘ϰϬΖ ƚŽƚĂů͘DŝǆĐĞŵĞŶƚϭϱ͘ϴƉƉŐ͘>ŽĂĚďĂŝůĞƌ͘ĞŵĞŶƚǁĞƚĂƚϭϲϮϬŚƌƐ͘Z/,ϯ͕ϮϬϬΖůŽƐŝŶŐǁĞŝŐŚƚĂŶĚƉŝĐŬŝŶŐƵƉŚĞĂǀǇ͘ EŽƚŝĐĞĚƚŽƉǁŝƌĞůŝŶĞƐŚŝǀĞŚĂĚƐƉƵŶ͘tŝƌĞůŝŶĞŝƐŬŶŽƚƚĞĚƵƉĂƚƐƵƌĨĂĐĞ͘tŽƌŬŬŝŶŬƐŽƵƚŽĨͲůŝŶĞĐĂďůĞ͘ϮŚƌƐŽĨĚŽǁŶ ƚŝŵĞ͘ĂďůĞĨŝǆĞĚ͘Z/,͘>ŽŐĐŽƌƌĞůĂƚŝŽŶƉĂƐƐĂŶĚƚŝĞŝŶ͘dĂŐƚŽ ƉŽĨƉůƵŐĂƚϳ͕ϴϯϬΖ͘WhϱΖĂŶĚĚƵŵƉďĞĂĚƐ͘ϵϮϬůďƐƚŽϵϬϮ ůďƐ͘WKK,ƚŽƐƵƌĨĂĐĞ͘^ƚŽƉĞǀĞƌǇϭ͕ϬϬϬΖĂŶĚůĞƚͲůŝŶĞƚŽƌƋƵĞůŽŽƐĞ͘>ŽĂĚϰϬΖďĂŝůĞƌĨŽƌƌƵŶηϮ͘ĂĐŚϰϬΖďĂŝůĞƌƌƵŶ ƉƌŽǀŝĚĞƐϰ͘ϳΖŽĨĐĞŵĞŶƚŝŶϱΗĐĂƐŝŶŐŽƌϯ͘ϳϯŐĂůůŽŶƐƉĞƌƌƵŶ͘Z/,͘ZƵŶĐŽƌƌĞůĂƚŝŽŶƉĂƐƐĨƌŽŵϳ͕ϳϱϬΖͲϳ͕ϲϮϬΖ͘WĂƌŬĂƚϳ͕ϴϭϰΖ ĂŶĚĚƵŵƉĐĞŵĞŶƚ͘WKK,ƚŽƐƵƌĨĂĐĞ͘dĂŐŐĞĚƵƉ͘>ŽĂĚĐĞŵĞŶƚďĂŝůĞƌǁŝƚŚϯ͘ϳϯŐĂůůŽŶƐ͘Z/,ǁŝƚŚƌƵŶηϯ͘ƵŵƉĐĞŵĞŶƚ ϳ͕ϴϭϯΖ͘WKK,ƚŽƐƵƌĨĂĐĞ͘>ŽĂĚĐĞŵĞŶƚďĂŝůĞƌǁŝƚŚϯ͘ϳϯŐĂůůŽŶƐŽĨϭϱ͘ϴĐůĂƐƐ'ĐĞŵĞŶƚ͘ZƵŶηϰ͘Z/,ĂŶĚĚƵŵƉĐĞŵĞŶƚ ϳ͕ϴϬϵΖ͘WKK,ƚŽƐƵƌĨĂĐĞ͘>ŽĂĚĐĞŵĞŶƚďĂŝůĞƌǁŝƚŚϯ͘ϳϯŐĂůůŽŶƐŽĨϭϱ͘ϴĐůĂƐƐ'ĐĞŵĞŶƚ͘ZƵŶηϱ͘Z/,ĂŶĚĚƵŵƉĐĞŵĞŶƚΛ ϳ͕ϴϬϱΖWKK,ƚŽƐƵƌĨĂĐĞ͘>ŽĂĚĐĞŵĞŶƚďĂŝůĞƌǁŝƚŚϯ͘ϳϯŐĂůůŽŶƐŽĨϭϱ͘ϴĐůĂƐƐ'ĐĞŵĞŶƚ͘ZƵŶηϲ͘ƵŵƉĐĞŵĞŶƚĂƚϳ͕ϴϬϲΖ͘ WKK,ƚŽƐƵƌĨĂĐĞ͘>ŽĂĚĐĞŵĞŶƚďĂŝůĞƌǁŝƚŚϯ͘ϳϯŐĂůůŽŶƐŽĨϭϱ͘ϴĐůĂƐƐ'ĐĞŵĞŶƚ͘ZƵŶηϳ͘ƵŵƉĐĞŵĞŶƚĂƚϳ͕ϳϴϬΖ͘WKK, ƚŽƐƵƌĨĂĐĞ͘>ŽĂĚĐĞŵĞŶƚďĂŝůĞƌǁŝƚŚϯ͘ϳϯŐĂůůŽŶƐŽĨϭϱ͘ϴĐůĂƐƐ'ĐĞŵĞŶƚ͘ZƵŶηϴ͘Z/,ĚƵŵƉĐĞŵĞŶƚϳ͕ϳϴϬΖ͘WKK,ƚŽ ƐƵƌĨĂĐĞ͘ĂůĐƵůĂƚĞĚƚŽƉŽĨĐĞŵĞŶƚƐŚŽƵůĚďĞĂƚϳ͕ϳϵϬ͘ϯϲΖ͘ůůŽǁĐĞŵĞŶƚƚŽƐĞƚƵƉ͘^ĞŶĚƚĞƐƚǁŝƚŶĞƐƐŶŽƚŝĨŝĐĂƚŝŽŶƚŽƐƚĂƚĞ ĨŽƌdĂŐĂŶĚWd͘>DƌĞƉǁŝůůďĞŽŶůŽĐĂƚŝŽŶĨŽƌǁŝƚŶĞƐƐ͘ dĞƐƚϮ͘ϯϳϱΗǆϳΗĐĂƐŝŶŐ;/ͿϮ͕ϬϬϬƉƐŝĨŽƌϯϬŵŝŶƵƚĞƐĂŶĚĐŚĂƌ ĂŶĚĚƵŵƉĐĞŵĞŶƚ͘WKK,ƚŽƐƵƌĨĂĐĞ͘dĂŐŐĞĚƵƉ͘>ŽĂĚĐĞŵĞŶƚďĂŝůĞƌǁŝƚŚϯ͘ϳϯŐĂůůŽŶƐ͘Z/,ǁŝƚŚƌƵŶηϯ͘ƵŵƉĐĞŵĞŶƚ ϳ͕ϴϭϯΖ͘WKK,ƚŽƐƵƌĨĂĐĞ͘>ŽĂĚĐĞŵĞŶƚďĂŝůĞƌǁŝƚŚϯ͘ϳϯŐĂůůŽŶƐŽĨϭϱ͘ϴĐůĂƐƐ'ĐĞŵĞŶƚ͘ZƵŶηϰ͘Z/,ĂŶĚĚƵŵƉĐĞŵĞŶƚ ϳ͕ϴϬϵΖ͘WKK,ƚŽƐƵƌĨĂĐĞ͘>ŽĂĚĐĞŵĞŶƚďĂŝůĞƌǁŝƚŚϯ͘ϳϯŐĂůůŽŶƐŽĨϭϱ͘ϴĐůĂƐƐ'ĐĞŵĞŶƚ͘ZƵŶηϱ͘Z/,ĂŶĚĚƵŵƉĐĞŵĞŶƚΛ ϳ͕ϴϬϱΖWKK,ƚŽƐƵƌĨĂĐĞ͘>ŽĂĚĐĞŵĞŶƚďĂŝůĞƌǁŝƚŚϯ͘ϳϯŐĂůůŽŶƐŽĨϭϱ͘ϴĐůĂƐƐ'ĐĞŵĞŶƚ͘ZƵŶηϲ͘ƵŵƉĐĞŵĞŶƚĂƚϳ͕ϴϬϲΖ͘Ĩ 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tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ ^ZhϰϯͲϭϱ ϱϬͲϭϯϯͲϭϬϭϰϰͲϬϮͲϬϬ ϭϵϵͲϬϰϳ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ϭϬͬϬϳͬϮϬϭϵͲDŽŶĚĂǇ W:^DΘWĞƌŵŝƚƚŽtŽƌŬ͘&ŝƌĞƵƉƌŝŐ͘DhϳͲϭͬϭϲΗ͕ϱDyϳΗKd/^dŚƌĚĐŽŵƉĂŶŝŽŶĨůĂŶŐĞƚŽƚŽƉŽĨKW͘,ĂůůŝďƵƌƚŽŶͲ>ŝŶĞ ŽŶůŽĐĂƚŝŽŶ͘ZhͲ>ŝŶĞƵŶŝƚĂŶĚDh'Zͬ>ůŽŐŐŝŶŐƐƵŝƚĞǁŝƚŚϳΗ ^s^ƋƵĞĞǌĞWĂĐŬĞƌ;/WͿ͘'Zͬ>ͲƚŽͲDŝĚͲůĞŵĞŶƚ сϭϱ͘ϬΖ͘>DZĞƉĂƌƌŝǀĞƐƚŽǁŝƚŶĞƐƐƉůƵŐƐĞƚĂŶĚƚƵďŝŶŐƉƵŶĐŚŽƉĞƌĂƚŝŽŶƐ;ůůŝĞ^ĐŚŽĞƐƐůĞƌͿ͘WƌĞͲ:Žď^ĂĨĞƚǇΘKƉĞƌĂƚŝŽŶƐ ŵĞĞƚŝŶŐ͘ƵŝůĚďůŽǁĚŽǁŶĨŝƚƚŝŶŐĨŽƌŵƵĚůŝŶĞƐΘĐŚĂŶŐĞĚŝĞƐΘĂŝƌƐůŝƉƐ͘ͲůŝŶĞZ/,ǁŝƚŚϳΗ/WƚŽƚĂŐΛƚŽƉŽĨϱΗůŝŶĞƌ сϲϴϮϴΖ͘/Wсϱ͘ϲϬΗK͕ĚĚϲ͘ϬΖĐŽƌƌĞĐƚŝŽŶ͘WƵůůĐŽƌƌĞůĂƚŝŽŶůŽŐƚŽϮϱϬϬΖ͘Z/,ƚŽϯϯϱϳ͘ϵΖ͕Wh,ƚŽƉƵƚ/WŽŶĚĞƉƚŚ ΛϯϭϱϲΖ'Zͬ>ĚĞƉƚŚ;нϭϱ͘ϬΖсϯϭϳϭΖDŝĚͲůĞŵĞŶƚͿ͘dĞŶƐŝŽŶсϱϴϬůďƐ͘&ŝƌĞƚŽƐƚƌŽŬĞƐĞƚƚŝŶŐƚŽŽůΘƐĞƚ/W͘dĞŶƐŝŽŶс ϰϵϬůďƐ͘Wh,ĐůĞĂŶƚŽϯϬϵϱΖ͕W>h'^d͘Z/,ĂŶĚƚĂŐƚŽƉŽĨ/WΛĂƚϯϭϱϲΖ'Zͬ>͘tŝŶƚĞƌŝǌĞĐŚŽŬĞŚŽƵƐĞ͕ůĂǇĚŽǁŶ ĂŶƚŝͲƐŬŝĚǁĂůŬǁĂǇƐ͕>hZ/,ǁŝƚŚWZ&'hEηϭ͕ϰΖƉĞƌĨŐƵŶ;ϰƐƉĨ͕ϬΎW,^͕ϭϰΖ'Zͬ>ƚŽŽƚƚŽŵ^ŚŽƚͿ͕ƚŽƚŽƉŽĨ/W͘ ĞƉƚŚŽƌƌĞĐƚϭϴΖ͘>ŽŐƵƉƚŽĐŽƌƌĞůĂƚĞ͕Z/,ƚŽϯϭϱϳΖ;нϭϰΖ'Zͬ>ͲdŽͲKddKD^,KdсϯϭϳϭΖͿ͘Wh,ƚŽϯϭϱϱΖƉůĂĐŝŶŐ ŐƵŶŽŶĚĞƉƚŚΛϯϭϲϵΖŽƚƚŽŵ^ŚŽƚ͘&ŝƌĞ'ƵŶdƵďŝŶŐWƵŶĐŚŝŶŐϳΗĂƐŝŶŐϯϭϲϵΖͲϯϭϲϱΖ;ϰ^W&Ϳ͘'ŽŽĚ/ŶĚŝĐĂƚŝŽŶΛ ƐƵƌĨĂĐĞŐƵŶĨŝƌĞĚ͘KK,ǁŝƚŚĂůůƐŚŽƚƐĨŝƌĞĚ͘KƌŐĂŶŝǌĞĂŶĚŝŶǀĞŶƚŽƌǆͲŽǀĞƌƐĂŶĚƐƵďƐ͘>hZ/,ǁŝƚŚWZ&'hEηϮ͕ϰΖƉĞƌĨ ŐƵŶ;ϰƐƉĨ͕ϬΎW,^͕ϭϰΖ'Zͬ>ƚŽŽƚƚŽŵ^ŚŽƚͿ͕ƚŽϯϬϲϬΖ͘ĞƉƚŚŽƌƌĞĐƚϭϭΖ͘>ŽŐƵƉƚŽϮϵϱϴΖ͘Z/,ƚŽϯϬϲϬΖΖĂŶĚWh, ƚŽϮϵϬϳΖƉůĂĐŝŶŐŐƵŶŽŶĚĞƉƚŚ;нϭϰΖ'Zͬ>ͲdŽͲKddKD^,KdсϮϵϮϭΖͿ͘&ŝƌĞ'ƵŶdƵďŝŶŐWƵŶĐŚŝŶŐϳΗĂƐŝŶŐϮϵϮϭΖͲ ϮϵϭϳΖ;ϰƐƉĨͿ͘'ŽŽĚ/ŶĚŝĐĂƚŝŽŶΛƐƵƌĨĂĐĞŐƵŶĨŝƌĞĚ͘KK,ǁŝƚŚĂůůƐŚŽƚƐĨŝƌĞĚ͘>ŽĂĚƌĞŵĂŝŶĚĞƌŽĨϯͬϴΗ^^ůŝŶĞŝŶĚƵŵƉƐƚĞƌ͕ ƌĞƉĂŝƌƉƵŵƉŚŽƵƐĞůŝŐŚƚƐ͕͘ZDK>h͘ZƐŚŽŽƚŝŶŐĨůĂŶŐĞ͘ŚĞĐŬƌŽǁŶ^ĂǀĞƌ͘Z/,ǁͬϮͲϯͬϴΗ͕ϰƉƉĨ>ͲϴϬ/dƚƵďŝŶŐ͘dƌŝƉ ŝŶŚŽůĞϭƐŝŶŐůĞũƚ͘ǁͬt>'ĂŶĚϮƐƚĂŶĚƐĨƌŽŵĚĞƌƌŝĐŬ͘^ƚŽƉƚŽ ƌĞƉĂŝƌ&ŽƐƚĞƌdŽŶŐƐ͘ZĞƉĂŝƌĞĚ&ŽƐƚĞƌdŽŶŐƐ͘ZĞƉĂŝƌƵƉƉĞƌ ĚĞƌƌŝĐŬŵĂƐƚůŝŐŚƚƐĂŶĚƌŽǁŶĞĂĐŽŶ͘^ĞĐƵƌĞǁĞůůĂŶĚůŽĐĂƚŝŽŶĨŽƌŶŝŐŚƚ͘/KWŝŶƐƚĂůůĞĚ͕ƚƵďŝŶŐƌĂŵƐĐůŽƐĞĚĂŶĚĚŽƵďůĞ ďůŽĐŬďŽƚŚƐŝĚĞƐŽĨŵƵĚĐƌŽƐƐ͘^&E͘:Žď/ŶWƌŽŐƌĞƐƐ͘ ŶůŽŐƚŽϮϱϬϬΖ͘Z/,ƚŽϯϯϱϳ͘ϵΖ͕Wh,ƚŽƉƵƚ/WŽŶĚĞƉƚŚ ΛϯϭϱϲΖ'Zͬ>ĚĞƉƚŚ;нϭϱ͘ϬΖсϯϭϳϭΖDŝĚͲůĞŵĞŶƚͿ͘dĞŶƐŝŽŶсϱϴϬůďƐ͘&ŝƌĞƚŽƐƚƌŽŬĞƐĞƚƚŝŶŐƚŽŽůΘƐĞƚ/W͘dĞŶƐŝŽŶс ϰϵϬůďƐ͘Wh,ĐůĞĂŶƚŽϯϬϵϱΖ͕W>h'^d͘Z ϵϮϭΖͿ͘&ŝƌĞ'ƵŶdƵďŝŶŐWƵŶĐŚŝŶŐϳΗĂƐŝŶŐϮϵϮϭΖͲ ϮϵϭϳΖ;ϰƐƉĨͿ͘' &ŝƌĞ'ƵŶdƵďŝŶŐWƵŶĐŚŝŶŐϳΗĂƐŝŶŐϯϭϲϵΖͲϯϭϲϱΖ;ϰ^W&Ϳ͘ /,ĂŶĚƚĂŐƚŽƉŽĨ/W ΛĂƚϯϭϱϲΖ'Zͬ> ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ϵͬϮϱͬϭϵ ϭϭͬϮϵͬϮϭ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ ^ZhϰϯͲϭϱ ϱϬͲϭϯϯͲϭϬϭϰϰͲϬϮͲϬϬ ϭϵϵͲϬϰϳ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ϭϬͬϬϴͬϮϬϭϵͲdƵĞƐĚĂǇ W:^DΘWĞƌŵŝƚƚŽtŽƌŬΛϬϱ͗ϯϬ͘dƌŝƉƉŝŶŐŝŶŚŽůĞǁŝƚŚϮͲϯͬϴΗ͕ϰ͘ϲƉƉĨ>ͲϴϬ/ddƵďŝŶŐŽƵƚŽĨĚĞƌƌŝĐŬ͘dƌŝƉŝŶϰϴƐƚĂŶĚƐ;Ϯ ƐƚĂŶĚƐнϭƐŝŶŐůĞƌĂŶƉƌĞǀŝŽƵƐĚĂǇͿ͘WhΘZ/,;ϮͿϭϬΖƉƵƉƐ͘^ŽĨƚƚĂŐ;ϱ<ͿƚŽƉŽĨ/WϮΖŝŶƚŽϮŶĚƉƵƉсϯϭϳϭΖ͘>ϮŶĚϭϬΖ ƉƵƉΘƐĞƚƐƚƌŝŶŐŝŶƐůŝƉƐϳΖĚŽǁŶŽŶϭƐƚϭϬΖƉƵƉсϯϭϲϱΖKd͘,ĂůůŝďƵƌƚŽŶĞŵĞŶƚĂƌƌŝǀĞƐ͘^ƉŽƚΘZhĐĞŵĞŶƚƵŶŝƚƐ͘>D ZĞƉ;ůůŝĞ^ĐŚŽĞƐƐůĞƌͿĂƌƌŝǀĞƐŽŶůŽĐĂƚŝŽŶ͘ZhŵƵĚƉƵŵƉΘƌĞƚƵƌŶůŝŶĞƚŽĐŚŽŬĞƚŽĐŝƌĐƵůĂƚĞϳΗyϭϭͲϯͬϰΗĂŶŶƵůƵƐ͘>ŽĂĚ ŚŽůĞƚŽƐƵƌĨĂĐĞ͘ůŽƐĞƉŝƉĞƌĂŵƐ͘ŝƌĐƵůĂƚĞϳΗǆϭϭͲϯͬϰΗĂŶŶƵůƵƐǁŝƚŚƌĞƚƵƌŶƐƚŽŵƵĚƉŝƚǁͬϮďďůĂǁĂǇ͘͘^/ĐŚŽŬĞ͘WƵŵƉ ϭϬ͘ϱďďůďƌŝŶĞŝŶũĞĐƚŝŶŐƚŽϳΗyϭϭͲϯͬϰΗĂŶŶƵůƵƐ͕^hZ&^'сϰϰ ϬƉƐŝ͘ZĞĐŽƌĚƉƌĞƐƐƵƌĞƐ͘ϱD/EсϰϬϬƉƐŝ͘ϭϬD/Eсϯϱϳ ƉƐŝ͘ϭϱD/EсϯϰϯƉƐŝ͘>DĂƉƉƌŽǀĞƐϭϳďďůĐĞŵĞŶƚƐƋƵĞĞǌĞƉůƵŐ͘ZŵƵĚůŝŶĞĂŶĚϭϭͲϯͬϰΗ^ƵƌĨƐŐ͘ƌĞƚƵƌŶůŝŶĞ͘/ŶƐƚĂůů /KWΘŚĞĂĚƉŝŶ͘ZhĐĞŵĞŶƚŝƌŽŶƚŽŚĞĂĚƉŝŶ͘,ĂůůŝďƵƌƚŽŶƉƌŝŵĞƐĐĞŵĞŶƚƉƵŵƉ͘W:^Dǁͬ,ĂůůŝďƵƌƚŽŶ͕ƌƵǌΘƌŝŐĐƌĞǁ͘ WdсϮϱϬϬƉƐŝ͕WƵŵƉϭϴďďů͕ϭϱ͘ϴƉƉŐďĂůĂŶĐĞĚƉůƵŐWƵŵƉ^ĐŚĞĚƵůĞ͗ϵďďů&t͕ϭϴďďůϭϱ͘ϴƉƉŐ͕ϵ͘ϱďďů&t͘ZDK ,ĂůůŝďƵƌƚŽŶ͘Kͬ>ƉƵŵƉŝƌŽŶĨƌŽŵŚĞĂĚƉŝŶ͘>ŚĞĂĚƉŝŶĂŶĚ/KW͘KƉĞŶƉŝƉĞƌĂŵƐ͘dƌŝƉŽƵƚŽĨŚŽůĞƐƚĂŶĚŝŶŐďĂĐŬϭϯ ƐƚĂŶĚƐŝŶĚĞƌƌŝĐŬ͘KdсϮϯϰϰΖ͕ƐƚŝŵĂƚĞĚdŽƉŽĨĞŵĞŶƚсϮϳϭϰΖ͘ŝƌĐƵůĂƚĞϭϬďďů;ϯϱϬƐƚŬƐͿďƌŝŶĞǁŝƚŚŵƵĚƉƵŵƉƚŽ ĐůĞĂƌƚƵďŝŶŐĂŶĚůŽĂĚŚŽůĞ͕/ŶƐƚĂůů/KW͕ĐůŽƐĞƉŝƉĞƌĂŵƐĂŶĚĐŚŽŬĞ͘WƵŵƉďƌŝŶĞƚŽƐƋƵĞĞǌĞĐĞŵĞŶƚǁͬϯŚĞƐŝƚĂƚŝŽŶƐ ƉƵŵƉŝŶŐϭ͘Ϭ;ϯϲƐƚŬƐͿďďůƚŽƚĂů͘t,WсϱϬϳƉƐŝ͘ϱDŝŶсϰϴϱ͕ϮϬŵŝŶсϰϬϬ͘WƵŵƉϮƐƚŬƐ͕t,WсϱϮϬ͘tĂŝƚϭϱŵŝŶƐ͕t,W сϰϮϮ͘dŽƚĂůsŽůƵŵĞWƵŵƉĞĚсϭ͘Ϭϱďďů͘ƐƚŝŵĂƚĞĚdŽƉŽĨĞŵĞŶƚсϮϳϰϬΖ͘DĞĐŚĂŶŝĐƌĞƉĂŝƌƐƉŝƉĞǁƌĂŶŐůĞƌĞǆŚĂƵƐƚΘ ƌĞƉůĂĐĞƐĐƌŽǁŶďĞĂĐŽŶůŝŐŚƚ͘ůĞĞĚWƌĞƐƐƵƌĞ͕>/KWĂŶĚŽƉĞŶƉŝƉĞƌĂŵƐ͘dƌŝƉƉŝŶŐŽƵƚŽĨŚŽůĞ>ϮͲϯͬϴΗ͕ϰƉƉĨ>ͲϴϬ/d ƚƵďŝŶŐ>ƐŝŶŐůĞũƚƐ͘͘>ϯϭũƚƐ͕ƉŝƉĞǁƌĂŶŐůĞƌŚǇĚƌĂƵůŝĐƐŽǀĞƌŚĞĂƚ͘ZĞƚƵƌŶƚŽƐƚĂŶĚŝŶŐŝŶĚĞƌƌŝĐŬ͘KK,ǁͬϯϲƐƚĂŶĚƐŝŶ ĚĞƌƌŝĐŬ͘dŽƚĂů^ĂĨĞƚǇŵŽǀĞƐϭ,Ϯ^'ĂƐƐĞŶƐŽƌƐŝŶĐĞůůĂƌΘƌĞƉĂŝƌƐϭ,Ϯ^ƐĞŶƐŽƌΛŵƵĚƉŝƚ͘/ŶƐƚĂůů/KW͕ĐůŽƐĞďůŝŶĚƌĂŵ ĂŶĚĚŽƵďůĞďůŽĐŬŵƵĚĐƌŽƐƐůŝŶĞƐ͘ůŽǁĚŽǁŶĂůůƐƵƌĨĂĐĞůŝŶĞƐ͘^&E͘:ŽďŝŶWƌŽŐƌĞƐƐ͘ WƵŵƉϭϴďďů͕ϭϱ͘ϴƉƉŐďĂůĂŶĐĞĚƉůƵŐWƵŵƉ^ĐŚĞĚƵůĞ͗ϵďďů&t͕ϭϴďďůϭϱ͘ϴƉƉŐ͕ϵ͘ϱďďů&t͘ ƐƚŝŵĂƚĞĚdŽƉŽĨĞŵĞŶƚсϮϳϭϰΖ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ϵͬϮϱͬϭϵ ϭϭͬϮϵͬϮϭ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ ^ZhϰϯͲϭϱ ϱϬͲϭϯϯͲϭϬϭϰϰͲϬϮͲϬϬ ϭϵϵͲϬϰϳ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ W:^DΘWĞƌŵŝƚƚŽtŽƌŬΛϬϱ͗ϯϬ͘&ŝƌĞƵƉƌŝŐ͘sĞƌŝĨǇϬƉƐŝ͕ŽƉĞŶůŝŶĚƌĂŵĂŶĚŵƵĚĐƌŽƐƐ͘,ĂůůŝďƵƌƚŽŶĞŵĞŶƚĂƌƌŝǀĞƐŽŶ ƐŝƚĞ͘ZhĐĞŵĞŶƚƉƵŵƉĞƋƵŝƉŵĞŶƚ͘ůĞĂŶsĂĐƚƌƵĐŬůŽĂĚƐϳϬďďůŽĨϳϬΎ&ƌĞƐŚtĂƚĞƌ͘tĞĂǀĞƌƌŽƐ͘ĚĞůŝǀĞƌƐϭ͕ϬϬϬŐĂů͘ ĚŝĞƐĞůĨƵĞů͘>DtŝƚŶĞƐƐZĞƉ;ůůŝĞ^ĐŚŽĞƐƐůĞƌͿŽŶƐŝƚĞ͘W:^D͘WƌŝŵĞƉƵŵƉĂŶĚWdсϭ͕ϬϬϬƉƐŝͲ'KKd^d͘ůĞŶĚ ĞŵĞŶƚ͕ϭϱ͘ϴƉƉŐǀĞƌŝĨŝĞĚďǇŵƵĚƐĐĂůĞ͘ŝƌĐƵůĂƚĞϭϵ͘ϱďďůŽĨϭϱ͘ϴƉƉŐ͕ůĂƐƐ'ĐĞŵĞŶƚƉůƵŐĨƌŽŵϭϱϵΖƚŽƐƵƌĨĂĐĞ͘ ^ƵƌĨĂĐĞƐĂŵƉůĞƚĂŬĞŶĂŶĚƉůĂĐĞĚŝŶŽ͘DĂŶŽĨĨŝĐĞ͘^/WƌŽĚƵĐƚŝŽŶĂƐŝŶŐĂŶĚ^ƵƌĨĂĐĞĂƐŝŶŐǀĂůǀĞƐ͘ZDKĐĞŵĞŶƚĞƌƐ͘ ZĂůůŚĂŶĚůŝŶŐĞƋƵŝƉŵĞŶƚĂŶĚƌĞŵŽǀĞĨƌŽŵƌŝŐĨůŽŽƌ͘ŝƐĐŽŶŶĞĐƚĂůůƐƵƌĨĂĐĞůŝŶĞƐ͘ĞͲĞŶĞƌŐŝǌĞ<ŽŽŵĞǇΘZ<ŽŽŵĞǇ ůŝŶĞƐ͘ZŵƵĚƉƵŵƉ͘ZƌŝŐĨůŽŽƌ͘EKWƐƚĂĐŬ͘hŶƉůƵŐĚĞƌƌŝĐŬůŝŐŚƚƐ͘ZĞŵŽǀĞƐĐŽƉŝŶŐƉŝŶĨƌŽŵƵƉƉĞƌƐĞĐƚŝŽŶŽĨ ĚĞƌƌŝĐŬŵĂƐƚ͘sĂĐdƌƵĐŬƵŶůŽĂĚƐŵƵĚƉŝƚĨůƵŝĚƐ͘ZYƵĂĚĐŽZŝŐ^ĞŶƐĞƐǇƐƚĞŵĂŶĚdŽƚĂů^ĂĨĞƚǇ'ĂƐůĂƌŵƐǇƐƚĞŵ͘^ĐŽƉĞ ĚĞƌƌŝĐŬĂŶĚůĂǇĚŽǁŶƐĂŵĞ͘ŝƐĐŽŶŶĞĐƚĂŶŐŽĂƌĚĂŶĚZĂůůĞůĞĐƚƌŝĐĂůůŝŶĞƐ͘EhdƌĞĞĂŶĚ^/ƐĂŵĞ͘ZŝŐWΘKƉĞƌĂƚŝŽŶƐ ŽŵƉůĞƚĞ͘ZĞĂĚǇĨŽƌWŽƐƚZŝŐďĂŶĚŽŶŵĞŶƚKƉĞƌĂƚŝŽŶ͘^&E͘DŽǀĞƚŽ^hϮϰϯͲϬϰŝŶŵŽƌŶŝŶŐ͘ ϭϬͬϬϵͬϮϬϭϵͲtĞĚŶĞƐĚĂǇ W:^DΘWĞƌŵŝƚƚŽtŽƌŬΛϬϱ͗ϯϬ͘&ŝƌĞƵƉƌŝŐĂŶĚǀĞƌŝĨǇŶŽƉƌĞƐƐƵƌĞƐŽŶǁĞůů͘KΘ>/KW͘KƉĞŶůŝŶĚƌĂŵ͘d/,ϯϲ ƐƚĂŶĚƐŽĨϮͲϯͬϴΗ͕ϰ͘ϲƉƉĨ>ͲϴϬ/dƚƵďŝŶŐŽƵƚŽĨĚĞƌƌŝĐŬ͘dKK,ǁͬϮͲϯͬϴΗƚƵďŝŶŐůĂǇŝŶŐĚŽǁŶϳϮƐŝŶŐůĞũŽŝŶƚƐ͘ZŝŐĚŽǁŶ ĂŝƌƐůŝƉƐĂŶĚƌĞŵŽǀĞĨƌŽŵĨůŽŽƌ͘>ŽĂĚĂůůϮͲϯͬϴΗƚƵďŝŶŐŝŶƉŝƉĞďƵŶŬ͘ZŝŐĚŽǁŶƉŝƉĞŚĂŶĚůĞƌĂŶĚŵŽǀĞƚŽƐŝĚĞŽĨƉĂĚ͘ ůŽƐĞůŝŶĚ͘ZhϳΗKd/^yϳͲϭͬϭϲΗ͕ϱD^ŚŽŽƚŝŶŐ&ůĂŶŐĞ͘,ĂůůŝďƵƌƚŽŶ>hĂƌƌŝǀĞƐŽŶƐŝƚĞ͘Zh>h͘W:^DͲ,ĂůůŝďƵƌƚŽŶΘƌŝŐ ĐƌĞǁ͘DhƚŽŽůƐƵŝƚĞͲƐĂŵƉůĞƚŽŽůĂŶĚ>͘KƉĞŶůŝŶĚƌĂŵĂŶĚEŝƉƉůĞƵƉ>hƚŽ^ŚŽŽƚŝŶŐ&ůĂŶŐĞ͘Z/,ƚŽϮ͕ϲϬϬΖ͘WƵůů ĐŽƌƌĞůĂƚŝŽŶůŽŐ͘tKΘ>D͘>DŽŶůŽĐĂƚŝŽŶ͘dĂŐdKсϮ͕ϳϭϴΖ;ϯϬϯΖKs^hZ&͘^/E'^,KͿ͘KK,ǁͬĐĞŵĞŶƚŝŶ ƐĂŵƉůĞƚŽŽů͘ϭϬDŝŶƵƚĞŚĂƌƚĞĚWƌĞƐƐƵƌĞdĞƐƚсϭϮϬϬƉƐŝͲ'KKd^d͘>hWKK,͘WhϳΗ^s/W͘>ͲDŝĚůĞŵĞŶƚс ϵ͘ϱϬΖ͘Z/,ƚŽϮϮϬΖ͕>ŽŐƵƉƚŽĐŽƌƌĞůĂƚĞ͘Z/,ƚŽϮϯϬΖ͕ůŽŐƵƉƚŽƉůĂĐĞŽŶĚĞƉƚŚΛϭϲϬ͘ϬΖDŝĚͲůĞŵĞŶƚ;ϵ͘ϱϬΖнϭϱϬ͘ϱϬΖ> ĚĞƉƚŚͿ͘dĞŶƐŝŽŶсϮϴϵ͘&ŝƌĞƚŽƐĞƚ/W͘'ŽŽĚΛƐƵĨĂĐĞ͕dĞŶƐŝŽŶсϭϵϬ͘>ŽŐƵƉϭϬϬΖ͕Z/,ΘƚĂŐ/W͘Z/,ǁͬϰΖWĞƌĨ'ƵŶ ;ϰƐƉĨ͕ϬΎWŚĂƐĞͿƚŽϭϱϬ͘ϰΖ>ĚĞƉƚŚĂƚƚŽƉŽĨ/W͘>ͲdŽƉ^ŚŽƚсϱ͘ϱϬΖ>ŽŐƵƉƚŽϭϭϲΖ͕Z/,ƚŽϭϱϬ͘ϰΖ>ĚĞƉƚŚ͘Wh ƚŽϭϰϵ͘ϱΖ>ĚĞƉƚŚ;ϭϰϵ͘ϱΖнϱ͘ϱϬΖсϭϱϱ͘ϬΖdŽƉ^ŚŽƚͿ͘&ŝƌĞŐƵŶ͕'ŽŽĚ/ŶĚŝĐĂƚŝŽŶŐƵŶĨŝƌĞĚΛƐƵƌĨĂĐĞ͘KK,ǁͬĂůůƐŚŽƚƐ ĨŝƌĞĚ͘ZDK>h͘WƵŵƉĨůƵŝĚƚŽϳΗWƌŽĚ͘ĂƐŝŶŐǁͬŵƵĚƉƵŵƉƚĂŬŝŶŐƌĞƚƵƌŶƐĨƌŽŵϭϭͲϯͬϰΗ^ƵƌĨĂƐŝŶŐǀĞƌŝĨǇŝŶŐ ĐŽŵŵƵŶŝĐĂƚŝŽŶƚŽĂŶŶƵůƵƐƚŚƌƵƉƵŶĐŚĞĚŚŽůĞƐ͘&ƌĞĞǌĞƉƌŽƚĞĐƚƚĞƐƚƉƵŵƉ͘ůĞĂŶ<ŽŽŵĞǇzͲƐƚƌĂŝŶĞƌƐ͘ůŽǁĚŽǁŶŵƵĚ ůŝĞƐ͘ůŽƐĞůŝŶĚƌĂŵΘĚŽƵďůĞďůŽĐŬŵƵĚĐƌŽƐƐ͘^&E͘:Žď/ŶWƌŽŐƌĞƐƐ͘ dKd>:K/EdK&ϮͲϯͬϴΗ͕ϰ͘ϲWW&>ͲϴϬ/ddh/E'dKK,сϮϰϳ͘ ϭϬͬϭϬͬϮϬϭϵͲdŚƵƌƐĚĂǇ dĂŐdKсϮ͕ϳϭϴΖ;ϯϬϯΖKs^hZ&͘^/E'^,KͿ сϭϱϱ͘ϬΖdŽƉ^ŚŽƚͿ͘&ŝƌĞŐƵŶ͕' ĚŝĞƐĞůĨƵĞů͘>DtŝƚŶĞƐƐZĞƉ;ůůŝĞ^ĐŚŽĞƐƐůĞƌͿŽŶƐŝƚĞ͘W:^D͘WƌŝŵĞƉƵŵƉĂŶĚWdсϭ͕ϬϬϬƉƐŝͲ'KKd^d͘ ϭϬDŝŶƵƚĞŚĂƌƚĞĚWƌĞƐƐƵƌĞdĞƐƚсϭϮϬϬƉƐŝͲ'KKd^d͘ ŝƌĐƵůĂƚĞϭϵ͘ϱďďůŽĨϭϱ͘ϴƉƉŐ͕ůĂƐƐ'ĐĞŵĞŶƚƉůƵŐĨƌŽŵϭϱϵΖƚŽƐƵƌĨĂĐĞ͘ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ϵͬϮϱͬϭϵ ϭϭͬϮϵͬϮϭ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ ^ZhϰϯͲϭϱ ϱϬͲϭϯϯͲϭϬϭϰϰͲϬϮͲϬϬ ϭϵϵͲϬϰϳ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ĞůĚĂƐĂĨĞƚǇŵĞĞƚŝŶŐĂďŽƵƚĞǆĐĂǀĂƚŝŶŐĂŶĚǁĞůůŚĞĂĚƌĞŵŽǀĂů͘tŽƌŬĞƌƐŵŽďŝůŝǌĞĚƚŽǁĞůů^ZhϰϯͲϭϱĂŶĚĐŽŵŵĞŶĐĞĚ ĞǆĐĂǀĂƚŝŶŐĂƌŽƵŶĚƚŚĞǁĞůůĐĞůůĂƌ͘ŽŶƚĂŵŝŶĂƚŝŽŶǁĂƐĨŽƵŶĚĂĚũĂĐĞŶƚƚŚĞĐĞůůĂƌĨůŽŽƌ͘tĞůůŚĞĂĚǁĂƐĂďůĞƚŽďĞ ƌĞŵŽǀĞĚĂŶĚĐĂƉƉĞĚƉĞƌK'ĂŶĚ>DƌĞƋƵŝƌĞŵĞŶƚƐ͘>DǁĂƐƉƌĞƐĞŶƚƚŽǁŝƚŶĞƐƐǁĞůĚŝŶŐŽĨĐŽǀĞƌƉůĂƚĞ͘WŚŽƚŽƐ ǁĞƌĞƐĞŶƚƚŽK'͘ǆĐĂǀĂƚŝŽŶůĞĨƚŽƉĞŶƵŶƚŝůŶŽƚŝĨŝĐĂƚŝŽ ŶŵĂĚĞĂŶĚƉůĂŶĂƌĞĂƉƉƌŽǀĞĚ͘ ϭϭͬϮϯͬϮϬϮϭͲdƵĞƐĚĂǇ ,ĞůĚĂƐĂĨĞƚǇŵĞĞƚŝŶŐĂďŽƵƚĞǆĐĂǀĂƚŝŶŐĂŶĚǁĞůůŚĞĂĚƌĞŵŽǀĂů͘tŽƌŬĞƌƐŵŽďŝůŝǌĞĚƚŽǁĞůů^ZhϰϯͲϭϱĂŶĚďĞŐĂŶ ĞǆĐĂǀĂƚŝŶŐĂƌŽƵŶĚƚŚĞǁĞůůĐĞůůĂƌ͘^ƚĞĂŵŝŶũĞĐƚŝŽŶǁĂƐƵƐĞĚƐƚĂƌƚŝŶŐƚŚĞƉƌĞǀŝŽƵƐĚĂǇ;ϭϭͬϮϯͬϮϬϮϭͿƚŽƚŚĂǁƚŚĞŐƌŽƵŶĚ ĂƌŽƵŶĚǁĞůůϰϯͲϭϱĐĞůůĂƌ͘>ŝŶĞůŽĐĂƚĞƐǁĞƌĞĂůƐŽƉƌĞǀŝŽƵƐůǇĚŽŶĞĨŽƌĨůŽǁůŝŶĞƐĂŶĚƵƚŝůŝƚǇůŝŶĞƐƐƵƌƌŽƵŶĚŝŶŐƚŚĞ ǁĞůůŚĞĂĚ͘&ůŽǁůŝŶĞƐƚŚĂƚǁĞƌĞƵŶĐŽǀĞƌĞĚǁĞƌĞĐƵƚĂƚƚŚĞĞĚŐĞŽĨƚŚĞĞǆĐĂǀĂƚŝŽŶĂŶĚ͕ƉůĂƚĞƐǁĞƌĞǁĞůĚĞĚŽǀĞƌƚŚĞ ŽƉĞŶŝŶŐŽŶĐĞĞĂĐŚǁĂƐĚĞĞŵĞĚƐĂĨĞ͘>DƌĞƉƌĞƐĞŶƚĂƚŝǀĞĂƌƌŝǀĞĚĂƚĂƉƉƌŽǆŝŵĂƚĞůǇϭϭĂŵƚŽǁŝƚŶĞƐƐĞǆĐĂǀĂƚŝŽŶ ĂĐƚŝǀŝƚǇ͘KŶĐĞĞǆĐĂǀĂƚŝŽŶŽĨƚŚĞĂƌĞĂĂƌŽƵŶĚƚŚĞĐĞůůĂƌǁĂƐĐŽŵƉůĞƚĞƚŽĂĚĞƉƚŚŽĨĂďŽƵƚϲĨĞĞƚĂŶĚĂůůĐĂƉƐǁĞƌĞ ǁĞůĚĞĚŽŶƚŚĞĨůŽǁůŝŶĞƐĂŶĚƵƚŝůŝƚǇůŝŶĞƐ͕ĚŝƐŵĂŶƚůŝŶŐŽĨƚŚĞĐ ĞůůĂƌǁĂůůĐŽŵŵĞŶĐĞĚ͘ŽŶĐƌĞƚĞĨƌŽŵĂƌŽƵŶĚƚŚĞĐĞůůĂƌĂƚ 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ŵĞĂƐƵƌĞƐŚŽǁĞĚĂƉƉƌŽǆŝŵĂƚĞůǇϭϰĨĞĞƚŽĨǀŽŝĚƐƉĂĐĞŝŶƚŚĞĂŶŶƵůƵƐĂŶĚĂƉƉƌŽǆŝŵĂƚĞůǇϲĨĞĞƚŽĨǀŽŝĚƐƉĂĐĞŝŶƚŚĞ ƐƵƌĨĂĐĞĐĂƐŝŶŐ͘ǀĂĐƵƵŵƚƌƵĐŬǁĂƐƵƐĞĚƚŽƌĞŵŽǀĞƚŚĞƌĞƐŝĚƵĂů