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ŚŝŐŚ͘'ŽŽĚ͘ZͬdĞƐƚŝŶŐĞƋƵŝƉŵĞŶƚ͘^ĞƌǀŝĐĞƌŝŐ͘DͬhDƵůĞƐŚŽĞĂŶĚϳΖΖƐĐƌĂƉĞƌĂƐƐĞŵďůǇΘZ/,ƉŝĐŬŝŶŐƵƉϯ͘ϱƉŝƉĞ ƚŽϲϮϬϬΖ͘^ĞƌǀŝĐĞƌŝŐ͘ŽŶΖƚZ/,ǁͬĐůĞĂŶŽƵƚĂƐƐǇ͘&ͬϲ͕ϮϬϬΖdͬϭϮ͕ϱϭϵΖ͘dĂŐĂƚϭϮ͕ϱϭϵΖϰŬWͬhŽďƐĞƌǀĞŽǀĞƌƉƵůůŽĨ ϴŬ͘^ĐƌĂƉĞƌĚĞƉƚŚĂƚϭϮ͕ϰϵϬΖƉŽƐƐŝďůǇĂƚƚŽƉŽƌŝŐŝŶĂůƉĞƌĨƐ͘ZŝŐƵƉƚŽƌĞǀĞƌƐĞĐŝƌĐƵůĂƚĞ͘>ŽĂĚǁĞůůŽŶďĂĐŬƐŝĚĞ͕ϭϭďďůƐ ƚŽĨŝůů͘ZĞǀĞƌƐĞĐŝƌĐƵůĂƚĞǁŚŝůĞĂƚƚĞŵƉƚƚŽǁŽƌŬƉĂƐƐŽďƐƚƌƵĐƚŝŽŶ͘WƵŵƉĂƚϯWDϯϱϬͲϯϴϬƉƐŝнϭ͘^ͬKǁƚсϯϯ<͕ WͬhǁƚϭϭϴŬ͕;ƐĞƚĚŽǁŶϱŬͲϲǆͿ͘KǀĞƌƉƵůůŝŶŐĂĨƚĞƌĞĂĐŚƐĞƚĚŽǁŶ͘ϴͲϭϬŬ͘^ĞƚŵƵůĞƐŚŽĞŽŶďŽƚƚŽŵĂƚƚĞŵƉƚƚŽ ĐŝƌĐ͕ŽƵƚĨŝůů͘KŶďŽƚƚŽŵƐƵƉ͕ŵŝŶŝŵĂůƐĂŶĚŽďƐĞƌǀĞĚ͘^ŚƵƚĚŽǁŶƚŽĨŝůůƉŝƚƐǁͬƐƚĂŶĚďǇǀĂĐƚƌƵĐŬ͘ƌĞƚĂŐŽďƐƚƌƵĐƚŝŽŶ ĂƚƐĂŵĞĚĞƉƚŚϭϮ͕ϱϭϵΖǁŝƚŚŽƵƚƉƵŵƉƐ͘^ͬKǁƚсϯϮ<͕WͬhǁƚϭϮϱŬ͕;ƐĞƚĚŽǁŶϰŬͲϰǆͿ͘ŽǀĞƌƉƵůůŝŶŐĂĨƚĞƌĞĂĐŚƐĞƚ ĚŽǁŶ͘ϴͲϭϬŬ͘ŝƌĐƵůĂƚĞĚŽǁŶƚƵďŝŶŐ͕ǁŚŝůĞĂƚƚĞŵƉƚƚŽǁŽƌŬƉĂƐƐŽďƐƚƌƵĐƚŝŽŶ͘WƵŵƉĂƚϯWDϲϯϬƉƐŝ͘^ͬKǁƚс ϯϯ<͕WͬhǁƚϭϭϴŬ͕;ƐĞƚĚŽǁŶϱŬͲϲǆͿ͘KǀĞƌƉƵůůŝŶŐĂĨƚĞƌĞĂĐŚƐĞƚĚŽǁŶϴͲϭϬŬ͘^ĞƚŵƵůĞƐŚŽĞŽŶďŽƚƚŽŵĂƚƚĞŵƉƚƚŽ ĐŝƌĐ͕ŽƵƚĨŝůů͘KŶďŽƚƚŽŵƐƵƉ͕ŵŝŶŝŵĂůƐĂŶĚŽďƐĞƌǀĞĚ͘^ŚƵƚĚŽǁŶƚŽĨŝůůƉŝƚƐǁͬƐƚĂŶĚďǇǀĂĐƚƌƵĐŬ͘ZŝŐĚŽǁŶ ĐŝƌĐƵůĂƚŝŽŶĞƋƵŝƉŵĞŶƚ͘&ŝůůƉŝƚƐǁͬƌĞŵĂŝŶŝŶŐĨůƵŝĚĨƌŽŵƚƌƵĐŬ͘WƌĞƉƚŽWKK,͕ŽďƚĂŝŶĨƌĞĞƌŽƚĂƚŝŶŐdY͘ϰϴϬϬĨƚͬďƐ͕ ďůŽǁĚŽǁŶĂůůůŝŶĞƐ͘ ϭϬͬϭϴͬϮϬϮϮͲdƵĞƐĚĂǇ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW&ͲϬϭ ^Zηϭ ϱϬͲϬϮϵͲϮϮϱϱϮͲϬϬͲϬϬ ϭϵϱͲϰϱ ϭϬͬϭϰͬϮϬϮϮ ϭϬͬϮϯͬϮϬϮϮ ϭϬͬϮϭͬϮϬϮϮͲ&ƌŝĚĂǇ dĞƐƚ^ŚŽŽƚŝŶŐĨůĂŶŐĞŽŶŐƌĞĂƐĞŚĞĂĚƚŽϮϱϬͬϮϱϬϬ͘'ŽŽĚ͘Zͬ'ƌĞĂƐĞŚĞĂĚ͘WƵůůdtĨƌŽŵǁĞůůŚĞĂĚ͘&ŝůůŚŽůĞ͘dŽŽŬϭϬ>͘ W:^D͕ZͬhtŝƌĞůŝŶĞ͕,ĂŶŐƐŚĞĂǀĞĂŶĚďƵŝůĚƚŽŽůƐ͘ƌŝŶŐƚŽĨůŽŽƌĂŶĚƐƚĂďŽŶ͘Z/,ǁŝƚŚϮϬΖ'ƵŶϲ^W&ǁŝƚŚϲϬ'ƉŚĂƐŝŶŐǁŝƚŚ 'ZΘ>͘dŝĞŝŶƚŽϮϬΖ:ŽŝŶƚƐĂƚϭϮϯϰϳΖ͘dĂŐďƚŵĂŶĚůŽŐƵƉƚŽϭϮϭϬϬΖ͘^ĞŶĚůŽŐƐƚŽƚŽǁŶĂŶĚĚĞĐŝƐŝŽŶŵĂĚĞƚŽƉĞƌĨŽƌĂƚĞďƚŵ ϯϮΖĨƌŽŵďƚŵ͕͘&ŝůůŚŽůĞ͘dŽŽŬϯ>͘WƵƚŐƵŶƐŽŶĚĞƉƚŚĂŶĚĨŝƌĞƐŚŽƚƐ͘^ĂǁŐŽŽĚŝŶĚŝĐĂƚŝŽŶŽĨĨŝƌŝŶŐŽŶǁƚĂŶĚǀŝƐƵĂů͘EŽ ƉƌĞƐƐƵƌĞĐŚĂŶŐĞ͘ƚŵ^ŚŽƚϭϮϱϮϰ͘ϳĂŶĚƚŽƉƐŚŽƚϭϮϱϬϰ͘ϳΖ͘WKK,Θ>ͬ'ƵŶƐ͘ůů^ŚŽƚƐĨŝƌĞĚ͘Z/,ǁŝƚŚƚǁŽŐƵŶƐϭϮΖΘϳΖϲ^W& ǁŝƚŚϲϬ'ƉŚĂƐŝŶŐǁŝƚŚ>ΘdŝĞŝŶƚŽϮϬΖŵĂƌŬĞƌũŽŝŶƚƐ͘WƵƚŐƵŶƐŽŶĚĞƉƚŚ͘&ŝƌĞŐƵŶƐ^ĂǁŐŽŽĚŝŶĚŝĐĂƚŝŽŶŽĨĨŝƌŝŶŐŽŶǁƚ ĂŶĚǀŝƐƵĂů͘EŽƉƌĞƐƐƵƌĞĐŚĂŶŐĞ͘ϭϮΖ'ƵŶƚŵƐŚŽƚϭϮϱϬϰΖdŽƉƐŚŽƚϭϮϰϵϮΖ͘ϳΖ'ƵŶƚŵƐŚŽƚϭϮϰϴϲΖdŽƉƐŚŽƚϭϮϰϳϵΖ͘WKK,Θ 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ƵƚƚĞƌƐǁĞƌĞtŽƌŶŽǁŶ͘ZĞĐŽǀĞƌĞĚĂƉŝĞĐĞŽĨĂŶĚůĂŵƉŚĂŶŐŝŶŐŽŶƚŽƚŚĞ,͘ůƐŽƌĞĐŽǀĞƌĞĚƐŽŵĞDŝůůŝŶŐ^ůƵĚŐĞŝŶƚŚĞ ďŽŽƚďĂƐŬĞƚƐ͘^ĞŶĚŝŶŐƚŚĞŽŽƚĂƐŬĞƚƐďĂĐŬƚŽzĞůůŽǁ:ĂĐŬĞƚƚŽďƌĞĂŬĚŽǁŶĐůĞĂŶĂŶĚƌĞƉŽƌƚďĂĐŬǁŝƚŚƚŚĞĨŝŶĚŝŶŐƐ͘WƵůů tĞĂƌƵƐŚŝŶŐ͘/ŶƐƚĂůůdƵďŝŶŐŚĂŶŐĞƌ͘Z/>^͘/ŶƐƚĂůůdt͘ZͬhKWdĞƐƚƋƵŝƉŵĞŶƚ͘&ŝůůKW^ƚĂĐŬǁŝƚŚĨƌĞƐŚǁĂƚĞƌ͘,ĂŶŐĞƌ ŶŽƚŚŽůĚŝŶŐƉƌĞƐƐƵƌĞ͘K>^͘WƵůůdƵďŝŶŐ,ĂŶŐĞƌĨŽƌŝŶƐƉĞĐƚŝŽŶ͘&ŽƵŶĚƚŚĞ,ĂŶŐĞƌďŽĚǇƐĞĂůĚĂŵĂŐĞĚ͘ZĞƉůĂĐĞ^ĞĂůĂŶĚZĞͲ ŝŶƐƚĂůů,ĂŶŐĞƌ͘Z/>^͘dĞƐƚKWĂƐƉĞƌ^ƚĂƚĞĂƉƉƌŽǀĞĚƐƵŶĚƌǇ͘ϮϱϬƉƐŝ͘ůŽǁͬϮϱϬϬƉƐŝŚŝŐŚ͘ůůƚĞƐƚĐŚĂƌƚĞĚĨŽƌϱŵŝŶ͘ĞĂĐŚ͘ tŝƚŶĞƐƐŽĨƚŚĞƚĞƐƚǁĂƐǁĂŝǀĞĚďǇK'ZĞƉ͘ĚĂŵĂƌů͘Eͬ&ůŽǁ>ŝŶĞ^ƉŽŽů͘EͬhϳΗ^ŚŽŽƚŝŶŐ&ůĂŶŐĞ͘ ƚŵ^ŚŽƚϭϮϱϮϰ͘ϳĂŶĚƚŽƉƐŚŽƚϭϮϱϬϰ͘ϳΖ͘WKK,Θ>ͬ'ƵŶƐ͘ůů^ŚŽƚƐĨŝƌĞĚ͘Z/,ǁŝƚŚƚǁŽŐƵŶƐϭϮΖΘϳΖϲ^W& ǁŝƚŚϲϬ'ƉŚĂƐŝŶŐǁŝƚŚ>ΘdŝĞŝŶƚŽϮϬΖŵĂƌŬĞƌũŽŝŶƚƐ͘WƵƚ ŐƵŶƐŽŶĚĞƉƚŚ͘&ŝƌĞŐƵŶƐ^ĂǁŐŽŽĚŝŶĚŝĐĂƚŝŽŶŽĨĨŝƌŝŶŐŽŶǁƚ ĂŶĚǀŝƐƵĂů͘EŽƉƌĞƐƐƵƌĞĐŚĂŶŐĞ͘ϭϮΖ'ƵŶƚŵƐŚŽƚϭϮϱϬϰΖdŽƉƐŚŽƚϭϮϰϵϮΖ͘ϳΖ'ƵŶƚŵƐŚŽƚϭϮϰϴϲΖdŽƉƐŚŽƚϭϮϰϳϵΖ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW&ͲϬϭ ^Zηϭ ϱϬͲϬϮϵͲϮϮϱϱϮͲϬϬͲϬϬ ϭϵϱͲϰϱ ϭϬͬϭϰͬϮϬϮϮ ϭϬͬϮϯͬϮϬϮϮ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ŽŶƚŝŶƵĞƚŽZ/,ǁŝƚŚϮϳͬϴΗ͕h͕ϵ͘ϲη͕>ͲϴϬŽŵƉůĞƚŝŽŶ&ͬϮϰϰΖdͬϲϭϴϴΖD͘/ŶƐƚĂůů^WĂďůĞůĂŵƉŽŶĞǀĞƌǇũŽŝŶƚϭƚŚƌƵϭϬ ĂŶĚĞǀĞƌǇŽƚŚĞƌũŽŝŶƚĂĨƚĞƌƚŚĂƚ͘dĞƐƚ^WĂďůĞǀĞƌǇϭϬϬϬΖ͘WƵŵƉŝŶϱ>^͘ŽĨϴ͘ϱƌŝŶĞǁĂƚĞƌǀĞƌǇ,ŽƵƌĨŽƌ,ŽůĞ&ŝůů͘/ŶƐƚĂůů ZĞĞůƚŽZĞĞů^WĂďůĞ^ƉůŝĐĞϭϬΖƵƉŽŶ:ŽŝŶƚηϭϵϰ;ϲϭϴϴΖDͿ͘dĞƐƚĞĚ^WĂďůĞ'ŽŽĚ͘ŽŶƚŝŶƵĞƚŽZ/,ǁŝƚŚϮϳͬϴΗ͕h͕ ϵ͘ϲη͕>ͲϴϬŽŵƉůĞƚŝŽŶ&ͬϲϴϳϬΖdͬϳϰϳϬΖD͘ĚĚŝƚŝŽŶĂů^ƉůŝĐĞĨƌŽŵZĞĞůηϮ͕ϮϴΖƵƉŽŶũŶƚ͘ηϮϭϱ;ϲϴϳϬΖDͿdĞƐƚŽŶ^WĂďůĞ ǁĂƐŝŶƚĞƌŵŝƚƚĞŶƚ͘ĂůůĞĚŽƵƚƐĞƌǀŝĐĞdĞĐŚĨƌŽŵ<ƵƉĂƌƵŬĂƐǁĞĐŽŶƚŝŶƵĞZ/,dϳϰϳϬΖ͘dƌŽƵďůĞ^ŚŽŽƚ^WdĞƐƚŝŶŐĞƋƵŝƉŵĞŶƚ͕ ůĞĂŶĞĚƵƉĐĂďůĞĐŽŶŶĞĐƚŝŽŶĂŶĚZĞͲdĞƐƚĞĚ'ŽŽĚ͘WƵŵƉŝŶϱ>^͘ǀĞƌǇ,ŽƵƌĨŽƌ,ŽůĞ&ŝůů͘ŽŶƚŝŶƵĞƚŽZ/,ǁŝƚŚϮϳͬϴΗ͕h͕ ϵ͘ϲη͕>ͲϴϬ͘ŽŵƉůĞƚŝŽŶ&ͬϳϰϳϬΖdͬϵϬϬϬΖD͘dĞƐƚŝŶŐ^WĂďůĞĞǀĞƌǇϭϬϬϬΖ͘WƵŵƉŝŶϱ>^͘ŽĨϴ͘ϱƉƉŐƌŝŶĞǀĞƌǇ,ŽƵƌĨŽƌ ,ŽůĞ&ŝůů͘ ϭϬͬϮϮͬϮϬϮϮͲ^ĂƚƵƌĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϭϬͬϮϱͬϮϬϮϮͲdƵĞƐĚĂǇ ϭϬͬϮϯͬϮϬϮϮͲ^ƵŶĚĂǇ ŽŶƚŝŶƵĞƚŽZ/,ǁŝƚŚϮϳͬϴΗ͕h͕ϵ͘ϲη͕>ͲϴϬŽŵƉůĞƚŝŽŶ&ͬϵϬϬϬΖdͬϭϮϭϲϬΖ͘Wͬh'>DηϮǁŝƚŚŽƌŝĨŝĐĞŝŶƐƚĂůůĞĚ͘ D͘dĞƐƚŝŶŐ^WĂďůĞĞǀĞƌǇϭϬϬϬΖ͘WƵŵƉŝŶϱ>^͘ŽĨϴ͘ϱƉƉŐƌŝŶĞǀĞƌǇ,ŽƵƌĨŽƌ,ŽůĞ&ŝůů͘ŽŶƚŝŶƵĞƚŽZ/,ǁŝƚŚϮϳͬϴΗ͕h͕ ϵ͘ϲη͕>ͲϴϬŽŵƉůĞƚŝŽŶ&ͬϭϮϭϲϬΖdͬϭϮϯϭϵΖ͘Dͬh,ĂŶŐĞƌĂŶĚůĂŶĚŝŶŐũŽŝŶƚǁŝƚŚWsŝŶƐƚĂůůĞĚ͘dĞƌŵŝŶĂƚĞ^WůŝŶĞĂŶĚŵĂŬĞ ƉĞŶĞƚƌĂƚŽƌƐƉůŝĐĞ͘dĞƐƚ'ŽŽĚ͘Z/,Θ>ĂŶĚŚĂŶŐĞƌǁŝƚŚϮϴ<͘>ĂŶĚǁŝƚŚĐŽƌĚĂŶĚƚĞƐƚĐĂďůĞŐŽŽĚ͘ Z/>͘hWͬE͘EͬϮϴ<͘ ϭϬͬϮϰͬϮϬϮϮͲDŽŶĚĂǇ ŽŶƚŝŶƵĞƚŽZ/,ǁŝƚŚϮϳͬϴΗ͕h͕ ϵ͘ϲη͕>ͲϴϬŽŵƉůĞƚŝŽŶ&ͬϭϮϭϲϬΖdͬϭϮϯϭϵΖ͘Dͬh,ĂŶŐĞƌĂŶĚůĂŶĚŝŶŐũŽŝŶƚǁŝƚŚWsŝŶƐƚĂůůĞĚ͘dĞƌŵŝŶĂƚĞ^WůŝŶĞĂŶĚŵĂŬĞ ƉĞŶĞƚƌĂƚŽƌƐƉůŝĐĞ͘dĞƐƚ'ŽŽĚ͘Z/,Θ>ĂŶĚŚĂŶŐĞƌǁŝƚŚϮϴ< ŽŶƚŝŶƵĞƚŽZ/,ǁŝƚŚϮϳͬϴΗ͕h͕ϵ͘ϲη͕>ͲϴϬŽŵƉůĞƚŝŽŶ&ͬϵϬϬϬΖdͬϭϮϭϲϬΖ ŽŶƚŝŶƵĞƚŽZ/,ǁŝƚŚϮϳͬϴΗ͕h͕ ϵ͘ϲη͕>ͲϴϬŽŵƉůĞƚŝŽŶ&ͬϲϴϳϬΖdͬϳϰϳϬΖD͘ ŽŶƚŝŶƵĞƚŽZ/,ǁŝƚŚϮϳͬϴΗ͕h͕ ϵ͘ϲη͕>ͲϴϬ͘ŽŵƉůĞƚŝŽŶ&ͬϳϰϳϬΖdͬϵϬϬϬΖD͘ Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/4/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221104 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU H-18 50029232240000 204174 10/2/2022 READ COILFLAG MPU F-01 50029225520000 195045 10/9/2022 READ CaliperSurvey MPU F-62A 50029226090100 220066 10/12/2022 READ CaliperSurvey MPU B-35 50029237240000 222085 10/17/2022 READ CaliperSurvey Please include current contact information if different from above. T37230 T37231 T27239 T37232 MPU F-01 50029225520000 195045 10/9/2022 READ CaliperSurvey Kayla Junke Digitally signed by Kayla Junke Date: 2022.11.07 16:21:15 -09'00' 1 Regg, James B (OGC) From:Sloan Sunderland <ssunderland@hilcorp.com> Sent:Friday, October 21, 2022 2:10 PM To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay Cc:Taylor Wellman; Alaska NS - ASR - Well Site Managers; Alaska NS - ASR - Toolpushers Subject:Hilcorp ASR#1 BOP Test MPU F-01 10-21-2022 Attachments:F-01 BOPE test report 10-21-22.xlsx See Attached Report Sloan Sunderland Hilcorp Alaska LLC Sr Drilling Forman Cookinlet Offshore Office 685‐1266 Cell Phone 907‐715‐0591 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Milne Point Unit F-01PTD 1950450 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:ASR 1 DATE:10/21/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #1950450 Sundry #322-512 Operation:Drilling:Workover:x Explor.: Test:Initial:Weekly:X Bi-Weekly:Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:2319 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators P P #1 Rams 1 2 7/8" x 5"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 2 1/16"P Time/Pressure Test Result HCR Valves 1 2 1/16"P System Pressure (psi)3000 P Kill Line Valves 2 2 1/16"P Pressure After Closure (psi)1700 P Check Valve 0 NA 200 psi Attained (sec)14 P BOP Misc 0 NA Full Pressure Attained (sec)48 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 / 2200 PSI P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 27 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0 NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:5.0 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 10/19/22 06:07 Waived By Test Start Date/Time:10/20/2022 23:00 (date)(time)Witness Test Finish Date/Time:10/21/2022 4:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Hilcorp Test preformed w/ 2-7/8" test joint. Bottle precharge pressure 1000 psi. J.Haberthur / C. Greub Hilcorp Alaska LLC S.Sunderland/ C. Huntington MPU F-01 Test Pressure (psi): askans-asr-toolpushers@hilcorp.co ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022)2022-1021_BOP_Hilcorp ASR1_MPU_F-01           J. Regg; 11/25/2022 From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:BOP - Hilcorp ASR1 Date:Friday, November 25, 2022 12:13:21 PM Attachments:2022-1021_BOP_Hilcorp ASR1_MPU_F-01.pdf MPU F-01 (PTD 1950450) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20221020 0800 Approval MPU F-01 (PTD 195-045) Sundry #322-512 Re-Perf Request Date:Thursday, October 20, 2022 8:43:25 AM From: Rixse, Melvin G (OGC) Sent: Thursday, October 20, 2022 8:40 AM To: Taylor Wellman <twellman@hilcorp.com> Subject: RE: MPU F-01 (PTD 195-045) Sundry #322-512 Re-Perf Request Taylor, Hilcorp is approved to perforate as described in your email request below. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Taylor Wellman <twellman@hilcorp.com> Sent: Wednesday, October 19, 2022 9:38 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: MPU F-01 (PTD 195-045) Sundry #322-512 Re-Perf Request Mr. Rixse, The approved Sundry 322-512 for MPU F-01 (PTD 195-045) included adding perforations to the Kuparuk A1B sands (12,578’-12,610’ MD) and the Kuparuk A3 sands (12,479’-12,486’ MD). E-Line tagged fill at ±12,546’ MD. An attempt to clean out below this depth was unsuccessful. We are unable to reach the bottom approved add perforations. We would like to request re-perforating the lowest interval that is reachable. This would be ±12,516’ - 12,546’ MD. Included is the proposed schematic from before for a visual reference for the perf intervals. I’ll follow up with you in the morning as current operations are TOOH w/ the clean out assembly and it would be good to confirm the scope of the next move. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC – Ops Engineer: Milne Point Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: MPU F-01 (PTD 195-045) Sundry 322-512 - Add Scraper Run Date:Monday, October 17, 2022 2:49:29 PM Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (OGC) Sent: Monday, October 17, 2022 2:46 PM To: Taylor Wellman <twellman@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: MPU F-01 (PTD 195-045) Sundry 322-512 - Add Scraper Run AOGCC does not need any additional information and does not intend to pursue any enforcement action. Good decision to pull back and test before proceeding with well work. Hilcorp is encouraged to remind crews about the requirement to test VBR with the smallest and largest pipe OD tubulars that may be used during the BOPE test cycle – the regulatory intent is to test before entry in the wellbore. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Taylor Wellman <twellman@hilcorp.com> Sent: Monday, October 17, 2022 9:01 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: FW: MPU F-01 (PTD 195-045) Sundry 322-512 - Add Scraper Run Mr. Rixse and Mr. Regg, The planned and approved operations on MPU MPU F-01 (PTD 195-045) under Sundry 322-512 was to pull the failed ESP and add perforations via E-Line. E-Line tagged high at 12,508’ md (midway through the existing perforations). The decision to rig down E-Line and add a clean out run was made. We picked up a 3-1/2” workstring to perform the clean out run and ran to a depth of 950’ md. At this point it was recognized that our VBR’s were only tested for 2-7/8” pipe. We pulled out of hole and a test of 3-1/2” rams was performed. I wanted to reach out to you to inform you of this and am ready to discuss this when you have time. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC – Ops Engineer: Milne Point Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Regg, James B (OGC) From:Russell Gallen - (C) <Russell.Gallen@hilcorp.com> Sent:Saturday, October 15, 2022 8:05 PM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Alaska NS - ASR - Well Site Managers Subject:F-01 BOPE test report Attachments:F-01 BOPE test report (initial ).xlsx Thank you. Regards, Russell Gallen ASR DSM, Mobile: 907-529-7202 Office: 907-685-1266 russell.gallen@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Some people who received this message don't often get email from russell.gallen@hilcorp.com. Learn why this is important CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. MPU F-01 PTD 1950450 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:ASR 1 DATE:10/14/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #1950450 Sundry #322-512 Operation:Drilling:Workover:x Explor.: Test:Initial:x Weekly:Bi-Weekly:Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:2319 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators P P #1 Rams 1 2 7/8" x 5"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 2 1/16"P Time/Pressure Test Result HCR Valves 1 2 1/16"P System Pressure (psi)3000 P Kill Line Valves 2 2 1/16"FP Pressure After Closure (psi)1760 P Check Valve 0 NA 200 psi Attained (sec)14 P BOP Misc 0 NA Full Pressure Attained (sec)53 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 / 2200 PSI P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 26 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0 NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:1 Test Time:5.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 10/13/22 07:12 Waived By Test Start Date/Time:10/14/2022 16:30 (date)(time)Witness Test Finish Date/Time:10/14/2022 21:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Hilcorp Test performed w/ 2-7/8" test joint. Test # 2 slow drip on non BOPE equipment "test pump" bled off low psi test & tighten fitting. Retested (good). Test # 3 Fail / Pass on K2 - Slow leak on high, bled off. Grease kill line valve "K2" & retested (good) Bottle precharge pressure 1000 psi. J.Haberthur / J. Werlinger Hilcorp Alaska LLC S.Sunderland/ R. Gallen MPU F-01 Test Pressure (psi): askans-asr-toolpushers@hilcorp.co ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022)2022-1014_BOP_Hilcorp_ASR1_MPU_F-01            J. Regg; 11/21/2022 From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:BOP - Hilcorp ASR1 Date:Monday, November 21, 2022 4:48:54 PM Attachments:2022-1014_BOP_Hilcorp_ASR1_MPU_F-01.pdf MPU F-01 (PTD 1950450) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 7\SHRI5HTXHVW $EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 5HSDLU:HOO 2SHUDWLRQVVKXWGRZQ 6XVSHQG 3HUIRUDWH 2WKHU6WLPXODWH 3XOO7XELQJ &KDQJH$SSURYHG3URJUDP 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 5HHQWHU6XVS:HOO $OWHU&DVLQJ 2WKHU(63&KDQJHRXW 2SHUDWRU1DPH &XUUHQW:HOO&ODVV 3HUPLWWR'ULOO1XPEHU ([SORUDWRU\ 'HYHORSPHQW $GGUHVV6WUDWLJUDSKLF 6HUYLFH $3,1XPEHU ,ISHUIRUDWLQJ:HOO1DPHDQG1XPEHU :KDW5HJXODWLRQRU&RQVHUYDWLRQ2UGHUJRYHUQVZHOOVSDFLQJLQWKLVSRRO" :LOOSODQQHGSHUIRUDWLRQVUHTXLUHDVSDFLQJH[FHSWLRQ" <HV 1R 3URSHUW\'HVLJQDWLRQ/HDVH1XPEHU )LHOG3RROV 7RWDO'HSWK0'IW 7RWDO'HSWK79'IW (IIHFWLYH'HSWK0' (IIHFWLYH'HSWK79' 0363SVL 3OXJV0' -XQN0' 1$ &DVLQJ &ROODSVH &RQGXFWRU 1$ 6XUIDFH SVL 3URGXFWLRQ SVL 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ZhzĞůůŽǁ:ĂĐŬĞƚϳ͟ƐŚŽŽƚŝŶŐĨůĂŶŐĞǁŝƚŚϳ͛͛ƋƵŝĐŬƚĞƐƚƐƵď͘ PJU 5LVNDVVHVVZKHWKHUSUHVVXUHXQGHU&76SOXJWRDVVXUHQR OXEULFDWRUUHTXLUHG ^W^ǁĂƉ tĞůů͗DWh&ͲϬϭ ĂƚĞ͗ϬϴͬϮϮͬϮϬϮϮ Ă͘ ŶĐŚŽƌƚŽƚŚĞƚŽƉŽĨƚŚĞKWƐƚĂĐŬ ď͘ /ŶƐƚĂůůϲ͛͛ƚĞƐƚƉůƵŐŽƌŚĂŶŐĞƌǁŝƚŚdt͘ Đ͘ ZŝŐƵƉ>/EW Ě͘ WƌĞƐƐƵƌĞƚĞƐƚƚŽϯϬϬƉƐŝůŽǁĂŶĚϮ͕ϱϬϬƉƐŝŚŝŐŚ Ğ͘ ƌĞĂŬϳ͛͛ƋƵŝĐŬƚĞƐƚƐƵďĐŽŶŶĞĐƚŝŽŶ Ĩ͘ WƵůůϲ͛͛ƚĞƐƚƉůƵŐŽƌŚĂŶŐĞƌǁŝƚŚdt͘ ϭϴ͘ WhϯͲϯͬϴ͕͟ϲ^W&ŽƌϮͲϳͬϴ͕͟ϮͲϯͬϰ͕͟Ϯ͟'ƵŶƐ͘ ϭϵ͘ DhŐƵŶƐƚŽZ/,ǁŝƚŚ>/EĂŶĚŝŶƐƚĂůůƐŚŽŽƚŝŶŐĨůĂŶŐĞĨŽƌƉƌ ĞƐƐƵƌĞĐŽŶƚƌŽůǁŚŝůĞƐŚŽŽƚŝŶŐ͘ ϮϬ͘ sĞƌŝĨǇƚŚĞǁĞůůŝƐƐƚĂƚŝĐ͘>ŽĂĚǁĞůůƚŽƐƵƌĨĂĐĞƉƌŝŽƌƚŽƐŚŽŽƚŝŶŐ Ϯϭ͘ WĞƌĨƚŚĞďĞůŽǁŝŶƚĞƌǀĂůƐ͗ Ă͘ ŽŶƚĂĐƚ'ĞŽůŽŐŝƐƚʹ:ŽŚŶ^ĂůƐďƵƌǇʹϵϬϳͲϯϱϬͲϭϬϴϴ;ĐͿŽƌϵϬϳͲϳϳϳͲϴϰϴϭƚŽĐŽŶĨŝƌŵ ĐŽƌƌĞůĂƚŝŽŶĚĞƉƚŚ͘ ŝ͘ WĞƌĨŽƌĂƚŝŽŶ/ŶƚĞƌǀĂůϭ͗цϭϮ͕ϱϳϴ͛ʹцϭϮ͕ϲϭϬ͛;ϯϮ͛Ϳʹ<ƵƉĂƌƵŬϭƐĂŶĚƐ ŝŝ͘ WĞƌĨŽƌĂƚŝŽŶ/ŶƚĞƌǀĂůϮ͗цϭϮ͕ϰϳϵ͛ʹцϭϮ͕ϰϴϲ͛;ϯϮ͛Ϳʹ<ƵƉĂƌƵŬϯƐĂŶĚƐ ϮϮ͘ &ůŽǁĐŚĞĐŬƚŚĞǁĞůů͘ŽŶĨŝƌŵƚŚĞǁĞůůŝƐĚĞĂĚ͕ƵůůŚĞĂĚƚŽŬŝůůƚŚĞǁĞůůĂƐŶĞĞĚĞĚ͘;EŽƚĞ͗<ƵƉĂƌƵŬ ϭĂŶĚϯĂƌĞĂŶƚŝĐŝƉĂƚĞĚƚŽďĞŶŽƌŵĂůƉƌĞƐƐƵƌĞĚϴ͘ϱƉƉŐĞƋƵŝǀĂůĞŶƚĂŶĚƚŝŐŚƚ͘Ϳ Ă͘ ŽŶƚŝŶŐĞŶĐǇͲ/ĨǁĞůůĐĂŶŶŽƚďĞŬŝůůǁŝƚŚ^ZƉƵŵƉƐ͘ZŝŐƵƉĂ ƵǆŝůŝĂƌǇĞƋƵŝƉŵĞŶƚƚŽĂůůŽǁ ǁĞůůƐŬŝůůĂƚϳнWD ď͘ ƵůůŚĞĂĚϭ͘ϱƚƵďŝŶŐǀŽůŽĨϴ͘ϴƉƉŐEĂů Đ͘ ƐƚĂďůŝƐŚĨŝůůƌĂƚĞĂŶĚŵĂŝŶƚĂŝŶŚŽůĞĨŝůů Ϯϯ͘ WKK,ĂŶĚZ>ĂŶĚƐŚŽŽƚŝŶŐĨůĂŶŐĞ͘ Ϯϰ͘ Dh^ƉŽŽůĞƌƚŽƌƵŶ^WĐĂďůĞ͘ Ϯϱ͘ WhŶĞǁ^WĂŶĚZ/,ŽŶϮͲϳͬϴ͟ϲ͘ϱη>ͲϴϬƚƵďŝŶŐ͘ŚĞĐŬĞůĞĐƚƌŝĐĂůĐŽŶŶĞĐƚŝŽŶƐĞǀĞƌǇϮ͕ϬϬϬ͛ Ă͘ ĂƐĞŽĨ^WĂƚцϭϮ͕ϯϰϯ͛D ď͘ ϭũŽŝŶƚƐŽĨϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ )0&´ ´. . ^W^ǁĂƉ tĞůů͗DWh&ͲϬϭ ĂƚĞ͗ϬϴͬϮϮͬϮϬϮϮ Đ͘ ϮͲϳͬϴ͟yE;Ϯ͘ϮϬϱ͟EŽͲ'ŽͿEŝƉƉůĞ Ě͘ ϯũŽŝŶƚƐŽĨϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Ğ͘ >ŽǁĞƌϮͲϳͬϴ͟ǆϭ͟^ŝĚĞͲƉŽĐŬĞƚ'>D ǁŝƚŚƵŵŵǇ'>s Ĩ͘ DƵůƚŝƉůĞũŽŝŶƚƐϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Ő͘ hƉƉĞƌϮͲϳͬϴ͟ǆϭ͟^ŝĚĞͲƉŽĐŬĞƚ'>DΛцϮϬϬ͛DǁŝƚŚϬ͘Ϯϱ͟Ks Ś͘ цϱũŽŝŶƚƐϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Ϯϲ͘ >ĂŶĚƚƵďŝŶŐŚĂŶŐĞƌĂŶĚůĂǇĚŽǁŶůĂŶĚŝŶŐũŽŝŶƚ͘EŽƚĞWh;WŝĐ ŬhƉͿĂŶĚ^K;^ůĂĐŬKĨĨͿǁĞŝŐŚƚƐŽŶ ƚĂůůǇ͘ Ϯϳ͘ ^ĞƚWs͘ WŽƐƚͲZŝŐWƌŽĐĞĚƵƌĞ;EŽŶͲ^ƵŶĚƌŝĞĚƐƚĞƉƐͿ͗ tĞůů^ƵƉƉŽƌƚ ϭ͘ ZŵƵĚďŽĂƚ͘DŽǀĞƚŽŶĞǆƚǁĞůůůŽĐĂƚŝŽŶ͘ Ϯ͘ ZhĐƌĂŶĞ͘EKW͘^Ğƚd^ƉůƵŐ͘ ϯ͘ EhƚƌĞĞĂŶĚƚƵďŝŶŐŚĞĂĚĂĚĂƉƚĞƌ͘ ϰ͘ dĞƐƚďŽƚŚƚƌĞĞĂŶĚƚƵďŝŶŐŚĂŶŐĞƌǀŽŝĚƚŽϱϬϬƉƐŝůŽǁͬϱ͕ϬϬϬƉƐŝŚŝŐŚ͘ ϱ͘ WƵůůd^ƉůƵŐΘWs͘ ϲ͘ ZĐƌĂŶĞ͘DŽǀĞϱϬϬďďůƌĞƚƵƌŶƐƚĂŶŬĂŶĚƌŝŐŵĂƚƐƚŽŶĞǆƚǁĞůůůŽĐĂƚŝŽŶ͘ ϳ͘ ZĞƉůĂĐĞŐĂƵŐĞ;ƐͿŝĨƌĞŵŽǀĞĚ͘ ϴ͘ dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ͘ZhǁĞůůŚŽƵƐĞĂŶĚĨůŽǁůŝŶĞƐĨŽƌĂ:ĞƚWƵŵƉĐŽŵƉůĞƚŝŽŶ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ KW^ĐŚĞŵĂƚŝĐ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϮͬϴͬϮϬϭϴ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DW&ͲϬϭ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭͬϭϴͬϮϬϭϴ Wd͗ϭϵϱͲϬϰϱ dс ϭϮ͕ϵϰϭ͛;DͿͬdсϳ͕ϯϯϰ͛;dsͿ ϮϬ´ KƌŝŐ͘<Ͳ&сϯϯ͘Ϭϯ͛ͬKƌŝŐ͘'>ůĞǀ͘сϭϯ͘ϭ ϳ͟ ϵͲϱͬϴ͟ ϯͬϴ͟^^ĂƉƐƚƌŝŶŐ $ 6DQGV Wdс ϭϮ͕ϴϯϳ͛;DͿͬWdсϳ͕Ϯϱϱ͛;dsͿ dǁŽϮϬ͛ŵĂƌŬĞƌ ũŽŝŶƚƐůŽĐĂƚĞĚ ĨƌŽŵϭϮ͕ϯϰϰ͛ƚŽ ϭϮ͕ϯϴϱǁůŵ͘ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ ƌŝĨƚ/ dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϭ͘ϭͬEdϴϬ>,ͬEͬ Eͬ ^ƵƌĨĂĐĞ ϭϭϬΖ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬƚƌĐ͘ ϴ͘ϲϳϵ ^ƵƌĨĂĐĞ ϳ͕ϭϮϰ͛ ϳΗ WƌŽĚƵĐƚŝŽŶ Ϯϲͬ>ͲϴϬͬƚƌĐ ϲ͘ϭϱϭ ^ƵƌĨĂĐĞ ϭϮ͕ϵϮϮΖ dh/E'd/> ϮͲϳͬϴΗ dƵďŝŶŐ ϲ͘ϰͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϯϰϳ ^ƵƌĨĂĐĞ ϭϮ͕ϯϰϳ͛ ϯͬϴ͟ ĂƉƐƚƌŝŶŐ ^ƚĂŝŶůĞƐƐ^ƚĞĞů Eͬ ^ƵƌĨĂĐĞ ϭϮ͕ϯϰϳ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ ϭϰϬ͛ ĂŵĐŽϮϳͬϴyϭΖΖ^ŝĚĞƉŽĐŬĞƚ͕tͬKƌŝĨŝĐĞ Ϯ ϭϮ͕ϭϬϬ͛ ĂŵĐŽϮϳͬϴyϭΖΖ^ŝĚĞƉŽĐŬĞƚ͕tͬƵŵŵǇ ϯ ϭϮ͕Ϯϳϲ͛ ϮͲϳͬϴΗyEEŝƉƉůĞͲ Ϯ͘ϮϬϱEŽͲ'Ž ϰ ϭϮ͕Ϯϴϳ͛ ŝƐĐŚĂƌŐĞ,ĞĂĚ͗'W/^ ϱ ϭϮ͕Ϯϴϴ͛ WƵŵƉ͗ϭϬϬWϯϭ^y ϲ ϭϮ͕ϯϬϳ͛ 'ĂƐ^ĞƉĂƌĂƚŽƌ͗'Z^&ZEZ ϳ ϭϮ͕ϯϭϬ͛ hƉƉĞƌƚĂŶĚĞŵ^ĞĂů͗ '^ϯhd^ͬ^W&^ ϴ ϭϮ͕ϯϭϳ͛ >ŽǁĞƌƚĂŶĚĞŵ^ĞĂů͗'^ϯ>d^ͬ^W&^>ϱ ϵ ϭϮ͕ϯϮϯ͛ DŽƚŽƌ͗yWʹϯϬϬ,Ɖͬϯ͕ϲϮϬsͬϱϭ ϭϬ ϭϮ͕ϯϰϯ͛ tĞůů>ŝĨƚ^ĞŶƐŽƌǁͬĞŶƚƌĂůŝǌĞƌʹ ŽƚƚŽŵΛϭϮ͕ϯϰϳ͛ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ <ƵƉ͘ϯ͕ϮΘ ϭ^ĂŶĚƐ ϭϮ͕ϰϴϴ͛ ϭϮ͕ϱϳϴ͛ ϲ͕ϵϵϮ͛ ϳ͕Ϭϱϵ͛ ϵϬ͛ ϭϬͬϮϮͬϭϵϵϱ KƉĞŶ EŽƚĞ͗:ƵŵďŽ:ĞƚWĞƌĨŽƌŵĂŶĐĞ͗ddWсϲ͘ϰΗ͕,сϬ͘ϳϲΗ͘ϯ͘ϯϴΗ'ƵŶŝĂŵƚĞƌ͕ϲƐƉĨ͘ KWE,K>ͬDEdd/> ϮϬΗ ŵƚǁͬϮϱϬƐŬƐŽĨƌĐƚŝĐƐĞƚ/ŝŶϯϬ͟,ŽůĞ ϵͲϱͬϴΗ ŵƚǁͬϭ͕ϯϲϰƐŬƐW&͕͟͞ϮϱϬƐǆůĂƐƐ͞'͕͟ϮϱϬƐǆW&͚͛ŝŶϭϮͲϭͬϰ͟,ŽůĞ ϳ͟ ŵƚǁͬϮϮϬƐŬƐůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟,ŽůĞ t>>/E>/Ed/KE d/> <KWΛϲϬϬ͛D DĂǆ,ŽůĞŶŐůĞсϲϵĚĞŐĨͬϳ͕ϴϬϬ͛ƚŽϴ͕ϮϬϬ͛ DĂǆĂŶŐůĞΛ^WсϰϱĚĞŐ͘ ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϲϴĚĞŐ͘ t>>^d/Dh>d/KEd/> ϳͬϭϵϵϱʹϭϯϵ͕ϳϱϬηŽĨϭϲͬϮϬĂƌďŽůŝƚĞ͘ dZΘt>>, dƌĞĞ &DϮͲϵͬϭϲ͟ͲϱD tĞůůŚĞĂĚ ϭϭ͟ϱD&DǁͬϮͲϳͬϴ͟&DƚƵďŝŶŐŚĂŶŐĞƌ͕hůŝĨƚ ƚŚƌĞĂĚƐ͕Ϯ͘ϱ͟/t,WsƉƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϱϱϮͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇEĂďŽƌƐϰͲ^ͲϰͬϮϴͬϭϵϵϱ ^WŽŵƉůĞƚŝŽŶďǇEĂďŽƌƐϰͲ^ʹϭϬͬϮϱͬϭϵϵϱ ^WŚĂŶŐĞŽƵƚďǇEĂďŽƌƐϰͲ^ʹϰͬϭϭͬϭϵϵϴ ^WŚĂŶŐĞŽƵƚďǇEĂďŽƌƐϰͲ^ʹϭϭͬϭϴͬϮϬϬϯ ^WŚĂŶŐĞŽƵƚďǇEĂďŽƌƐϯ^ʹϳͬϭϮͬϮϬϬϴ ^WŚĂŶŐĞŽƵƚďǇEĂďŽƌƐϯ^ʹϵͬϳͬϮϬϬϴ ^WŚĂŶŐĞŽƵƚďǇEŽƌĚŝĐϯʹϯͬϭϳͬϮϬϭϱ ^WŚĂŶŐĞŽƵƚďǇ^ZηϭʹϮͬϭϴͬϮϬϭϴ EKd^͗ EĞĞĚĞŵĞŶƚŝŶŐZĞƉŽƌƚƚŽƐƚĂďůŝƐŚdŽƉƐ &KǁͬZŝŐƚŽϭϮ͕ϲϲϰ͛ϳͬϭϬͬϮϬϬϴ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϴͬϮϱͬϮϬϮϮ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DW&ͲϬϭ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭͬϭϴͬϮϬϭϴ Wd͗ϭϵϱͲϬϰϱ dсϭϮ͕ϵϰϭ͛;DͿͬdсϳ͕ϯϯϰ͛;dsͿ ϮϬ´ KƌŝŐ͘<Ͳ&сϯϯ͘Ϭϯ͛ͬKƌŝŐ͘'>ůĞǀ͘сϭϯ͘ϭ ϳ͟ ϵͲϱͬϴ͟ ϯͬϴ͟^^ĂƉƐƚƌŝŶŐ $ 6DQGV Wdс ϭϮ͕ϴϯϳ͛;DͿͬWdсϳ͕Ϯϱϱ͛;dsͿ dǁŽϮϬ͛ŵĂƌŬĞƌ ũŽŝŶƚƐůŽĐĂƚĞĚ ĨƌŽŵϭϮ͕ϯϰϰ͛ƚŽ ϭϮ͕ϯϴϱǁůŵ͘ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ ƌŝĨƚ/ dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϭ͘ϭͬEdϴϬ>,ͬEͬ Eͬ ^ƵƌĨĂĐĞ ϭϭϬΖ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬƚƌĐ͘ ϴ͘ϲϳϵ ^ƵƌĨĂĐĞ ϳ͕ϭϮϰ͛ ϳΗ WƌŽĚƵĐƚŝŽŶ Ϯϲͬ>ͲϴϬͬƚƌĐ ϲ͘ϭϱϭ ^ƵƌĨĂĐĞ ϭϮ͕ϵϮϮΖ dh/E'd/> ϮͲϳͬϴΗ dƵďŝŶŐ ϲ͘ϰͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϯϰϳ ^ƵƌĨĂĐĞ ϭϮ͕ϯϰϳ͛ ϯͬϴ͟ ĂƉƐƚƌŝŶŐ ^ƚĂŝŶůĞƐƐ^ƚĞĞů Eͬ ^ƵƌĨĂĐĞ ϭϮ͕ϯϰϳ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ цϭϰϬ͛ '>DηϮ͗ϮϳͬϴyϭΖΖ^ŝĚĞƉŽĐŬĞƚ͕tͬKƌŝĨŝĐĞ Ϯ цϭϮ͕ϭϬϬ͛ '>Dηϭ͗ϮϳͬϴyϭΖΖ^ŝĚĞƉŽĐŬĞƚ͕tͬƵŵŵǇ ϯ цϭϮ͕Ϯϳϲ͛ ϮͲϳͬϴΗyEEŝƉƉůĞͲϮ͘ϮϬϱEŽͲ'Ž ϰ цϭϮ͕Ϯϴϳ͛ ŝƐĐŚĂƌŐĞ,ĞĂĚ͗ ϱ цϭϮ͕Ϯϴϴ͛ WƵŵƉ͗ ϲ цϭϮ͕ϯϬϳ͛ 'ĂƐ^ĞƉĂƌĂƚŽƌ͗ ϳ цϭϮ͕ϯϭϬ͛ hƉƉĞƌƚĂŶĚĞŵ^ĞĂů͗ ϴ цϭϮ͕ϯϭϳ͛ >ŽǁĞƌƚĂŶĚĞŵ^ĞĂů͗ ϵ цϭϮ͕ϯϮϯ͛ DŽƚŽƌ͗ ϭϬ цϭϮ͕ϯϰϯ͛ tĞůů>ŝĨƚ^ĞŶƐŽƌǁͬĞŶƚƌĂůŝǌĞƌʹŽƚƚŽŵΛцϭϮ͕ϯϰϳ͛ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ <ƵƉ͘ϭ цϭϮ͕ϰϳϵ͛ цϭϮ͕ϰϴϲ͛ цϲ͕ϵϴϲ͛ цϲ͕ϵϵϭ͛ цϳ &ƵƚƵƌĞ WĞŶĚŝŶŐ <ƵƉ͘ϯ͕ϮΘϭ ϭϮ͕ϰϴϴ͛ ϭϮ͕ϱϳϴ͛ ϲ͕ϵϵϮ͛ ϳ͕Ϭϱϵ͛ ϵϬ͛ ϭϬͬϮϮͬϭϵϵϱ KƉĞŶ <ƵƉ͘ϯ цϭϮ͕ϱϳϴ͛ цϭϮ͕ϲϭϬ͛ цϳ͕Ϭϱϵ͛ цϳ͕Ϭϴϯ͛ цϯϮ &ƵƚƵƌĞ WĞŶĚŝŶŐ EŽƚĞ͗:ƵŵďŽ:ĞƚWĞƌĨŽƌŵĂŶĐĞ͗ddWсϲ͘ϰΗ͕,сϬ͘ϳϲΗ͘ϯ͘ϯϴΗ'ƵŶŝĂŵƚĞƌ͕ϲƐƉĨ͘ KWE,K>ͬDEdd/> ϮϬΗ ŵƚǁͬϮϱϬƐŬƐŽĨƌĐƚŝĐƐĞƚ/ŝŶϯϬ͟,ŽůĞ ϵͲϱͬϴΗ ŵƚǁͬϭ͕ϯϲϰƐŬƐW&͕͟͞ϮϱϬƐǆůĂƐƐ͞'͕͟ϮϱϬƐǆW&͚͛ŝŶϭϮͲϭͬϰ͟,ŽůĞ ϳ͟ ŵƚǁͬϮϮϬƐŬƐůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟,ŽůĞ t>>/E>/Ed/KEd/> <KWΛϲϬϬ͛D DĂǆ,ŽůĞŶŐůĞсϲϵĚĞŐĨͬϳ͕ϴϬϬ͛ƚŽϴ͕ϮϬϬ͛ DĂǆĂŶŐůĞΛ^WсϰϱĚĞŐ͘ ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϲϴĚĞŐ͘ t>>^d/Dh>d/KEd/> ϳͬϭϵϵϱʹϭϯϵ͕ϳϱϬηŽĨϭϲͬϮϬĂƌďŽůŝƚĞ͘ dZΘt>>, dƌĞĞ &DϮͲϵͬϭϲ͟ͲϱD tĞůůŚĞĂĚ ϭϭ͟ϱD&DǁͬϮͲϳͬϴ͟&DƚƵďŝŶŐŚĂŶŐĞƌ͕hůŝĨƚ ƚŚƌĞĂĚƐ͕Ϯ͘ϱ͟/t,WsƉƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϱϱϮͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇEĂďŽƌƐϰͲ^ͲϰͬϮϴͬϭϵϵϱ ^WŽŵƉůĞƚŝŽŶďǇEĂďŽƌƐϰͲ^ʹϭϬͬϮϱͬϭϵϵϱ ^WŚĂŶŐĞŽƵƚďǇEĂďŽƌƐϰͲ^ʹϰͬϭϭͬϭϵϵϴ ^WŚĂŶŐĞŽƵƚďǇEĂďŽƌƐϰͲ^ʹϭϭͬϭϴͬϮϬϬϯ ^WŚĂŶŐĞŽƵƚďǇEĂďŽƌƐϯ^ʹϳͬϭϮͬϮϬϬϴ ^WŚĂŶŐĞŽƵƚďǇEĂďŽƌƐϯ^ʹϵͬϳͬϮϬϬϴ ^WŚĂŶŐĞŽƵƚďǇEŽƌĚŝĐϯʹϯͬϭϳͬϮϬϭϱ ^WŚĂŶŐĞŽƵƚďǇ^ZηϭʹϮͬϭϴͬϮϬϭϴ EKd^͗ EĞĞĚĞŵĞŶƚŝŶŐZĞƉŽƌƚƚŽƐƚĂďůŝƐŚdŽƉƐ &KǁͬZŝŐƚŽϭϮ͕ϲϲϰ͛ϳͬϭϬͬϮϬϬϴ hƉĚĂƚĞĚϴͬϭϭͬϮϬϮϬ DŝůŶĞWŽŝŶƚ ^ZZŝŐϭKW ϮϬϮϮ ϭϭ͟KW ϰ͘ϰϴΖ ϰ͘ϱϰΖ Ϯ͘ϬϬΖ /tͲh ϰ͘ϯϬΖ,ǇĚƌŝů'< ϭϭΗͲϱϬϬϬ sZŽƌWŝƉĞZĂŵƐ ůŝŶĚϭϭΖ͛ͲϱϬϬϬ ^͕ϭϭϱDyϳϭͬϭϲϱD;/ĨEĞĞĚĞĚͿ ϮϭͬϭϲϱD<ŝůů>ŝŶĞsĂůǀĞƐ ϮϭͬϭϲϱDŚŽŬĞ>ŝŶĞsĂůǀĞƐ ,ZDĂŶƵĂůDĂŶƵĂů,Z ^ƚƌŝƉƉŝŶŐ,ĞĂĚ ´[´9%5 HEUEIVED STATE OF ALASKA Al&OIL AND GAS CONSERVATION COASION FEB 0 8 2018 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations Li Fracture Stimulate U Pull Tubing U O�� Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well Q Re-enter Susp Well ❑ Other: ESP Change-out D 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑✓ Exploratory ❑ 195-045 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-029-22552-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0355018 MILNE PT UNIT F-01 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/ KUPARUK RIVER OIL 11.Present Well Condition Summary: Total Depth measured 12,941 feet Plugs measured N/A feet true vertical 7,334 feet Junk measured N/A feet Effective Depth measured 12,837 feet Packer measured N/A feet true vertical 7,255 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 110' 110' N/A N/A Surface 7,088' 9-5/8" 7,124' 4,557' 5,750 psi 3,090 psi Production 12,889' 7" 12,922' 7,320' 7,240 psi 5,410 psi Perforation depth Measured depth See Schematic feet SCANNED FEB 1 6 201 True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5/L-80/EUE 8rd 12,347' 6,889' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 480 0 Subsequent to operation: 225 87 2,680 260 222 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations D Exploratory Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-565 Authorized Name: Bo York Contact Name: Paul Chan Authorized Title: Operations Manager Contact Email: pchan@hilcorp.com Authorized Signature: Date 2/8/2018 Contact Phone: 777-8333 �: 2.13-JJ r 23/0 BDNIS 0- Fw - , 18 Form 10-404 Revised 4/2017 Submit Original Only H • • Milne Point Unit Well: MP F-01 SCHEMATIC Last Completed: 1/18/2018 tlileorp Alaska,LLC PTD: 195-045 TREE&WELLHEAD Tree FMC 2-9/16"-5M Wellhead 11"5M FMC w/2-7/8"FMC tubing hanger,EUE lift Orig.KB BF=33.03'/Orig.GL Elev.=13.1 threads,2.5"CIW H BPV profile A OPEN HOLE/CEMENT DETAIL 217 n 20" Cmt w/250 sks of Arcticset I in 30"Hote 9-5/8" Cmt w/1,364 sks PF"E",250 sx Class"G",250 sx PF'E'in 12-1/4"Hole 1 7" Cmt w/220 sks Class"G"in 8-1/2"Hole WELL INCLINATION DETAIL KOP@600'MD Max Hole Angle=69deg f/7,800'to 8,200' Max angle @ ESP=45 deg. Hole Angle through perforations=68 deg. CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm ' 20" Conductor 91.1/NT8OLHE/N/A N/A Surface 110' 9-5/8" Surface 40/L-80/Btrc. 8.679 Surface 7,124' 7" Production 26/L-80/Btrc 6.151 Surface 12,922' TUBING DETAIL 2-7/8" Tubing 6.4/L-80/EUE 8rd 2.347 Surface 12,347' 3/8" Capstring Stainless Steel N/A Surface 12,347' 9-5/8JEWELRY DETAIL No Depth Item 3/8"SSCapstring 1 140' Camco 2 7/8 X 1"Side pocket,W/Orifice 2 2 12,100' Camco 2 7/8 X 1"Side pocket,W/Dummy 3 12,276' 2-7/8"XN Nipple-2.205 No-Go 4 12,287' Discharge Head:GPDIS 5 12,288' Pump:100P31 SXD • 3 6 12,307' Gas Separator:GRS FER N AR ' ' 7 12,310' Upper tandem Seal: GSB3DBUT SB/SB PFSA 8 12,317' Lower tandem Seal:GSB3DBLT SB/SB PFSA CL5 ..`' 4 9 12,323' Motor:XP-300Hp/3,620V/51A ! 10 12,343' WeIILift E Sensor w/Centralizer-Bottom @ 12,347' 5 PERFORATION DETAIL 6Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 7 Kup.A3,A2& 12,488' 12,578' 6,992' 7,059' 90' 10/22/1995 Open 'r.' Al Sands Note:Jumbo Jet Performance:TTP=6.4",EHD=0.76". 3.38"Gun Diamter,6 spf. 8&9 WELL STIMULATION DETAIL 404. 7/1995-139,750#of 16/20 Carbolate. 4,4 , 10 GENERAL WELL INFO API:50-029-22552-00-00 P Drilled and Cased by Nabors 4-ES -4/28/1995 0. ESP Completion by Nabors 4-ES-10/25/1995 ESP Changeout by Nabors 4-ES-4/11/1998 rl ESP Changeout by Nabors 4-ES-11/18/2003 g ti ESP Changeout by Nabors 3S-7/12/2008 Two 20'marker ka Vi ESP Changeout by Nabors 3S-9/7/2008 joints located M il ESP Changeout by Nordic 3-3/17/2015 from 12,344'to ' ESP Changeout by ASR#1-2/18/2018 12,385wim. NOTES: Need Cementing Report to Establish Tops A3,21 # }Sands& FCO w/Rig to 12,664'7/10/2008 TD=12,941'(MD)/1D=7,334'(TVD) PBTD=12,837'(MD)/PBTD=7,255'(1VD) Revised By:TDF 2/8/2018 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-01 ASR#1 50-029-22552-00-00 195-045 1/14/18 1/19/18 Dailytap ations: _ „° "" ii..' „ n 1/10/2017-Wednesday No activity to report. 1/11/2017-Thursday No activity to report. 1/12/2017-Friday No activity to report. 1/13/2017-Saturday No activity to report. 1/14/2017-Sunday Rig crews arrive at Milne Point, conduct welcome back meetings as well as Sundry for F-01. Day crew prep rig and A pad location for rig move to F-pad. LRS on location at 6pm to perform well kill. Circulate 580bbls of 120 deg,8.5ppg seawater @ Sbpm = 1,500psi TBG and 100psi IA down the TBG taking returns out the IA. 415bbls of fluid returned to surface from circulation. Night crew begin rig move from A pad to F pad. NES on location w/winch tractor to support move. Roads and pads crane operator load rig floor and well house on low boy trailer, crews remove circulation manifold from F-01 foot print, spot mud boat in place. Once mud boat in place, spot mud pit trailer. 1/15/2017-Monday Rig crew continue to R/U on well F-01. N/D tree, N/U BOPE. Spot well house and rig floor in place,spot company rep trailer and dog house into position, run power from pits to company rep trailer, back rig carrier onto mud boat, raise mast and pin in place, L/D herculite containment for pipe racks, spot catwalk into position,take on fresh water for camps, as well as for testing BOPE. Prep for running glycol system. Hook up Accumulator, kill, choke, & Hp pump lines, r/u glycol boiler&winterize lines, rig &cellar.function test BOPE,good, Fill surface eq w/fluid, shell test t/2,500psi,chase & repair leaks, (one wellhead gland nut, CMV 14, kill line flange) Cont.trouble shoot shell test not holding high test, isolate& verify no surface leaks, cont. working through getting a test. 1/16/2017-Tuesday 1/19Continue to test BOPE as per Sundry and ASR test procedure to 250psi low and 2,500psi high w/2-7/8"test joint. P;),-)e, AOGCC Rep Jeff Jones waived witness to testing.;Well head reps on location to pull TWC and BOLDS. M/U landing joint (10 turns) and pull TBG hanger to the floor.Took 103klbs to get ESP moving, before leveling off at 88klbs. Cut ESP cable and cap line to prep to pull over sheave. Fill hole prior to tripping out of hole(16bbls);POOH w/ ESP completion on 2-7/8" EUE 6.5ppf TBG f/12,253' md. Cont. POOH w/ESP completion, I/d 132 jts,t/cable splice. Change out cable spool,tally 2- 7/8"tubing. Cont. POOH w/ESP completion. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-01 ASR#1 50-029-22552-00-00 195-045 1/14/18 1/19/18 Daily Operations: 1/17/2017-Wednesday Continue to POOH w/ESP completion on 2-7/8" 6.5ppf EUE TBG to discharge head on ESP. 381 joints of TBG, 2 GLM's, and one XN recovered from well. Fill hole and verify fluid level prior to laying down ESP. L/D ESP completion.,Tally recovered joints from well. Roads and pads operators on location to swap ESP reel and cap string reel in the ESP spooling unit in prep to RIH w/new ESP. P/U ESP completion and service as per Centrilift hand. Prep ESP cable and cap string. Pull both lines over double ESP sheave. M/U MLE cable and cap string to ESP. Conduct well control drill while ESP completion is across the BOP and conduct AAR. Cont. P/U ESP completion and service as per Centrilift hand. RIH, pinched ctl line on protector, repair same. RIH t/102'test cable & cap line good. RIH w/ESP assy on 2 7/8" 6.5#, L-80 EUE 8rd tubing t/5192', testing cable &cap line every 2000' Good. 1/18/2017-Thursday Continue to RIH w/ESP completion and capillary line to jnt 262, (-8300'md). Stop to complete ESP cable splice. Complete cable checks every 2000'md. Stop to circulate down TBG and ensure TBG is clear. Pump 10bbls @ 1.5BPM =600psi. Perform cable megger test and capillary line pressure test. (Good) Roads and Pads on location to perform reel swap in the ESP spooler. Centrilift perform reel to reel cable splice. Rig crews perform maintenance. Continue to RIH w/ESP completion and capillary line to jnt 346, (^'11 050'md). Test cable and capillary line every 2000'md. Fill hole @ 3BPH while tripping in hole. Continue to RIH w/ ESP completion and capillary line t/12325'Test cable and capillary line every 2000'md. Fill hole @ 3BPH while tripping in hole. M/U hanger& landing jt, m/u penetrator splice& cap lines t/hanger, test same good. Land hanger placing ESP tail assembly @ 12346', up wt 90k, do wt 24k, run in l/d pins,set BPV. Blow down lines, r/d pipe racks, r/d circulating& accumulator lines, prep floor t/l/d mast. 1/19/2017- Friday Phase 3 weather conditions restricted rig work, hands worked on maintenance & procedures, while monitoring eq. Prep pad for rig move to F-61, clear snow, spot rig mats, until wind decreased. Prep & lay down mast, ready rig to move, clear snow from liner& prep t/spot crane to cont. Rig down from F-01. Setup crane, r/u & pull floor, N/D BOPE & put in warm up trailer. (Release from well F-01 @ 6:00am) 1/20/2017-Saturday No activity to report. 1/21/2017-Sunday No activity to report. 1/22/2017- Monday No activity to report. 1/23/2017-Tuesday No activity to report. . \v of 7'4 • � ��j��s� THE STATE Alaska Oil and Gas • ti ►;,s�i � of A T ® 1 T A Conservation Commission Witt= _ 333 West Seventh Avenue e, Alaska 99501 3572 -40 GOVERNOR BILL WALKER Anchorage, Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLCN 0 a: o? t 3800 Centerpoint Drive, Suite 1400 SCANW6D Anchorage, AK 99503 Re: Milne Point Field, Kuparuk Oil Pool, MPU F-01 Permit to Drill Number: 195-045 Sundry Number: 317-565 Dear Mr. York: 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, 6f2(X1 Hollis S. French �� Chair DATED this 1 day of December, 2017. U ti�7 • • RECEIVED . NOV 2 9 2017 STATE OF ALASKA ØrS 12'p4) 1 7 ,A ALASKA OIL AND GAS CONSERVATION COMMISSION GCC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑., Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑., Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out El 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q, 195-045 1 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 111Service EI 6.API Number: Anchorage Alaska 99503 50-029-22552-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D ' Will planned perforations require a spacing exception? Yes ❑ No 0 • MILNE PT UNIT F-01 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0355018 ' MILNE POINT/KUPARUK RIVER 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): 12,941' 7,334' 12,837' 7,255' 1,554 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 78 20" 110' 110' N/A N/A Surface 7,088 9-5/8" 7,124' 4,557' 5,750 psi 3,090 psi Production 12,889 7" 12,922' 7,320' 7,240 psi 5,410 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic ' See Schematic 2-7/8" 6.5/L-80/EUE 8rd 12,200' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A&N/A N/A&N/A 12.Attachments: Proposal Summary 0 Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑' Stratigraphic❑ Development❑., ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 12/16/2017 Commencing Operations: OIL ❑., WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Paul Chan Authorized Title: Operations Manager Contact Email: pCharinG hIICOrp.COm Contact Phone: 777-8333 Authorized Signature: -^ iVClate: 11/29/2017 COMMISSION USE ONLY Conditions of appro otify Commission so that a representative may witness Sundry Number: 51-x . 54 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other. Soo . S /JoP aftJ /-- Post Initial Injection MIT Req'd? Yes ❑ No ❑ �fl ,��++ �' i r 9 �-�( u t..[ REDLIS DECU J �41 Spacing Exception Required? Yes ❑ No LJ Subsequent Form Required: / 0 / 6 1 APPROVED BY Z (y ' Approved by: _. COMMISSIONER THE COMMISSION Date: ( 'la Ii140- «00/7 Z -17 ,0S \� RGINAL Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • Well Prognosis Well: MPU F-01 Ilitctirp Alaska.LL) Date: 11/27/2017 Well Name: MPU F-01 API Number: 50-029-22552-00 Current Status: Oil Well Pad: F-Pad Estimated Start Date: December 16th, 2017 Rig: ASR 1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 195-045 First Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) AFE Numbier:,, d4116, '4w,41° Job Type: ESP Repair Current Bottom Hole Pressure: 2,232 psi @ 6,782'TVD (ESP Gauge 09/19/2017/6.33 ppg EMW) Maximum Expected BHP: 2,232 psi @ 6,782'TVD (No new perfs being added) v MPSP: 1,554 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU F-01 was drilled in May 1995, fracture stimulated in July, and completed in October 1995 as a Kuparuk River producer. ESP installation history: October 1995 (initial),April 1998, November 2003,July 2008, September 2008,and March 2015. The ESP has failed. Notes Regarding Wellbore Condition • The 7" production casing was tested to 1490 psi at 12,113' MD on March 16, 2015. • CO 390A: Hilcorp Alaska respectfully requests that a packer not be required on this ESP completion ✓ as the reservoir pressure is less than 8.55 ppg EMW. Qac Peri- �� Objective: ` !/3a./? Replace failed ESP. J Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.5 ppg sea water down tubing, taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. • • Well Prognosis • Well: MPU F-01 Hilcoru Alaska,LD Date: 11/27/2017 Brief RWO Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg sea water prior to pulling BPV. Set TWC. 12. Test ROPE to 250 psi Low 2500 psi High annular to 250 psi Low/2 500 psi Hu (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking VA.,v4 anywhere at surface.) C// d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg sea water as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2015 ESP swap was 120K lbs. (includes 36K block weight) b. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. 16. Recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 17. POOH and lay down the 2-7/8"tubing. Number all joints. Tubing will be re-used as noted. Lay down ESP. a. Replace bad joints of tubing as necessary and note on tally new tubing run. b. Junk the 2-7/8" GLM and XN profile. c. Note any sand or scale inside or on the outside of the ESP on the morning report. d. Look for over-torqued connections from previous tubing runs. • • Well Prognosis Well: MPU F-01 flileocu Alaska,LLD Date: 11/27/2017 18. PU new ESP and RIH on 2-7/8" tubing. Set base of ESP assembly at± 12,346' MD. a. Upper GLM @ ± 140' MDw/SO b. Lower GLM @ ± 12,123' MD w/DGLV c. 2-7/8" XN (2.205" No-Go) @ ±12,267' MD d. Base of ESP centralizer @ ± 12,346' MD 19. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off)weights on tally. 20. Set BPV. Post-Rig Procedure: 21. RD mud boat. RD BOPE house. Move to next well location. 22. RU crane. ND BOPE. 23. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500ps1low/5,000 psi high. Pull BPV. 24. RD crane. Move 500 bbl returns tank and rig mats to next well location. 25. Replace gauge(s) if removed. 26. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. Blank RWO MOC Form Milne Point Unit III Well: MPF-01 SCHEMATIC Last Completed: 3/17/2015 Ililcorp Alaska,LLC PTD: 195-045 TREE&WELLHEAD Tree FMC 2-9/16"-5M Wellhead 11"SM FMC w/2-7/8"FMC tubing hanger,EUE lift Orig.KB BF=33.03'/Orig.GL Elev.=13.1 threads,2.5"CIW H BPV profile C. _ OPEN HOLE/CEMENT DETAIL 2O1. b " 20" Cmt w/250 sks of Arcticset I in 30"Hole 9-5/8' Cmt w/1,364 sks PF"E",250 sx Class"G",250 sx PF'E'in 12-1/4"Hole 1 7" Cmt w/220 sks Class"G"in 8-1/r Hole o WELL INCLINATION DETAIL ;< KOP @ 600'MD j ' V Max Hole Angle=69deg f/7,800'to 8,200' kl 6 4Max angle @ ESP=45 deg. 0. Hole Angle through perforations=68 deg. rk F CASING DETAIL V ` Size Type Wt/Grade/Conn Drift ID Top Btm 1:4i 20" Conductor 91.1/NT8OLHE/N/A N/A Surface 110' 9-5/8" Surface 40/L-80/Btrc. 8.679 Surface 7,124' ,^ » 7" Production 26/L-80/Btrc 6.151 Surface 12,922' ' TUBING DETAIL ;• 2-7/8" Tubing 6.4/L-80/EUE 8rd 2.347 Surface 12,220' 3/8" Capstring Stainless Steel N/A Surface 12,220' 1 JEWELRY DETAIL g5/g' I No Depth Item 3/8"SS Capstring 1 175' GLM#2—Set dummy 11/2/17 2 2 12,030' GLM #1—dummy set on 8/18/17 3 12,174' HES XN-Nipple 4 12,185' Discharge Head—GPDIS corrected Depth was off on 8-16-17 5 12,186' Pump—100P31 PMSXD corrected Depth was off on 8-16-17 II_ 3 6 12,204' Gas Separator—538GSTHVEVXH6 i 7 12,210' Tandem Seal Section-GSB3DBUT SB/SB PFSA:GSB3DBUT SB/SB PFSA 8 12,224' Motor—MSP1-250,336HP/2,650V/77A mg 4 9 12,249' WellLift Sensor w/Centralizer—Bottom @ 12,253' 5 PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status I11 6SIN V Kup.A3,A2& 7 Al Sands 12,488' 12,578' 6,992' 7,059' 90' 10/22/1995 Open AIM r .0 Note:Jumbo Jet Performance:TTP=6.4",EHD=0.76". 3.38"Gun Diamter,6 spf. it" lie WELL STIMULATION DETAIL *',8 7/1995—139,750#of 16/20 Carbolite. r NE i ' ?11 GENERAL WELL INFO 1 API:50-029-22552-00-00 il 9 Drilled and Cased by Nabors 4-ES -4/28/1995 i. ? ESP Completion by Nabors 4-ES—10/25/1995 ESP Changeout by Nabors 4-ES—4/11/1998 j'< ESP Changeout by Nabors 4-ES—11/18/2003 11 ESP Changeout by Nabors 3S-7/12/2008 ESP Changeout by Nabors 3S—9/7/2008 ESP ChangeoutNordic 3—3/17/2015 a It Two 20'marker 0 b y joints located NOTES: fro12,344' i 12,385 wWm. Need Cementing Report to Establish Tops lm. ,,,:,4141 - —— FCO w/Rig to 12,664'7/10/2008 f}A32&1 Sands i'' 14 T �" TD=12,941'(MD)/1D=7,334'(TVD) PBTD=12,837'(MD)/PBTD=7,255'(TVD) Created By:1CM 11/2/2017 • IIIWell: Point Unit Well: MPF-01 PROPOSED Last Completed: 3/17/2015 Hilcorp Alaska,LLC PTD: 195-045 TREE&WELLHEAD Tree FMC 2-9/16"-5M Wellhead 11"5M FMC w/2-7/8"FMC tubing hanger,EUE lift Orig.KB BF=33.03'/Orig.GL Elev.=13.1 threads,2.5"CIW H BPV profile kl , E OPEN HOLE/CEMENT DETAIL 20' : 20" Cmt w/250 sks of Arcticset I in 30"Hole t.. 9-5/8" Cmt w/1,364 sks PF"E",250 sx Class"G",250 sx PF'E'in 12-1/4"Hole e 1 7" Cmt w/220 sks Class"G"in 8-1/2"Hole WELL INCLINATION DETAIL KOP @ 600'MD "_' Max Hole Angle=69deg f/7,800'to 8,200' 1 +> Max angle @ ESP=45 deg. Hole Angle through perforations=68 deg. CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 91.1/NT80LHE/N/A N/A Surface 110' 9-5/8" No Depth Surface 40/L-80/Btrc. 8.679 Surface 7,124' 7" Production 26/L-80/Btrc 6.151 Surface 12,922' TUBING DETAIL ''` 2-7/8" 3/8" Tubing 6.4/L-80/EUE 8rd 2.347 Surface 12,220' Stainless Steel N/A Surface 12,220' ,a JEWELRY DETAIL 9-5/8" 3/8"SS Capstring 1 ±140' GLM#2—Set dummy 11/2/17 2 2 ±12,123' GLM #1--dummy set on 8/18/17 3 ±12,267' HES XN-Nipple–2.205 No-Go 4 ±12,278' Discharge Head 5 ±12,279' Pump te 3 6 ±12,297' Gas Separator 1 I 7 ±12,303' Tandem Seal Section 8 ±12,317' Motor 4 9 ±12,342' Sensor w/Centralizer–Bottom @±12,346' 5 PERFORATION DETAIL I / Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 111 ps Kup.A3,A2&tor 12,488' 12,578' 6,992' 7,059' 90' 10/22/1995 Open t ,.7 Al Sands Note:Jumbo Jet Performance:TTP=6.4",EHD=0.76". 