ĨůƵŝĚŝŶƚŚĞĂŶŶƵůĂƌĂŶĚƐƵƌĨĂĐĞĐĂƐŝŶŐǀŽŝĚƐĂŶĚƚĂŬĞŶ ƚŽƚŚĞƐŬŝŵƉŝƚĨŽƌĚŝƐƉŽƐĂů͘ϴďĂŐƐŽĨĐŽŶĐƌĞƚĞǁĞƌĞŵŝǆĞĚǁŝƚŚǁĂƚĞƌĂŶĚƵƐĞĚƚŽĞůŝŵŝŶĂƚĞƚŚĞ͕ǀŽŝĚƐƉĂĐĞ͘>D ǁŝƚŶĞƐƐĞĚƚŚĞǁĞůĚŝŶŐŽŶŽĨƚŚĞĐŽǀĞƌƉůĂƚĞ͘t ŽƉĞŶŝŶŐŽŶĐĞĞĂĐŚǁĂƐĚĞĞŵĞĚƐĂĨĞ͘>DƌĞƉƌĞƐĞŶƚĂƚŝǀĞĂƌƌŝǀĞĚĂƚĂƉƉƌŽǆŝŵĂƚĞůǇϭϭĂŵƚŽǁŝƚŶĞƐƐĞǆĐĂǀĂƚŝŽŶ tŽƌŬǁĂƐƐƚŽƉƉĞĚǁŚĞŶƚŚĞYWŽŶƐŝƚĞĚĞƚĞƌŵŝŶĞĚƚŚĂƚƚŚĞƌĞǁĂƐ ƉƌĞƐĞŶĐĞŽĨĂŚǇĚƌŽĐĂƌďŽŶͲůŝŬĞƐƵďƐƚĂŶĐĞ͘^ ^ZhϰϯͲϭϱDĞĂƐƵƌŝŶŐƚŽƵƚKĨĨtĞůůŚĞĂĚ ^ZhϰϯͲϭϱĞŵĞŶƚƚŽ^ƵƌĨĂĐĞ &ŝŐƵƌĞϭĞƉƚŚŽĨŐƌŽƵƚĂĚĚĞĚƚŽƐƵƌĨĂĐĞĐĂƐŝŶŐŵĂŬĞĨůƵƐŚǁŝƚŚĐƵƚΕϭϰĨĞĞƚ ^ZhϰϯͲϭϱDĂƌŬĞƌWůĂƚĞtĞůĚĞĚKŶ 2021-1123_Surface_Abandon_SRU_43B-15 Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg DATE:11/29/2021 P. I. Supervisor FROM:Matt Herrera SUBJECT: Surface Abandon Petroleum Inspector SRU 43B-15 Swanson River Field Hilcorp Alaska LLC PTD 1990470; Sundry 319-141 11/23/2021:I traveled to SRU 43B-15 and met with Hilcorp Operator Kraig McGhieto check the SRU 43B-15 to check progress of their prep work surface abandonment. I observed they were still in the process of steam thawing area around wellhead. They anticipated being ready to begin excavation tomorrow. Elevations on the surrounding grade for this well had been shot and excavation depth had been determined. Attachments: Photos (2) 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.02.14 16:33:07 -09'00' 2021-1123_Surface_Abandon_SRU_43B-15 Page 2 of 2 Surface Abandonment – SRU 43B-15 (PTD 1990470) Photos by AOGCC Inspector M. Herrera 11/23/2021 Schwartz, Guy L (CED) From: Schwartz, Guy L (CED) Sent: Wednesday, July 31, 2019 8:59 AM To: Ted Kramer; Rixse, Melvin G (CED) Cc: Donna Ambruz Subject: RE: SRU 43B-15 Sundry Amendment for a Coil Cleanout. Sundry # 319-141 ( PTD 199-047) Ted, You have verbal approval to modify the sundry as proposed below. You will also need to tag the CTU cement plug during the witnessed pressure test to verify its placement. I will file this email in our records ... update your MOC as required. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guv.schwartzQalaska.aov). From: Ted Kramer <tkramer@hilcorp.com> Sent: Monday, July 29, 2019 2:20 PM To: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: SRU 4313-15 Sundry Amendment for a Coil Cleanout. Sundry # 319-141 ( PTD 199-047) Mel and Guy, Hilcorp tagged fill in the above well at 6,842'. Therefore as pursuant to your e-mail of July 18, 2019, Hilcorp would like to amend the procedure of Sundry # 319-141( PTD 199-047) to include the following Coil Tubing Work before moving in Rig 401: 1. MIRU Coiled Tubing, PT BOPE to 3,500 psi Hi 250 Low. 2. SI well. 3. Route well production to open top diffuser 400 bbl tank. 4. RIH w/ 1.5" coil w/ jet nozzle BHA. a. Top of fill estimate in tbg to be @ ±6,842'. Engage fill and clean out to PBTD ( 8,161') using nitrogen if necessary help lift fill. 5. RU Cementers and place a 15.8 ppg cement plug from 8,161' up to 7,750' (104' above the top perf as per 20 AAC 25.112. (c) (1) (c) and for BLM 43 CFR 3160 (111)(G)(2)) . PU and clean up coil and POOH. WOC. Note: This work also takes the place of Plug #1 ( Steps 16 and 17 of Sundry If 319-141). 6. RDMO CTU. a. Re-enter Sundry # 319-141 at step # 5 of Rig 401. Note: Since Steps 16 and 17 are replaced with step #5 above, the 7" casing will still need to be pressure tested to 2,500 psi on a chart for 30 min. after the tubing is removed from the well. Ted Kramer Sr. Operations Engineer Hilcorp-Alaska LLC Office — 907-777-8420 Cell — 985-867-0665 The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Tyonek Gas Pool, SRU 4313-15 Permit to Drill Number: 199-047 Sundry Number: 319-141 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a ogc c. a I aska.g ov Enclosed is the approved application for the 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, Jessie L. Chmielowski Commissioner DATED this I day of April, 2019. RBDMSLA/Ap# I A g#q STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED MAR Z 2019 r, T�> 'f-11 0 /( % AOGCC 1. Type of Request: Abandon [Z Plug Pedorations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑� Stratigraphic ❑ Service ❑ 199-047 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-10144-02-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 716.001 Will planned perforations require a spacing exception? Yes ❑ No � ❑ Swanson River Unit (SRU) 43B-15 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028384 Swanson River / Tyonek Gas Pool it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): Pert 8,250' 8,250' 8,161' 8,161' 3,028 6,770' debris/fiill@ 7,785' Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,021' 11-3/4" 3,021' 3,021' 3,070 psi 1,510 psi Intermediate Production 8,468' 7" 8,468' 8,468' 6,340 psi 3,830 psi Liner 1,413' 5" 8,241' 8,241' 8,290 psi 7,250 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-3/8" 4.6# / L-80 7,772' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker FH Retrievable Packer 7,698' (MD/TVD) 12. Attachments: Proposal Summary ❑/ Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 10 Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 1, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned Q 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: So York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerCrDhilcoro.com �// Contac[ Phone: 777-8420 �— �t 1�1 Authorized Signature: G _ Date: �"'t f.. 1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3i�-iy f d Plug Integrity BOP Test Mechanical Integrity Test ❑ Location Clearance El 2 3100 Other: ylt PSL T 5 f" RBDMS�Ew APR 10 20 7So6 ps " w Post Initial Injection MIT Req'd? Yes ❑ No ❑ u –�]� Spacing Exception Required? Yes ❑ No Subsequent Form Required: ©– 1 0 i APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: L` �o GI V 1 `' i RIG] IG � A � A �( Submit Form and Form 10-403 Revised 4/2017 Approved applic I o 1 rr�t the data of approval. [ach " T tments in Duplicate n Hilt ro Alaska, LLQ Well Prognosis Well: SRU 436-15 Date: 03/21/2019 Well Name: SRU 43B-15 API Number: 50-133-10144-02 Current Status: Shut -In Gas Well Leg: N/A Estimated Start Date: May 1, 2019 Rig: Rig 401 Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 199-047 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: Current Bottom Hole Pressure: — 3,840 psi @ 8,118' TVD (0.473 psi/ft pressure gradient) Maximum Expected BHP: — 3,840 psi @ 8,118' TVD (Based on normal gradient) Max. Potential Surface Pressure: — 3,028 psi (Based on 0.1 psi/ft Gas grad. to Surf.) Brief Well Summary /yo 9 ' 1 ,1 2� Swanson River Unit 43B-15 was sidetracked out of SRU 43A-15 in 1999, targeting the Tyonek gas sands. The well was perforated in the Tyonek 77-3 and 73-9 gas sands. The well never produced and was shut-in. r The purpose of this Sundry is to permanently P&A the SRU 43B-15 wellbore. Pre - Rig Work: 1. Provide 24 hour notice to AOGCC that Plug and Abandonment of well will commence per AOGCC regulations 20 AAC 112(h). Notify BLM of P&A as per 43 CFR 3160 G. 2. RU Pump Truck. RU on IA and perform a pressure test to 2,000 psi on chart for 30 min. Bleed down pressure. 3. RU Slickline. RIH and pull Packoff Plug @ 6,770'. RD Slickline. 4. RU Pump Truck and bullhead 9.8 ppg kill weight brine down tubing, into Tyonek perforations. RD Pump Truck Rig #401: 5. MIRU Rig401. 3iov 6. Set Back Pressure valve. ND wellhead, NU BOP and test 250 low & 2�si high, annular to 250 psi low & 2,500 psi high. Record accumulator pre -charge pressures and chart tests. Notify AOGCC and BLM 24 hours in advance of test to extend the opportunity to witness. a. Perform Test. b. Test VBR rams on 2-3/8" test joint. c. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Copy to BLM. 7. PU tension on the 2-3/8" tubing string, to release the Baker FH packer (set @ 7,698'). a. If the packer releases, go to Step 8. b. If the packer does Not release, go to Step 10. 8. RU pump truck and circulate hole with 9.8 ppg kill weight fluid. 9. POOH with 2-3/8" tubing, laying down GLM & bottom -hole assembly and racking back pipe. Go to Step 16. H Iiil.0 p Alaska, LU Well Prognosis Well: SRU 43B-15 Date: 03/21/2019 10. RU E -line. PU and RIH with tubing cutter to 6,800'. Cut tubing and POOH. RD E -line. 11. PU tension on the 2-3/8" tubing string. a. If tubing is free, circulate hole with 9.8 ppg kill weight fluid. b. If tubing is not free, repeat Steps 10 & 11. 12. POOH with 2-3/8" tubing, laying down GLM and racking back pipe. 13. PU and RIH w/ a set of Jars on 2-3/8" tubing and engage tubing stub @ 6,800'. 14. PU w/ Jars to release FH packer. 15. POOH with 2-3/8" tubing and packer assembly, laying down assembly and racking back pipe. 16. RU E -line. PU & RIH w/ 5" CIBP to 7,780' (+/-) and set same. POOH. ' 1 T(S ! o Ar 17. PU Dump Bailer and dump bail cement from 7,780' up to 7745'. W Note: From this point forward, all perforations are isolated from the wellbore. 18. PU & RIH w/ 7" CIBP to 3,171' (+/-) and set same. POOH 19. PU V set of casing punches and RIH to 3,169'. Punch casing from 3,169 to 3165'. POOH. 20. PU 2nd set of casing punches and RIH to 2,921'. Punch casing from 2,921' to 2,917'. POOH. RD E - line. 1/ 21. RIH w/ 2-3/8" tubing to 3,165'. 22. RU Cementers. Spot a balanced 15.8 ppg cement plug from 3,165' up to 2,800'. 23. PU above cement plug and clean out tubing. 24. Pressure up to 500 psi and hold for 30 minutes, to force cement in behind 7" casing to isolate the surface casing shoe. WOC. 25. RU Slickline. RIH with GR and tag top of cement (TOC). Ensure TOC is at or above 2,921' (to ensure at least 100' of cement above surface casing shoe). POOH & RD Slickline. 26. POOH w/ tubing, laving down. INDC- iN- P"'� T.y t [aaz! Ps.� Aiv . 27. RU E -line. PU & RIH w/ 7" CIBP to 160'. Set same. POOH. 28. PU Casing Punches and RIH to 159'. Punch 7" casing from 159' to 155'. POOH and RD E -line. 29. Rig up cementers to back side. Establish circulation down the IA through the casing punches and Sr` up the 7" casing. Circulate a 15.8 ppg cement plug from 159' to surface. RD Cementers, WOC. 30. Place dry hole tree on well. 31. RDMO Workover Rig. Post Rig Abandonment Procedures: 32. Excavate cellar, cut off casing 3' below natural GL. 33, NoUty AOGCC and BLM 48hrs in advance. 