3.38"Gun Diamter,6 spf. WELL STIMULATION DETAIL 8il 7/1995—139,750#of 16/20 Carbolite. .M GENERAL WELL INFO t, 9 API:50-029-22552-00-00 Drilled and Cased by Nabors 4-ES -4/28/1995 ESP Completion by Nabors 4-ES–10/25/1995 k k,,„ ESP Changeout by Nabors 4-ES–4/11/1998 ESP Changeout by Nabors 4-ES–11/18/2003 '4; ESP Changeout by Nabors 3S-7/12/2008 tESP Changeout by Nabors 3S–9/7/2008 Two 20'marker #r k+? ESP Changeout by Nordic 3–3/17/2015 f.; ). joints located ); NOTES: from 12,344'to 4. Need Cementing Report to Establish Tops 12,385 wlm. ° FCO w/Rig to 12,664'7/10/2008 a' IT Sands Sands 1 j t 4 ' 7" TD=12,941'(MD)/TD=7,334'(TVD) PBTD=12,837'(MD)/PBTD=7,255'(TVD) Revised By:TDF 11/28/2017 • • Milne Point ASR Rig 1 BOPE 2017 iftlr.ir1. rn.hr.I.t.t: 11" BOPE , Stripping Head r1 „ ,. ,.. , . , , 4.48' ' Hydril GI "' 11" - 5000 '�4 lor III IEE 111 I/11111 ilia 111111W III III / CI -U 4.54' -an' - VBR or Pipe Rams MC 011111E J' 11"- 5000 ajp--_i Blind if. gnu Iii ill III Ill ii 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves — 1111I191'11'Il 2.00' - 1 jL W '1I - ' ' II'1.111.1 1I1I1,111' - Manual Manual s Manual HCR Updated 11/20/2017 . M P F-01 0 S 11-27-17 Current configuration Swab Valve OW 3 1/8" 5K, manual gate valve, EE PSL2,PR2 PN 141522-31-02-01 Wing valve CIW FL-3 1/8" 5K, in Iiiiiing,. reverse actuating gate valve, ;,f.. ,, EE.PSL2,PR2 w/ OW 03/03 0 actuator. b� ‘F-4.94. Assy PN SSV CIW FL-3 1/8" 0 O r ‘ 5K, reverse actuating gate valve, EE.PSL2,PR2 w/ CIW 03/03 actuator. `` ;II.' N / Assy PN 141522-31-02-01 Master CIW 3 1/8" 5K„ Lt ti. / N manual gate valve, EE Note, this tbg HGr can be '"' "„ PSL2,PR2 plugged on top for BOPS PN 141522-31-02-01 equipment testing OO Tbg Hd adapter FMC 11" 5K lea ESP Hi, 1/8" %2� 5K, w/2ea " . •,+" x 3 IIIIW lea Control line control line preps and no III 141 penetrator preps. i� ' � Centralized Bottom prepped 0 for 31/2"" SBMS seal. 3" "H" o •`0 BPV Ete. �i�/ I] PN i -,r 'I — I0 i )/ .2 i 4D/Zr, ili; ,ci O �.,.. Ell, I° • III 7 ii.t .. r �I� ;,IJ ,J 0 • 13 _ °' °3 d ? (a a) v0 o °' Vic Q ac =o a � Q E — E rn o U � N CO a) Y > :F+ = aa)) < 2E Q Q L,E co a.) C L Iw U) 4CD 13 o E• D Q ea — ' 2 d 0- 5 L (o °' m CU .(n W g> o g 0 0 (nc a) (v CD-C Co (a0 L 0 — i o To ti d ag o _o 5.- O > co a� L C O C c a �� as ka. a 3 a, C C a) (aa 0 c '..-. Q d L. ° aQ o E tai a 0 73U U •15) L2 mN a LX N =, o > W as c a N Q cQa Y W CCI - Q.Cid Q L N to L C C a) O 3 47. cs E a) (n .� C)cn a -4!i < > (d O a) d C) Q o w Z C) a O O x -1 _ C E• V o (0 •,--1 _ .r+ x c >, Q Z3 a) `►Z'i U CO can can Q N ¢ a STATE OF ALASKA • Ai. -..iKA OIL AND GAS CONSERVATION COMMISSION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well L Plug Perforations U Perforate Other L R&R ESP Performed: Alter Casing ❑ Pull Tubing E 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 E 195-045 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-029-22552-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0355018 MILNE PT UNIT KR F-01 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Point Field/Kuparuk River Oil Field 11.Present Well Condition Summary: n Total Depth measured 12,941 feet Plugs measured 12,837 fie' E l V E D true vertical 7,334 feet Junk measured 7,255 feet APR 3 0 2015 Effective Depth measured 12,837 feet Packer measured N/A feet /"�� true vertical 7,255 feet true vertical N/A feet t\Q(3 Cyst Casing Length Size MD ND Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 7,124' 9-5/8" 7,124' 4,557' 5,750psi 3,090psi Intermediate Production 12,922' 7" 12,922' 7,320' 7,240psi 5,410psi Liner 2 n Perforation depth Measured depth See Attached Schematic SCANNED i4.A 0 2015 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 12,220' 6,797' Packers and SSSV(type,measured and true vertical depth) N/A N/A 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: 118 500 2,100 280 285 Subsequent to operation: 262 249 2,564 300 254 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development E Service E Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil D 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: L315-110 Contact Chris Kanyer Email ckanverahilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signature Jo rw 1-oarks- _Gr. C,. 4. Phone 907-777-8377 Date 4/30/2015 34 S 7_�s� RBDMS APR 302015 Form 10-404 Revised 10/2012 Submit Original Only --r,--n.40---- Milne Point Unit . II Well: MPF-01 • SCHEMATIC Last Completed: 9/7/2008 flacon,Ala.ka,IlkPTD: 195-045 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm Orig.KB-BF 33.03 /Clog.GL Elev. 13.1 20" Conductor 91.1/NT8OLHE/N/A N/A . Surface 110' 9-5/8" Surface 40/L-80/Btrc. 8.679 Surface 7,124' 7" Production 26/L-80/Btrc 6.151 Surface 12,922' 20 i TUBING DETAIL 2-7/8" Tubing 6.4/L-80/EUE 8rd 2.347 Surface 12,220' , (I 1 i 3/8" Capstring Stainless Steel N/A Surface 12,220' JEWELRY DETAIL No Depth Item 1 142' GLM . r 2 11,997' GLM 3 12,141' HES XN-Nipple 4 12,152' Discharge Head—GPDIS 5 12,153' Pump—100P31 PMSXD 6 12,171' Gas Separator—538GSTHVEVX H6 7 12,177' Tandem Seal Section-GSB3DBUT SB/SB PFSA:GSB3DBUT SB/SB PFSA 8 12,191' Motor—MSP1-250,336HP/2,650V/77A 9 12,216' WellLift Sensor w/Centralizer—Bottom @ 12,220' PERFORATION DETAIL i Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.A3,A2& 12,488' 12,578' 6,992' 7,059' 90' 10/22/1995 Open 9-5/8" I L Al Sands Note:Jumbo Jet Performance:TTP=6.4",EHD=0.76". 3.38"Gun Diamter,6 spf. 3/8"SS Capstring WELL STIMULATION DETAIL 2 11/18/2003—139,7504 of 16/20 Carbolite. WELL INCLINATION DETAIL KOP @ 600'MD 3 Max Hole Angle=69deg f/7,800'to 8,200' Max angle @ ESP=45 deg. Hole Angle through perforations=68 deg. 4 OPEN HOLE/CEMENT DETAIL 5 20" Cmt w/250 sks of Arcticset I in 30"Hole 9-5/8" Cmt w/1,364 sks PF"E",250 sx Class"G",250 sx PF'E'in 12-1/4"Hole 6 7" Cmt w/220 sks Class"G"in 8-1/2"Hole TREE &WELLHEAD Tree FMC 2-9/16"-5M Wellhead 11"5M FMC w/2-7/8"FMC tubing hanger,EUE lift a threads,2.5"CIW H BPV profile GENERAL WELL INFO 1 API:50-029-22552-00-00 9 Drilled and Cased by Nabors 4-ES -4/28/1995 ESP Completion by Nabors 4-ES—10/25/1995 ESP Changeout by Nabors 4-ES—4/11/1998 ESP Changeout by Nabors 4-ES—11/18/2003 ESP Changeout by Nabors 3S—7/12/2008 ESP Changeout by Nabors 3S—9/7/2008 Two 20'marker NOTES: joints located Need Cementing Report to Establish Tops from 12,344'to FCO w/Rig to 12,664'7/10/2008 12,385 w1m 1 A3 2&1 JJ Sands 7 A ►' TD=12,941'(MD)/TD=7,334'(TVD) PBTD=12,837'(MD)/PBTD=7,255'(TVD) Created By:TDF 4/29/2015 Hilcorp Alaska, LLC 1.I.1 Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MPF-01 50-029-22552-00-00 195-045 2/24/2015 3/17/2015 Daily Operations: 3/11/15-Wednesday No operations to report. 3/12/15-Thursday No operations to report. 3/13/15-Friday Wait on Temperature to reach -35.MIRU. Rig accepted. Hot Kill fluid ordered at 13:00 hours. Berm cellar,spot all tanks and support equipment. Berm as needed. Run all hardline to kill tanks. Heat tree. Remove BPV. Run hardline and blow down. RU to pump kill. Delays on vac trucks freeze up problems.Temp @ rig-39 and dropping. Offloading 9.0ppg 140 degree brine.SITP 500psi.SICP 700psi: PT lines 250psi low/2,500psi. Blow down well. Pump 440 bbls recovered 391. Oil/diesel and and water mix.9 ppg heavy was ordered at 9 ppg 140 degrees fluid arrived 1st load 100 degrees second load 104 degress.Observe well while offloading kill tank fluid. 3/14/15-Saturday RD hoses, pump SSV,set BPV drain tree, bleed off void. ND NU,PJSM ND tree inspect hanger and pack. NU Stack. Pull BPV install TWC and shell test 250psi low/3,000 psi high.All good.Test BOPE 250psi low/3,000psi high as well as annular.Test all visual and audio gas alarms.Test accumulator draw down.All OK.Open Backside light blow 30psi—. Remove TWC PU landing jt pull hanger 115K well trying to flow. Close annular.Circ conventional 92 bbls 3BPM @ 650psi through degasser,monitor slight flow. Bull head 50 bbl 9.0ppg to perfs and 35 bbls into perfs. Let well equalize still light flow. Elect to weight up fluid to 9.2 ppg with NaCI as BOP and spill safety not optimum with ESP cable trip.Trip kick drill.Circ first weight batch 9.2 ppg 268bb1s @ 4 bpm 1,160 psi displace to pits weight pits again to 9.2ppg and circ hole volume 4 bpm 1,160psi.Observe well.well is static/vacuum. 182 sx NaCI used. Drain up, blow down top drive and all lines PU and decomplete hanger and terminate penetrator connection. POOH string ESP to spooler.Well is drinking 18 bph. POOH with ESP completion.Strapping Out. 3/15/15-Sunday Continue POOH with ESP LD bottom GLM XN nipple and 3' pup. No scale evidence on ports,clamps, motor and pump connections,pipe looks in good shape, pipe in derrick. 11,986.08'-126 stands-378 jts. 1 bad jt LD. Pull through motor to examine for scale RIH to begin BO/LD of ESP assy.Call for test packer. BO/LD ESP assy.All hardware recoverd as per G s' completion drawing. Offload old GLMs and ESP gear.Wait on test packer. PU MU 7"champ test packer and RIH w/pipe 1/4- c from derrick. PU singles. Fill hole —20 bbls,set packer @ 12,113'.Set packer w/20K down.Presssure up to 1,530psi bleed off trapped air pressure up to 1,530psi hold and chart 30 minutes. Final pressure 1,490psi. Initial 30 psi pressure loss in first 7 minutes.Stable test. Bleed off pressure open bypass release packer POOH BO/LD packer. 3/16/15-Monday LD packer.Organize floor and pipe racks.Strap all ESP tools and GLM assemblies. PU MU ESP pump motor and seals and service same.String cable and cap over sheaves. Make up ESP motor and capillary connection.Meg test and cycle cap check. RIH with ESP and 2-7/8"6.5#L-80 completion. Check cable every 2,000'.On 4,000'check cable short. POOH w/ESP completion to troubleshoot.Troubleshoot motor shorted. Cracked insulation on electrical fitting. LD Motor. Decomplete LD ESP assembly. PU new motor ESP assy and service.Slip n cut drilling line. Install centralizer and hook up cap string/check valve meg check cable. Install flat bars and protectolizers and deploy system. 3/17/15-Tuesday RIH w/ESP completion and 3/8"stainless capillary injection line.Test cable&check valve every 2,000',splice cable @ 9,100'and continue RIH with ESP and 381 jts tubing.Total capillary 12,220'.Check valve cycle pressure 4,600psi. PU hanger,landing joint, install penetrator,space out cable and capillary.Centralizer 12,220',pumpmate 12,216',motor 12,190',tandem seals 12,176',gas separator 12,171', pump 12153',discharge head' 12,153',10'tubing pup,XN nipple 12,141' 4 jts 2-7/8"tbg, 10'pup,GLM 11,997', 10'pup,373 jts tbg, 10'pup GLM 142', 10'pup,4 jts tbg,4'pup&hgr. Install ESP and cap connectors.SW with 36K blocks 120k up 65K down land hanger. Run In lockdown screws. LD landing jt. Install BPV. ND BOPE NU tree test void 250psi low/5,000psi high.Test ESP and capillary.Release Rig. TAr • (cOF �� j,Cs. THE STATE Alaska Oil and Gas 9 ofALASI�:A Conservation Commission _ap ttiltz___ _ 333 West Seventh Avenue \Th GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 go. ALAS*p. Fax: 907 276.7542 *145) ;I www.aogcc.alaska.gov Chris Kanyer SCP Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR F-01 Sundry Number: 315-110 Dear Mr. Kanyer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /0.;22_44526, Cathy P. oerster Chair, Commissioner DATED this Say of March, 2015 Encl. . RECEIVED STATE OF ALASKA FEB 2 6 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION 3 1-97/,— 0 ' APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon E Plug for Redrill ❑ Perforate New Pool❑ Repair Well[v]'Gj7 Change Approved Program ❑ Suspend❑ Plug Perforations ❑ Perforate Q Pull Tubing Q ' Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other. Remove and Replace ESP 2, 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC , Exploratory ❑ Development 2 v 195-045 . 3.Address: Stratigraphic 0 Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22552-00-00 c 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.432C Will planned perforations require a spacing exception? Yes ❑ No 0 / MILNE PT UNIT KR F-01 • 9.Property Designation(Lease Number): 10.Field/Pool(s): V ADL0355018 ' Milne Point Field/I a anik River Oil Field 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): 12,941 • 7,334 ` 12,664 7,123 N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 7,124' 9-5/8" 7,124' 4,557' 5,750PSI 3,090psi Intermediate Production 12,922' 7" 12,922' 7,320' 7,240psi 5,410psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic I See Attached Schematic 2-7/8" 6.44//L-80/EUE 8rd 12,229' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A and N/A N/A and N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑., Exploratory ❑ Stratigraphic❑ Development Q • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 3/3/2015 Oil ❑✓ . Gas ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned 0 Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Email ckanyera.hilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signature Phone 777-8377 Date 2/26/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3k5—k\C) Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4 3c)61,) / s4. AD 1 eS'r ( 1 Ase T WO r s:, ) k esc i)_ /p r�,-S w,t_ -. 2, f-- r 1 c. v'e,.Q, Spacing Exception Required? Yes ❑ No Subsequent Form Required: /O —1 O y APPROVED BY 2 Approved by: P COMMISSIONER THE COMMISSION / Date: J�3�/ .Z•/sCriRleatittAtd f 4Z�l'r ,�iyfr /193+Z'/� Submit Form and Form 10-403(Revs 10/2 12) for 12 months from the d��pt pprov MAR 5Attachments in Duplicate Well Prognosis Well: MPF-01 Hilcorp Alaska,LL' Date:2/25/2015 Well Name: MPF-01 API Number: 50-029-22552-00-00 Current Status: SI Producer Pad: F Pad Estimated Start Date: March 4, 2015 Rig: Nordic 3 Reg.Approval Req'd? March 3, 2015 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 195-045 First Call Engineer: Chris Kanyer (907) 777-8377 (0) (907) 250-0374 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: 1550356 Current Bottom Hole Pressure: — 3,607 psi @ 7,000' TVD (Last BHP measured 2/1/2015) Maximum Expected BHP: — 3,607 psi @ 7,000' TVD (No new perfs being added) Max.Allowable Surface Pressure: 710 psi (Based on actual reservoir conditions and water cut of 89% (0.428psi/ft)with an added safety factor of 1000' ND of oil cap) Brief Well Summary: The Milne Point F-01 well was drilled as a Kuparuk development well that TD'd at a depth of 12,941' and ran and cemented 7" production casing in October 1995. The well was perforated in the Kuparuk A sands and initially completed with an ESP. The well has had ESPs failed and replaced in 1998, 2003, April 2008, and July 2008. The recent pump failed in May 2014 with an electrical failure. The well has remained shut in ever since. There is no recent casing pressure test performed and one will be completed during this workover. Due to observed scale issues, a downhole chemical injection line will be run as part of the new completion. / No subsidence issues are expected in this well. Notes Regarding Wellbore Condition Current well status is shut in oil producer. No subsidence issue suspected. �--� );it fres s RWO Objective: d,,,w,.A. 6#t ' eM.L.->• Pull ESP, perform fill cleanout, pressure test casing, & run 2-7/8" ESP completion with downhole chemical injection. Brief Procedure: 1. MIRU Nordic#3 Rig. 2. Circulate well with 8.5ppg seawater and monitor well. 3. If necessary, circulate well with 9.9ppg brine (or appropriate kill weight fluid). Monitor well. 4. ND tree, NU 13-3/8" BOPE with 11" spool adapter and test to 250psi low/3,000psi high, annular to 250psi low/2,500psi high. a. Notify AOGCC 24hrs in advance to witness test. 5. Unseat hanger and pull 2-7/8" ESP completion from 12,229'to surface and lay down same. 6. RIH with 7" cleanout BHA to+/-12,488'. POOH with same. 7. RIH and set test packer at+/-12,000' (within 500ft of open perforations). V 8. Perform a charted casing pressure test to 1,500psi for 30min. Bleed off pressure and POOH with same. Well Prognosis Well: MPF-01 Hilcoru Alaska.LL Date:2/25/2015 9. MU and RIH with ESP with gas separator and 3/8"chemical injection line on 2-7/8" 8RD EUE L-80 tubing [to be replaced if necessary]. Set ESP at+/-12,229'. Land tubing hanger. 10. ND BOP, NU and tree. 11. RDMO workover rig and equipment. 12. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic II Milne Point Unit Well: MPF-01 SCHEMATIC Last Completed: 9/7/2008 Ililcorp Alaska,LLI: PTD: 195-045 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm Orig.KB-BF=33.03'/Orig.GL Elev.=13.1 20" Conductor 91.1/NT8OLHE/N/A N/A Surf 110' 9-5/8" Surface 40/L-80/Btrc. 8.679 Surf 7,124' 7" Production 26/L-80/Btrc 6.151 Surface 12,922' 20'' I . L TUBING DETAIL 2-7/8" Tubing 6.4/L-80/EUE 8rd2.347 Surf 12,229' 1 JEWELRY DETAIL No Depth Item 1 133' Camco 2-7/8"x 1"KBMG-M-2 GLM 2 11,970' Camco 2-7/8"x 1"KBMG-M-2 GLM 3 12,116' 2-7/8"HES XN-Nipple(2.250 no-go ID) :e 4 12,159' WeIILift Gauge ,, ,I 5 12,162' Centrilift PMSXD 1-5/100-P31 Pump • 6 12,181' Centrilift Gas Separator GRSFTXARH6(513 Inernals) 7 12,186' Centrilift Tandem Seal Section GSB3DB UT/LT SB/SB PFSA/FSA CL5 8 12,200' Centrilift KMH Motor,304hp motor,2,290 v/81 amp 9 12,225' Well lift MGU Sensor w/Centralizer, intake sensor TVD=6,800' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.A3,A2& 12,488' 12,578' 6,992' 7,059' 90' 10/22/1995 Open Al Sands 9-5/8"'a & Note:Jumbo Jet Performance:TTP=6.4",END=0.76". 3.38"Gun Diamter,6 spf. WELL STIMULATION DETAIL 11/18/2003—139,750#of 16/20 Carbolite. I 2 WELL INCLINATION DETAIL KOP@600'MD 3 Max Hole Angle=69deg f/7,800'to 8,200' Max angle @ ESP=45 deg. Hole Angle through perforations=68 deg. 4 OPEN HOLE/CEMENT DETAIL 6 20" Cmt w/250 sks of Arcticset I in 30"Hole 9-5/8" Cmt w/1,364 sks PF"E",250 sx Class"G",250 sx PF'E'in 12-1/4"Hole 6 7" Cmt w/220 sks Class"G"in 8-1/2"Hole ';.7 TREE&WELLHEAD Tree FMC 2-9/16"-5M Wellhead 11"5M FMC w/2-7/8"FMC tubing hanger,EUE lift 8 threads,2.5"CIW H BPV profile GENERAL WELL INFO 0 ` API:50-029-22552-00-00 9 I Drilled and Cased by Nabors 4-ES -4/28/1995 +N ESP Completion by Nabors 4-ES—10/25/1995 "A ESP Changeout by Nabors 4-ES—4/11/1998 t ESP Changeout by Nabors 4-ES—11/18/2003 ,� ESP Changeout by Nabors 3S—7/12/2008 4 ESP Changeout by Nabors 3S—9/7/2008 NOTES: Two 20'marker 6.• I. Need Cementing Report to Establish Tops joints located 1; j from 12,344'to c FCO w/Rig to 12,664'7/10/2008 12,385 w1m s.i'? i 1 til /-A328,1 Sands i 7„J ', TD=12,941'(MD)/TD=7,334'(TVD) PBTD=12,837'(MD)/PBTD=7,255'(TVD) Created By:TDF 1/15/2015 Milne Point Unit Well: MPF-01 14 PROPOSED Last Completed: 9/7/2008 Hilcorp Alaska,LLC PTD: 195-045 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm Orig.KB BF 33.03/Orig.GL Elev.= 20" Conductor 91.1/NT8OLHE/N/A N/A Surface 110' 9-5/8" Surface 40/L-80/Btrc. 8.679 Surface 7,124' 7" Production 26/L-80/Btrc 6.151 Surface 12,922' 20 TUBING DETAIL 2-7/8" Tubing 6.4/L-80/EUE 8rd 2.347 Surface _ ±12,229' 1 3/8" Capstring Stainless Steel N/A Surface ±12,229' JEWELRY DETAIL No Depth Item 1 ±133' GLM 2 ±11,970' GLM 3 ±12,116' HES XN-Nipple 4 ±12,159' WellLift Gauge 5 ±12,162' Pump 6 ±12,181' Gas Separator 7 ±12,186' Tandem Seal Section 8 ±12,200' Motor 9 ±12,225' MGU Sensor w/Centralizer PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.A3,A2& 9-5/8" Al Sands 12,488' 12,578' 6,992' 7,059' 90' 10/22/1995 Open 1 ` Note:Jumbo Jet Performance:TTP=6.4",EHD=0.76". 3.38"Gun Diamter,6 spf. 3/8 SS Capstring WELL STIMULATION DETAIL 2 11/18/2003—139,7508 of 16/20 Carbolite. WELL INCLINATION DETAIL KOP @ 600'MD Max Hole Angle=69deg f/7,800'to 8,200' Max angle @ ESP=45 deg. Hole Angle through perforations=68 deg. 4 OPEN HOLE/CEMENT DETAIL I 5 20" Cmt w/250 sks of Arcticset I in 30"Hole 9-5/8" Cmt w/1,364 sks PF"E",250 sx Class"G",250 sx PF'E'in 12-1/4"Hole 6 7" Cmt w/220 sks Class"G"in 8-1/2"Hole TREE&WELLHEAD Tree FMC 2-9/16"-5M Wellhead 11"5M FMC w/2-7/8"FMC tubing hanger,EUE lift 8 threads,2.5"CIW H BPV profile GENERAL WELL INFO API:50-029-22552-00-00 • 9 Drilled and Cased by Nabors 4-ES -4/28/1995 ESP Completion by Nabors 4-ES—10/25/1995 ESP Changeout by Nabors 4-ES—4/11/1998 • ESP Changeout by Nabors 4-ES—11/18/2003 ESP Changeout by Nabors 35—7/12/2008 ESP Changeout by Nabors 3S—9/7/2008 Two 20'marker NOTES: joints located Need Cementing Report to Establish Tops from 12,344'to FCO w/Rig to 12,664'7/10/2008 12,385 wim --3I=j-A3,2&1 Sands 7", I' TD=12,941'(MD)/TD=7,334'(TVD) PBTD=12,837'(MD)/PBTD=7,255'(TVD) Created By:TDF 2/11/2015 MPU BOP Stack r , O iii ii Hydril 13 5/8 5M 13 5/8 5M 2 7/8"-5-1/2" variables Spacer spool 13 5/8 5M 13 5/8 5M Blinds litre 40E1 t, MEI Spacer spool 13 5/8 5M 13 5/8" 5MX11" 5M DSA Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, February 27, 2015 2:29 PM To: 'Chris Kanyer' Cc: Tom Fouts Subject: RE: MPF-01: Pre-RWO Waterflood Management Chris, As we discussed you have approval to continue to produce MPF-01 to reduce BHP.This is in order to facilitate the upcoming RWO to replace ESP. Guy Schwartz Senior 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.schwartz@alaska.gov). From: Chris Kanyer [mailto:ckany hilcorp.com] Sent: Friday, February 27, 2015 12:54 PM To: Schwartz, Guy L (DOA) Cc: Tom Fouts Subject: MPF-01: Pre-RWO Waterflood Management Guy, As discussed, prior to the upcoming rig workover(RWO) on well MPF-01 (API#50-029-22552-00-00 PTD#195-045), we are currently managing the well's bottom hole pressure (BHP) by shutting in offset injectors. Here is the associated inu requested: MPF-01 ESP Prod: • Gross fluid rate prior to ESP failure=2400bfpd • ESP failed 5/11/14. — • Latest static taken 9/14/14—3607psi at datum, 9.9ppg EMW, No functioning BH gauge MPF-84B WIND: • Previously injecting 900bwpd—Shuand Freeze Protected on 1/31/15. MPF-91 WINJ: • Currently online injecting 1400bwpd—currently under consideration for shutting in. (Also supports online producers MPF-06, MPF-96, MPF-86, & MPF-14) No other current offset injection. We plan to produce the MPF-0 by opening it to flow through the tubing until the well's BHP is low enough for us to safely perform the RWO as planned on sundry submitted on 2/26/2015. 1 Please advise regarding any additional steps to move forward. Chris Kanyer I Operations Engineer Hd+nrl+ 4.la+La.LT( ckanyer@ hilcorp.com Direct: (907) 777-8377 Mobile: (907) 250-0374 2 --' - Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. f1'~- 045 File Number of Well History File PAGES TO DELETE Complete RESCAN o Color items - Pages: o Grayscale, halftones, pictures, graphs, charts - Pages: o Poor Quality Original - Pages: o Other - Pages: DIGITAL DATA o Diskettes, No. o Other, NolType OVERSIZED o Logs of various kinds o Other COMMENTS: 9'3 ~~ '-J\ "'".\ Scanned by: BeverlBncent Nathan Lowell Date: ~ L( -\ 151 J7 6 o TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: 151 • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 (.) December 30, 2011 $4ANNED FEB k . 2012 `O o Mr. Tom Maunder Alaska Oil and Gas Conservation Commission \� r ' 333 West 7 Avenue N N\ Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPF -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator ... , . , • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPF -Pad 10/29/2011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls ft gal ---p• MPF -01 1950450 50029225520000 10.2 N/A 10.2 N/A 122.4 8/7/2011 MPF-02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF -05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 1.2 N/A 15.3 8/2/2011 MPF-09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 8/212011 MPF -13 1950270 50029225490000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 8/2/2011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 WA 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/1/2011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/9/2011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF -33 2010620 50029226890000 23 Need top job MPF -34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF -37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -38 1951680 50029226140000 0.3 N/A 0.3 WA 6.8 10/5/2011 MPF-41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF-42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF-45 1950580 50029225560000 8 N/A 8 _ WA 78.2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A N/A MPF-49 1970030 50029227320000 2.3 N/A 23 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF-61 1951170 50029225820000 62 Needtopjob MPF-62 1951610 50029226090000 2.0 NA/ 2.0 N/A 13.6 9/1/2011 MPF -65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/31/2011 MPF-69 1951250 50029225860000 0.8 N/A 0.8 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 WA 13.6 7/31/2011 MPF -77 1951360 50029225940000 0.2 N/A 0.2 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 N/A 5.1 7/31/2011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 N/A 6.8 8/3/2011 MPF-80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/3/2011 MPF -81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF -82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF-83 2000930 50029229630000 1.2 N/A 12 N/A 13.6 8/3/2011 MPF-840 2001760 50029229310200 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF -86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/122011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/132011 MPF -88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/32011 MPF -89 2050900 50029232680000 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/13/2011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/13/2011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/13/2011 MPF -95 1981790 50029229180000 0.5 WA 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 WA 6.0 9/1/2011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/11/2011 ~G STATE OF ALASKA ~ '~~' ALA OIL AND GAS CONSERVATION COA~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ^ Abandon ®Repair Wel! ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ~ ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Changeout ESP - ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. , ®Development ^ Exploratory 195-045 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 SO-029-22SS2-00-00 7. KB Elevation (ft): KBE = 48 8' - 9. Well Name and Number: . MPF-01- 8. Property Designation: 10. Field /Pool(s): ADL 355018 ' Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 12941 ~ feet true vertical 7334 ~ feet Plugs (measured) N/A Effective depth: measured 12664 feet Junk (measured) N/A true vertical 7123 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 110' 110' Surface 7088' 9-5/8" 7124' 4557' 5750 3090 Intermediate Production 12889' 7" 12922' 7373' 7240 5410 Liner Perforation Depth MD (tt): 12488' - 12578' Perforation Depth TVD (ft): 6992' - 7059' 2-7/8", 6.5# L-80 12229' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 1077 388 2041 300 267 Subsequent to operation: 1060 344 2233 390 258 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 ~/q Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number: Si ture - Phone 564-4750 Date (C~'©t'L ~ Sondra Stewman 564-4750 Form 10-404 Revised 04/2006 ~~ ~,',,~~~~ ~ Submit O' final Only /J ~f ~,5~ ~ +~.. TREE: 2 9/16" - 5M F " M P U F -01 O B-BF = 33.03' WELLHEAD: 11 5M FM ORIG. GL. ELEV = 13.1' w/ 2 7/8" FMC Tubing Hanger ,EUE ORIG. KB. -MSL= 48.80' lift threads, 2.5" CIW H BPV profile ORIG. KB- MLSH= 35.96' KB-top of tbg spool= 31.98' 13 3/8" 54 5#/ft K-55 ' . gp I 2-7/8" x 1" KBMG-M-2 GLM 133` KOP @ 600 MD ` ' Max. Hole Angle = 69' ~ 7800 -8200 Hole angle C~ ESP = 45° 9 5/8", 40 #/ft, 7124' NT-80S Btrc Outer annulus shoe is open 2-7/8", 6.4 ppf, EUE 8rd. tbg. j (cap. = 0.0058 bpf) 7" 26 ppf, L-80, btrc. casing (drift ID= 6.151", cap. _ .0383 bpf) (Cap. w/ tbg inside = .02758 bpf) 2-7/8" x 1" KBMG-M-2 GLM 11970` 2-7/8" HES XN nipple( 2.25" id) 12116' WeIILift DGU Discharge Gauge 12159' Centrilift ESP SXD 100-P31 12162' Centrilift Gas Separator 12181' GRSFTXARH6 (513 Internals ) Centrilift Tandem Seal Section 12186' GSB3D6 UT/LT SB/SB PFSA/FSA CLS Centrilift KMH motor, 12200' 304 hp. motor, 2290 v. / 81 amp. Stimulation Summary Interval: 12,578' - 12,488' Well Lift MGU Sensorw/Centralizer 12225' 139,750 lbs. of 16/20 Carbolite Intake Sensor TVD = 6800' Perforation Summary REF LOG: GR/CCL 07/10/95 Gun SPF Interval (TVD) 3 3/8" 6 12,488'-12,578' 6989' - 7057' mid-perf = 7023' tvd Jumbo Jet Performance: TTP = 6.4", EHD = 0.76" Hole angle through perforated interval is 68 deg Two 20' marker joints from 12, 344' to 12,385' wlm Fill cleaned out to 12,664' and w/rig. 7/10/08 7202' tvd ORIG. PBTD(float collar) 12837' 7" 26#, NT-80S NSCC 12921' DATE IREV. BY 1 COMMENTS 11/18/03 MDO ESP Changeout 4-ES 7-12-08 REH ESP Changeout -Nabors 3S 7-12-08 L Hulme ESP Changeout -Nabors 3S MILNE POINT UNIT WELL F-1 API NO: 50-029-22552 BP EXPLORATION • BP EXPLORATION Page 1 of 3 Operations Summary Report Legal Well Name: MPF-01 Common Well Name: MPF-01 Spud Date: 4/13/1995 Event Name: WORKOVER Start: 9/3/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/8/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code , NPT Phase Description of Operations 9/3/2008 00:00 - 06:00 6.00 MOB P PRE MIRU on MPF-01. Assemble Rig and reconnect and test all components, post annual Rig Maintenance. 06:00 - 00:00 18.00 MOB P PRE Scope up derrick, R/U derrick board and rig floor. Trouble shoot operational problems with pipe skate. Work on installation of engine #4 and wire in generator. Mechanic and electricians sent to bed due to hours worked. 9/4/2008 00:00 - 02:30 2.50 MOB P PRE Hook up radiator and air vents to #4, add fluids to engine. Bring handling equipment to rig. Check choke operations. 02:30 - 05:30 3.00 KILL P DECOMP Rig up tiger tank and hard line to tiger tank. Hook up circulating lines to tree. Pressure test circulating lines to 3,500 psi, pressure test hardline to tiger tank to 500 psi. Tank on fluid to pits. 05:30 - 06:00 0.50 KILL P DECOMP R/U Lubricator and pressure test to 500 psi with diesel. 06:00 - 07:00 1.00 KILL P DECOMP Pull BPV. W HPs: T / IA / OA - 700 / 400 / 380 psi. PJSM with Vac truc drivers and Rig crew regarding well kill operation 07:00 - 08:00 1.00 KILL P DECOMP Wind direction venting gas over air intakes for manifold building (could cause Halon system to dump). Knock Tiger Tank loose, move 50 feet farther away, and test to 500 psi. 08:00 - 09:00 1.00 KILL P DECOMP Bleed gas from IA. 380 psi to 90 psi. Come on line pumping 8.7 #/gal brine down Tbg, returns from the IA. Catch fluid in Tbg after 30 Bbls, pump 70 Bbls with 20 bbls returns to tank. Close choke and Bullhead 50 Bbls into formation ~ 2 BPM, 800 psi. IA pressure to 300 psi. Flowcheck well, Tbg pressure to 0 psi, IA C~ 250 psi. 09:00 - 12:30 3.50 KILL P DECOMP Circulate to kill well, pumping down Tbg, returns from IA through choke manifold. Circulate 700 Bbls of 8.7 #/gal brine Q 4 BPM, 1000 psi -Tbg, IA from 250 psi to 20 psi. 415 Bbls of crude, produced water, and brine returned. Losses of 40% to formation 12:30 - 13:00 0.50 KILL P DECOMP Flowcheck well. Tubing and IA to 0 psi. Both on strong vacuum. 13:00 - 14:00 1.00 WHSUR P DECOMP D rod TWC. Test from above to 3500 si and chart for 5 minutes. Prep to ND tree and NU BOPE. 14:00 - 16:30 2.50 WHSUR P DECOMP ND Tree. Check hanger lifting threads w/ 2-7/8" xo, 8-1/2 turns. 16:30 - 00:00 7.50 BOPSU P DECOMP NU BOPE, Remove 13-5/8" GL Hydril and remove from cellar. Install 13-5/8" GK Hydril and lifting ring. Tighten flanges. 9/5/2008 00:00 - 05:00 5.00 BOPSU P DECOMP N/U BOPE, Install blind rams and 2-7/8" x 5" VBR's, Install flow riser, kill line, choke line and koomey lines. Function test ROPE 05:00 - 06:00 1.00 BOPSU P DECOMP Fill BOPE and choke manifold with water and purge air from system. State's right of witness testing waived by Lou Grimaldi. 06:00 - 12:00 6.00 BOPSU P DECOMP Test BOPE. Utilize 2-7/8" test joint. Test all components to 250 / 3500 psi for 5 minutes and chart. Koomey drawdown test. 12:00 - 13:00 1.00 PULL P DECOMP PUMU Opso-Lopso. Screw into tubing hanger with 9 turns. PUMU lubricator. Pull TWC. Tubing and IA on vacuum. 13:00 - 14:30 1.50 PULL P DECOMP PUMU 2-7/8" landing joint with TIW valve installed. Screw into hanger. BOLDS. Pull hanger with 92K PUW. Pull hanger up into stack. Pump 8.8 #/gal brine down tubing ~ 3.5 BPM, 760 psi. Returns after 45 Bbls pumped. 14:30 - 15:30 1.00 PULL P DECOMP BOLD tubing hanger and landing joint. Cut ESP cable and run up over shieve to spooler unit. 15:30 - 00:00 8.50 PULL P DECOMP Regulate hole fill ~ 20 Bls/Hr with 8.8 #/ al brine. POH Printed: 9/22/2008 12:37:34 PM BP EXPLORATION Page 2 of 3 Operations Summary Report Legal Well Name: MPF-01 Common W ell Name: MPF-01 Spud Date: 4/13/1995 Event Nam e: WORKO VER Start : 9/3/2008 End: Contractor Name: N ABOBS ALASK A DRI LLING I Rig Release: 9/8/2008 Rig Name: N ABOBS 3S Rig N umber: Date ~ From - To I Hours ' Task I Code I NPT I Phase ', Description of Operations 9/5/2008 15:30 - 00:00 8.50 PULL P DECOMP standing back 2-7/8" tubing in the Derrick. 9/6/2008 00:00 - 07:00 7.00 PULL P DECOMP Regulate hole fill ~ 20 Bls/Hr with 8.8 #/gal brine. POH standing back 2-7/8" tubing in the Derrick. 07:00 - 09:30 2.50 PULL P DECOMP BOLD ESP assembly. I wire from intake and discharge of pump "mangled". Recovered all but 6-8' of 1/4" tech wire. Fished a 5' piece out of stack. Shaft from motor twisted off a connection to lower tandem seal. 09:30 - 12:00 2.50 BUNCO RUNCMP Clean and clear floor. Rig up for running completion. BOLD 11 joints of galled 2-7/8" tubing. Discuss options with Town Eng. Decide to run 2 Tess joints of tubing on re-completion. 12:00 - 16:30 4.50 BUNCO RUNCMP PUMU new ESP BHA. Service motor, apply 8 Canon Crossguard clamps to Tec wire on motor. Attempt to RIH w/ _ ESP BHA. Hang up in wellhead with Canon clam s; PU and inspect kinked I wire. Troubleshoot and try to work ESP into Casing. Unable to do so because of tight clearances 16:30 - 20:30 4.00 BUNCO RUNCMP Remove Canon clamps. Install new tech wire with 2 protectolizers and 8 bands to I wire and motor cable lead. M/U ESP Cable Lead. Check connections. Run in hole without problems. 20:30 - 00:00 3.50 BUNCO RUNCMP RIH with ESP completion on 2-7/8", L-80, 6.5#, EUE 8rd tubing. Use Best-O-Life 2000 pipe dope. Make up torque of 2,300 fUlbs. Check ESP cable conductivity every 2,000' and flush pump with 10 bbls of brine. 1.5 bpm at 700 psi. Maintain holefill of 20 bbls/hr with 8.8 ppg brine. 9/7/2008 00:00 - 03:00 3.00 BUNCO RUNCMP RIH with ESP completion on 2-7/8", L-80, 6.5#, EUE 8rd tubing. Use Best-O-Life 2000 pipe dope. Make up torque of 2,300 Wlbs. Check ESP cable conductivity every 2,000' and flush pump with 10 bbls of brine. 1.5 bpm at 700 psi. Maintain hole fill of 20 bbls/hr with 8.8 ppg brine. 03:00 - 07:00 4.00 BUNCO RUNCMP Make splice in ESP cable. Flush pump with 10 bbls of brine. 1.5 bpm at 700 psi. Maintain holefill of 20 bbls/hr with 8.8# brine. 07:00 - 12:30 5.50 BUNCO RUNCMP RIH with ESP completion on 2-718", L-80, 6.5#, EUE 8rd tubing. Use Best-O-Life 2000 pipe dope. Make up torque of 2,300 ft/Ibs. Check ESP cable conductivity every 2,000' and flush pump with 10 bbls of brine. 1.5 bpm at 700 psi. Maintain hole fill of 20 bbls/hr with 8.8 ppg brine. 12:30 - 13:30 1.00 BUNCO RUNCMP Flush pump @ 1.5 BPM, 700 psi. Check cable - ok. PUMU landing jt with TIW valve, tubing hanger, orient properly. 13:30 - 15:30 2.00 BUNCO RUNCMP Make penetrator splice. Final checks: 4.2 ohms -phase to phase / 400 meg ohms -phase to ground /intake psi - 3065 psi /discharge psi - 3048 /temp - 157 deg F. 15:30 - 16:30 1.00 BUNCO RUNCMP PUW - 78K /SOW - 44K. Final tally on accessories: 197 LaSalle clamps / 8 bands / 3 Flatguards / 4 protectolizers. Land tubin han er. RILDS. 16:30 - 17:00 0.50 WHSUR P RUNCMP D rod TWC. Test from above to 3500 psi. Chart for 5a minutes. 17:00 - 20:30 3.50 WHSUR P RUNCMP N/D and lay over BOP stack. 20:30 - 23:30 3.00 WHSUR P RUNCMP N/U 2-9/16" 5M Tree. Test hanger void to 5,000 psi for 20 minutes, test tree to 5,000 psi with diesel. Centrilift performed final check on ESP, 4.8 ohms phase to phase / 400 meg ohms - phase to ground, intake psi - 2961 psi, discharge psi - 2940 psi, temp 163 deg F. Printed: 9!22!2008 12:37:34 PM Printed: 9/22/2008 12:37:34 PM -" STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION C011AMISSION BODE Test Report submit to: Contractor: Nabors Rig No.. 3S DATE: 9/5/2008 Rig Rep.: J. Greco / R. Bjorhus Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: Bp Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: J. Menke f B.Burson FieldJUnit & Well No.. MP F-01 PTI3 # 195046ft Operation: Drlg: Workover: x Ea~lor.: Test: Initial: x Weekly: Bi-Weekly Test Pressure: Rams: 250135 r: 25013541Q Valves: 250/3500 MISC. INSPECTIONS: Test Result Location Gen.: P Weti Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P soP sTACK: FLOOR SAFETY VALVES: Test Result Quantity Test Result P Upper Kelly 0 NA P Lower Kelly 0 NA P Bali Type 1 P Inside BOP 1 P Quantity Size Test Result Annular Preventer 1 13 518 5000 P Pipe Rams 1 2 718 X 5 P Lower Pipe Rams 0 NA Blind Rams 1 P Choke Ln. Valves 1 31/8" 5(1~ P HCR Valves 2 3118" 5040 P Kill Line Valves 1 2 1116" 5000 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P F Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Tune/Pressure Test F System Pressure 3100 P Pressure After Closure 1850 P 200 psi Attained 19 P FuN Pressure Atta~ed 1 min 33 sec P B~td Sv~itdt Covers: All stations P Nitgn. Botties (avg): 1900 Number of Failures: 0 TestTuc-e: 4 Hours Components tested A~LI Repair or replacement of . meat w be maces with clays. Notify the North Slope Inspector 659-3607, foNow with written confirmation to Supenriser at: Remarks: Tested with 2 7/8" test iou~t, test apa~st Two Wav Check valve E TWC ). 24 HOUR NOTICE GIVEN YES X NO _ Date 09/03108 Time 8:00 est start 8:30 Finish BOP Test (for rigs) ~ ;~~~~~i'ivC~` .~ ~ ~~~~~ BFL 11/14/07 By Lou Gramaldi Witness J.Greco/J Menke Nabors 3s BOP Test MP F-01 9-5-200$.xls STATE OF ALASKA tZ ALF~ OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS c, 1. Operations Performed: f~.' ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Changeout ESP ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 195-045 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22552-00-00 7. KB Elevation (ft): `~ KBE = 48.8' 9• Well Name and Number: MPF-01 8. Property Designation: 10. Field/Pool(s): '!. ADL 355018 ~ Milne Point Unit I Kuparuk River Sands 11. Present well condition summary Total depth: measured 12941 feet true vertical 7334 feet Plugs (measured) N/A Effective depth: measured 12837 feet Junk (measured) N/A true vertical 7255 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 110' 110' Surface 7088' 9-5/8" 7124' 4557' 5750 3090 Intermediate Production 12889' 7" 12922' 7373' 7240 5410 Liner r ( {~(~ Perforation Depth MD (ft): 12488' - 12578' Perforation Depth TVD (ft): 6992' - 7059' 2-7/8", 6.5# L-80 12290' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 730 269 1748 340 302 Subsequent to operation: 26 9 65 180 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ^ Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 N/A Printed Name Sondra Stewman Title Drilling Technologist Sign ure cJ .Prepared By Name/Number: Phone 564-4750 Date(~~ (~~ ~jS Sondra Stewman, 564-4750 Form 10-404 Revised 04/2006 ~ $ ~l ~ (_.~ ~ ~~ /~ -~~1~ S mit n I O ~ TREE: 2 9/16" - 5M F WELLHEAD: 11" 5M FM MPU F-01 O .KB-BF=33.03' ORIG. GL. ELEV = 13.1' w/ 2 7/8" FMC Tubing Hanger ,EUE ORIG. KB. -MSL= 48.80' lift threads, 2.5" CIW H BPV profile ORIG. KB- MLSH= 35.96' I KB-top of tbg spool= 31.98' 13 3/8" 54.5#/ft K-55 80' KOP C~3 600 MD Max. Hole Angle = 69° 7800' to 8200' 2-7/8" x 1" KBMG-M-2 GLM 131' 9 5/8", 40 #/ft, 7124' NT-80S Btrc Outer annulus is open 2-7/8", 6.4 ppf, EUE 8rd. tbg. (cap. = 0.0058 bpf) 7" 26 ppf, L-80, btrc. casing (drift ID= 6.151", cap. _ .0383bpf) Stimulation Summary Interval: 12,578' - 12,488' 139,750 lbs. of 16/20 Carbolite Perforation Summary REF LOG: GR/CCL 07/10/95 Gun SPF Interval (TVD) 3 3/8" 6 12,488'-12,578' 6989' - 7057' mid-perf = 7023' tvd Jumbo Jet Performance: TTP = 6.4", EHD = 0.76" Hole angle through perforated interval is 68 deg DATE REV. BY COMMENTS 4/28/95 10/25/95 DBR JBF Drill and Case ESP Com letion b N 4ES 04/11/98 M. Linder E5P Changeout 4-ES 11/18/03 MDO ESP Changeout 4-ES 7-12-08 REH ESP Changeout -Nabors 3S 2-7/8" x 1" KBMG-M-2 GLM 12,150' I 2-7/8" HES XN nipple( 2.25" id} 12,176' Centrilift ESP PMSXD 1-5/100-P31 12,220` Centrilift Gas Seperator 12,241' GRSTXARH6 (513 internals ) Centrilift Tandem Seal Section 12,247` GS63DBUT/LT SB/SB PFSA/FSA CL5 Centrilift KMH motor, 12,260' 304 hp. motor, 2290v. / 81 amp. Well Lift MGU Sensor w/Centralizes 12,286' Two 20' marker joints from 12, 344' to 12,385' wlm Fill cleaned out to 12,771' and w/rig. 11 /18103 7202' tvd ORIG. PBTD(float collar) 12837' 7" 26#, NT-80S NSCC 12921 MILNE POINT UNIT WELL F-1 API NO: 50-029-22552 BP EXPLORATION (A Page 1 s~f 1 • Well: MPF-01 Well History Well Date Summary MPF-01 6/27/2008 (Freeze Protect TBG /Flush FL's) T/I/0= 300/380/360 Pump 15 bbls diesel down TBG followed by 2 bbls 60/40 then 3 bbls diesel then 2 bbls 60/40 meth down FL and test line. FWHP= 300/380/360 wing =shut,swab=shut,master =shut, ssv=shut, IA and OA valves open to gauges. MPF-01 6/30/2008 PRE RIG GAS LIFT***ARRIV ON LOC WELL S/I*** PULLED D-VALVE FROM STA # 1 C~ 12,171' SLM LEFT EMPTY PULL DPSOV FRO STA # 2 C~ 123' SLM SET D-VALVE *** TURN WELL OVER TO DSO *** ««< NEEDS SBHPS AND BPV »»> MPF-01 6/30/2008 T/IA/OA= SSV/540/500 Temp= SI PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RWO) PPPOT-T RU 2 HP bleed tools onto THA 150 psi to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 4950/ 30 minutes. Bleed void to 0 psi, RD test equipment, re installed Alemite cap. Cycle and torque LDS "ET style" all moved with no problems. PPPOT-IC RU 2 HP bleed tools onto IC test void 50 psi to 0 psi. Pressured to 3500 psi for 30 minute test, 3400/ 15 minutes, 3400/ 30 minutes. Bleed IC void to 0 psi, RD test equipment re installed Alemite cap. Cycle and torque LDS "ET style" all moved with no problems. MPF-01 7/1/2008 The Well Support Techs rigged up and s_et a back pressure valve and then removed the wellhouse, owin't1Tan~Tou' nTcalion. NOTE: The BPV was left IN!!!!! MPF-01 7/3/2008 ****WELL S/I ON ARRIVAL**** (sbhps) RAN DUAL SPARTEK GAUGES TO 11722' MD FOR 30 MIN & 12211' MD FOR 6 HRS ASSISTED WELL SUPPORT PULL & RESET BPV ****WELL LEFT SHUT IN TURNED OVER TO PAD-OP UPON DEPARTURE******** MPF-01 7/13/2008 (Freeze Protect TBG and IA) T/I/O= 0/0/0 Pump 15 bbls dead crude down TBG followed by 65 bbls dead crude down IA to freeze protect well. FWHP=O/0/0 swab shut /wing shut/ ssv shut /master shut / IA and OA open to gauges. MPF-01 8/5/2008 The Well Support Techs rigged up and removed the back pressure valve and leak tested the flowlines to 1150 psi. NOTE: The BPV was left OUT and the leak test was GOOD!!!! Print Date: 8/7/2008 Page 1 of 1 PoSa~~ • BP EXPLORATION Operations Summary Report Legal Well Name: MPF-01 Common Well Name: MPF-01 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 3S Date From - To I Hours !, Task Code NPT Start: 7/7/2008 Rig Release: 7/12/2008 Rig Number: Page 1 of 3 Spud Date: 4/13/1995 End: Phase ', Description of Operations 7/7/2008 02:00 - 09:30 7.50 RIGD P PRE 09:30 - 12:00 2.50 MOB P PRE 12:00 - 18:00 6.00 RIGU P P RE 18:00 - 23:00 5.00 KILL P D ECOMP 23:00 - 00:00 1.00 KILL P D ECOMP 7/8/2008 00:00 - 02:30 2.50 KILL P D ECOMP 02:30 - 03:00 0.50 KILL P D ECOMP 03:00 - 04:30 1.50 KILL P D ECOMP 04:30 - 08:00 3.50 KILL P D ECOMP 08:00 - 09:00 1.00 KILL P DECOMP 09:00 - 10:00 1.00 WHSUR P DECOMP Rig down components off of MPG-08A. Scope and lower the Derrick at 03:30 hrs. Disconnect hardline from wellhead. Pull off of well slot MPG-08A at 08:30 hrs with the Pad Operator, Well Site Leader and Toolpusher present. Connect Peak Trucks to all Modules and prepare for rig move. Notify Milne Point Radio of moving the Rig. Mobilize the Rig and all Modules from MPG-Pad to MPF-Pad. Arrive on MPF-Pad. Spot the Camp, Generator, Shop and Parts Trailer per approved Camp Siting Form. Spot the BOPE behind the well. Back the Carrier over well slot MPF-01 and pull off. Lay out Herculite and Rig Mats. Spot and connect the Pipe Shed and Pits Modules. RU Handy Berm. Raised and scoped Derrick at 17:00 hrs. Prep & clean rig. Rig accepted 1800 hrs on 07/07/08. RU double annulus valve and begin RU circulating lines to the Tree. GPB Well Support rig up the Tiger Tank and hardline from MPG-Pad to MPF-Pad. Pressure test all surface lines to 3500 psi. Pressure test lines downstream from choke to Tiger Tank to 500 psi. RU lubricator and pressure test lubricator to 500 psi. Pull BPV. TBG = 700 psi, IA = 630 psi, OA = 650 psi. Bleed OA from 650 psi to 10 psi in 120 min. 2 trucks w/ 290 bbls of 8.8 seawater on location. Wait on final truck to arrive with 8.8 seawater. Final load of 8.8 ppg on location. Fill pits with brine and check weight off truck, 8.8 ppg. Bleed TBG pressure thru choke from 690 psi to 140 psi in 4 min. Bled back gas then swapped to heavy crude. Bled IA thru choke from 650 psi to 60 psi in 16 min. Bled back gas then swapped to fluid. Starting pressures before circulation, TBG = 260 psi, IA = 140 psi. Circulated 80 bbls the long way thru the choke taking returns to the Tiger Tank. Circulated ~ 2 BPM, tubing pressure ranged from 230-260 psi, annulus pressure ranged from 140-200 psi. Shut in well, bullhead 25 bbls down tubing C~3 3 BPM with final pressure = 1000 psi on tubing & 720 psi on IA. Shut down pump, tubing bled back to 0 psi in 1 min and IA bled back to 280 psi in 5 min. Lost 4 bbls while circulating. Returns were gas and heavy crude. Begin circulating down the tubing taking returns thru the choke and to the Tiger tank. Circulating ~ 2 - 2.5 BPM controling returns with the choke. Bleeding back gas and heavy crude. Shut down pump and strap tank. Losing almost 1/2 circulating fluff .Continue circulating. 160 bbls circulated ~ 0600 hrs. Final circulating parameters were 3.5 bpm / 910 psi on the Tubing with 30 psi on the Casing and full Choke. Circulated until clean 8.8 ppg brine returns observed on surface. Pumped a total of 525 bbls up the IA to clean it out. Lost 155 bbls during circulation. Shut down the Pump and monitor the well for 30 mins. The Tubing and IA are on a vacuum. Blow down and RD circulating lines. PU T-bar and set 2-1/2" Type "H" TWC with FMC rep. Printed: 7/24/2008 1:40:27 PM • BP EXPLORATION Operations Summary Report Page 2 of 3 Legal Well Name: MPF-01 Common Well Name: MPF-01 Spud Date: 4/13/1995 Event Name: WORKOVER Start: 7/7/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/12/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code NPT I! Phase Qescription of Operations 7/8/2008 09:00 - 10:00 1.00 WHSUR P DECOMP Blow down and RD test equipment. 10:00 - 12:00 2.00 WHSUR P DECOMP ND Tree and Adapter Flange with FMC rep. Check the Hanger Threads. 2 7/8" EUE, 7 turns. 12:00 - 16:00 4.00 BOPSU P DECOMP NU BOPE. John Crisp w/ AOGCC waived State's right to witness testing ~ 14:00 hrs. 16:00 - 20:30 4.50 BOPSU P DECOMP FIII Stack. Function test BOPE components. Pressure test to 250 / 3500 psi w/ 2 7/8" test joint. Test witnessed by NAD toolpusher and BP WSL. 20:30 - 22:00 1.50 BOPSU P DECOMP RD test equipment & test joint. MU Opso Lopso to tubing hanger. RU wells support lubricator and pressure test to 500 psi. Pull TWC, tubing & IA on vacuum. Well took an average 22:00 - 23:30 I 1.501 PULL I P 23:30 - 00:00 I 0.50) PULL I P 7/9/2008 100:00 - 01:30 I 1.501 PULL I P 01:30 - 02:30 1.00 PULL P 02:30 - 04:00 1.50 PULL P 04:00 - 06:00 2.00 PULL P 06:00 - 15:30 9.50 PULL P 15:30 - 19:30 I 4.00 I PULL I P DECOMP PUMU landing jt with circulated head. BOLDS, screw into hanger 7 turns with landing jt. Hanger pulled free ~ 110k. Pick up 5' to circulate. DECOMP Circulate 75 bbls ~ 3 BPM / 650 psi. Took 19 bbls to catch returns. Lost 35 bbls while circulating. Monitor well for 10 min. Fluid level visibly dropping. -Loss rate = 20 bbls/hr. DECOMP Pull tubing hanger to floor. PUW = 100k, SOW = 30k. Centralift disconnect ESP cable from penetrating head. L/D landing jt & tubing hanger. MU 1 jt of tubing to string, secure cable pig tail to collar with LaSalle clamp & SS banding. DECOMP Sinole in hole from 12,278'. Taa ~ 12.541', unable to work, thru. L/D 9 jts used to tag. Install TIW and continue hole fill ~ 20 bbl/hr. DECOMP PJSM. RU ESP spooling unit to rig. Attach upper sheave and elephant trunk. DECOMP Stand back 2-7/8" ESP completion from 12,278' while spooling cable to unit. 06:00, 22 stands, 10' pup, and 1 GLM OOH. Continuous hole fill regulated ~ 25 Bbl / Hr. DECOMP POH standing back 2-7/8" ESP completion in Derrick. 70 Stands OOH ~ 10:00 and get returns. Continue POH pumping across the top w/ 8.8 #/gal brine. Losses stable ~ 25 Bbls / Hr. DECOMP Losses consistent ~ 25 Bbls / Hr. BOLD ESP Assembly. Competion recovered: -382 joints, 2 GLM ass'y, 1 XN ass'y, ESP Pump & Seal ass'y w/ Phoenix Guages. -195 LaSalle Clamps, 3 Armesters, 5 Protectalizers 19:30 - 00:00 4.50 CLEAN P CLEAN Clean and clear rig floor. PUMU 3-1/2" muleshoe, XO to 2-7/8" EUE. Strap stands &RIH on 380 joints from previous completon. 70 stands in ~ 24:00 hrs. 7/10/2008 00:00 - 04:00 4.00 CLEAN P CLEAN Continue RIH w/ 2-7/8" stands. 04:00 - 06:00 2.00 CLEAN P CLEAN PU singles from pipe shed. RIH and tag ~ 12.540'. R/U circulating head to reverse circulate. 06:00 - 13:00 7.00 CLEAN P CLEAN Crew change, re-check pipe tally and tag depths. Pump 30 Bbls of Hi-Vis pill ~ 3 BPM, 610 psi jetting to 12,555'. Swap over and reverse circulate ~ 3 BPM, 540 psi. Jet then reverse as RIH w/ singles from pipe shed cleaning fill. Frac sand and "silt" material in returns. FCO to 12664' (86' of rathole). Started getting rocks and gravel in returns, hard bottom. Losses ~ 0 Bbls. Flow check well, well balanced. Printed: 7/24/2008 1:40:27 PM • BP EXPLORATION Operations Summary Report Page 3 of 3 Legal Well Name: MPF-01 Common Well Name: MPF-01 Spud Date: 4/13/1995 Event Name: WORKOVER Start: 7/7/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/12/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task 'Code NPT Phase Description of Operations 7/10/2008 13:00 - 16:00 3.00 CLEAN P CLEAN Mix and pump 30 Bbl of Hi-Vis pill ~ 4.2 BPM, 1000 psi circulating the long way. Pump pill surface to surface. 'r 7 B I wit 13 B Is I t. Flo-check well. Well stable. POH to 12285'. Weight up brine system to 9.1 #/gal for 16:00 - 22:00 6.00 CLEAN P CLEAN Weight up pit system to 9.1 #/gal. Circulate and weight up hole volume C~3 3.5 BPM / 870 psi. Circulate 9.1 #/gal in - 9.1 #/gal out. Circulated $]~ bbls. lost 20 bblc dt!rina circclation. Monitor well, fluid visibly dropping. 22:00 - 00:00 2.00 CLEAN P CLEAN PJSM. RD circulating head. POH standing back 2-7/S" TBG. -43 stands pulled ~ 24:00 hrs. 7/11/2008 100:00 - 06:00 6.001 CLEAN ~ P 06:00 - 07:00 I 1.001 CLEAN I P 07:00 - 12:30 I 5.501 RU 12:30 - 22:00 I 9.50 22:00 - 00:00 I 2.00 7/12/2008 00:00 - 03:00 3.00 RU 03:00 - 06:00 3.00 RU 06:00 - 07:00 I 1.00 07:00 - 08:30 I 1.50 08:30 - 10:00 I 1.50 10:00 - 11:30 I 1.50 I RNTBHG P 11:30 - 15:00 3.50 BOPSUF~ P 15:00-18:00 3.00 WHSURP 18:00 - 19:00 1.00 WHSUR P 19:00 - 20:00 1.00 WHSUR P CLEAN Continue standing back 2-7/8" tubing. Maintain losses ~ 7 bbl/hr while POH. UD 4 bad jts (gaulded threads). Jt #128, #129, #142, #143. L/D muleshoe & XO. CLEAN Clean and clear rig floor. Rig down elephant trunk. Prep for running ESP. RUNCMP PUMU ESP as er Centrilift uidance. Make connection splice for I-wire between MGU Sensor and WeIILift gauge. RUNCMP PU 2-7/8" singles from pipe shed (5 ea), w/ XN nipple and GLM w/ DGLV. RIH on 2-7/8" tubing from Derrick. Insped flat spot in cable armor (OK). Continue RIH w/ constant hole fill and losses ~ -6 Bbls / Hr. Found bad jt #133 -swap out from shed. Check cable and flush pump every 2000' as RIH (1.5 BPM / 480 psi). 120 stands in hole. Pump across hole and monitor. RUNCMP Change spools. Centralift cut & splice ESP cable in spooling unit. RUNCMP Continue ESP splice. Loss rate during splice 6 bbl/hr. RUNCMP RIH w/ 2-7/8" tubing. Check conductivity every 2000'. Pumped down tubing ~ 1.5 BPM / 480 psi. RUNCMP Finish RIH w/ 382 'ts of 2-7/8" tubin , 1 XN, 2 GLM's. Flush pump ~ 1 BPM, 500 psi. PUMU hanger. Ran 198 LaSalle clamps, 5 Protectos, 3 Armster guards, 5 SS x 3/4" bands on "I" wire. Final cable checks show upper WeIILift gauge to not be working. Troubleshoot, change computers (used to check gauge). RUNCMP PUMU tubing hanger. Unable to diagnose problem with downhole discharge pressure gauge. RUNCMP Cut cable and make penetrator splice. MU to tubing hanger. Final checks: 4.2 ohm phase to phase / 400 meg /Intake psi - 3221 psi / BHT - 163.37 deg f / 162.6 Volts. TUBHGR PUW - 88,000 #'s /SOW - 33,000 #'s. Land hanger, RILDS. Break out and lay down landing joint. Dry rod TWC. Test from WHDTRE Drain stack. Nipple down BOPE. Film crew on location. WHDTRE NU Tree. Test tubing head adaptor and tree to 5000 psi. Centilift make final checks: 4.2 ohms balanced phase to phase / 2 K phase to ground / 420 meg ohms / 3128 psi BHP / 166 deg F BHT. (-50 on Pump discharge gauge -failed) WHDTRE P/T lubricator to 500 psi. Pull TWC. Set BPV. Normal up tree WHDTRE I Final checks. `~~Release rig ~ 20:00 hrs 7112/08"' Printed: 7/24/2008 1:40:27 PM STATE OF ALASKA 11l14/~7 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report submit to: Contractor: Nabors Rig No.: 3S DATE: 7/8/2008 Rig Rep.: J. Greco / J. Fritts Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: Bp Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: J. Menke / V. Volpe Field/Unit & Well No.: MP F-01 PTD # 19b04ti0 Operation: Drlg: Workover: x Test: Initial: x Weekly: Test Pressure: Rams: 250/3500 Annular: 250!3500 TEST DATA MISC. INSPECTIONS: Test ResuR Test Result Location Gen.: P Well Sign P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13 518 5000 P Pipe Rams 1 2 7/8 X 5 P Lower Pipe Rams 0 NA Blind Rams 1 Blind P Choke Ln. Valves 1 3 i/8" 5000 P HCR Valves 2 3 1/8" 5000 P Kill Line Valves 1 2 1/16" 5000 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3050 P Pressure After Closure 1700 P 200 psi Attained 31 sec P Full Pressure Attained 2 min 3 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 2000 Explor.: Bi-Weeky Valves: 250/3500 FLOOR SAFETY VALVES: Quanfity Test Re Upper Kely 0 NA Lower Kely 0 NA Bab Type 1 P tnside BOP 1 P Number of Failures: 0 Test Time: 4 Hours Components tested ALL Repair or replacement of equipment wiN be made witlrin days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: Remarks: Tested with 2 7/8"'test joint. test against Two Wav Check valve (TWC ). 24 HOUR NOTICE GIVEN YES X NO Date 07/06/08 Time 1830 hrs start 1630 hrs Finish By John Witness J.FrittsN: BOP Test (for rigs) BFL 11/14/07 ~~~~C~ JUL ~ ~ 2008 Nabors 3s BOP Test MP F-01 7-8-08.x1s Ke: MPr-U 1 lA pressure '~-- .~~ Subject: Re: MPF-Ol IA pressure From: Thomas Maunder <tom _ maunder@admin.state.ak.us> \ ~S -OL..\ç Date: Fri, 21 Jul 2006 14:20:37 -0800 To: -"MPU,W ell Operations Supervisorft<welloperationssupervisor@BP.com> : CC:. "Anders, . Joe.L "~<anciers22@BP . com>, "Engel,HarryR" <~any.Engel@BP.com>, .ItMPU, Opefatîons Mariager" <ACTOperatiönsManager@BP.com;>, Jim Regg. <jim-1"egg@ádmin.state.alcus> Clint, Thanks for the notice. The IA pressure is a consequence of the SD and the wellbore fluids that flowed into the well following pump SD. I'd expect that a number of other wells out there have elevated pressures now as well, although not as high as this well. As you note, when the well is started back up the gas head will be relieved into the production system. Nothing further is needed at this time. Tom Maunder, PE AOGCC MPU, Well Operations Supervisor wrote, On 7/21/2006 2:14 PM: Tom, To follow up our phone conversation: We shut in MPF-01 (ESP producer, no packer) yesterday due to turn around, and the operator noted an IA pressure of 2200 psi. The pressure exhibited is gas pressure setting on top of the fluid column and once we bring on the well we will be able to relieve the IA pressure through the orifice in the tubing. Plan is to bring on the well July 24th. We are currently are monitoring the pressure and it is stable. Thanks Clint Spence 670-3330 ~CANNED JUL 2 1 2005 1 of 1 7/21/20062:30 PM ( STATE OF ALASKA { ALASKA --_L AND GAS CONSERVATION CO)vllv1ISSION REPORT OF SU NDRY WELL OPERATIONS 1. Type of Request: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): KBE = 48.8' 8. Property Designation: ADL 355018 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 78' Surface 7088' Intermediate Production 12889' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 0 Suspend 181 Repair Well 181 Pull Tubing 0 Operation Shutdown 0 Perforate 0 Plug Perforations 0 Stimulate 0 Perforate New Pool 0 Re-Enter Suspended Well 4. Current Well Class: iii Development 0 Exploratory 0 Stratigraphic 0 Service 0 Variance 181 Othe! 0 Time Extension Changeout ESP 0 Annular Disposal 5. Permit To Drill Number 195-045 6. API Number: 50-029-22552-00-00 9. Well Name and Number: MPF-O1 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands 12941 7334 12837 7255 feet feet Plugs (measured) Junk (measured) N/A N/A feet feet Size MD TVD 110' 110' 7124' 4557' 12922' 7373' Burst Collapse 20" 9-5/8" 5750 3090 7" 7240 5410 12488' - 12578' 6992' - 7059' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 2-7/8",6.5# L-80 12282' N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: DEC 172003 Alaska Oil & Gas Cons. Commission Anchorage 13, Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl Re resentative Dail Gas-Met Tubin Pressure Water-Bbl 15. Well Class after proposed work: 0 Exploratory iii Development 0 Service 16. Well Status after proposed work: iii Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL est 0 my know e ge. Sundry Number or N/A if C.O. Exempt: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations Printed Name Sondra Stewman Title Technical Assistant Phone Prepared By Name/Number: Sondra Stewman, 564-4750 Date l ~ - \ Sighatwe Form 10-404 Revis,ed 2/2003 " \",','.1, C «" ~ 1l) n O"f '~'. . ',",;""';;,."" J En..