34. Create well abandonment marker per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10. The Ld.API: e bead -w ed directly to the marker plate: p Alas a, LLC 199-047 Name: SRU 436-15 0-133-1014 -02 35. Set marker plate per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10, collect GPS coordinates. 36. Photo document casing cut-off and Welded Plate install. 37. Backfill excavation, close out location. U I[ik.n, Afwku, LU Attachments: Actual Schematic Proposed Schematic BOPE Schematic RWO Sundry Revision Change Form Well Prognosis Well: SRU 4313-15 Date: 03/21/2019 T( 6,! Swanson River Field SCHEMATIC Well SRU #4311-15 Hi].p Alaska, LLC Actual Completion 7/7/1999 RKB to TBG Head = 15.25' TD = 8,250' MD / 8,249' TVD PBTD = 8,161' MD / 8,160' TVD Max Hole Angle = 4.11 deg, KOP= 7,140' SIZE WT CASING AND TUBING DETAIL GRADE CONN ID MD TOP MD BTM. 11-3/4" 47 J-55 11.0" Surf 3,021' 7" 29 N-80 6.184" Surf 306' 7" 26 N-80 6.276" 306 1,115' 7" 23 N-80 6.366" 115' 4,819' 7" 26 N-80 6.276" 4,819' 6,643' 7" 29 N-80 6.184" 6,643' 8,468' DV Collar 7,372' Window 7,143' 7,165' 5 15 L-80 TKC Butt 4.408" 6,828' 8,241' Tubing: 2-3/8" 4.6 L-80 Buttress 1.995" Surf 7,772' NO Depth ID 1 15.25' 1.995" 2 2,497' 1.901" 2A 6,770' 3 6,797' 1.901" 3A 6,828' 4 7,656' 1.870" 5 7,698' 2.00" 6 7,739' 1.875" 7 7,772' 2.196" JEWELRY Item 2-3/8" Shaffer Tbg Hanger w/ Type H profile 2-3/8" McMurry Macco SMO -1 Chem Injection Mandrel with 500 psi Chemical Injection Valve and 3/8" SS methanol injection line 2-3/8" Packoff Plug 2-3/8" McMurry Macco SMO -1 Gas Lift Mandrel with Dummy Valve Liner Top Packer 08/23/99 Baker CMU Sliding Sleeve W/ F profile (Open up) Baker EH Retrievable Packer (30 Kip shear) Baker X Nipple Baker Wireline Entry Guide/Shear Out Sub Perforations Date Zone Top BTM Comments 9-1-99 73-9 7,854' 7,870' 1-11/16 EJ 6spf 0 deg phase 7-22-99 77-3 8,095' 8,119' 1-11/16 EJ 4 spf0 deg phase Fill/Fish Information 1. 55 perforating disks lost in hole after both perforating runs 2. 9/4/99 --Tag fill with 1.75" bailer @ 7,785'. SRU 43B-15 Schematic 03-20-19 UPDATED BY PMW 03-20-19 PSwanson River Field PROPOSED S E D SCHEMATIC Well SRU #43B-15 Hilc"ra Alaska, LLC Actual Completion 7/7/1999 RKB to TBG Head =15.25' TOC @ 2,800'- 2,921 TOC @ Surface Casing Punches @ 1155'3159' Casing Punches @ ±2,917'- ±2,921' 3 ±3,165'- ±3,169' 4 TOL @ 5 , t) 6,828' TOC @- 17,745' 6 F2 73-9 77-3 SIZE WT CASING AND TUBING DETAIL GRADE CONN ID MD TOP MD BTM. 11-3/4" 47 J-55 11.0" Surf 3,021' 7" 29 N-80 6.184" Surf 306' 7" 26 N-80 6.276" 306 1,115' 7" 23 N-80 6.366" 115' 4,819' 7" 26 N-80 6.276" 4,819' 6,643' 7" 29 N-80 6.184" 6,643' 8,468' DV Collar 7,372' Window 7,143' 7,165' 5 15 L-80 TKC Butt 4.408" 6,828' 8,241' Tubing: 2-3/8" 4.6 L-80 Buttress 1.995" 6,800' 7,772' JEWELRY 1 ±160' CIBP w/ 160' cement to surface 2 12,800' Top of cement (TOC 2,800' to 2,921') 3 3,021' 11-3/4" Surface casing shoe 4 ±3,171' CIBP w/--371' cement on top (TOC ±2,800') 5 6,828' Liner Top Packer 08/23/99 6 ±7,780' CIBP w/ -35' cement on top (TOC ±7,745') r/ Perforations 9-1-99 73-9 7,854' 7,870' 1-11/16 EJ 6spf0 deg phase 7-22-99 77-3 8,095' 8,119' 1-11/16 EJ 4 spf 0 deg phase Fill/Fish Information 55 perforating disks lost in hole after both perforating runs 9/4/99 --Tag fill with 1.75" bailer @ 7,785'. TD = 8,250' MD / 8,249' TVD PBTD = 0' MD/TVD Max Hole Angle = 4.11 deg, KOP = 7,140' MD SRU 43B-15 Proposed Schematic 03-20-19-21-19 UPDATED BY PMW 03-21-19 HILCORP ALASKA 7-1/16" SM BOPE /16" 5M HYDRIL GK ANNULAR 32" TALL, FLANGE TO FLANGE 7-1/16" 5M LWS DBL GATE BOP DRESSED W/VARIABLE RAMS IN TOP DRESSED W/BLIND RAMS IN BOTTOM FLANGE TO FLANGE 7-1/16" SM DRILLING SPOOL W/2-1/16" 5M OUTLETS 18" TALL, FLANGE TO FLANGE —77" TOTAL STACK HEIGHT ANNULAR STYLE BOP SPECS: - 3.30 gallon open chamber volume - 3.86 gallon close chamber volume GATE STYLE BOP SPECS: -1.45 gallons to close per gate - 1.18 gallons to open per gate - 5.45:1 closing ratio -1.93:1 opening ratio Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well SCU 43B-15 (PTD 199-047) Sundry M XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By Initials HAK Approved By Initials AOGCC Written Approval Received (Person and Date) Approval: Prepared: msset i earn operations manager Date rirst cau operations engineer Date 199-047-0 SWANSON RIV UNIT 43B-15 50- 133-10144-0:2 UNION OIL CO OF CALIFORNIA Roll #1: Start: Stop Roll #2:t .~.~Start- Stop MD 08250 '~TvD 08249 ~C~ompletion ~ °7722/99 Completed Status: 1-GAS Current: T Name L AIT COMP RCD L COMP RCD MUD L PEX-AIT R SRVY LSTNG Interval t~PIN~AL 4~E(-C)-7150-8240 ff-C4~-7300_8127 ~1~' ' 7730-8000 9/1/99 /~L BL(C). 7150-8240 0~t~;-8250 OH 10/12/99 10/14/99 OH 2 8/18/99 8/19/99 CH 5 12/29/99 1/3/00 OH 2 8/18/99 8/19/99 OH 10/12/99 10/14/99 OH 8/23/99 8/23/99 Sent Received T/C/D · Wednesday, June 20, 2001 Page I of I Unocal Alaska Resources Unocal Corporation 909 West 9th Ave. Anchorage, AK 99,519-6247 Tele: (907) 263-7889 Fax: (907) 263-7828 E-maih childersd@.unocal, com UNOCAL ) Debra Childers Geotech Assistant DATA TRANSMITTAL December 29, 1999 To: Lori Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items: I~ ~' ' '' ~' We~ - I .:.: r ~m '. : ~' ~r~ ~ L~ TYPEi'~ ~.'~:~ I.SCALE t LOG DATE~. INTERVAL LOGGED t COPIES~:-~ium ]'ti~ - 0~'~ SCU 243B-4 ~ CORRELATION LOG i5 INCH 8/3/99 5000-5980 1 Film J. ~ SCU 243B-4 :. CORRELATION LOG i 5 INCH 8/3/9915000-5980 ;Scu 243B14 ~r cOUPLETio~ REC(~R-D- '~-i'~--i~R~ 8/10/99 i 5500-5910 1 Film ! scu 243BL4 ;COMiS[.E'~ION ~I~C~o~{D-i~5 INCH 8/10/9915500-5910 1 B-Line j~_>i , ~ '~sCLJ31;°8'- ' c°MPLETIO~'RECOR~ .... ~51NCH 11/5/99 10000-10560 1 Film ~S® 3i'-o8' :~0Mp~E~I0~-REC:0~b .... ~INCH 11/5/99 10000-10560 1 ': ~~,~AMM~ RAY MD-'~-:2~O ......... ?~'i'~'-- .....~'~-~-4~:~6~ ......................... / :~SCU-321-9 , CEMENT BOND-E~G .... ~'-5--J'N*~ ~)~9 950~7j~f¥~ ; , 1 B-Line r sC~ 32i-9 ,~ -CEMEN~B~'ND~oG~ff~'.5 INC~ .......... 8~'2~/~9~~7'~6-- ......... '~SCU 32i-9 INCH 8/15/99 9420-9867 ~SCU. 321-9. J ~.GAMMA_RA~ ~):24~_~..~_~J~H_ ........... ~8[]5(99.~.~2_~:9~6~ ...................... [sc.u 321;9 / . ~GAMM~RAY_~D_~!~.~__~_2_~.~.C~.~_~ ........ ~()~9~_~_42_0:~ ................. ~SCU32!-9 ./~GAMMA RA~M_D~_!_:240_ ..... ~.5 INCH 8/15/999420-9867 1 B-Line [SCU 321-9~; GAMMA RAY MD 1:1600 ~2 INCH 8/15/99 ~ 9420-9867 1 B-Line /~[- ~)~ ~SC~32i-9~ ' ~ ~.P~G'SE'~ING~EC~o~'~_~.~ ......... 7~3~97~_]~;~. ~- - ~ scu 321-9 ; PLUG SE~ING RECORD (5 INCH 7/31/99~ 9150-9450 1 Film . _ ~SCU3219 ~ GAMMA RAY ~D1:1600 f21NCH ~ 8/15/99 9420-9867 1 Sepia ~ ~ scu ~ CUST ~NST SURVEY ~ ~NCH ~ ~ ~Z~-~a~ :SCU~A-a COMPLET~ONRECORD ~S~NCH ~m99 9800-~059~ ~ Fi~m t ~/~' O'~ ~- ; SCU 4iA-8 ~ COMPLETioN R~b~ .... ~ 5 INCH 11~/99 9800-10598 'Scu ~A~.~OMp~ETION ~EC-'~D ...... ~-~ i~C~ 1~)~9~ ~0~7~-0~9~ ....... ~ ...... 'Fii-~- ........ / ff~', OU~ [SCU.43B-!5RD CQMRLE~.!ON_.BECO~_~ jSINCH 9/1/99,7730~000 1 Film · ~ ;SCU43B-15RD COMPLETION RECORD ~51NCH 9/1/99~7730~000 1 B-Line j ~-') ,' 1~ Z ' SCU 43'B~ '~ C0~EET~N-~E~D'---'[5-i~ .......... -¥~3/9~';~'2-~u-i~0~ .................. ,ease rec s, n,n e,urn, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION L,- -, MMISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: X SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number UNOCAL 99-47 3. Address 8. APl Number PO Box 196247, Anchorage, AK 99519-6247 50- 133-10144-02 4. Location of well at surface ::':,o~,,.,'~?¢.',~;¢ 9. Unit or Lease Name 1980 FSL and 620' FEL Sec. 15, T8N, R9W, SM ~ .X~;4'.': ;:','¢~,,,~ : ~' ..... ~ ~ ~ ~~~~~ ~~ Swanson River Unit At Top Producing I nte~al ~~~:'~'?~ . ~.. : 10. Well Number Straight hole . - ~~. ~ ' ~ 43B-15 At Total Depth ' ~.' ~';~ ' ' ~ ~ ~~~ 11. Field and Pool Straight hole _ fv~ Swanson River Field 5. Elevation in feet (indicate KB, DF, etc.) ~ 6. Lease Design'ati0h~nd Serial No. Tyonek 77-3 Pool 15.25' RKB~ A-028384 12. Date Spudded 13. Date T.D. Reached ~ 14. Date Comp., Susp. or Aband. ~ 15. Water Depth, if offshore 16. No. of Completions 6/28/19'99 6~30~99I ~1' NA feet MSL 1 17. Total Depth (MD+~D) 18. Plug Back Depth (MD+~D) ~ 19. DirectionalSu~ey ~20. DepthwhereSSSVset8,250,/8,8,249, 8,161'/8,160' Yes: X No: NA feetMD 21. Thickness of Pe~afrostNA 22. Type Electric or Other Logs Run GR,DNL, DIL, Density, SP 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE ~. PER FT. G~DE TOP BOSOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 5" 15 L-80 6,828' 8,241' 6 32 BBLS of G Cement NA 24. PeRorations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8,095' to 8,119' MD 2-3/8" 7,772' 7,698' 8,094' to 8,118' TVD 26. ACID, F~CTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production ~ Method of Operation (Flowing, gas lift, etc.) NA~ NA Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL ~TIO 7/23/99 TEST PERIOD => 0 0 0 NA~ 0 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL G~VI~-API (corr) Press. 0 0 24-HOUR ~TE => NA NA NA ~A 28. CORE DATA Brief description of lithology, porosi~, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NA ORIGItqAL Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. ' ' 30. GEOLOGIC MARKERS FO~ATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Tyonek 77-3 Sand 8084 8120 31. LIST OF ATTACHMENTS Operations Summary, Well Diagram, Survey Listing 32. I hereb~.~ .~re~and correct to the best of my knowledge . . , Signe~l'~'' 'Z:~ ~. ¢.;c2~'¢.-.¢~¢-7'..~.~,,~' Title "~:~,¢.~.