\lß Q)) .1 !..UUJ! '.. '- . ,"" ,,-..-_.- ." DEC 1 ., ',JOn] ~BfL Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/14/2003 11/15/2003 11116/2003 (' ( BP EXPLORATION Operations Summary Report MPF-01 MPF-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From - To Hours 06:00 - 09:30 09:30 - 10:00 10:00 - 21 :30 21 :30 - 00:00 00:00 - 01 :00 01 :00 - 03:00 03:00 - 08:30 08:30 - 10:00 10:00 - 14:30 14:30 -19:00 19:00 - 20:00 20:00 - 22:30 22:30 - 11 :30 11 :30 - 00:00 00:00 - 02:30 02:30 - 04:00 04:00 - 04:30 04:30 - 07:00 07:00 - 09:30 09:30 - 13:30 13:30 - 15:00 15:00-17:00 17:00-19:00 19:00 - 19:30 Task Code N PT Phase 3.50 MOB 0.50 MOB p P PRE PRE 11.50 MOB P PRE 2,50 MOB P PRE 1.00 KILL 2.00 KILL P P DECOMP DECOMP 5.50 KILL P DECOMP 1.50 KILL P DECOMP 4,50 KILL P DECOMP 4.50 KILL 1,00 KILL P P DECOMP DECOMP 2,50 KILL 13,00 KILL P P DECOMP DECOMP 12.50 KILL P DECOMP 2.50 KILL P DECOMP 1.50 KILL P DECOMP 0.50 WHSUR P 2.50 WHSUR P 2.50 BOPSUR P 4.00 BOPSUR P DECOMP DECOMP DECOMP DECOMP 1.50 WHSUR P DECOMP 2.00 PULL P DECOMP 2.00 PULL P DECOMP 0.50 PULL P DECOMP POOH wI 27/8" tbg & ESP completion. LID 3 jts of 27/8" tbg. LID GLM assy. Spool ESP cable over sheave & attach to Page 1 of 2 Start: 11/14/2003 Rig Release: 11/20/2003 Rig Number: Spud Date: 4/29/1997 End: 11/20/2003 Description of Operations PJSM. Lower & layover derrick, Prepare modules for move, PJSM. Conduct pre move meeting with Security, electricians, truck drivers & all associated with move. Move rig components from A-24 to Milne Point F-01. 39 mile move, PJSM, Rig up on MP F-01, Raise & scope derrick & level pipe shed, Rig Accepted @ 00:00. Rig up lines to tiger tank, PJSM. Pull BPV & check pressures. 9.1 ppg brine being weighted up to 9.5 ppg as recent BHPs require. PJSM. Take on fluid & circulate down tbg @ 4 bpm I 1500 psi, taking returns to tiger tank. wI 70 bbls pumped, close choke & bullhead (25) bbls. Final bullhead rate = 1.5 bpm @ 2500 psi. Resume circulating @ 4 bpm I 1550 psi, 500 bbls total pumped. Take returns to pits...9.4 ppg coming back with slight oil skim. Monitor well, well flowing. Shut in & monitor pressures. SITP = 150 psi & buiilding, SICP = 180 psi & building. Call for bromide & make plans to weight system up. Bromide a little slow in arriving as rig #7 moving at this time. Monitor well while waiting, SITP up to 330-350 psi now, indicating need to weight system up to 11 ppg. PJSM. Begin mixing bromide to weight system up to 11 ppg. Begin killing well wI 11 ppg NaBr fluid. Pump @ 3 BPM. 1200 psi. Pumped 200 bbls of weighted fluid. SID & con't to weight up fluid. TP 20 psi, CP 60 psi. Con't to mix & weight up fluid from 9.6 to 11 ppg. Con't to Kill well, Pump 200 bbls @ 3 BPM, 800 psi. SD & con't to weight up fluid. TP 10 psi, CP 20 psi. Need to pump additional 25 bbls to have complete circulation. Con't to weight up fluid from 9.5 ppg to 11 ppg. Note: sacks of NaBr are caked & have to broken up to mix in hopper. Con't to mix & weight up fluid from 9.5 to 11 ppg. Sack contents are caked & have to broken up to mix in hopper. Pump 11 ppg, 3 BPM @ 1000 psi. Pump total of 480 Bbls until 11 ppg in & 11 ppg out. SD & monitor well. Circulate 50 more bbls of 11 ppg fluid. Monitor well, well dead. Blow down & RID circulating lines. Set TWC & test to 3500 psi. PJSM. NID tree. PJSM. N/U 13 5/8" x 5M BOPE. PJSM. Pressure test annular preventor @ 250 I 2500 psi & all other components of the BOP system @ 250 I 3500 psi. Witnessing of test waived by AOGCC rep Jeff Jones, No failures. PJSM. Pull 2 way check. Tubing on vacuum. Check IIA, also on vacuum. PJSM, Back out lock down screws & make up landing joint. Pull hanger to floor, 96K to get pipe moving, up weight leveled off at 87K. Break out hanger & rig up to pull ESP cable. Circulate bottoms up @ 4.5 bpm I 2100 psi. 22 bbls to fill hole, Printed: 11/24/2003 8:32:11 AM ( ( BP EXPLORATION Page 2 of 2 Operations Summary Report Legal Well Name: MPF-01 Common Well Name: MPF-01 Spud Date: 4/29/1997 Event Name: WORKOVER Start: 11/14/2003 End: 11/20/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/20/2003 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/16/2003 19:00 -19:30 0,50 PULL P DECOMP spooler. 19:30 - 22:30 3,00 PULL P DECOMP POOH wI 46 stands of tbg, 22:30 - 23:00 0.50 PULL P DECOMP Change out ESP cable spools. Attach cable to new spool. 23:00 - 00:00 1,00 PULL P DECOMP Con't to POOH wI stands of 27/8" tbg, 64 stands out @ midnight. 11/17/2003 00:00 - 05:00 5.00 PULL P DECOMP Con't to POOH w/2 7/8" ESP completion, Laid down jt # 234, bad pin (galled). Replaced coupling on jt # 235. Everything below ports in lower GLM was plugged wI grey sludge & very fine sand. Some gas entrapment. Break out & LID everything from GLM assy to pump. 126 stands in derrick. 05:00 - 08:30 3.50 PULL P DECOMP Break out & LID ESP. Recovered 211 clamps, & (2) pump clamps. 08:30 - 10:00 1.50 CLEAN P DECOMP Clear I Clean rig floor & prep to pick up 3 1/2" DP. Set Wear Bushing. 10:00 - 12:00 2.00 CLEAN P DECOMP PJSM. Pick up clean out BHA. 12:00 - 23:00 11.00 CLEAN P DECOMP Pick up 31/2" DP & RIH wI clean out BHA. RIH to 11878', 370 Jts. Down drag increased to 30K, 23:00 - 00:00 1.00 CLEAN P DECOMP M/U head pin & reverse circulate. 5 BPM @ 1500 psi. Reversed up 2 DP volumes. Lost 14 Bbls of fluid. Had scale & fine sand returns, 11/18/2003 00:00 - 01 :00 1.00 CLEAN P DECOMP Con't to P/U DP 1x1 & RIH, Tag up @ 12471' 389 jts + 22', 01 :00 - 06:00 5.00 CLEAN P DECOMP Attempt to reverse out,hard bottom, P/U kelly & rotate down thru fill. Reverse out. Had scale, & carbolite to surface. Con' t to rotate down & reverse out. Getting much carbolite back. Cleaning out @ 12, 581' @ 0600 hrs. P/U 180K. SIO 85K, Rot 90K. Reverse @ 3BPM, 800 psi. 06:00 - 12:00 6.00 CLEAN P DECOMP Continue to clean out wellbore, circulating I rotating down @ 4 bpm I 300 psi each connection, then reverse circulating @ 3 bpm I 1100 psi to clean returns. Clean out to 12,771'. 12:00 - 14:30 2.50 CLEAN P DECOMP PJSM. Reverse circulate 25 bbls Hi Vis sweep around @ 12,771'. 14:30 - 00:00 9,50 CLEAN P DECOMP PJSM. Stand back kelly & POOH laying down 3 1/2" DP. 11/19/2003 00:00 - 02:30 2.50 CLEAN P DECOMP Clean rig floor, prepare Centrilift equipment. 02:30 - 03:00 0.50 CLEAN P DECOMP Hold PJSM for Centrilift ESP assembly and RIH activities. 03:00 - 08:00 5.00 RUNCO~ /P CaMP M/U ESP and lube sub assemblies, penetrator. 08:00 - 09:30 1,50 RUNCO~ /P CaMP Tag up 20' in after running discharge head. POOH & examine assembly for marks. Run in after removing power cable, detect area of restriction. Pull out, re-attach power cable & La Salle clamps, run in & work thru casing top. 09:30 - 15:30 6.00 RUNCor ~ CaMP Continue in hole with 2 7/8" L80 EUE tubing & ESP assembly, checking conductivity every 2000'.80 stands run. 15:30-19:00 3.50 RUNCor fp CaMP Perform ESP cable splice. Fill tubing & pump (10) bbls @ 1 bpm 1100 psi. 19:00 - 22:30 3.50 RUNcor (p CaMP Continue RIH wI 2-7/8" L80 EUE and Land ESP at 12,280'. Up Weight on string = 81,000 Ibs; Slack-off Weight = 35,000 Ibs. 22:30 - 00:00 1.50 RUNCor fp CaMP Make cable cut and assemble pigtail to penetrator in tubing hanger. 11/20/2003 00:00 - 01 :00 1.00 RUNCOr (p CaMP Complete pigtail assembly and allow adhesive to cure. 01 :00 - 06:00 5.00 RUNcor ~ CaMP RD Centrilift; Install TWCV and test; ND BOPE and NU lock down flange, Tbg. head adaptor, and 2-9/16" tree. Pres test Tbg. Hd. adaptor and tree to 5,000 psi. Pull TWC wI lubricator, Set BPV. Release Rig @ 06:00, Printed: 11/24/2003 8: 32: 11 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Convert to injection 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: I~ Development [] Exploratory [--I Stratigraphic i-'-I Service 4. Location of well at surface 1711' NSL, 2801' WEL, Sec. 6, T13N, R10E At top of productive interval 571' NSL, 631' WEL, Sec. 35, T14N, R9E At effective depth 677' NSL, 672' WEL, Sec. 35, T14N, R9E At total depth 709' NSL, 901' WEL, Sec. 35, T14N, R9E 6. Datum Elevation (DF or KB) KBE = 49' 7. Unit or Property Name Milne Point Unit 8. Well Number MPF-01 9. Permit Number 95-45 10. APl Number 50- 029-2255200 1. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 12941 feet true vertical 7330 feet Effective depth: measured 12837 feet true vertical 7251 feet Casing Length Size Structural Conductor 78' 20" Sudace Intermediate 7088' 9 5/8" Production Liner 12889' 7" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset 1 (Approx.) 1364 sx PF 'E', 250 sx 'G', 250 sx PF'E' 20 sx Class 'G' ORIGINAL MD TVD 110' 110' 7124' 4557' 12922' 7320' Perforation depth: measured true vertical 12488' - 12578' (Subsea) 6944' - 7010' Tubing (size, grade, and measured depth) 2 7/8" L-80 to 12262' Packers and SSSV (type and measured depth) None RECeiVED 16 t.998 GaS C011s. C0rllffljssJ0rl ~ch0rage 13. Attachments [~ Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation December 23, 1998 16. If proposal was verbally approved 15. Status of well classifications as: [~ Oil [] Gas [] Suspended Service Name of approver Date approved Contact Engineer Name/Number: Bob Laule, 564-5195 Prepared By Name/Number: Jeanne Haas, 564-5225 17. I hereby certify that the foregoing is true an,d correct to the best of my knowledge TitW- '/¢/ Date ~ Commission Use Only Approved by order of the Commission Notify Commission so representative may Witness I Approval Plug integrity __ BOP Test __ Location clearance Mechanical Integrity Test /,/ Subsequent form required 10- /Vi IT- u--~r~ginai Signca Oavid W Johnstor, Commissioner Date Scope of work outline for the Milne Point well F-1 conversion to Injection service. MIRU Pull BPV with lubricator. Circulate well with kill weight brine. Install TWC and ND tree. NU BOP and test. Pull TWC with lubricator Pull existing 2-7/8" ESP completion Make GR/JB mn to PBTD. Run 4-1/2" robing with permanent packer completion. Set TWC ND BOP and NU and test tree. Pull TWC with lubricator Displace annulus with inhibited brine and Freeze protect Set packer. Test packer. Testing to be wimessed by AOGCC representative. Set BPV release rig. F' E R H ~ T D A T A T D A T A__P !.. L! S 95---()."4.5 6772 "T i2000-'i2~'~,27 GR - ~ "r"' N ,q / :.;:..-; I.. D ~ 'i ,2 q '-- 'i 29 ~.,,- 'i H ..O !.;', -- 0 ~ 5 D (-, R/' . ........... 95 .... 0 L,,. 5 ID G F,: / ('; "'4 '..3,/S L D ~ 5 -- 7 :~ :!;/,.- T V D 95-'-0'4.5 E;,,.3R/'E',,,',,'R/~. ~ "i 25 .... i'294-'i b'iD 9B 0/4. ~'~ ,'qR/'CCL ~ 1 ''~3 00- 'i 27 00 'i 07/'2~/'q ,.3 .. . ~ , '- ' '--,'~ 95 -- O ."..~ 5 :5 T i:,, T F' R E S S U R E ~ 'l 25 :¢ B .... 'i 26 '-.? 0 J 7, ?/' 2./~/' g !3 ,L'.. 0 M b4 E i'q '1- S STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. ~tatus of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 95-45 3. Address B. APl Number P.O. BOX 196612, Anchorage, Alaska 99519-6612 5o-029-22552 4. Location of well at surface ~~,~ 9. Unit or Lease Name 1711'NSL, 2801'WEL, SEC. 6, T13N, R10E ",~,~! MilnePointUnit At Top Producing Interval ./~"~?i::"~7' :"~;;:..."~! ~) . :. 10. Well Number ~ ..... '~' ~ MPF-01 571' NSL, 631' WEL, SEC. 35, T14N, RgE ; 11. Field and Pool At Total Depth 709' NSL, 901' WEL, SEC. 35, T14N, R9E ,. ,_ 5. Elevation in feet (indicate KB, DF, etc.) 16.' L~aSe Designation and Serial No. KBE = 49' I ADL 355018 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 04/14/95 04/28/95 10/25/95I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey ~20. Depth where SSSV set 21. Thickness of Permafrost 12941'MD/7334'TVD 12837'MD/7255'TVD YES [] NO []! N/A feet MD 1800'(Approx.) 22. Type Electric or Other Logs Run Gyro, MWD, GR/RES/NEU/DEN 23. CASING, UNER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# NT8OLHE 32' 110' 30" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 36' 7124' 12-1/4" 1364 sx PF 'E', 250 sx 'G; 250 sx PF 'E' 7" 26# L-80 33' 12922' 8-1/2" 220 SX Class 'G' 24. Pedorations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" gun diameter, 6 spf 2-7/8", L-80 12271' N/A MD TVD 26. ACID, FRACTURE, CEMENT SQUFFTF, ETC. 12488' - 12578' 6993' - 7074' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect w~ 64 bbls diesel to 2100' 27. -PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 12/13/95 I ESP Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SlZE IGAS-OIL RATIO I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. ORIGINAL RECEIVED MAY 05 1996 ~,la~ka 0il & Gas Cons. commission Form 10-407 Ancn0rag~ Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TKUA 12475' 6983' TKA3 12486' 6991' TKA2 12503' 7004' TKA 1 12532' 7025' 31. LIST OF A'I-rACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~-----'~ ~'C~/~ Title~niorDri/lino_En_clineer Date-~q"~~/~~ ~/'. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS' PAGE: 1 WELL: MP F-01 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 04/15/95 12:01 SPUD: RELEASE: 04/30/95 11:59 OPERATION: DRLG RIG: NABORS 27E WO/C RIG: NABORS 4ES 04/15/95 (1) TD: 110'( 0) 04/16/95 (2) TD: 1739'(1629) 04/17/95 ( 3) TD: 3631'(1892) 04/18/95 (4) TD: 5305'(1674) 04/19/95 (5) TD: 6823'(1518) 04/20/95 (6) TD: 7144'( 321) MU BHA MW: 0.0 VIS: 0 SET OUT PIPE SHED, PITS, MOTOR COMPLEX AND PULL SUB OFF MP F-37. SET SUB OVER MP F-01. SET MOTOR COMPLEX. SET PIT COMPLEX AND FUEL STORAGE TANK. LAY MATS FOR PIPE SHED AND SET PIPE SHED. BERM AND SET CUTTINGS TANK. BERM AND SET PARTS HOUSE. BUILD BERMS AROUND RIG AND PIPE SHED, SET DOWN STAIRS. SET TIOGA HEATER. HOOK UP SUCTIONS. SET 20" HYDRIL, HOOK UP DIVERTER LINE. HOOK UP FLOWLINE. SET MOUSE HOLE. PREP, OD, ID, BHA. MU BHA #1. DRILLING MW: 0.0 VIS: 0 PICK UP BHA. ORIENT, ATTEMPT TO PROGRAM MWD, BAD CONNECTION. CHANGE OUT TOP SECTION. RE-ORIENT. KELLY UP. TAG BTM @ 110'. DRILL F/ 110 - 1739' DRILLING MW: 0.0 VIS: 0 DRILL F/ 1739 - 3065'. SHORT TRIP TO 1120'. NO PROBLEMS, NO FILL. DRILL F/ 3224 - 3631'. DRILLING MW: 0.0 VIS: 0 DRILL F/ 3631 - 4579'. MWD FAILED. BATTERY WENT DEAD PREMATURALY. CBU. MONITOR WELL, PUMP DRY JOB. POH. CHANGE BIT. GAUGE STABILIZERS. DOWNLOAD MWD. CHANGE OUT TOP SECTION OF MWD. ORIENT TOOL. RIH. FILL PIPE @ 2600'. RIH. KELLY UP. NO PROBLEMS, NO FILL. DRILL F/ 4579 - 5305'. DRILLING MW: 0.0 VIS: 0 DRILLING F/5305 T/6062. CBU. MONITOR THE WELL, PUMP DRY JOB. SHORT TRIP T/4362. NO PROBLEMS. NO FILL. DRILL F/6062 T/6823. RIH WITH 9 5/8" CASING MW: 0.0 VIS: 0 DRILLING FROM 6823 - 7144'. CIRCULATE SWEEP AROUND. FLOWCHECK WELL, OK. PUMP DRY JOB. SHORT TRIP TO HWDP. NO PROBLEMS. HOLE IN GOOD SHAPE. SLM. NO CORRECTION. RIH. HOLE CLEAN. NO FILL. CIRCULATE AND CONDITION HOLE BEFORE POH TO RUN SURFACE CASING. FLOWCHECK WELL, OK. PUMP DRY JOB. SET BACK KELLY. POH. LD SURFACE HOLE BHA. DOWNLOAD MWD. LD SAME. CLEAR FLOOR. RU CASING TOOLS. RIH WITH 9 5/8-", 40#, NT-80, BTC CASING. WELL : MP F-01 OPERATION: RIG : NABORS 27E PAGE: 2 04/21/95 ( 7) TD: 7144'( 0) 04/22/95 (8) TD: 7154' ( 10) 04/23/95 (9) TD: 8384' (1230) 04/24/95 (10) TD: 9331'( 947) 04/25/95 (11) TD:10688' (1357) FINISH NU BOPE/CHOKE/RISER MW: 0.0 VIS: 0 FINISH RIH W/ 9 5/8", 40#, NT-80L, BTC CASING TO TD AT 7124'. CASING WENT RIGHT TO BOTTOM. AT TIMES HOLE WOULD BEGIN TO TAKE FLUID WHILE RIH. BREAK CIRCULATION. CIRCULATE AND CONDITION HOLE BEFORE CEMENTING. TEST CEMENT LINES, OK. LD CEMENT HEAD. RU AND PERFORM TOP JOB. LD LANDING JOINT. CLEAR FLOOR. ND HYDRIL AND DIVERTER. NU SPEED HEAD. NU BOPE, CHOKE LINE, RISER AND FLOWLINE. RINISH RUN LEAKOFF TEST MW: 0.0 VIS: 0 FINISH RU NEW TEST MANIFOLD. CONDUCT JAR SCHOOL AT RIG W/ CHAS KIDD OF DAILEY OIL TOOLS. TEST BOPE. GOOD TEST. TD TEST EQUIPMENT AND INSTALL WEAR RING. STRAP/CALIPER BHA. MU SAME. RIH W/ HWDP. SLIP N CUT DRLG LINE. RIH TO 5684'. CONDUCT STRIPPING DRILL. CONTINUE RIG TO 7013'. BREAK CIRCULATION. CIRC AND CONDITION MUD. TEST CASING. GOOD TEST. BLEED OFF PRESSURE. DRILL FLOAT EQUIPMENT + 10' OF NEW HOLE. CBU. PERFORM LOT. RUNNING IN HOLE REF GYRO MW: 0.0 VIS: 0 DRILLING F/ 7154'. SWEEP HOLE. CBU. FLOWCHECK WELL. OK. PUMP DRY JOB. SET BACK KELLY. SHORT TRIP. PULL INTO 9 5/8" SHOE. HOLE IN GOOD SHAPE. RIH AFTER SHORT TRIP. NO PROBLEMS. NO FILL. RU ATLAS W/ GYRO DATA. RIH F/ IN HOLE REFERENCE GYRO. DRILLING MW: 0.0 VIS: 0 CONTINUE RUN IN HOLE REFERENCE GYRO F/ 8030 TO SURFACE. RD GYRO/DATA. RD ATLAS WL. PU KELLY AND REAM TO BOTTOM @ 8384'_ DRILLING FROM 8384 - 9299' SWEEP HOLE/CBU. FLOWCHECK WELL, OK. PUMP DRY JOB. SET BACK KELLY. SHORT TRIP TO 7663'. NO PROBLEMS. HOLE IN GOOD SHAPE. PU KELLY AND TAKE BENCHMARK SURVEYS AT 7663' AND 7753' RIH. PU KELLY. DRILLING FROM 9299 - 9331'. DRILLING MW: 0.0 VIS: 0 DRILLING FROM 9331 - 9807' LEVEL RIG. SUBSTRUCTURE BEGIN TO SETTLE CAUSING BIND IN LINES BETWEEN SUBSTRUCTURE AND PITS. DRILLING FROM 9807 - 10698'. WELL : MP F-01 OPERATION: RIG : NABORS 27E PAGE: 3 04/26/95 (12) TD:10945' ( 257) 04/27/95 (13) TD:11542' ( 597) 04/28/95 (14) TD:12730' (1188) RIH W/ BHA #4 MW: 0.0 VIS: 0 DRILLING FROM 10688 - 10931' LAST 30 - 50' UNABLE TO SLIDE AND ROTATE ROP DOWN. SHUT SOWN PUMPS. SET BACK KELLY. PULL 5 STANDS JUST TO WIP HOLE ACROSS BHA IN EFFORT TO GIVE SECURITY PDC BIT CHANCE TO DRILL. DRILL FROM 10688 - 10945'. NO IMPROVEMENT. FLOWCHECK WELL. OK. PUMP DRY JOB. POH TO SHOE. FLOWCHECK WELL, OK. POH TO LWD EQUIPMENT. UNLOAD SOURCES AND DOWNLOAD LWD/MWD. BREAKOFF BIT. INSPECT TURBINE~ BEARING SECTION FAILED IN TURBINE. SERVICE WEAR RING. PU MOTOR, BIT, XO SUB. ORIENT MWD AND MOTOR. CHANGEOUT PULSER TOOL, UPLOAD LWD. INSTALL SOURCES. RIG TO 5000'. FILL DP. CONTINUE RIH TO 7751'. GET BENCHMARK SURVEYS. OK. DRILLING MW: 0.0 VIS: 0 RIH TO 10896'. KELLY UP, CIRCULATE TO 10946'. DRILL F/ 10946 - 11318'. MIDDLE POT WASHED ON #2 PUMP WASHED OUT. ATTEMPT TO ISOLATE PUMP, 4" DISCHARGE VALVE WASHED OUT. REPAIR VALVE. DRILL F/ 11318 - 11411'_ CIRCULATE SWEEP, PUMP DRY JOB, MONITOR WELL. POH TO 9 5/8" SHOE. CHANGE OUT WASHED OUT POT ON #2 PUMP. RIH. NO PROBLEMS. 10' OF FILL. DRILL F/ 11411 - 11542' DRILLING DRILL F/ 11542 - 12730'. MW: 0.0 VIS: 0 04/29/95 (15) TD:12941' ( 211) 04/30/95 (16) TD:12941' ( 0) DOWN LOAD MWD MW: 0.0 VIS: 0 DRILL F/ 12730 - 12894'. CIRCULATE LO-HI VIS SWEEP. MONITOR WELL, PUMP DRY JOB, BLOW DOWN LINES, SET BACK KELLY. POH TO CSG SHOE. MONITOR WELL. RIH TO 12894'. DRILL F/ 12894 - 12941'. CIRCULATE LO - HI VIS SWEEP. MONITOR WELL, PUMP DRY JOB, BLOW DOWN LINES, SET BACK KELLY. STAND BACK 10 STANDS. LAY DOWN DRILL PIPE. RUN 10 STANDS IN HOLE FROM DERRICK. BREAK KELLY. LAY DOWN DRILL PIPE AND HWDP. LAY DOWN BHA #4. DOWN LOAD MWD SOURCES. CIRCULATE AND CONDITION MW: 0.0 VIS: 0 LAY DOWN BHA #4. CHANGE RAMS TO 7". PULL WEAR RING. BODY TEST BOPE. RIG UP TO RUN 7" CSG. RUN 312 JTS 7", L-80, 26#, NSCC CSG. CIRC @ 7117, 9000, 10500'. MAKE UP HGR AND LDG JT. MU CMT HEAD. CIRCULATE AND CONDITION MUD. WELL : MP F-01 OPERATION: RIG : NABORS 27E PAGE: 4 05/01/95 (17) TD:12941' ( 0) 10/18/95 (18) TD:12921 PB:12837 RELEASE RIG MW: 0.0 VIS: 0 TEST LINES. XO BETWEEN CMT HEAD AND CSG LEAKED. REPAIR, RETEST. LD LDG JT, CSG TOOLS, CLEAR FLOOR. INSTALL PACKOFF AND TEST. CHANGE RAMS TO 5". LAY DOWN STAND OF HWDP AND PU RUNNING TOOL. CUT 224' DRLG LINE. SLIP 328'. LD MOUSE HOLE, ND FLOWLINE, RISER, CHOKE AND KILL LINE. SET BACK BOPE. INSTALL FALSE BOWL, HOLE DOWN FLANGE, ADAPTOR AND TREE. TEST FLANGE AND TREE. CLEAN PITS, RD FLOOR, INJECT MUD AND~ATER, FREEZE PROTECT ANNULUS. CLEAN CELLAR. RELEASE RIG ~ 1159 HRS ON 04/30/95. MIRU MW: 0.0 RIG DOWN, MOVE OUT. STANDBY. CONT MIRU TO MPF-01. 10/19/95 (19) TD:12921 PB:12837 10/20/95 (20) TD:12921 PB:12837 10/21/95 (21) TD:12921 PB:12837 10/22/95 (22) TD:12921 PB:12837 SLM & DRIFT TUBING MW: 0.0 SPOT RIG, SCOPE & RAISE DERRICK. BERM COMPONENTS & TAKE ON BRINE. RIG ACCEPTED @ 1100 HRS., 10/18/95. TEST RBP, ND TREE, PULL DUMMY HANGER, SET TEST PLUG & RILDS. NU BOPE. ATTEMPT TO TEST HYDRIL. TEST FAILED. CHANGE OUT HYDRIL PACKING ELEMENT. TEST BOPE'S. TEST WITNESSING WAIVED BY BOBBY FOSTER WITH AOGCC. LOAD PIPE SHED WITH 2-7/8" TUBING. STRAP & DRIFT. CIRC/COND WORKOVER FLUID MW: 0.0 SERVICE RIG. LOAD, STRAP & DRIFT TUBING. MU RETRIEVING HEAD & PU TUBING. TAG ICE. WASH DOWN BRINE DISPLACING METHANOL TO TT. PU SINGLES & WASH DOWN ICE WITH BRINE. PU TUBING T/11814'. CIRC & WASH F/11814' T/11840'. CIRC & COND BRINE. CLEAN OUT RUN MW: 0.0 CIRC & COND BRINE. WASH DOWN T/11641' & LATCH ON RBP. CBU WITH BRINE. MIX XANVIS PILL. SHUT WELL IN & CIRC OIL GAS OUT TO TT THRU DEGASSER & CHOKE. MONITOR. RIH T/11940'. CIRC & SPOT XANVIS PILL. MONITOR WELL. POOH WITH 2-7/8" TUBING & LD RBP. STRAP & MU BHA & RIH WITH 2-7/8" TUBING. PUMP DIRT MAGNET SOLUTION MW: 0.0 RIH TO PERF TOP @ 12488'. ATTEMPT TO REV CIRC, HANGING & PLUGGING UP. WASH DOWN LONG WAY T/12600'. UNABLE TO REV CIRC. SUCCESSFUL @ SCRAPING PERFS. POOH T/12485'. SIW & CIRC GAS OUT THRU CHOKE & DEGASSER. REV CIRC F/12485' T/12524'. MIX & SPOT XANVIS PILL @ 12524'. POOH WITH 2-7/8" & BHA #2. PU BHA #3 & RIH TOF @ 12528'. REV CIRC & WASH F/12485' T/12837'. RECIPROCATE & ROV CIRC SAND @ 12837' PBTD. MIX & PUMP DIRT MAGNET SOLUTION FOLLOWED BY SOURCE WATER. MAY 0 5 1996 Alaska 011 & Gas Cons. Commissio~ Anchora~le WELL : MP F-01 OPERATION: RIG : NABORS 4ES PAGE: 5 10/23/95 (23) TD:12921 PB:12837 RIH WITH TUBING MW: 0.0 REV CBU & PUMP DIESEL. CLEAN PLUG UP FLOWLINE. REPAIR MUD PUMP. REV CIRC BRINE. CLEAN PLUG FLOWLINE. SHUT DOWN & REPAIR VALVE IN PIT #3. MIX XANVIS SWEEP. REV CIRC XANVIS SWEEP. CIRC LONG WAY & CATCH XANVIS SWEEP & PUMP SAME DOWN TUBING & BULLHEAD INTO PERFS. OBSERVE WELL. CONT CIRC XANVIS PILL OUT PIT GAIN. REPAIR MUD PUMP. TAKE ON BRINE. MIX XANVIS SWEEP. ATTEMPT TO REV XANVIS SWEEP. SHUT DOWN, CIRC LONG WAY & RETURN.)XANVIS PILL TO SURFACE & SAVE. PUMP DOWN TUBING. BULLHEAD'IN PERFS. MONITOR. POOH & LD DP. PULL OUT SLOW THRU PERF & POOH WITH TUBING. LD DRILL COLLARS & JARS. MU MS & RIH WITH 2-7/8" TUBING. 10/24/95 (24) TD:12921 PB:12830 RIH WITH BHA #5 MW: 0.0 RIH WITH 2-7/8" TUBING T/12602'. CIRC XANVIS SWEEP & DISPLACE BRINE, RETURNS TO TT. PUMP LONG WAY XANVIS SWEEP, SPOT & BULLHEAD INTO PERFS. ATTEMPT TO REV CIRC, COULD NOT REVERSE. PUMPING AWAY FLUID. RIH & TAG FILL @ 12830'. PU KELLY, ROTATE & RECIPROCATE 30' WHILE PUMPING XANVIS SWEEPS. RECOVER LITTLE SAND FRAC ON #1 SWEEP & LOTS OF SAND FRAC ON #2 SWEEP. PUMP #3 SWEEP WITH XANVIS WHILE ROTATE & RECIPROCATE 30' RECOVER VERY LITTLE SAND @ SHAKERS. MONITOR. POOH & LD DP. SLOW THRU PERFS. WET. MIX & PUMP PILL. LD & POOH WITH 2-7/8" TUBING. LD BHA #4. STRAP & MU HA #5. RIH WITH 2-7/8" TUBING. 10/25/95 (25) TD:12921 PB:12830 MAKE IN LINE ESP SPLICE MW: 0.0 RIH WITH BHA #5. TAG FILL @ 12792'. POOH & LD BHA #5. PWR. PU KELLY & WASH BOP'S. CLEAN FLOW LINE. RU & MU ESP ASSY. CENTRILIFT SPOOL UNIT. MU PIG TALL SPLICE. RIH WITH 2-7/8" TUBING. ESP COMP ASSY. DRIFT TUBING. CHANGE SPOOL & MAKE IN LINE ESP SPLICE. 10/26/95 (26) TD:12921 PB:12830 RELEASED @ 1800 HRS,10/25 MW: 0.0 SPLICE ESP CABLE. CONT RIH WITH ESP ASSY. MU HANGER & LANDING JT. INSTALL 2 WAY CHECK. SPLICE ESP LINE FROM HANGER. LAND TUBING. RILDS & LD LANDING. ND FLOW LINE, RISER & BOP. NU ADAPTER FLANGE & TREE & TEST. PULL 2 WAY WITH LUB & INSTALL BPV. FREEZE PROTECT WELL DOWN ANNULUS & DOWN TUBING. SECURE XMAS TREE & PREPARE TO MOVE. RIG RELEASED @ 1800 HRS., 10~25/95. (drill£ng suplrintendent) DATE: ~,~/~,¥ 0 ~ 1996 Gas Cons. commissio~ Anchorage gyroLdafa ':¡ ,'I ~ ~,~ ~ ,'" IfD1' 0 FI LMED P'/ " ,.: ':o'¡ If" ,. "', ~ .J, ",' " '. . ", .J:.:, j".,;i.~.,~,1.: ., I~ "'... .' ~ !ri 'Ü Ii; ¡j' ~ ~ II \!l Date~ RECE\VED MAV 031996 Alaska OU & Gas Cons. Comm\ss\on Anchorage B.P. EXPLORATION MILNE POINT FIELD, WELL NO. MPF-O1 NORTH SLOPE, ALASKA Gyro Multishot Survey in 5.5" drill pipe 1£ Survey date: 23 April, 1995 ¿;;/t~ ./ 'D 1 v Job number: AKO495G261 . ( ,.,., """"""~"I ..."'0.. .<":,~:'\\';:::=J"<~./ /_, ';, . '.\ ,.- ,r" "'--' " I '\J ;' ( " i) '\' ,"';" '~""./ " 'r'--/ \~/ SR 106. DOC gyro/data Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 May 2, 1995 Ms. Marian Sloan B.P. Exploration Prudhoe Bay Drilling Department 900 E. Benson Blvd. Anchorage, AK 99508 Re; Milne Point Field, Well No. MPF-01 North Slope, Alaska Dear Ms. Sloan, Enclosed please find one (1) original and four copies (4) of the completed survey of Well #MPF-01 We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Sincerely Operations Manager RS/gr Serving the Worldwide Energy Industry with Precision Survey Instrumentation gyro/data CONTENTS JOB NUMBER :AK0495G261 1. DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR106.DOC gyro/data 1. DISCUSSION, SURVEY CERTIFICATION SHEET SR106.DOC gyro/data DISCUSSION JOB NUMBER' AK0495G261 Tool 113 was run in MPF-01 on ATLAS 7~32" Wireline inside 5.5" drill pipe. The survey was run without problems. SR106.DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER: AK0495G261 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS ENGINEER SR106.DOC gym/data 2. SURVEY DETAILS SR106.DOC gyro/data SURVEY DETAILS JOB NUMBER: AK0495G261 CLIENT: B.P. EXPLORATION RIG: ATLAS LOCATION: MILNE POINT WELL: MPF-01 LATITUDE: 70.515 N LONGITUDE: 149.5 W SURVEY DATE: 23-APRIL, 1995 SURVEY TYPE : MULTISHOT IN 5.5" drill pipe DEPTH REFERENCE: MAX. SURVEY DEPTH: ROTARY TABLE EVELATION 45.6 asl 8010 SURVEY TIED ONTO: N/A SURVEY INTERVAL: 100' 30' (8010-7380') UTM CO-ORDINATES: TARGET DIRECTION: 297.15 GRID CORRECTION: CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: STODDARD SR106.DOC gyro/data 3. OUTRUN SURVEY LISTING SR106.DOC A Gyroda t a D i r e c t i ona i Survey for B.P. EXPLORATION WELL: MILNE POINT, MPF-01 Location: NABORS 27E, MILNE POINT, ALASKA Job Number: AK0495G261 Run Date: 23-Apr-95 04:45:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.515000 deg. N Sub-sea Correction from Vertical Reference: 45.6 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 297.150 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyr oda t a D i r e c t i on a i Survey B.P. EXPLORATION WELL: MILNE POINT, MPF-01 Location: NABORS 27E, MILNE Job Number: AK0495G261 POINT, ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 0.0 0.00 0.00 0.0 0.0 0 - 8030 FT. GYRO SURVEY RUN IN DRILLPIPE. MEASURED DEPTHS ARE REFERENCED TO AN R.K.B A 20 PT. WIRELINE CORRECTION IS APPLIED TO -45.6 0.00 0.0 0.0 . HEIGHT OF 45.6 FT. THE MEASURED DEPTHS. 0.00 N 0.00 E i20.0 .33 203.50 120.0 -.0 220.0 .30 212.99 220.0 -.0 320.0 .46 207.04 320.0 .0 420.0 .49 222.19 420.0 .1 520.0 .36 212.96 520.0 .3 74.4 .27 .3 203 .5 174.4 .06 .9 206.3 274.4 .16 1.5 207.6 374.4 .13 2.4 210.1 474 · 4 .14 3 · 1 212 · 1 · 31 S .14 W .79 S .39 W 1.37 S .71 W 2.04 S 1.18 W 2.61 S 1.63 W 620.0 .34 203.73 620.0 .3 720.0 1.53 287.58 720.0 1.6 820.0 3.42 296.42 819.9 5.9 920.0 '4.18 304.44 919.7' 12.5 1020.0 6.29 300.14 1019.2 21.6 574.4 .06 3.7 211.5 674.4 1.54 4.5 227.8 774.3 1.92 7.4 260.0 874.1 .93 13.1 279.3 '973.6 2.14 21.8 288.5 3.14 S 1.92 W 3.01 S 3.32 W 1.28 S 7.27 W 2.11 N 12.94 W 6.92 N 20.69 W 1120.0 8.11 291.40 1118.4 34.1 1220.0 10.38 292.91 1217.1 50.1 1320.0 12.53 296.55 1315.1 69.9 1420.0 15.31 297.88 1412.2 93.9 1520.0 17.48 299.53 1508.1 122.2 1072.8 2.12 34.3 290.9 1171.5 2.28 50.3 291.4 1269.5 2.27 70.1 292.4 1366.6 2.80 94.1 293.6 1462.5 2.23 122.3 294.8 12.25 N 32.00 W 18.33 N 46.87 W 26.69 N 64.87 W 37.71 N 86.24 W 51.29 N 110.98 W 1620.0 19.42 301.07 1603.0 153.8 1720.0 21.75 301.08 1696.6 188.8 I820.0 21.99 301.81 1789.4 226.0 1920.0 22.10 301.10 1882.1 263.4 2020.0 22.43 299.13 1974.6 301.2 1557.4 2.00 153.8 295.9 1651.0 2.33 188.8 296.9 1743.8 .36 226.0 297.6 1836.5 .29 263.4 298.2 1929.0 .81 301.3 298.4 67.27 N 138.30 W 85.42 N 168.41 W 104.85 N 200.18 W 124.44 N 232.20 W 143.44 N 264.98 W A Gyro da t a D i r e c t i o n a i Survey B.P. EXPLORATION WELL: MILNE POINT, MPF-01 Location: NABORS 27E, MILNE POINT, Job Number: AK0495G261 ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. HORIZONTAL COORDINATES feet .2120.0 24.37 300.88 2066.4 2220.0 26.04 300.43 2156.9 2320.0 28.71 301.32 2245.7 2420.0 30.94 300.64 2332.4 2520.0 32.76 302.76 2417.4 340 383 429 478 531 .9 .4 .3 .9 .5 2020.8 2111.3 2200.1 2286.8 2371.8 2.06 341.0 298.6 1.68 383.6 298.8 2.70 429.5 299.1 2.26 479.2 299.3 2.13 531.9 299.5 163.32 N 299.35 W 185.02 N 335.98 W 208.63 N 375.43 234.22 N 418.07 m 261.96 N 462.94 W 2620.0 34.76 302.43 2500.5 2720.0 37.58 304.08 2581.2 2820.0 39.71 302.28 2659.3 2920.0 41.15 301.36 2735.4 3020.0 42.49 301.08 2810.0 586 645 707 772 838 .8 .5 .6 .2 .7 2454.9 2535.6 2613.7 2689.8 2764.4 2.02 587.4 299.8 2.97 646.3 300.1 2.41 708.7 300.4 1.56 773 .5 300.5 1.35 840.2 300.6 291.89 N 509.76 W 324.27 N 559.09 W 358.42 N 611.36 W 392.60 N 666.47 W 427.17 N 723.49 W 3220.0 47.79 300.97 2951.0 3320.0 51.64 300.73 3015.6 3420.0 53.94 304.09 3076.1 3520.0 58.19 303.90 3131.9 3620.0 62.37 303.97 3181.5 98O 1056 1135 1217 1304 .1 .2 .5 .8 .1 2905.4 2970.0 3030.5 3086.3 3135.9 2.65 981.9 300.6 3.85 1058.2 300.6 3.53 1137.8 300.8 4.25 1220.6 301.0 4.18 1307.3 301.2 500.21 N 539.32 N 582.02 N 628.40 N 676.88 N 844.94 W 910.42 W 977.62 W 1046.39 W 1118.43 W 3720.0 65.60 302.16 3225.3 3820.0 67.77 303.53 3264.9 3920.0 67.41 302.44 3303.0 4020.0 68.51 301.70 3340.6 4120.0 68.88 299.40 3376.9 1393 1484 1576 1669 1762 .4 .8 .8 .1 .1 3179.7 3219.3 3257.4 3295.0 3331.3 3.62 1397.1 301.3 2.51 1488.9 301.4 1.07 1581.3 301.5 1.29 1674.0 301.5 2.18 1767.2 301.5 725.89 N 775.70 N 826.03 N 875.24 N 922.59 N 1193.74 W 1270.88 ~ 1348.43 W 1426.98 W 1507.20 W 4220.0 68.08 296.98 3413.6 4320.0 67.90 296.86 3451.0 4420.0 67.14 298.06 3489.3 4520.0 67.12 297.94 3528.1 4620.0 67.58 298.12 3566.7 1855.1 1947.8 2040.2 2132.4 2224.7 3368.0 3405.4 3443.7 3482.5 3521.1 2.39 1860.0 301.3 .21 1952.5 301.1 1.35 2044.7 300.9 · 11 2136.7 300.8 · 49 2228.9 300.7 966.54 N 1008.51 N 1051.11 N 1094.38 N 1137.75 N 1589.19 W 1671.86 W 1753.85 W 1835.20 W 1916.66 W A Gyroda t a D i r e c t i on a i Survey B.P. EXPLORATION WELL: MILNE POINT, MPF-01 Location: NABORS 27E, MILNE POINT, Job Number: AK0495G261 ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 4720.0 67.00 296.55 3605.3 4820.0 66.71 295.19 3644.6 4920.0 66.55 300.16 3684.3 5020.0 66.04 299.97 3724.5 5120.0 66.38 298.13 3764.8 2316.9 2408.8 2500.6 2592.0 2683.5 3559.7 3599.0 3638.7 3678.9 3719.2 1.56 2321.0 300.6 1.28 2412.7 300.4 4.56 2504.3 300.3 · 54 2595.9 300.3 1.72 2687.4 300.2 1180.12 N 1998.60 W 1220.24 N 2081.33 W 1262.86 N 2162.59 1308.74 N 2241.83 ~, 1353.17 N 2321.81 W 5220.0 66.42 299.75 3804.8 5320.0 65.39 297.05 3845.7 5420.0 65.24 297.72 3887.4 5520.0 65.71 299.09 3929.0 5620.0 66.14 298.38 3969.7 2775 2866 2957 3048 3139 .0 .3 .2 .1 .4 3759.2 3800.1 3841.8 3883.4 3924.1 1.49 2779.0 300.2 2.67 2870.2 300.1 · 62 2961.0 300.1 1.33 3051.9 300.0 · 78 3143.2 300.0 1397.51 N 1440.94 N 1482.73 N 1526.01 N 1569.90 N 2402.00 W 2482.28 W 2562.96 W 2642.98 W 2723.04 W 5720.0 65.64 298.23 4010.6 5820.0 65.70 293.77 4051.8 5920.0 67.27 292.92 4091.7 6020.0 67.33 295.34 4130.3 6120.0 67.96 297.17 4168.3 3230 3321 3413 3505 3597 .6 .7 .2 .3 .8 3965.0 4006.2 4046.1 4084.7 4122.7 .52 3234.4 299.9 4.06 3325.3 299.8 1.75 3416.4 299.6 2.24 3508.2 299.5 1.80 3600.6 299.4 1613.17 N 1653.10 N 1689.43 N 1727.14 N 1768.06 N 2803.40 W 2~85.28 W 2969.47 W 3053.65 W 3136.58 W 6220.0 67.84 296.50 4206.0 6320.0 67.42 296.05 4244.0 6420.0 67.28 296.47 4282.5 6520.0 66.50 294.69 4321.8 6620.0 66.85 292.58 4361.4 3690 3782 3875 3967 4O58 .4 .9 .2 .1 .8 4160.4 4198.4 4236.9 4276.2 4315.8 .63 3693.1 299.3 .59 3785.5 299.3 .41 3877.6 299.2 1.81 3969.4 299.1 1.96 4060.9 299.0 1809.88 N 1850.81 N 1891.64 N 1931.35 N 1968.16 N 3219.26 W 3302.18 W 3384.94 W 3467.90 W 3552.02 W 6720.0 67.09 293.21 4400.5 6820.0 67.41 293.24 4439.2 6920.0 67.46 291.60 4477.5 7020.0 67.29 294.71 4516.0 7120.0 66.72 292.00 4555.1 4150 4242 4334 4426 4518 .5 .5 .6 .6 .5 4354.9 4393.6 4431.9 4470.4 4509.5 .62 4152.4 298.9 .32 4244.2 298.7 1.52 4336.0 298.6 2.88 4427.8 298.5 2.56 4519.5 298.4 2003 . 97 N 2040.33 N 2075.55 N 2111.84 N 2148.34 N 3636.80 W 3721.55 W 3806.91 W 3891.77 W 3976.27 W A Gyro d a t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: MILNE POINT, MPF-01 Location: NABORS 27E, MILNE POINT, Job Number: AK0495G261 ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet 'feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 7220 . 0 66 · 56 292 . 80 4594 · 7 7320.0 66.75 291.48 4634.4 7400 . 0 67 · 07 293 · 80 4665 · 7 7430 · 0 67 · 12 293 · 55 4677.4 7460 · 0 67.30 293 · 07 4689 · 0 4610.0 4549.1 .75 4610.8 298.3 4701.4 4588.8 1.23 4702.1 298.1 4774.8 4620.1 2.70 4775.4 298.1 4802.4 4631.8 .78 4802.9 298.0 4830.0 4643.4 1.60 4830.5 298.0 2183.32 N 2217.92 N 2246.24 N 2257.33 N 2268.28 N 4061.14 W 4146.18 W 4214.10 4239.41 W 4264.81 W 7490.0 67.47 293.73 4700.6 7520 . 0 67.67 293 . 11 4712 . 0 7550.0 67.84 293.33 4723.4 7580.0 67.99 293.35 4734.7 7610 . 0 68 . 11 293 . 05 4745 . 9 4857.6 4655.0 2.14 4858.1 298.0 4885.3 4666.4 2.03 4885.7 298.0 4913.0 4677.8 .89 4913.4 297.9 4940.7 4689.1 .49 4941.1 297.9 4968.5 4700.3 1.01 4968.9 297.9 2279.28 N 2290.30 N 2301.25 N 2312.26 N 2323.22 N 4290.22 W 4315.67 W 4341.18 W 4366.71 W 4392.28 W 7640.0 68.32 292.66 4757.0 7670.0 68.44 292.88 4768.1 7700.0 68.64 293.25 4779.0 7730.0 68.46 293.41. 4790.0 7760.0 68.55 293.40 4801.0 4996.2 4711.4 1.41 4996.6 297.8 5024.0 4722.5 .80 5024.4 297.8 5051.9 4733.4 1.34 5052.2 297.8 5079.8 4744.4 .77 5080.0 297.8 5107.6 4755.4 .30 5107.9 297.7 2334.04 N 2344.84 N 2355.78 N 2366.83 N 2377.92 N 4417.95 W 4443.67 W 4469.35 W 4494.99 W 4520.61 W 7790.0 68.82 293.67 4811.9 7820.0 69.05 293.04 4822.7 7850.0 69.21 293.35 4833.4 7880.0 69.47 293.20 4844.0 7910.0 69.37 293.57 4854.5 5135.5 4766.3 1.22 5135.8 297.7 5163.4 4777.1 2.11 5163.7 297.7 5191.4 4787.8 1.09 5191.6 297.7 5219.4 4798.4 .98 5219.6 297.7 5247.4 4808.9 1.19 5247.6 297.6 2389.08 N 2400.18 N 2411.21 N 2422.31 N 2433.45 N 4546.23 W 4571.94 W 4597.70 W 4623.49 W 4649.27 W 7940.0 68.89 292.82 4865.2 7970.0 69.10 293.16 4876.0 8000.0 69.29 292.85 4886.6 8030.0 69.05 293.80 4897.3 5275.4 4819.6 2.82 5275.6 297.6 5303.3 4830.4 1.27 5303.5 297.6 5331.3 4841.0 1.15 5331.4 297.6 5359.3 4851.7 3.07 5359.4 297.5 2444.49 N 2455.43 N 2466.39 N 2477.49 N 4675.03 W 4700.81 W 4726.63 W 4752.38 W Final Station Closure: Distance: 5359.39 ft Az: 297.53 deg. A Gyro da t a D i r e c t i o n a i Survey for B.P. EXPLORATION WELL: MILNE POINT, MPF-01 Location: NABORS 27E, MILNE POINT, ALASKA Job Number: AK0495G261SS Run Date: 23-Apr-95 04:4:5:00 Surveyor: TOM STODDARD Calculation Methed: MINIMUM CURVATURE Survey Latitude: 70.515000 deg. N Sub-sea Correction from Vertical Reference: 45.6 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 297.150 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro d a t a D i r e c t i ona i Survey ~ B.P. EXPLORATION WELL: MILNE POINT, MPF-01 Location: NABORS 27E, MILNE Job Number: AK0495G261SS POINT, ALASKA Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet -45.6 0.00 0.00 0.0 0.0 0.00 0.0 0.0 0.00 N 0.00 E 0 - 8030 MEASURED A 20 FT. FT. GYRO SURVEY RUN IN DRILLPIPE. DEPTHS ARE REFERENCED TO AN R.K.B. HEIGHT OF 4 WIRELINE CORRECTION IS APPLIED TO THE MEASURED 5.6 FT. DEPTHS. 100.0 200.0 300.0 400.0 500.0 · 32 205.93 145.6 -.0 .22 · 34 211.47 245.6 -.0 .08 .46 210.92 345.6 .0 .15 · 45 219.83 445.6 .2 .13 · 35 210.60 545.6 .3 .12 · 9 204.2 1.5 206.6 2.4 208.3 3.1 210.6 3.7 211.9 · 44 S .20 W .94 S .47 W 1.54 S .83 W 2.18 S 1.30 W 2.75 S 1.71 W 6O 70 8O 90 00 0.0 0.0 0.0 0.0 0.0 · 65 225 . 21 645 · 6 · 6 . 44 2 · 02 289.85 745 · 6 2 · 7 1.63 3 .62 298.48 845.6 7.6 1.66 4.73 303.32 945.6 14.8 1.24 6 · 77 297 · 82 1045 . 6 24 · 9 2 . 14 4.5 215.6 7.4 236.1 13.1 265.0 21.8 '281.7 34.3 289.1 3.11 S 2.28 W 2.57 S 4.33 W 1.49 N 8.73 W 3.36 N 14.96 W 8.34 N 23.69 W 11 12 13 14 15 00.0 00.0 00.0 00.0 00.0 8.74 291.82 1145.6 38.5 2.17 11.00 293.97 1245.6 55.8 2.27 13.40 296.97 1345.6 77.4 2.43 16.06 298.45 1445.6 103.8 2.60 18.25 300.14 1545.6 134.6 2.14 50.3 291.1 70.1 291.7 94.1 292.8 122.3 294.0 153.8 295.3 13.92 N 36.09 W 20.76 N 52.09 W 30.15 N 71.57 W 42.44 N 94.86 W 57.60 N 121.77 W 16 17 18 19 20 00.0 00.0 00.0 00.0 00.0 20.48 301.08 1645.6 169.7 2.15 21.87 301.47 1745.6 208.4 1.29 22.06 301.38 1845.6 248.7 .32 22.33 299.75 1945.6 289.4 .65 23.93 300.49 2045.6 331.9 1.78 188.8 296.4 226.0 297.3 263.4 298.0 301.3 298.4 341.0 298.6 75.53 N 152.00 W 95.68 N 185.19 W 116.73 N 219.60 W 137.48 N 254.69 W 158.81 N 291.56 W A Gy r o d a t a D i r e c t i o n a i S u r ve y B.P. EXPLORATION WELL: MILNE POINT, MPP-01 Location: NABORS 27E, MiLNE POINT, Job Number: AK0495G261SS ALASKA Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 2100.0 25.83 300.49 2145.6 2200.0 28.71 301.32 2245.6 2300.0 31.22 300.97 2345.6 2400.0 33.44 302.65 2445.6 2500.0 36.34 303.35 2545.6 378.1 429.2 487.0 550.3 619.6 1.73 2.70 2.24 2.09 2.55 383.6 298.8 429.5 299.1 531.9 299.3 587.4 299.6 646.3 300.0 182.32 N 331.41 W 208.61 N 375.39 W 238.52 N 425.02 W 272.12 N 478.84 W 309.98 N 537.32 W 2600.0 39.33 302.60 2645.6 2700.0 41.34 301.32 2745.6 2800.0 43.66 301.40 2845.6 2900.0 47.55 301.04 2945.6 3000.0 52.77 302.38 3045.6 696.6 781.2 872.6 973.7 1094.6 2.51 1.53 1.87 2.94 3.69 708.7 300.3 840.2 300.5 909.2 300.6 981.5 300.7 1137.4 300.7 352.42 N 602.17 W 397.31 N 674.24 W 444.90 N 752.53 W 49'7.64 N 839.06 W 560.79 N 942.58 W 3100.0 59.32 303.92 3145.6 3200.0 66.70 302.85 3245.6 3300.0 68.56 301.40 3345.6 3400.0 67.93 296.87 3445.6 3500.0 67.33 298.02 3545.6 1240.6 1439.0 1680.7 1933.1 2172.9 4 .23 3 .06 1 .41 .55 .28 1307.0 301.1 1488.6 301.4 1766.8 301.5 1952.1 301.2 2228.6 300.8 642.00 N 1065.01 W 751.51 N 1231.80 W 881.92 N 1436.59 W 1002.57 N 1658.31 W 1114.19 N 1870.61 W 3600.0 66.70 295.28 3645.6 3700.0 66.21 299.03 3745.6 3800.0 65.40 297.08 3845.6 3900.0 65.88 298.80 3945.6 4000.0 65.69 294.48 4045.6 2410.0 2638.7 2864.9 3084.1 3306.8 1.34 1.15 2.66 1.11 3 .50 2503.9 300.4 2687.0 300.3 2869.8 300.2 3142.8 300.0 3324.9 299.8 1221.53 N 1332.19 N 1441.03 N 1544.09 N 1647.30 N 2081.97 W 2282.28 W 2480.67 W 2674.20 W 2871.49 W 4100.0 67.58 296.06 4145.6 4200.0 67.42 296.06 4245.6 4300.0 66.71 293.44 4345.6 4400.0 67.42 292.98 4445.6 4500.0 66.87 292.68 4545.6 3541.2 3785.4 4021.0 4256.7 4494.9 2.07 .58 1.90 .51 2.64 3600.2 299.5 3877.3 299.3 4060.5 299.1 4335.6 298.7 4519.1 298.4 1743.78 N 1852.67 N 1953.72 N 2046.47 N 2139.71 N 3085.48 W 3304.05 W 3517.00 W 3734.33 W 3954.24 W A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: MILNE POINT, MPF-01 Location: NABORS 27E, MILNE POINT, Job Number: AK0495G261SS ALASKA SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG CLOSURE DEPTH DEPTH SECTION SEVERITY DIST. AZIMUTH feet deg. deg. feet feet deg./ feet deg. 100 ft. 4600.0 66.86 292.28 4645.6 4700.0 68.10 293.07 4745.6 4800.0 69.46 293.24 4845.6 4852.0 69.05 293.80 4897.6 Final Station Closure: Distance: 4726.4 4966.5 5222.4 5358.9 5358.98 Page ft 1.74 4775.0 298.1 · 98 4968.5 297.9 1.01 5247.2 297.7 3.07 5359.0 297.5 Az: 297.54 deg. HORIZONTAL COORDINATES feet 2228.30 N 2323.16 N 2424.21 N 2478.05 N 4168.99 W 4390.09 W 4625.86 W 4751.62 W gyro/data 4. QUALITY CONTROL SR106. DOC Quality Control Comparisons B.P. EXPLORATION WELL: MILNE POINT, MPF-01 Location: NABORS 27E, MILNE POINT, ALASKA Job Number : AK0495G261 / AK0495G261 INRUN/OUTRUN Comparison INRUN OUTRUN Depth Inc Inc Delta 520.0 .56 .36 .201 1020.0 5.85 6.29 -.444 1520.0 17.19 17.48 -.292 2020.0 22.54 22.43 .117 2520.0 32.77 32.76 .010 3020.0 42.33 42.49 -.167 3520.0 59.19 58.19 .999 4020.0 67.97 68.51 -.542 8030.0 69.05 69.05 -.004 For Inclinations Greater than 10 degrees: Average Inclination Difference = .01715 deg. Average Azimuth Difference = -.0970 deg. INRUN Az 150.36 300.77 298.69 298.65 302.62 301.75 303.17 302.63 293.71 OUTRUN Az 212.96 300.14 299.53 299.13 302.76 301.08 303.90 301.70 293.80 Delta -62.600 .630 -.837 -.476 -.140 .667 -.731 .928 -.089 gyro/data QUALITY CONTROL REPORT JOB NUMBER: AK0495G261 TOOL NUMBER: 113 MAXIMUM GYRO TEMPERATURE: 76.8c MAXIMUM AMBIENT TEMPERATURE: 38.0 c MAXIMUM INCLINATION: 69.1 AVERAGE AZIMUTH: 297.5 WIRELINE REZERO VALUE: 20' correction REZERO ERROR / K: n/a CALIBRATION USED FOR FIELD SURVEY: 4-4-95 CALIBRATION USED FOR FINAL SURVEY: 4-4-95 PRE JOB MASS BALANCE OFFSET CHECK: POST JOB MASS BALANCE OFFSET CHECKt: CONDITION OF SHOCK WATCHES -.15 -.70 -.63 USED-.63 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: ok UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS: M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY FINAL SURVEY 8030 69.05 293.8 4897.6 2478.0 4751.6w 8030 69.05 293.8 4897.3 2477.49 4752.38w SR106.DOC gyro/data FUNCTION TEST JOB NUMBER' AK0495G261 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 3120 42.49 42.49 42.49 42.49 42.49 AZIMUTH M.D. ft 1 2 3 4 5 3120 301.6 301.8 301.9 301.9 301.7 SR106.DOC gy~oldata 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR106.DOC gyro/data. EQUIPMENT REPORT JOB NUMBER: AK0495G261 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 113 GYRO SECTION A0012 DATA SECTION A0032 POWER SECTION A0027 BACKUP TOOL No. 718 GYRO SECTION A0054 DATA S ECTI ON A0025 POWER SECTION A0052 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0153 A0074 A0079 A0071 A0122 A0074 A0082 A0035 WIRELINE COMPANY: CABLE SIZE: ATLAS WIRELINE 7/32 RUNNING GEAR 2 1/4" System TOTAL LENGTH OF TOOL: MAXIMUM O.D.: 23.5 feet 2.25 INCHES TOTAL WEIGHT OF TOOL: 210Lbs SR106.DOC gyro/data CHRONOLOGICAL REPORT JOB NUMBER: AK0495G261 4/22/95 1145 4/23/95 0100 0300 0445 0525 0540 0635 0720 0915 1055 1200 1320 1530 1915 2200 LEAVE FOR MILNE POINT ARRIVE LOCATION, MU TOOL. PU TOOL. LD TOOL. REHANG SHEAVES. PU TOOL. ZERO TO OL. MU PACK OFF. START INRUN. 