~_~ /~/~-'~,4~¢~te ,/'~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 UNOCAL RKB to TBG Head = 15.25' SIZE WT Swanso~__tAver Field Well SRU #43B-15 Actual Completion 7/7/1999 CASING AND TUBING DETAll J GRADE CONN ID MD TOP MD BTM. 11-3/4" 47 J-55 11.0" Surf 3,021' 7" 29 N-80 6.184" Surf 306' 7" 26 N-80 6.276" 306 1,115' 7" 23 N-80 6.366" 115' 4,819' 7" 26 N-80 6.276" 4,819' 6,643' 7" 29 N-80 6.184" 6,643' 8,468' DV Collar 7,372' Window 7,143' 7,165' 5 15 L-80 TKC Butt 4.408" 6,828' 8,241' Tubing: 2-3/8" 4.6 L-80 Buttress 1.995" Surf 7,772' JEWELRY NO Depth ID Item 1 15.25' 1.995" 2 2,497' 1.901" 3 6,797' 1.901" 4 7,656' 1.870" 5 7,698' 2.00" 6 7,739' 1.875" 7 7,772' 2.196" 2-3/8" Shaffer Tbg Hanger w/Type H profile 2-3/8" McMurry Macco SMO-1 Chem Injection Mandrel with 500 psi Chemical Injection Valve and 3/8" SS methanol injection line 2-3/8" McMurry Macco SMO-1 Gas Lift Mandrel with Dummy Valve Baker CMU Sliding Sleeve W/F profile (Open up) Baker FIt Retrievable Packer (30 Kip shear) Baker X Nipple Baker Wireline Entry Guide/Shear Out Sub TOL ~ 6,823' Perforations Date Zone Top BTM Comments 9-1-99 73-9 7,854' 7,870' 1-11/16 EJ 6spf 0 deg phase 7-22-99 77-3 8,095' 8,119' 1-11/16 EJ 4 spf 0 deg phase Ij.FilFFish Information · 55 perforating disks lost in hole after both perforating runs 9/4/99--Tag fill with 1.75" bailer ~ 7,785' TD = 8,250' MD PBTD = 8,161' Max Hole Angle = 4.11 deg, KOP= 7,140' SRU 43B-15 7-7-99.doc.doc REVISED: 9/08/99 by: MWD UNOCAL Alaska Drilling Operations Summary SRU 43B-15 6/20/99 to 7/7/99 Mobilized new drilling rig onto location. Removed existing tree and rigged up BOPE. Accept rig 6/20/99. Pulled existing 2-3/8" completion. Change out tubing spool and casing packoff. Test new spool and casing packoff to 3,000 psi. NU BOP and test to 250/5,000 psi. Ran 7" casing scraper without any incident. k, , Set bridge plug on wireline @ 7,283. Ran one trip whipstock/milling assembly and could not mill the window. Milled on the whipstock rather than milling the casing. Ran second one trip milling assembly and the window was milled without success. Ran new bridge plug on wireline. Ran new one trip whipstock/milling assembly. Mill window @ 7,143 without any problems. Performed formation integrity test (EMW = 14.78 PPG). Drill 6" hole to 8,250' with 11.7 PPG. Make wiper trip and weight up to 12.3 PPG POOH. Well started to flow while RU wireline shooting flange. RIH with drillpipe and circulate out gas. Weight up to 12.8 PPG to kill well static. Weight up to 13.1 PPG for trip margin. Drop multi-shot gyro and POOH. Run open hole logs. Run and cement 5" liner without incident from 6828'-8241' Change well over to lease water with 6% KCI. Pressure tested 5" liner and liner lap to 2,700 psi for 30 minutes. RIH with 2-3/8" completion. Land hanger and set packer @ 6797'. Test packer and casing to 2,700 psi ND BOPE and NU tree. Pressure test tree to 250/5,000 psi. 7~22~99 Perf Tyonek 77-3 sand @ 8,095'-8119'. 9/1/99 RU wireline and perf 7,854'- 7,870'. Unocal Alaska Resources Unocal Corporation 909 West 9th Ave. Anchorage, AK 99519-6247 Tele: (PO7) 263-7889 Fax: (907) 265-7828 E-mai/: childersd@, unocal, com UNOCAI. Debra Childers Geotech Assistant DATA TRANSMITTAL October 12, 1999 To: Lori Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From' Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items: !~o. io'-] ' ' ~-9 ~ompletion Record 12 HSD Power Jet 5 INCH 9/18/99 10300-10677 1 B-Line AOGCC ~ ( SCU_ 11~9 ......... ~pJe~ioQ~.e~[d- 12~'__H~Pq~e_j.Jel .... } I~_~ ..... 9~ 8J~_9 :~0_3~0-~_0~7~ 1 Film AOGCC .,.,,~ ~ SCU 1.!.~9 ....... ~T~erm~_~e~y_T!_~_.~og .......... 5 INCH 9~/99:6400-10690 1 B-Line : AOGCC ~ SCU 11-~ Thermal Decay Time Log 5 INCH 9P/99 6400-10690 1 Film AOGCC ~ ',~ ~ .c~ ~B~4 ..... C9.~eji?_~grd_~__l~_/l~'~_E0!rjet 5 INCH 9/2N99 5400-5570 1 B-Line AOGCC SCU 2.43B-4_ ~o.m~l.9~io~ ~cod. }.~_!_/.~?~n_~[J~t. 5 INCH 9/22/99 5400-557P- ............... ~___ Film AOGCC ........ SCU 243B~4- _P9.si}~t_PJUg_20' Ce.mint ........ ~l~CH_ ...........~_~.!_9J9~:5}~0.-}5~0_ ....... ~ ...... B-~n~ .... A~GCC. __ SCU 243B~4' pg~is~plgg. ~' cg~ep~ .................... }J_N~_~ 9/19/99:5400.5500 1 Film AOGCC SCU_.4.1B:9. . _C0~_pl?~jp~_~q~[d~_Ga~a_Ray(cc~__._~_l~_ ........ 9~}~9 .~_9~_9.33~ .................. j ....... B-Line AOGCC SCU 4!B-9 ....... Ce~l~ligp_R!c~r~. (Ga_~_m~_R~?C_%__ 5 INCH 9/15/99:5900-9335 1 Film AOGCC SCU 43Ad 5R~ ~.ri~g.e_Pju_g.S.9~jng_.~9~grd ........... _5 i~c~ ........ ~.(~5/9~0~0~72~ .......... ~__ __~:L~~G~ SCU.43A71.BBD___B~!dge~l~g~_e_Ri_og..B~0[~- ....... 5 INCH 6/25/997000-7200 1 Film SCU 43B~! 5 ~[[~nd~lig~__Tg9! ............... 5 INC~ ............2~3~9~ 7~}p-~_240_ ............. 1 B-Line SCU.43B-~ ~ .... ~rl~y In~uc_~qQ.T~p~ ............................ ~ I~H ........ ~/?~7j~?_82_~0~_ ............. ~ .... Fi~m scu 43Bd5 .... Pl~gr.m_Ezpr!~ w(Array ~nducti~n.To01__ _2_.(_5 I~H_ ........ Y/~/~gJ ~1~o~4_0 ......... L B-Line ,./ SCU 43B-15 .. P~a~r~_E. xpr~ ~/~.r[ay.l~99ti0n Tpol 2 / 5 INCH ..... 7/~ ~.~}0_~82~ ........ ~. ___ Film ~ /. , ~ ~- , / ~. ~.~ ~/. ~~ ~ Co~~~. /I~., ~/~'~ - · AOGCC iAOGCC AOGCC AOGCC AOGCC RECEIVED Please acknowl~ signing and returning one copy of this transmittal or FAX to (907) 263-7828. Roe e'ved b~-~~,~/~'---~, IDate' !'~i~"~' '¥ 'i 4" ~C)C)C)I ,,~Jas~a Oil & Gas Cons. Commission Anchorage Re: SRU 43B~15 proposed perforating plan Subject: Re: SRU 43B-15 proposed perforating plan Date: Wed, 25 Aug 1999 11:07:48 -0800 From: Blair Wondzell <blair wondzell~admin, state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: "Smetanka, Jeff W" <smetankaj~unocal.com> CC: "Graven, Erik P" <gravene~Orion. Unocal.com> Jeff, I also received your fax. I hereby verbally approve these additional perforations. You will need to send in a 10-403 requesting approval; show my name and this date in blank 16 for verbal approval. Good Luck with these perfs. Blair "Smetanka, Jeff W" wrote: Hi Blair, As we spoke on the telephone today, we are proposing to add perforations in the 73-9 sand from 7854 to 7874 to the existing completion. The 77-3 sand is currently completed at 8095 to 8119'. That interval will not flow. We are presently rigged up on SRU 43B-15 with coil tubing. We have succeeded in cleaning out fill to bottom and have jetted the tubing down to 5100' with nitrogen in attempts to flow the 77-3 interval. With zero pressure on the tubing, the well will not flow. We ran in and tagged bottom and verified that there is no fill. We intend to displace the remainder of the fluid in the tubing over to nitrogen. We then propose perforating the 73-9 sand. The top of the Tyonek is at 5655' ~D and TVD. The Base of the Tyonek is the top of the Hemlock at 11,123' MD and TVD. I faxed over to you a wellbore schematic and a section of the openhole log for this well. Please reply to me by email regarding our request for approval on this plan. Please call me at 263-7622 if you have any other questions. Thanks, Jeff Smetanka 1 of 1 8/25/99 11:08 AM unocal 909 W. 9th Avenue Anchorage, AK 00501 Fax 907-263-7874 907-263-7665 (conFirmation) Fax transmittal To: Fax Number: From; Date: Subject: Pages' Cover plus Comments' Alaska 0it & Gas (;ohs, 6ommlssion UNOCAL Iplll II _ I I [ [ RKB to TBG Head = 15.25' SIZE Swanson'~iver Field Well SRU #43B-15 Actual Completion 7/7/1999 i i~_ _ i i ii ~.. · E ......ti CASING AND TUBING DETAIL WT GRADE CONN ID l 1-3/4" 47 J-55 7" 29 N-80 7" 26 N-80 7" 23 N-80 7" 26 N-80 7" 29 N-80 DV Collar Windnw ~ 15 L-80 Tubing: 2-3/8" 4.6 L-80 NO 1 2 MD TOP MD BTM. 11.0" 6.184" 6.276" 6.366" 6.276" 6.184" TKC Butt 4.408" Buttress 1.995" Surf 3,021' Surf 306' 306 1,115' 115' 4,819' 4,819' 6,643' 6,643' 8,468' 7,372' 7,143' 7,165' 6,828' 8,241' Surf 7,772' Depth 15.25' 2,497' ID 1.995" 1.901" JEWELRY Item 6,797' 7,656' 7,698' 7,739' 7,772' 1.901" 1.870" 2.00" 1.875" 2.196" 2-3/8" Shaffer Tbg Hanger w/Type H profile 2-3/8" McMurry Macco SMO-1 Chem Injection Mandrel with 500 psi Chemical Injection Valve and 3/8" SS methanol injection line 2-3/8" McMurry Macco SMO-1 Gas Lift Mandrel with Dummy Valve Baker CMU Sliding Sleeve W/F profile (Open up) Baker FH Retrievable Packer (30 Kip shear) Baker X Nipple Baker Wireline Entry Guide/Shear Out Sub TOL @ 6,823' Date Perforations Zone Top BTM Comments 77-3 8,095' 8,119' 7-22'99 1-11/16 EJ 4 slff 0 deg phase TD - 8,2~0' MD PBTD = 8,161' Max Hole Angle = 4.11 deg, KOP= 7,140' SRU 43B-15 7-7-99.doc,doc RECEIVED AUG 25 1999 Alaska 0il & Gas ,~u,,.~. Commission Anchorage REVISED: 7/26/99 by: MWD HUb-~'b-U:d Nt:.U IU; r'l UI~tUL"HL flbbl'. I bHb "bKY l-', US/U5 . _ k .... ~-~, .... .. ~ --,.- ~-~-~~!¢ ~L''~ ¥ ~;{ ''L' -:.c :~;~: _~:E;Z~;: ~;~ { ;/. :.~5 .~ .:.-'.~" .': z~::..{~'-.:~:: '. ~ ~- ~ ~ ~ .~- )~- :...;.,.: ~ _:'. '... ,.., .~ ~ -- ..... ,'. .... ~ ..... ~ ! .... ~.= ........ ~ ' ': ~ , [ . ..... ~ , .... ......... ;u' 8000 f _. ,~ ~ ..., . _ , ..... . ~ " _ :, ~- 0~---~ ...... · ,, . . '"', ~ ~ GOZ - ~0 ~ ; ~ i . : ~= i ~ ......... ~r ,, , . . ( :- : :.....::::.,.:.: :. ..:: .- :'"":' .... -,-,"'. .... ? ' B200~ ~ '-' '~ '"" -- ---- ';~ ~'-~ ..... i , ~td. Res. HILT Ca,er ~CA~ Density AIT-H 80 Inch Investigation ...... Standoff -- - (IN) 14: (DSO~ 0 (OHMM) 5050~ (LBF) 2 (IN) 0' ............... ~ 'L, r _ _ &.~"L .... ........... ~ ~ . ..... 1.65 (G/C3) 2.6 ............ , ~-~sSlOO ., . t o: - 0il ~ L~'~ ~ PiP SUMMARY . k,,~o~,~ ~,~0b0r~ge ~Tlme Mark Every 60 S...................... _ ..... AIT-H Answer Product Processing Summary, Data taken with toot # 108 (AHTNO) .,,Acquired data from HILT/HAlT ***** Bhole Correction ***** Effective Tool Standoff computed. Borehole diameter and mud r~, taken as input (see GCSE and GRSE parameters) Tool Is run in ECCENTERED mode with a tool stand-off of 0,13 IN, Blt Size le 6,00 IN, ***** Input Selections to AtT Answer Produot prooessing ***** ' Caliper (GCSE): HCAL Mud Resistivity (GRSE): AHMF Temperature (GTSE); LINEAR_ESTIMATE Porosity (FPHI): DPHZ ***** Other parameters used by AlT-H/SAlT Answer Product processing ***** Surface Hole Temperature (SHT) 55.000 DEGF Bottom Temperature (BHT) 212.000 DEGF Total Depth (TD) 8250.000 FT STATE OF ALASKA ALASKA oi'E AND GAS CONSERVATION C OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Wel o,.: x 2. N~e of O~rato~ 7. Permit Numbe~ * ~ UNOCAL 9~47 3. Address 8. APl Number ""---;-' ~; PO ~x 1~247, Anchorage, AK 99519-624; : ......... 50- 1~-10144-~ ~; 4. Lo~tion of well at sudam ....... .... '. '-.;~ ~ ..... ' ....... ; . :~,;' r~ ~ ~~~[ 9. Unit or Lea~ Na~f~,'~ U/; ~*~ U~.~:-~', ....... 1980 FSL and 620' FEL S~. 15, T8N, R9W, Sb ' '~~' i ~ Ii Sw~son R~er Uni' ". ........ ~ I~~~i 10. Well Number At Top Pr~ucing Inte~a ~ ..__~~ - ~u,~0;;u~;~, ~'~'~ S~aight hole ¢~ r.~__u~~ .... ~ 43~ 15 At Total DepB 11. Field and Poo Sbai~ht hole "' ........ ~ ...... ~ Sw~n R~er Fiek 5. Elevation in feet (indicate KB, DF, etc. ~ 6. Lease Designation and Seri~ Nc Tyonek 77-3 P~ 15.25' RKB~ A-028384 12. Date Spu~6/28/19'~ 13. Date m.D. Reached6/30/99 14' Date ~mP" Susp' °r Aband' I 15' Water Depth' if °fish°re ~ 16' N°' °f C°mpleti°ns7~/99 NA feet MSL 1 17. To~l Dep~ (MD+~D) 18. Plug ~ck Dep~ (MD+~D) 19. Dir~tional Su~ey ~ 20. Dep~ where SSSV set ~ 21. Thickness of Permafrost 8,2~'/8,8,249' 8,161'/8,160' Yes: X No:~ NA feetMD~ NA 22. Ty~ Elecbic or O~er L~s Rut GR,DNL, DIL, Densi~, SP 23. CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~. PER ~. GRADE TOP ~OM " _HOLE SIZE CEMENTING RECORD AMOUNT PULLED 5" 15 L-80 6,828' 8,241' 6 32 BBLS of G ~menl NA 24. Pedorations o~n to Pr~ucaon (MD+~D of Top ~d BoSom ~ 25. TUBING RECORD intew~, size ~d number SIZE DEPTH SET (MD) PACKER SET (MD) 8,~5' to 8,119' ME 2-3/8" 7,~2' 7,698' 8,~4' to 8,118' ~E 26. ACID, F~CTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED NA 27. PRODUCTION TEST ~ I ~ ~ ~ ~ ~.~./i. Date First Pr~uctior [ Me~ of Operation (Flowing, gas lift, etc. ' · ~ ~ NA~ NA Date of Tesl Hours Test~ PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL ~TIO 7/23/~ TEST PERIOD => 0 0 0 NA~ 0 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVIS-APl (corr) Press. 0 0 24-HOUR RATE => NA =NA NA NA 28. CORE DATA Brief descrip~on of li~ol~, porosi~, fractures, apparent dips and presence of oil, gas or water. Submit core chi NA Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. - 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravit~ MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Tyonek 77-3 Sand 8084 8120 31. LIST OF A-I-FACHMENTS Operations Summary, Well Diagram, Survey Ustin~ 32. I hereby c¢.'~ that the f~regoiFg.~isi~~ and correct to the best of my knowledge Signed ~'~~ Title ~l~ ~//~ ~~ Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log o all types of lands and leases in Alaska Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, sal water disposal, water supply for injection, observation, injection for in-situ combustion Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurement= given in other space on this form and in any attachments Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reports in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interv~ Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage cemenl lng and the location of the cementing tool Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Ir~ jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 UNOCAL RKB to TBG Head = 15.25' Swanst~lt4Jver Field Well SRU #43B-15 Actual Completion 7/7/1999 CASING AND TUBING DETAHJ SIZE WT GRADE CONN ID MD TOP MD BTM. 11-3/4" 47 J-55 11.0" Surf 3,021' 7" 29 N-80 6.184" Surf 306' 7" 26 N-80 6.276" 306 1,115' 7" 23 N-80 6.366" 115' 4,819' 7" 26 N-80 6.276" 4,819' 6,643' 7" 29 N-80 6.184" 6,643' 8,468' DV Collar 7,372' Window 7,143' 7,165' 5 15 L-80 TKC Butt 4.408" 6,828' 8,241' Tubing: 2-3/8" 4.6 L-80 Buttress 1.995" Surf 7,772' JEWELRY NO Depth ID Item 1 15.25' 1.995" 2 2,497' 1.901" 3 6,797' 1.901" 4 7,656' 1.870" 5 7,698' 2.00" 6 7,739' 1.875" 7 7,772' 2.196" 2-3/8" Shaffer Tbg Hanger w/Type H profile 2-3/8" McMurry Macco SMO-1 Chem Injection Mandrel with 500 psi Chemical Injection Valve and 3/8" SS methanol injection line 2-3/8" McMurry Macco SMO-1 Gas Lift Mandrel with Dummy Valve Baker CMU Sliding Sleeve W/F profile (Open up) Baker FIt Retrievable Packer (30 Kip shear) Baker X Nipple Baker Wireline Entry Guide/Shear Out Sub TOL ~ 6,823' Perforations Date Zone Top BTM Comments 7-22-99 77-3 8,095' 8,119' 1-11/16 EJ 4 spf 0 deg phase TD = 8,250' MD PBTD = 8,161' Max Hole Angle = 4.11 deg, KOP= 7,140' SRU 43B-15 7-7-99.doc.doc REVISED: 7/26/99 by: MWD UNOCAL Alaska Drilling Operations Summary SRU 43B-15 6/20/99 to 7/7/99 Mobilized new drilling rig onto location. Removed existing tree and rigged up BOPE. Accept rig 6/20/99. Pulled existing 2-3/8" completion. Change out tubing spool and casing packoff. Test new spool and casing packoff to 3,000 psi. NU BOP and test to 250/5,000 psi. Ran 7" casing scraper without any inCident. Set bridge plug on wireline @ 7,283'. Ran one trip whipstock/milling assembly and could not mill the window. Milled on the whipstock rather than milling the casing. Ran second one trip milling assembly and the window was milled without success. Ran new bridge plug on wireline. Ran new one trip whipstock/milling assembly. Mill window @ 7,143 without any problems. Performed formation integrity test (EMW = 14.78 PPG). Drill 6" hole to 8,250' with 11.7 PPG. Make wiper trip and weight up to 12.3 PPG POOH. Well started to flow while RU wireline shooting flange. RIH with drillpipe and circulate out gas. Weight up to 12.8 PPG to kill well static. Weight up to 13.1 PPG for trip margin. POOH and run logs. Run and cement 5" liner without incident from 6828'-8241' Change well over to lease water with 6% KCI. Pressure tested 5" liner and liner lap to 2,700 psi for 30 minutes. RIH with 2-3/8" completion. Land hanger and set packer @ 6797'. Test packer and casing to 2,700psi ND BOPE and NU tree. Pressure test tree to 250/5,000 psi. 7~22~99 Perf Tyonek 77-3 sand @ 8,095'-8119'. Well did not flow. UNOCAL SRU 43-15,43A-15RD Swanson River Unit,Kenai Peninsula, Alaska SURVEY LISTING Page 2 Your ref : PMMS <7140 - 8250> Last revised : 6-Ju1-1999 Comments in wellpath MD TVD Rectangular Coords. Comment 8250.00 8248.51 4.56 N 53.67 W Projection to TD. - No Survey. Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 43-15 Tyonek 77-'J Sa 8025.00 360.00S 1670.00W 25-Mar-1999 UNOCAL SRU 43-15 43A- 15RD SRU 43-15 Swanson River Unit Kenai Peninsul a, A1 aska SURVEY LISTING by Baker Hughes INTEQ Your ref : PMMS <7140 - 8250> Our ref : svy5995 License : Date printed : 7-Ju1-1999 Date created : 6~Ju1-1999 Last revised : 6~Ju1-1999 Field is centred on 0.000,0.000,999.00000,N Structure is centred on 353092.501,2476932.943,999.00000,N Slot location is n60 46 57.468,w150 49 31.569 Slot Grid coordinates are N 2478917.000, E 352482.000 Slot local coordinates are 1976.41 N 635.34 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Mitchell W. Datum JUL 0 7 19o~):· UNOCAL SRU 43-15.43A-15RD Swanson River Unit,Kenai Peninsula, Alaska Measured Inclin. Azimuth True Vert R E C Depth Degrees Degrees Depth C 0 0 0.00 0.00 0.00 0.00 0 7140.00 0.00 0.00 7140.00 0 7435.00 2.81 280.43 7434.88 1 7499.00 2.82 281.08 7498.80 1 7562.00 2.82 279.03 7561.73 2 7621.00 2.91 279.83 7620.65 2 7687.00 2.93 277.08 7686.57 3 7750.00 3.04 275.62 7749.48 3 7814.00 3.00 275.11 7813.39 4 7877.00 3.26 272.32 7876.30 4 7941.00 3.44 271.87 7940.19 4 8004.00 3.55 272.61 8003.07 4 8068.00 3.62 272.38 8066.95 4 813t.00 3.92 267.86 8129.81 4 8193.00 4.11 268.74 8191.66 4 8250.00 4.11 268.74 8248.51 SURVEY LISTING Page 1 Your ref : PMMS <7140 - 8250> Last revised : 6-Ju1-1999 T A N G U L A R Dogleg Vert R D I N A T E S Deg/lOOft Sect .00 N 0.00 E 0.00 0.00 .00 N 0.00 E 0.00 0.00 · 31 N 7.11 W O. 95 7.11 · 90 N 10.20 W O. 05 10,20 · 44 N 13.25 W 0.16 13.25 .92 N 16.16 W 0.17 16.16 .41 N 19.49 W 0.21 19.49 .78 N 22.75 W 0.21 22.75 .09 N 26.10 W 0.08 26.10 .31 N 29.54 W 0.48 29.54 .45 N 33.27 W 0.28 33.27 .60 N 37.11 W 0.19 37.11 .77 N 41.11W 0.11 41.11 .77 N 45.25 W 0.67 45.25 .65 N 49.59 W 0.32 49.59 4.56 N 53.67 W 0.00 53.67 Projection to TD. - No Survey. All data is in feet unless otherwise stated. Coordinates from SRU 43-15 and TVD from est. rkb. (325.00 Ft above mean sea level). Bottom hole distance is 53.86 on azimuth 274.85 degrees from wellhead. Vertical section is from wellhead on azimuth 270.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Unocal Alaska Resources Unocal Corporation 909 West 9th Ave. Anchorage, AK 99501 Fe/e; (907) 265-7889 Fax: (907) 263-7828 E-rna#: ch#dersd@unoca/, corn UNOCAL Debra Childers Geotech Assistant DATA TRANSMITTAL August 18, 1999 To: Laurie Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items: O ~ SCU 243B-4 Platform Express Array Induction/SP 2/5 7/22/993450-6066 1 B-Line sC'U"2~-B24~' Platform Express Array Induction/SP 2/5 7/22/99 3450-6066 1 Film SCU 243B-~ ._p.l_a_ff0_r._m_Expres~sDens!ty/N_e_u_tr?_n _._~5_ ...... ?_2_2/_9_9__3,~_5_0_-6_066 ___ 1 B-Line SCU 243B-4 Platform Express Density/Neutron2/5 7/22/99!3450-6066 1 Film O~'7 SRU 43B-15 Completion Record 5 7/22/997300-8127 1 B-Line ,~ SRU43B~15'' c~n~p~etion ReC(~id 5 ...... 7;/2~9~-~3~-(~'8i2~ .... i--i~i~- -- sBu 43Bd5 Mu'dlog - 6~30/99 7i~0:8250 -B-El--ne . · SRU ~43B-i5 MUdlog 6/30/99: 7170-8250 Film TONY KNOWLE$, GOVERNOR .. ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 15. 1999 Dan Williamson Driling Manager Unocal Corporation P O Box 196247 Anchorage, AK 99519-6247 Re~ Swanson River Unit SRU ~ Unocal Corporation Permit No: 99-47 Sur Loc: 1980'FSL and 620'FEL. Sec. 15 T8N. R9W. SM Btmhole Loc. 1980'FSL and 745'FEL. Sec. 15 T8N, R9W. SM Dear Mr. Williamson: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given bv contacting the Commission at 279-1433. Robert N. Christenson. P. E. Chairman BY ORDER OF THE COMMISSION dlffEnclosures CC; Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re~ THE APPLICATION OF Union Oil Company ) of California (Unocal)for an order granting ) an exception to the spacing requirements of ) 20 AAC 25.055(a)(4) to provide for the drilling ) of the Swanson River Unit Well 43B-15 deviated ) well to an undefined gas pool. ) Conservation Order No. 444 Well 43B-15 Swanson River Unit June 14. 1999 IT APPEARING THAT: . Union Oil Company of California (Unocal) by letter dated May 18, 1999, requested an exception to the well spacing provisions of 20 AAC 25.055(a)(4). The exception would allow drilling the Swanson River Unit (SRU) 43A-15RD gas well to a bottomhole location that is closer than 1500 feet to a section line. The Commission published notice of opportunity for public hearing in the Anchorage Daily Nexvs on May 25. 1999, pursuant to 20 AAC 25.540. 3. Well SRU 43A-15RD was renamed to SRU 43B-15. 4. No protests to thc application were received. FINDINGS: The SRU 43B-15 well will be drilled as a deviated well from a surface location of 1980' from the south line (FSL), 620' from the east line (FEL) of Section 15, T8N, R9W, Seward Meridian (SM) to a bottomhole location 1980' FSL, 745' FEL of Section 15, T8N, R9W, SM. 2. Offset owner ARCO Alaska, Inc. has been duly notified. 3. An exception to the well spacing provisions of 20 AAC 25.055(a)(4) is necessary, to allow the drilling of this well. CONCLUSION: Granting a spacing exception to allow drilling of the SRU 43B-15 gas well will not result in waste nor jeopardize correlative rights. Conservation Order No. 444 June 14, 1999 Page 2 NOW, THEREFORE, IT IS ORDERED: Unocal's application for exception to the well spacing provisions of 20 AAC 25.055 (a)(4) for the purpose of drilling the SRU #43B-15 is approved. DONE at Anchorage, Alaska and dated June 14, 1999. Robert N. Christenson, P. E., Chairman Alaska Oil and Gas Conservation Commission Camill60echsli, Commissioner Alaska Oil and Gas Conservation Commission D~on, ~Comr~ssi.oner~- Alaska Oil an~?vation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Comnfission an application for reheahng. A request for reheating must be received bv 4:30 PM on the 23rd day following the date of the order, or ne~ working day ifa holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not a~ing on it within the 10-day period. An affected person has 30 days fi.om the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commissiom to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Conmfission. the 30-day period for appeal to Superior Court rum from the date on which the request is deemed denied (i.e.. l0N day after the application for rehearin$ was filed). STATE OF ALASKA '~ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill Redrill X I lb. Type of well Exploratory Stratigraphic Test Development Oil Re-entry DeepenI Service Development Gas X Single Zone Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Unocal 324' RKB Swanson River Field 3. Address P.O. Box 196247 6. Property Designation Tyonek 77-3 Pool Anchorage. Ak 99519-6247 A-028384 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (see 20AAC25.025) 1980' FSL and 620' FEL Sec. 15, T~N, R9W, SM Swanson River Unit AK Statewide Oil & Gas Bond At top of productive interval Tyonek 77-3 @ 8000' TVD 8. Well Numbe,~.- Number 1980' FSL and 690' FEL Sec. 15, T~N, R9W, SM SRU #42"'i-15~ U 62-9269 At total depth 9. Approximate #pUd da'~e Amount 1980' FSL and 745' FEL Sec. 15, TIN, R9W, SM 6/15/99 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15 Proposed depth (MD and TVD) property line 1998' (SRU #234-15) 8300' MD 3358' No active 77-3 producers Lease 2560 acres 8291' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2) Kickoff depth 7300 feet Maximum hole angle 20° Maximum Surface 1329 psig. At total depth (TVD) 4920 psig 18. Casing Setting Depth program size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD 6" 5" 15 L-80 TKC Butt 1200' 7-100' 7100' 8300' 8291' 112 cuff Class G blend 19. To be completed for Redrill, Re-entry and Deepen Operations i-~'~ Present well condition summary ~i':~ Total depth: measured 1 1380 feet Plugs (measured) 9997' MD true verical 11300 feet,. Effective Depth measured feet Junk (measured) true vertical feet ~.J88~ 0JJ Casing Length Size Cemented Measured Depth True Vertical Dept~ Structural Conductor 28' 22" Drive 28' 28' Su trace 3021' 11-3/4" 3021' 3021' Intermediate Production 11380' 7" 11380' 11300' Liner Perforation Depth: measured 11122'-11250' plugged and abandoned 8/91 true vertical 11054'-11176' 21. I hereby: ~ertify ~at~e foregoing is true and correct to the best of my knowledge~ Signed ~~/~/~_~_~j,~l~~ Title: Drilling Manager Date Commission Use Only ~,,p.... ~/Z~ 50_/Z3~./0//~/~.. ~.2_ ~//~- q¢ for other requirements Conditions of approval Samples required Yes /"~NO") Mud Icg required Yes ("~No~ Hydrogen Sulfide measures Yes Directiofial. al..~urvey required ~ No Required working pressure for BOPE 3M ~ 10M 15M~ Other: ORIGINAL SIGNED BY by order of ~_¢ ~'//~' -'/~' _Approved by ~h~.,? N ChrJsten$on Commissioner the commission Date ......... Form 10-401 Rev. 12-~1;~'~ AFE#134750 Submit in triplicate Application for Permit to Drill SRU #43B-15RD Hazard Section Gas Sands' 73-9 @ 7,840 - 7,860' MD 77-3 @ 8,075-8,120 MD Anticipated Pore Pressure of Gas Sands are .594 psi/ft Loss Circulation: Loss circulation is not anticipated unless gas sands are pressure depleted. LC has been historically a problem at Swanson River after drilling down into the Hemlock. Proximity Concerns:None. Mud and Cutting Disposal The mud from SRU #43A-15RD will be disposed in the mud disposal well, SCU #43-4MD. The cuttings generated by drilling ff43A-15RD will be disposed in the solid waste facility at Swanson River Field. 1'8 17 2O 29 51 8N-9 ? 52 t ~ I I I 4 ILS 13-4 42A-5 42B-5 ........ 28 43-a8 , 331-27 1-27 T.S. 22-23 I ~-27 i i I i 3~4-~? 27 ,- ...... ~i 26 / I I / / I P~S iPILL I I : ,~D EQUIPMENT ~~ t~DZNG STORAGE. , ~ , xx. C' STRIP "221-33 /.~ ~--' - ~~__ I ez, ~~_m Ii ,. ,j,;V 32-33 1-1-A-33 23-33 il '4 ,,, 34. 24-33 +1.-4 OFF[CE AND FLA .~.E 23-4 '~ 243-4 34 -4 314-4 DISPOSAL 312-9 _ L\\ .~' ,---, I ~OR- 4-34 43A-4 i %' 5 t 10 I // I / / / / / / / / / / / / / / / I +-~ \ Swanson River Unit #43A-15RD Proposed Location Plat Surface Location: 1980' FSL, 620' FEL, Sec 15, T8N, R9W, SM Proposed Bottomhole Locations Target Tyonek 77-3 sand @ 8004' MD/8000' TVD = 1980' FSL, 690' FEL, Sec 15, T8N, R9W, SM Total Depth = 8300' MD/8291' TVD= 1980' FSL, 745' FEL, Sec 15, T8N, R9W, SM Section 9 Section 16 Section 21 SRU g23-15 Section 10 Section 15 2725' SRU #234-15 Section 22 SRU g41A-15 Proposed TD For SRU g43A- 15RD .~ SRU g43A-15 iert. Well 4.- 620' '-~ 745' --~ 1980' Section 11 Section 14 Section 23 1" = 1000' UNOCAL SRU 43A-15RD General Procedure 5/13/99 1) Move in Inlet Drilling Rig # CC-1 or equivalent. 2) NU and test BOPE to 5000 psi/250 psi. 3) Pull and lay down 2-7/8" tubing down to tubing cut at 9882'. (Hemlock perforations were already abandoned with cement in 1991 .) 4) RU E-line and set bridge plug at 7300'. 5) RIH with whipstock on drill pipe. Set whipstock on top of bridge plug and mill window at 7300'. 6) POOH with window mills. 7) RU mudloggers. RIH with 6" bit. Drill 10' of new formation and perform Leak-off Test. 8) Continue drilling 6" hole from 7300' to 8300' TD. There will only be a slight directional deviation from vertical. The estimated directional plan is attached. Obtain single shot surveys at least every 500' MD. 9) Log open hole interval from 8300' TD to 7300' with triple combo density/neutron/induction log. 10) Run 5" 15# L-80, TKC Buttress liner from 8300' to 7100' with 5" x 7" liner hanger. 11 ) Set hanger, release from hanger, re-engage drive spline to allow liner rotation. 12) Cement 5" liner from 8300' to top of liner at 7100' with 112 cuft based on 50% excess while rotating liner. 13) PU running tool to top of liner and circulate excess cement to surface. POOH with running tool. 14) RIH and set liner top packer. Pressure test liner and liner top to 2500 psi. POOH with drill pipe. 15) RIH with liner clean out assembly on 2-7/8" PAC drill pipe. Clean out liner to PBTD of 8220'. Displace well to 6% KCL. POOH with clean out assembly. 16) Run 2-3/8" completion tubing to 7900' with retrievable packer. Methanol injection mandrel will be at 2500' with 3/8" methanol line strapped to outside of tubing. 17) Displace tubing to diesel, land hanger and set packer at 7840'. 18) Pressure test annulus to 2500 psi. 19) ND BOP stack, NU seal flange and tree. Test tree to 5000 psi. 20) Move rig. P ROC43A- 15RD.DOC 1 5/13/99 UNOCAL SRU 43A-15RD General Procedure 5/13/99 21) RU flowline and methanol injection pump. 22) RU E-line unit. 23) Perforate Tyonek 77-3 sand with through-tubing guns at 8000'-8030' and flow test well. PROC43A- 15RD. DOC 2 5/13/99 UNOCAL ) RKB to TBG Head = Swanson 'i~ver Field Well SRU #43A-15 RD Proposed Sidetrack, 1999 CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 11-3/4" 47 J-55 Surf 3021' 7" 29# N-80 7" 26g N-80 7" 23# N-80 7" 26g N-80 7" 29# N-80 5" liner Surf' 306' 306' 1115' 1115' 4819' 4819' 6643' 6643' 8468' Window 7300' DVtool 7372' 7100' 8300' Tubing: 2-3/8" 4.6 L-80 Surf JEWELRY DETAIL NO. Depth Item 7900' 2-3/8" Tbg hgr w/Cameron "H" BPV profile 2 2400 3 2500 4 7840 5 787O 6 7900 2-3/8" dummied GLM Macco 2-3/8" SMO-1 Chem Inj Mdrl w/1000 psi chem inj valve 2-3/8" x 5" Packer 2-3/8" X nipple 2-3/8" tbg tail Window @ 7300' TOP 4 8000' PROPOSED PERFORATION DATA BTM ZONE SPF DATE COMMENTS 8025' 77-3 Tyonek TD = 8300' MD Max Hole Angle = 10 to 20 deg, KOP= 7300' SRU43A-15RD SCHPROP3.DOC REVISED: 5/13/99 DRAWN BY: TAB UNOCAL ) RKB to TBG Head = DV tool 7372' TOC @ 9800'N,& Hole in Tbg @ 8508' Tbg Cut @ 9882' Swanson i~ver Field Well SRU #43A-15 Abandoned 8/91 CASING ANI) TUBING DETAIL SIZE WT GRADE CONqN TOP BOTTOM 11-3/4" 47 J-55 Surf 3021' 7" 29# N-80 Surf' 306' 7" 20g N-80 306' 1115' 7" 23# N-80 1115' 4819' 7" 26g N-80 4819' 6643' 7" 29# N-80 6643' 8468' DV tool 7372' 7" 29# P-110 8468' 11389' Tubing: 2-7/8" 6.4 N-80 EUE Surf 11220' JEWELRY DETAIL NO. Depth Item 2 10964 3 10974 4 11000 5 11026 GLMs at 1607', 3010', 4346', 5528', 6551', 7318', 7994', 8508', 9025', 9513', 10,032', 10,547', 10,939', 11,017' Baker H-1 2-7/8" Cmt Retainer Tubing perfs for abandonment Baker 2-7/8' Cmt retainer Brown 2-7/8' x 7" HS-16-1 packer TOC in 7" @ 9997' TOP 8225' PROPOSED PERFORATION DATA BTM ZONE SPF DATE COMMENTS 8255' 77-3 Tyonek Proposed Post-Sidetrack Abdnd Hemlock 11122'-11250' TD = 11380' MD Max Hole Angle = 39 deg, KOP = 8900' SRU43A-15 SCH8-91.DOC REVISED: 5/13/99 DRAWN BY: TAB Swanson River Well #SRU 43A-15RD Bottomhole Pressure Information The following presents data used for calculation of anticipated surface presures (ASP) during drilling of the sidetrack SRU 43A-15RD. The pore pressure gradient was estimated from the following information: BHP Depth Well psi TVD EMW, pp.q Comment SRU 212-27 4344 7620 11.4 10/61, initial BHP before production The fracture gradient at sidetrack window at 7300' was conservatively estimated at .80 psi/ft or 15.4 ppg. Casing Pore Casing Setting Fracture Pressure Mud Pore ASP Size Depth Gradient Gradient Weight Pressure Drilling (in.) (TVD ft) flbs/._qal) (lbs/gal) (Ib/.qal) (psi) (psi) 7 7300 15.4 11.4 11.9 4327 1329 5 liner 8300 NA 11.4 11.9 4920 Procedure for Calculatinq Anticipated Surface Pressure While Drilling ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat (with gas bubble just below shoe and mud gradient above shoe) or 2) formation pore pressure at the next casing point less 1/4 gas gradient and 3/4 mud gradient to the surface as follows: 1) ASP = (FGx.052xD) - (MWx.052xD) = (15.4 x .052 x 7300) - (11.9 x .052 x 7300) =1329 psi OR 2) ASP = FPP - (0.1gas gradient xDx.25) - (MWx.052xDx.75) = 5136 - (. 1 x8300x.25) - (11.9x.052x8300x.75) = 2777 - 150 - 2200 = 1076 psi Swanson River #43A- 15RD Offset Mud Weight vs Depth 2000 4000 6000 234-15 5/98 2.2 PPg8000 10000 12000 Mud Weight, ppg 7.0 8.0 9.0 10.0 11.0 12.0 13.0 9/89 ~.~ 1 234-15 12/98 I 212-27 10/61 -e.-#43-15, 1961 = #34-15, 1961 = #242-16, 1989 Initial Reservoir Pressures SCU #43A-15RD Casing Design 7" Production Casinq, 29#, 26# and 23# L-80, Buttress Worst case for burst is tubing leak near the surface after the well is completed. Burst 8000' x((11.4 formation x .052) - 0.1 gas grad)) 23# rated @ 6340 psi for burst = 4742 psi Safety Factor = 1.34 OK Worst case for collapse is if lost returns occur while drilling below the 7" surface casing. Collapse = (11.4x.052x7300') -(7300' x .1) : 3597 psi for full evacuation Tension = NA (casing already in place and cemented) 5" 15#, L~80, TKC buttress liner @ 8300' MD/8290' TVD Tension = (8300'-7100') x 15#= 18K 29# rated @ 7020 psi for clpse Safety Factor: 1.95 OK Rated: 350K for body yield Safety Factor: 51 OK Worst case for collapse of the liner would be when the completion interval depletes and a formation with virgin pressure is behind pipe. Collapse = (11.4 x .052 x 8300') - (.1 gas x 8300') psi inside Rated = 7250 psi for collapse - 4090 psi (Unrealistic but worst case) Safety Factor 1.8 OK Worst case for burst would be a tubing leak with gas in the annulus, the effective burst pressure at the liner top at 1950' would be: Burst - (8000'xl 1.4 formation x .052) - (0.1 gas grad x8000') Rated -- 8290 psi for burst - (8.4 x .052 x7100')-- 841 psi Safety Factor = 9.9 OK SRU #43A-15RD Casing Specifications Proposed Casing 5" 15#, L-80, TKC Buttress JOint Strength, K lbs 350 B0dy..Strength, K lbs 396 Burs~ Rating, psi 8,290 Collapse Rating, psi 7,250 Max -Torque, fi-lbs 7,700 OPt Makeup, fi-lbs 3,140 'Mi-n Make-up 2,900 CSGSPEC43A-15RD.XLS SRU 43A-15RD Cementing Program 5" Liner 6" hole @ 8300' MD, top of liner at 7100' MD Cement volume for liner based on open hole volume plus 50%, liner lap, and shoe joints. Estimated volume is: 1000' (8300' - 7300') x 0.0600 cuft/ft (6"x 5") x 1.50 = 90 cuft 200' liner lap @ 0.0722 cuft/ft = 14 cuft 80' shoe jts x 0.1059 cuft/ft (5" liner capacity) = 8 cuft Total Cement = 90 + 14 +8 = 112 cuft Class G cement @ 15.8 ppg with additives. Inlet Drilling Rig #CC-1 7-1/16" 5000 psi BOP Stack 7-1/16" Annular Preventer 3-1/8" Kill Line 5k psi Blind Rams 5k psi Pipe Rams ~ Drilling ~ '-1'~1 ~' I , Spool , 2 1 5k psi Pipe Rams 7-1/16'"' 5M Tubinglhead~ Casing 4-1/16" Choke Line 1 = HCR Valve 2 = Gate Valve Blowout Prevention Equipment Inlet Drilling Rig #CC-1 or Equivalent 7-1/16" BOP Equipment 1 ea 7-1/16"x 5000 psi wp single ram type preventer 1 ea 7-1/16"x 5000 psi wp double ram type preventer 1 ea 7-1/16"x 5000 psi wp annular preventer 1 ea 7-1/16"x 5000 psi wp drilling spool with 2 ea 4" side outlets (choke and kill), HCR and manual valves on choke line and two manual valves on kill line. 1 ea Koomey BOP control unit with 120 gallon volume tank, w/twelve 10-gallon accumulator bottles and nitrogen back-upsystem. 1 ea 5 station, remote control panel 1 ea 5,000 psi choke manifold with Cameron automatic hydraulic choke 3" - 10,000 psi with control choke panel. 1 lot Hydraulic pipe and fittings from manifold to BOP stack. Drilling Fluid System Description Inlet Drilling Rig #CC-1 Mud Pumps 1 ea PZ9 Gardner Denver, 3" x 5000 psi shear release valve and a 4" x 4000 psi gates bumper hose powered by a 398 TA Cat. 1 ea 214P Oilwell powered by twin 671 Detroit diesel engines. Mud Tank System (466 bbl Total Volume) Tank A- 88 bbl suction tank Tank B- 150 bbl middle tank Tank C- 172 bbl shaker tank Tank D- 27 bbl pill tank Tank E- 17 bbl centrifuge tank Tank F- 12 bbl sand trap Trip Tank- 35 bbl 501 bbl total Mud Svstem Equipment 1 ea 1 ea 1 ea 1 ea 1 ea 3 ea Brandt dual tandem 800 gpm shale shakers Drilco See-FIo degasser 36"x 6' Poor Boy gas buster Pioneer eight cone desilter Pioneer Model S-800 mud hopper Medearis 3" revolving mud agitator guns 1 ea 1 ea 1 ea Pit level indicator with audio and visual alarms Fluid flow sensor Gas monitoring for H2S and LEL with sensors at rig floor, sub and shakers. MUD TANKS ATTACHMENT E rS'~"cl ' UNOCAL DRILLING FLUIDS PROGRAM SWANSON RIVER WELL SRU 43A-15RD OVERVIEW Well SRU 43A-15RD is a sidetrack re-driiil well in the Swanson River Field. Potential problems in the sidetrack interval include coal sloughing, gas kicks, and lost circulation. Maximize use of solids equipment in order to avoid overloading the system with sand. This interval will be drilled with a conventional Iow-solids non-dispersed mud system with an initial mud weight of 11.5 - 11.8 ppg. A lubricant may be used if torque becomes a problem. MILLING SECTION @.(..+/- 7300') Consider milling the window with drillwater/brine. Biozan additions of 2.0 to 2.5 ppb should provide adequate viscosity to clean the metal cuttings. Proper placement of ditch magnets is necessary in order to remove metal cuttings at the surface. The milling fluid can be weighted with barite if needed for well control. Use only one surface pit (if possible) to minimize the volume of milling fluid for disposal purposes. Initial yield point should be above 40. Maintain 3 RPM reading above 20 for adequate hole cleaning. Monitor returns of cuttings and adjust rheology or pump high viscosity sweeps if needed. Fluid Properties - Milling Operation ., Density (PPG) Yield Point Gels(10sec/10min) 3 RPM pH 8.6 - 9.0 40 - 50 20/30 > 20 8.5-9.5 ,, CASED HOLE DISPLACEMENT TO LSND FLUID 1. Drill out window plus 10' of new hole with milling fluid. 2. Clean pits and build new Iow-solids non-dispersed drilling fluid. o Displace well to LSND mud as follows. Pump 25 bbls fresh water with one drum Safekleen followed by 25 bbls water viscosified with 3 ppb FLO-VIS (weight up as needed with Barite for well control). Follow with the LSND fluid. (TM9910) (04/99) o Pump at highest rate practical. Aggressively rotate and reciprocate pipe while displacing. Make sure bit is on bottom when leading edges of spacers and LSND fluid are at the bit. Calculate strokes and monitor returns at the flowline. Discard spacers until clean LSND returns are observed. Make sure all pits and lines are cleaned prior to adding additional fluid to the pits. 6" PRODUCTION INTERVAL: (7300' - 8600' MD) The 6" hole will be drilled with a LSND fluid. Initial mud weight should be above 11.5 ppg. Control fluid loss at +/- 5 cc's with additions of Drispac and/or Resinex. Use barite for weighting up as needed. Add Soitex @ 2 PPB for coal stabilization. Run as fine of mesh shaker screens as possible. Centrifuge mud system both while drilling and during trips. Bit/BHA bailing from sticky clays can be treated with Drilling Detergent, DrilI-Kleen, SAPP and/or Nut Plug sweeps. Lubetex can be used to reduce torque and drag. Use Defoam-X if foaming becomes a problem. Drill to T.D. If hole conditions warrant, spot a viscous pill on bottom. Run and cement casing. Fluid Properties - Production Interval (LSND Fluid) Density Plastic Yield Gels Fluid Drill (PPG) Viscosity Point 10s/10m Loss pH Solids 11.5- 12.0 15- 20 '20- 24 14- 18 + 5 cc 9.0- 9.5 < 5% LOST CIRCULATION CONTINGENCY SEEPAGE LOSSES: For seepage losses add 5 - 10 PPB of Liquid Casing while drilling. MODERATE LOSSES: Mix 10 - 30 PPB of M-I Seal Fine & Medium while drilling and/or spot pills across loss zone. Check motor orifice and tool size restrictions. SEVERE LOSSES: For severe losses due to fractures, faults, rubble zones. Mix and spot a 40 bbl 50 PPB LCM pill with M-I Seal Medium, Coarse and Nut Plug Coarse. Pull up into casing shoe and squeeze pill into loss zone with 200 psi, shut in and watch for pressure bleed-off. When pressure holds for 15 minutes resume drilling. Prior to pumping coarse pills, check motor orifice and tools for size restrictions. NOTE: Liquid Casing will pass through 60-80 mesh screens. Liquid Casing and OM Seal will lower pH rapidly - increase Caustic Soda additions accordingly. · At 6-8 ppb, Liquid Casing and OM Seal will raise YP significantly and PV about 3 cps. Volume Usage and Cost Estimate ....... Interval Milling Production Total Volume 470 790 1260 Mated al Cost $10,700 $27,300 $38,000 Engineering $4,375 $4,375 $8,750 ....... , (TM9910) (04/99) UNOCAL . . ~itruolure: SRU 43--15 Well: 43-15 Field: Swanlon River Unit LQoIIlen t Kenal Peninsula, AIOIKQ <- West (feet) UNOCAL: 140 130 120 110 100 90 80 70 60 ~0 40 .~) 20 10 0 10 20 30 I _ ~ . ! I I .!_ . I ] I I. i I I I .-k.., I I I J. __.~ t [ I .~,_ I I I . I_ i I I I I _1_ I 7200 7300' 7400 7500 7800 7?00 U 7800 e~ 7goo I-- I V 9100 82o0 8300 3,00 4.00 5.00 bLS: 1.00 deg per 100 ft 6,00 7.00 9,00 10.00 11,00 12,00 -f '' ~ i 1 --" i , I ~1 i I I ' i I' !" i 200 ! OD 0 I O0 200 300 4UO 500 Vertical Section (feet) -> Azlmulh 270.00 with referenoe 0.00 N, 0.00 E from SRU 41-15 8400 2O 2O 3O UNOCAL LISTING Page 1 SRU 43-15,43-15 ref : SRU43-15Rd Ver.#3 Swanson River Unit,Kenai Peninsula, Alaska revised : il-May-99 Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth RECTANGULAR COORDINATES 0.00 0.00 270.00 0.00 500.00 0.00 270.00 500.00 1000.00 0.00 270.00 1000.00 1500.00 0.00 270.00 1500.00 2000.00 0.00 270.00 2000.00 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 2500.00 0.00 270.00 2500.00 3000.00 0.00 270.00 3000.00 3500.00 0.00 270.00 3500.00 4000.00 0.00 270.00 4000.00 4500.00 0.00 270.00 4500.00 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 Iq 0.00 E 5000.00 0.00 270.00 5000.00 5500.00 0.00 270.00 5500.00 6000.00 0.00 270.00 6000.00 6500.00 0.00 270.00 6500.00 7000.00 0.00 270.00 7000.00 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 7300.00 0.00 270.00 7300.00 7320.00 2.40 270.00 7319.99 7380.00 3.00 270.00 7379.93 7480.00 4.00 270.00 7479.74 7580.00 5.00 270.00 7579.43 0.00 N 0.00 E 0.00 S 0.42 W 0.00 S 3.25 W 0.00 S 9.35 W 0.00 S 17.20 W 7680.00 6.00 270.00 7678.97 7780.00 7.00 270.00 7778.32 7880.00 8.00 270.00 7877.47 7980.00 9.00 270.00 7976.37 8003.93 9.24 270.00 8000.00 Top of Target 77-3 Sand 0.00 S 26.78 W 0.00 S 38.10 W 0.00 S 51.15 W 0.00 S 65.93 W 0.00 S 69.73 W 8080.00 10.00 270.00 8075.00 8180.00 11.00 270.00 8173.32 8280.00 12.00 270.00 8271.31 8300.00 12.20 270.00 8290.87 0.00 S 82.44 W 0.00 S 100.66 W 0.00 S 120.60 W 0.00 S 124.79 W PROPOSAL Your Last Dogleg Deg/100ft 0.00 0.00 0.00 0.00 0.00 0'.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 12.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 Vert Sect 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.42 3.25 9.35 17.20 26.78 38.10 51.15 65.93 69.73 1.00 1.00 1.00 1.00 82.44 100.66 120.60 124.79 Ail data is in feet unless otherwise stated. Coordinates from SRU 43-15 and TVD from est. rkb. (325.00 Ft above mean sea level). from wellhead. degrees. 270.00 degrees. method. Bottom hole distance is 124.79 on azimuth 270.00 degrees Total Dogleg for wellpath is 12.20 Vertical section is from wellhead on azimuth Calculation uses the minimum curvature Presented by Baker Hughes INTEQ UNOCAL LISTING Page 2 SRU 43-15,43-15 ref : SRU43-15Rd Ver.#3 Swanson River Unit,Kenai Peninsula, Alaska revised : il-May-99 PROPOSAL Your Last MD TVD Rectangular Coords. Comments in wellpath Comment 8003.93 8000.00 0.00 S 69.73 W Top of Target 77-3 Sand Target name Rectangular Coordinates Targets associated with this wellpath Geographic Location T.V.D. Revised 43-15 Tyonek 77-J Sa 1670.00W 25-Mar-99 8025.00 360.00S UNOCAL SRU 43-15 43-15 SRU 43-15 Swanson River Unit Kenai Peninsula, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : SRU43-15Rd Ver.#3 Our ref : prop3379 License Date printed : il-May-99 Date created : 25-Mar-99 Last revised : il-May-99 Field is centred on 0.000,0.000,999.00000,N Structure is centred on 353092.501,2476932.943,999.00000,N 31.569 352482.000 635.34 W Slot location is n60 46 57.468,w150 49 Slot Grid coordinates are N 2478917.000, E Slot local coordinates are 1976.41 N Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL Dan Willlamson Drilling Manager Thursday, May 13, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Ddve Anchorage, Alaska 99501 Attn: Re: Commissioner David Johnston Application for Permit to Ddll (Form 10-401 ) Swanson River Field Swanson River Unit #43~-15 Commissioner Johnston: Enclosed is the Application for Permit to Drill the SRU #43j~-15 including two copies. This proposed well will be a Tyonek 77-3 sand gas producer sidetracked from an existing vertical wellbore, SRU #43A-15. The existing well has already been abandoned with cement placed above Hemlock perforations in August 1991. The sidetrack has been proposed because there was no primary cement across from the target interval in the existing wellbore. The new well will cement in place a 5" liner which will provide isolation for the target interval from other zones. The proposed sidetrack point in the 7" casing will be at 7300' and the new well will be ddlled to a TD of 8300' MD. The proposed directional plan will result in only 125' of horizontal displacement from the odginal well at 8300' TD. Since the proposed sidetrack is mechanical in nature and horizontal displacement will be minimal, Unocal proposes that single shot directional surveys at no more than 500' MD intervals will be sufficient as per 20 AAC 25.050(a) (1- 2). The proposed SRU #43A-15RD will be less than 1500' from a section line and a spacing exception request has been submitted as per spacing requirements described in 20AAC25.055(a)(3). If there are any questions, please contact Dan Williamson at 263-7677 or Tim Billingsley at 263-7659. Dan Williamson Drilling Manager Unocal Alaska Unocal Corporation P.O. Box 19~247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL( Dan Williamson Drilling Manager Thursday, May 13, 1999 Alaska Oil and Gas Conservation Commission 3001 porcupine Ddve Anchorage, Alaska 99501 . · . Commissioner Johnston: Attn: Re: Commissioner David Johnston Application for Permit to Ddll (Form 10-401 ) Swanson River Field Swanson River Unit #43~-15 Enclosed is the Application for Permit to Drill the SRU #43~-15 'including two copies. This proposed well will be a Tyonek 77-3 sand gas producer sidetracked from an existing vertical wellbore, SRU #43A-15. The existing well has already been abandoned with cement placed above Hemlock perforations in August 1991. The sidetrack has been proposed because there was no pdmary cement across from the target interval in the existing wellbore. The new well will cement in place a 5' liner which will provide isolation for the target interval from other zones. The proposed sidetrack point in the 7" casing will be at 7300' and the new well will be ddlled to a TD of 8300' MD. The proposed directional plan will result in only 125' of horizontal displacement from the odginal well at 8300' TD. Since the proposed sidetrack is mechanical in nature and horizontal displacement will be minimal, Unocal proposes that single shot directional surveys at no more than 500' MD intervals will be sufficient as per 20 AAC 25.050(a) (1- 2). The proposed SRU #43A-15RD will be less than 1500' from a section line and a spacing exception request has been submitted as per spacing requirements described in 20AAC25.055(a)(3). If there are any questions, please contact. Dan Witliamson at 263-7677 or Tim Biilingsley at 263-7659. Sincerely, Dan Williamson Drilling Manager Unocal Alaska i',;::, i;i. ~.i .... .... / I .... . '. . ,1 ,: ......... ,., ,'~: VENDORNO. DATE CHECKNO. 1031548 05-17-99 2003564 I . DATE INVOICE/CREDIT MEMO NO. VOUCHER NO. GROSS DISCOUNT NET 17-MAY-99 DRILLPERMITSRU4]A 05993000236 100.00 100.00 { ~o~^~ ,~ ~oo oo ~oo oo FORM 4-2B181 (REV. 1 1-95) PRINTED IN U.S.A. [)F:"I~4{~H ,c;"l"t f{'.~ Ri-%':!"J.~!.:.: t it-.-i:.'/~:::;{'flr.,il:~, i t li. l :;~ . .. ' ' CITIBANK DELAWARE 62-20 A Subsidiary of Citicorp 311 ONE PENN'S WAY NEW CASTLE, DE 19720 Union Oil Company of California Accounts Payable Field Disbursing UNOCAL~:~ PW One Hundred Dollars And 00 ********************************** 2003564 I'o the ~rder :)f STATE OF ALASKA , ALASKA OIL &GAS CONSERVATION COMMISSION 3001 PORCUPINE DR ANCHORAGE, AK 99501 Date V 17-MAY-99 Check Amount ****100. O0 above date. ~'" WELL PERMIT CHECKLIST COMPANY~/4~".,~// WELL NAME.~,~¢'~' (-'//,~ g'"/,~' __. PROGRAM: exp dev X~ redrll serv wellbore seg ann. disposal para req FIELD & POOL 7 7 GEOL AREA ~;"~ UNIT# .~'/~' .~'~ ON/OFF SHORE t,~3~ ADMINISTRATION 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11 12. 13. ~-_~;"~:;~O INIT CLASS / _t~~-~ / Permit fee attached ...................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. · Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... (.N N Y N (~ N ~.~1~ DATE GEOLOGY 24. Drilling fluid program schematic & equip list adequate ..... ~d~ N 25. BOPEs, do they meet regulation ................ ~ N 26. BOPE press rating appropriate; test to .~"oo~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... ~ N 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N 31. Data presented on potential overpressure zones ....... Y 32. Seismic analysis of shallow gas zones ............. /'7'. 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports [explorator¥9~rly] Y N .~~R D~TE/ ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitab~'eiving zone; ....... Y N (B) will not contaminate fres~tea'ter; or cause drilling Waste... Y N to surface; / / __ (C) will not impair/rpedhan~tegr~f the well used for disposal; Y N (D) will not dama¢~mfition or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLO~,Y: ENGINEERIN<G: UlC/Annular f-" COMMISSION: co c,o ~l~l~ Comments/Instructions: c:\msoffice\wordian\diana\checklist