3000'. 3500' RU TO PUMP TOOL. 4000' PUMPING 6BPM. 8010' START OUTRUN. 4000'. LD TOOL. RD ATLAS AND BD TOOL. ARRIVE ATLAS. CHECK TOOL. O.K. PROCESS SURVEY. FAX TO RIG. RTN RIG WITH FINAL COPIES OF SURVEY, ASD DISK. ATLAS, STAND BY FOR JOB AT X PAD. SR106.DOC SF'~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ~RED SERVICES DRILLING .4ILNE PT/MPF-01 500292255200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 4/95 DATE OF SURVEY: 042895 MWD SURVEY JOB NUMBER: AK-MM-950418 KELLY BUSHING ELEV. = 48.80 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 0 .00 -48.80 120 120.00 71.20 220 220.00 171.20 320 320.00 271.20 420 419.99 371.19 0 0 N .00 E .00 .00N .00E 0 19 S 23.50 W .27 .32S .14W 0 18 S 32.99 W .06 .80S .40W 0 27 S 27.04 W .17 1.38S .72W 0 29 S 42.19 W .13 2.05S 1.19W .00 -.02 -.01 .01 .12 520 519.99 471.19 620 619.99 571.19 720 719.97 671.17 820 819.86 771.06 920 919.64 870.84 0 21 S 32.96 W .15 2.63S 1.65W 0 20 S 23.73 W .06 3.17S 1.94W 1 31 N 72.42 W 1.53 3.04S 3.33W 3 25 N 63.58 W 1.92 1.31S 7.27W 4 10 N 55.56 W .93 2.08N 12.95W .27 .28 1.58 5.88 12.47 1020 1019.21 970.41 1120 1118.40 1069.60 1220 1217.09 1168.29 1320 1315.08 1266.28 1420 1412.13 1363.33 6 17 N 59.86 W 2.14 6.89N 20.69W 8 6 N 68.60 W 2.12 12.22N 32.00W 10 22 N 67.09 W 2.28 18.30N 46.86W 12 31 N 63.45 W 2.27 26.65N 64.87W 15 18 N 62.12 W 2.80 37.68N 86.24W 21.56 34.05 50.05 69.88 93.94 1520 1508.05 1459.25 1620 1602.89 1554.09 1720 1696.49 1647.69 1820 1789.29 1740.49 1920 1881.98 1833.18 17 28 N 60.47 W 2.22 51.26N 110.98W 19 25 N 58.93 W 2.00 67.24N 138.29W 21 45 N 58.92 W 2.33 85.38N 168.40W 21 59 N 58.19 W .36 104.81N 200.17W 22 6 N 58.90 W .29 124.40N 232.19W 122.14 153.73 188.80 225.95 263.37 2020 1974.53 1925.73 2120 2066.29 2017.49 2220 2156.76 2107.96 2320 2245.55 2196.75 2420 2332.29 2283.49 22 25 N 60.87 W .82 143.40N 264.96W 24 22 N 59.12 W 2.06 163.28N 299.34W 26 2 N 59.57 W 1.68 184.99N 335.97W 28 42 N 58.68 W 2.70 208.59N 375.42W 30 56 N 59.36 W 2.26 234.18N 418.06W 301.21 340.86 383.36 429.24 478.86 2520 2417.22 2368.42 2620 2500.35 2451.55 2720 2581.07 2532.27 2820 2659.16 2610.36 2920 2735.27 2686.47 32 45 N 57.24 W 2.14 261.92N 462.93W 34 45 N 57.57 W 2.01 291.85N 509.74W 37 34 N 55.92 W 2.98 324.23N 559.07W 39 42 N 57.72 W 2.41 358.38N 611.34W 41 9 N 58.64 W 1.56 392.56N 666.44W 531.44 586.75 645.42 707.51 772.14 3020 2809.79 2760.99 3120 2882.10 2833.30 3220 2951.15 2902.35 3320 3015.80 2967.00 3420 3076.28 3027.48 42 29 N 58.92 W 1.35 427.12N 723.46W 44 51 N 58.27 W 2.41 463.10N 782.38W 47 47 N 59.03 W 2.98 500.72N 844.15W 51 38 N 59.27 W 3.85 539.82N 909.63W 53 56 N 55.91 W 3.53 582.53N 976.82W 838.65 907.50 979.62 1055.73 1135.01 RECEIVED MAY 0 ~ 1996 Alaska Oil & Ga~ Gons. G(~mmissio~ Anchorage Sr~'RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ~RED SERVICES DRILLING .4ILNE PT/MPF-01 500292255200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 4/95 DATE OF SURVEY: 042895 MWD SURVEY JOB NUMBER: AK-MM-950418 KELLY BUSHING ELEV. = 48.80 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3520 3132.09 3083.29 3620 3181.66 3132.86 3720 3225.51 3176.71 3820 3265.09 3216.29 3920 3303.21 3254.41 58 11 62 22 65 35 67 46 67 24 N 56.10 W 4.25 628.90N 1045.60W N 56.03 W 4.18 677.37N 1117.63W N 57.84 W 3.62 726.38N 1192.94W N 56.47 W 2.51 776.18N 1270.07W N 57.56 W 1.07 826.51N 1347.62W 1217.37 1303.59 1392.96 1484.32 1576.28 4020 3340.73 3291.93 4120 3377.07 3328.27 4220 3413.75 3364.95 4320 3451.22 3402.42 4420 3489.46 3440.66 68 30 68 52 68 4 67 54 67 8 N 58.30 W 1.30 875.72N 1426.16W N 60.60 W 2.17 923.06N 1506.38W N 63.02 W 2.39 967.00N 1588.35W N 63.14 W .21 1008.98N 1671.01W N 61.94 W 1.34 1051.58N 1753.00W 1668.63 1761.61 1854.60 1947.31 2039.71 4520 3528.32 3479.52 4620 3566.83 3518.03 4720 3605.44 3556.64 4820 3644.75 3595.95 4920 3684.43 3635.63 67 7 67 34 67 0 66 42 66 33 N 62.06 W .11 1094.84N 1834.35W N 61.88 W .49 1138.21N 1915.82W N 63.45 W 1.56 1180.56N 1997.75W N 64.81 W 1.28 1220.68N 2080.48W N 59.84 W 4.56 1263.30N 2161.74W 2131.83 2224.11 2316.35 2408.27 2500.02 5020 3724.64 3675.84 5120 3764.97 3716.17 5220 3805.01 3756.21 5320 3845.84 3797.04 5420 3887.60 3838.80 66 2 66 22 66 25 65 23 65 14 N 60.03 W .54 1309.17N 2240.99W N 61.87 W 1.72 1353.59N 2320.97W N 60.25 W 1.49 1397.93N 2401.15W N 62.95 W 2.67 1441.35N 2481.44W N 62.28 W .63 1483.14N 2562.12W 2591.47 2682.91 2774.49 2865.74 2956.60 5520 3929.11 3880.31 5620 3969.90 3921.10 5720 4010.75 3961.95 5820 4051.97 4003.17 5920 4091.86 4043.06 65 42 66 8 65 38 65 41 67 16 N 60.91 W 1.33 1526.42N 2642.13W N 61.62 W .78 1570.31N 2722.19W N 61.77 W .52 1613.59N 2802.55W N 66.23 W 4.06 1653.52N 2884.42W N 67.08 W 1.75 1689.85N 2968.60W 3047.55 3138.81 3230.07 3321.14 3412.62 6020 4130.46 4081.66 6120 4168.49 4119.69 6220 4206.11 4157.31 6320 4244.17 4195.37 6420 4282.68 4233.88 67 19 67 57 67 50 67 25 67 16 N 64.66 W 2.23 1727.56N 3052.78W N 62.83 W 1.81 1768.47N 3135.71W N 63.50 W .63 1810.29N 3218.38W N 63.95 W .59 1851.23N 3301.30W N 63.53 W .41 1892.06N 3384.06W 3504.73 3597.19 3689.84 3782.30 3874.58 6520 4321.93 4273.13 6620 4361.52 4312.72 6720 4400.65 4351.85 6820 4439.32 4390.52 6920 4477.69 4428.89 66 30 66 50 67 5 67 24 67 27 N 65.31 W 1.81 1931.77N 3467.01W N 67.42 W 1.97 1968.57N 3551.12W N 66.79 W .63 2004.38N 3635.90W N 66.76 W .32 2040.74N 3720.64W N 68.40 W 1.52 2075.96N 3806.00W 3966.50 4058.14 4149.92 4241.92 4333.94 S¥~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 .ARED SERVICES DRILLING .,IILNE PT/MPF-01 500292255200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 4/9 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 7020 4516.17 4467.37 7120 4555.23 4506.43 7220 4594.88 4546.08 7320 4634.51 4585.71 7400 4665.88 4617.08 COURS COURSE INCLN DIRECTION DG MN DEGREES DG/ DATE OF SURVEY: 042895 MWD SURVEY JOB NUMBER: AK-MM-950418 KELLY BUSHING ELEV. = 48.80 FT. OPER3ATOR: BP EXPLORATION DLS TOTAL RECTANGULAR COORDINATES 100 NORTH/SOUTH EAST/WEST 67 17 N 65.29 W 2.88 66 43 N 68.00 W 2.56 66 33 N 67.20 W .75 66 45 N 68.52 W 1.23 67 4 N 66.20 W 2.70 VERT. SECT. 2112.25N 3890.86W 2148.73N 3975.34W 2183.72N 4060.21W 2218.32N 4145.25W 2246.64N 4213.16W 4426.01 4517.83 4609.32 4700.77 4774.12 7430 4677.56 4628.76 7460 4689.18 4640.38 7490 4700.72 4651.92 7520 4712.16 4663.36 7550 4723.52 4674.72 67 7 N 66.45 W .79 67 18 N 66.93 W 1.59 67 28 N 66.27 W 2.11 67 40 N 66.89 W 2.02 67 50 N 66.67 W .88 2257.74N 4238.47W 2268.68N 4263.87W 2279.68N 4289.28W 2290.70N 4314.73W 2301.65N 4340.25W 4801.71 4829.30 4856.93 4884.61 4912.31 7580 4734.80 4686.00 7610 4746.01 4697.21 7640 4757.15 4708.35 7670 4768.20 4719.40 7700 4779.18 4730.38 67 59 N 66.65 W .50 68 6 N 66.95 W 1.01 68 19 N 67.34 W 1.40 68 26 N 67.12 W .79 68 38 N 66.75 W 1.33 2312.66N 4365.77W 2323.62N 4391.35W 2334.44N 4417.02W 2345.24N 4442.73W 2356.17N 4468.42W 4940.04 4967.80 4995.58 5023.39 5051.24 7730 4790.15 4741.35 7760 4801.14 4752.34 7790 4812.04 4763.24 7820 4822.83 4774.03 7850 4833.51 4784.71 68 27 N 66.59 W .78 68 33 N 66.60 W .30 68 49 N 66.33 W 1.23 69 3 N 66.96 W 2.10 69 12 N 66.65 W 1.10 2367.23N 4494.06W 2378.32N 4519.68W 2389.48N 4545.30W 2400.58N 4571.00W 2411.62N 4596.77W 5079.10 5106.95 5134.85 5162.78 5190.74 7880 4844.10 4795.30 7910 4854.64 4805.84 7940 4865.33 4816.53 7970 4876.08 4827.28 8000 4886.74 4837.94 8030 4897.41 4848.61 8107 4925.56 4876.76 8202 4960.45 4911.65 8298 4996.44 4947.64 8389 5030.28 4981.48 69 28 N 66.80 W .98 69 22 N 66.43 W 1.20 68 53 N 67.18 W 2.83 69 5 N 66.84 W 1.27 69 17 N 67.15 W 1.16 69 3 N 66.20 W 3.07 68 36 N 66.59 W .73 68 3 N 66.91 W .67 67 57 N 66.96 W .10 68 9 N 67.03 W .23 2422.71N 4622.55W 2433.86N 4648.33W 2444.90N 4674.09W 2455.84N 4699.88W 2466.80N 4725.69W 2477.90N 4751.44W 2507.00N 4818.03W 2541.67N 4898.73W 2576.58N 4980.70W 2609.41N 5058.02W 5218.75 5246.77 5274.74 5302.67 5330.64 5358.62 5431.16 5518.78 5607.65 5691.43 8488 5067.70 5018.90 8583 5103.50 5054.70 8677 5138.88 5090.08 8773 5174.45 5125.65 8867 5209.65 5160.85 67 45 N 67.44 W .56 67 40 N 67.65 W .22 68 11 N 67.54 W .55 68 10 N 67.48 W .06 67 56 N 67.32 W .30 2645.16N 5143.24W 2678.53N 5223.97W 2711.79N 5304.65W 2745.79N 5386.77W 2779.37N 5467.45W 5783.57 5870.64 5957.61 6046.19 6133.30 RECEIVED I~A¥ 0 ~5 1996 G~s Co.s. Oommission Anchorage S¥~'~RY-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE 4 ~RED SERVICES DRILLING ~ILNE PT/MPF-01 500292255200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 4/95 DATE OF SURVEY: 042895 MWD SURVEY JOB NUMBER: AK-MM-950418 KELLY BUSHING ELEV. = 48.80 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/100 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERT. SECT. 8962 5245.60 5196.80 9057 5282.08 5233.28 9150 5318.56 5269.76 9244 5354.97 5306.17 9340 5392.03 5343.23 67 39 N 66.98 W .45 67 5 N 66.33 W .87 67 4 N 67.24 W .90 67 16 N 67.59 W .40 67 5 N 68.24 W .65 2813.57N 5548.60W 6221.12 2848.25N 5628.95W 6308.44 2882.26N 5708.24W 6394.51 2915.47N 5788.10W 6480.73 2948.60N 5869.73W 6568.48 9435 5429.52 5380.72 9533 5468.82 5420.02 9626 5506.77 5457.97 9721 5545.82 5497.02 9817 5585.98 5537.18 66 28 N 67.72 W .83 66 7 N 67.50 W .41 65 56 N 65.63 W 1.84 65 24 N 66.18 W .79 65 9 N 65.46 W .73 2981.37N 5950.76W 6655.54 3015.46N 6033.51W 6744.73 3049.41N 6111.84W 6829.92 3084.67N 6190.69W 6916.17 3120.40N 6270.27W 7003.29 9908 5624.31 5575.51 10005 5664.70 5615.90 10098 5703.17 5654.37 10194 5742.36 5693.56 10287 5779.83 5731.03 65 15 N 63.44 W 2.01 65 24 N 62.20 W 1.17 65 45 N 61.61 W .70 66 6 N 61.20 W .53 66 19 N 61.63 W .48 3156.19N 6345.13W 7086.23 3196.35N 6423.33W 7174.14 3236.25N 6498.07W 7258.85 3278.25N 6575.12W 7346.58 3318.93N 6649.78W 7431.57 10383 5818.13 5769.33 10477 5855.41 5806.61 10571 5892.22 5843.42 10666 5929.13 5880.33 10758 5964.73 5915.93 66 33 N 61.48 W .28 66 50 N 61.52 W .32 67 2 N 62.23 W .72 67 15 N 62.77 W .57 67 13 N 62.56 W .21 3360.75N 6726.99W 7519.36 3402.05N 6803.05W 7605.89 3442.82N 6879.33W 7692.37 3483.26N 6957.00W 7779.93 3522.21N 7032.37W 7864.76 10854 6002.96 5954.16 10951 6043.16 5994.36 11047 6085.75 6036.95 11142 6130.65 6081.85 11236 6176.99 6128.19 65 48 N 62.36 W 1.49 64 52 N 62.96 W 1.11 62 42 N 64.16 W 2.51 61 7 N 65.00 W 1.84 59 19 N 65.69 W 2.03 3562.88N 7110.35W 7952.72 3603.10N 7188.15W 8040.29 3641.63N 7265.62W 8126.81 3677.75N 7341.60W 8210.90 3711.54N 7415.21W 8291.82 11328 6226.03 6177.23 11422 6278.75 6229.95 11518 6334.87 6286.07 11611 6390.55 6341.75 11705 6448.60 6399.80 56 40 N 63.19 W 3.67 54 41 N 63.24 W 2.12 53 58 N 63.58 W .80 52 40 N 63.83 W 1.41 50 46 N 63.12 W 2.10 3745.36N 7485.98W 8370.23 3780.16N 7554.92W 8447.45 3815.16N 7624.85W 8525.64 3848.28N 7691.86W 8600.38 3881.13N 7757.69W 8673.95 11801 6510.10 6461.30 11896 6571.91 6523.11 11991 6634.95 6586.15 12085 6700.13 6651.33 12180 6767.44 6718.64 49 32 N 62.55 W 1.37 49 28 N 62.77 W .19 47 1 N 62.36 W 2.60 45 15 N 62.52 W 1.90 44 3 N 61.86 W 1.35 3914.78N 7823.27W 8747.66 3948.02N 7887.57W 8820.04 3980.56N 7950.25W 8890.67 4011.94N 8010.38W 8958.50 4042.97N 8069.21W 9025.00 SF~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 ~RED SERVICES DRILLING .4ILNE PT/MPF-01 500292255200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 4/95 DATE OF SURVEY: 042895 MWD SURVEY JOB NUMBER: AK-MM-950418 KELLY BUSHING ELEV. = 48.80 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES DG/100 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERT. SECT. 12275 6836.73 6787.94 43 24 N 62.64 W .88 4073.84N 8127.88W 12370 6905.67 6856.87 42 55 N 62.63 W .52 4103.56N 8185.30W 12465 6975.52 6926.72 42 39 N 62.40 W .32 4133.40N 8242.66W 12558 7044.35 6995.55 42 4 N 62.42 W .62 4162.48N 8298.30W 12654 7115.45 7066.65 41 22 N 62.64 W .76 4191.72N 8354.56W 9091.29 9155.94 9220.60 9283.38 9346.78 12748 7186.41 7137.61 40 36 N 62.79 W .82 4219.99N 8409.36W 12839 7256.28 7207.48 40 4 N 62.21 W .71 4247.39N 8462.00W 12941 7333.76 7284.96 40 4 N 62.21 W .00 4277.79N 8519.68W 9408.45 9467.79 9532.99 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 9533.33 FEET AT NORTH 63 DEG. 20 MIN. WEST AT MD = 12941 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 297.15 DEG. SP~-~'~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ~RED SERVICES DRILLING ~ILNE PT/MPF-01 500292255200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 4/95 DATE OF SURVEY: 042895 JOB NUMBER: AK-MM-950418 KELLY BUSHING ELEV. = 48.80 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 0 .00 -48.80 .00 N .00 E .00 1000 999.33 950.53 5.79 N 18.80 W .67 2000 1956.04 1907.24 139.69 N 258.30 W 43.96 3000 2795.04 2746.24 420.14 N 711.89 W 204.96 4000 3333.41 3284.61 865.94 N 1410.33 W 666.59 .67 43.29 161.00 461.64 5000 3716.51 3667.71 1300.04 N 2225.15 W 1283.49 6000 4122.75 4073.95 1719.66 N 3036.10 W 1877.25 7000 4508.45 4459.65 2104.63 N 3874.05 W 2491.55 8000 4886.74 4837.94 2466.80 N 4725.69 W 3113.26 9000 5259.88 5211.08 2827.16 N 5580.57 W 3740.12 616.89 593.77 614.30 621.71 626.86 10000 5662.36 5613.56 3193.96 N 6418.80 W 4337.64 11000 6063.97 6015.17 3623.23 N 7227.62 W 4936.03 12000 6640.87 6592.07 3983.51 N 7955.88 W 5359.13 12941 7333.76 7284.96 4277.79 N 8519.68 W 5607.24 597.52 598.39 423.10 248.11 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. Alaska Oil & Gas Cens~ commissior~ Ancl~orage SP~--~'RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ~RED SERVICES DRILLING .,IILNE PT/MPF-01 500292255200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 4/95 DATE OF SURVEY: 042895 JOB NUMBER: AK-MM-950418 KELLY BUSHING ELEV. = 48.80 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASD VERTICAL DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 0 .00 48 48.80 148 148.80 248 248.80 348 348.80 -48.80 .00 N .00 E .00 .00 .00 N .00 E .00 100.00 .47 S .20 W .00 200.00 .93 S .48 W .00 300.00 1.58 S .83 W .01 .00 .00 .00 .00 448 448.80 548 548.80 648 648.80 748 748.80 848 848.80 400.00 2.23 S 1.36 W .01 .00 500.00 2.78 S 1.75 W .01 .00 600.00 3.32 S 2.01 W .01 .00 700.00 2.80 S 4.06 W .04 .03 800.00 .54 S 8.82 W .19 .15 949 948.80 1049 1048.80 1150 1148.80 1252 1248.80 1354 1348.80 900.00 3.29 N 14.71 W .44 1000.00 8.53 N 23.52 W .97 1100.00 13.80 N 36.03 W 1.90 1200.00 20.56 N 52.22 W 3.44 1300.00 30.18 N 71.84 W 5.82 .25 .54 .93 1.54 2.37 1458 1448.80 1562 1548.80 1668 1648.80 1776 1748.80 1884 1848.80 1400.00 42.37 N 95.12 W 9.22 1500.00 57.62 N 122.18 W 13.94 1600.00 75.69 N 152.31 W 19.94 1700.00 96.21 N 186.28 W 27.53 1800.00 117.44 N 220.65 W 35.39 3.40 4.72 6.00 7.59 7.85 1992 1948.80 2100 2048.80 2211 2148.80 2323 2248.80 2439 2348.80 1900.00 138.23 N 255.69 W 43.37 2000.00 159.21 N 292.54 W 52.00 2100.00 183.02 N 332.62 W 62.34 2200.00 209.52 N 376.94 W 74.90 2300.00 239.22 N 426.57 W 90.45 7.98 8.63 10.34 12.56 15.54 2557 2448.80 2679 2548.80 2806 2648.80 2937 2748.80 3073 2848.80 2400.00 272.92 N 480.02 W 108.75 2500.00 310.71 N 538.85 W 130.79 2600.00 353.78 N 604.06 W 157.74 2700.00 398.71 N 676.53 W 189.17 2800.00 445.80 N 754.35 W 224.36 18.30 22.04 26.94 31.43 35.19 3216 2948.80 3373 3048.80 3552 3148.80 3777 3248.80 4042 3348.80 2900.00 499.39 N 841.95 W 267.72 3000.00 562.22 N 945.92 W 325.13 3100.00 644.37 N 1068.61 W 403.57 3200.00 754.28 N 1236.96 W 528.29 3300.00 886.49 N 1443.59 W 693.22 43.36 57.41 78.44 124.71 164.94 RECEIVED MAY 0 3 "199t AI~I(~ 011 & Gas Cons, Commission Anchorage S~ ',RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 8 .~ARED SERVICES DRILLING ~ILNE PT/MPF-01 500292255200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 4/95 DATE OF SURVEY: 042895 JOB NUMBER: AK-MM-950418 KELLY BUSHING ELEV. = 48.80 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 4313 3448.80 3400.00 4572 3548.80 3500.00 4830 3648.80 3600.00 5079 3748.80 3700.00 5327 3848.80 3800.00 1006.28 N 1665.69 W 1117.65 N 1877.33 W 1224.76 N 2088.96 W 1336.15 N 2288.36 W 1444.29 N 2487.19 W 864.76 171.53 1023.99 159.23 1181.45 157.46 1330.84 149.39 1478.31 147.47 5567 3948.80 3900.00 5812 4048 . 80 4000 . 00 6067 4148 . 80 4100.00 6332 4248 . 80 4200.00 6587 4348.80 4300.00 1547.63 N 2680.34 W 1650.64 N 2878.03 W 1746.50 N 3092.52 W 1856.12 N 3311.30 W 1957.15 N 3523.64 W 1619.13 140.82 1763.50 144.37 1918.90 155.39 2083.26 164.36 2238.84 155.58 6844 4448.80 4400.00 7103 4548.80 4500.00 7356 4648.80 4600.00 7617 4748.80 4700.00 7893 4848.80 4800.00 2049.74 N 3741.59 W 2143.13 N 3961.48 W 2230.50 N 4176.21 W 2326.34 N 4397.73 W 2427.67 N 4634.07 W 2395.89 157.05 2554.93 159.04 2707.40 152.48 2868.68 161.27 3044.59 175.92 8171 4948.80 4900.00 8438 5048.80 5000.00 8704 5148.80 5100.00 8970 5248.80 5200.00 9228 5348.80 5300.00 2530.33 N 4872.13 W 2627.43 N 5100.56 W 2721.27 N 5327.57 W 2816.61 N 5555.77 W 2909.86 N 5774.48 W 3222.47 177.88 3390.07 167.60 3555.29 165.22 3722.06 166.77 3880.00 157.94 9483 5448.80 5400.00 9728 5548.80 5500.00 9967 5648.80 5600.00 10210 5748.80 5700.00 10460 5848.80 5800.00 2998.14 N 5991.68 W 3087.30 N 6196.65 W 3180.15 N 6392.60 W 3285.25 N 6587.86 W 3394.68 N 6789.46 W 4034.90 154.91 4179.80 144.90 4318.63 138.83 4461.88 143.26 4612.13 150.24 10717 5948.80 5900.00 10964 6048.80 6000.00 11180 6148.80 6100.00 11370 6248.80 6200.00 11542 6348.80 6300.00 3504.73 N 6998.69 W 3608.56 N 7198.86 W 3691.65 N 7371.42 W 3760.91 N 7516.76 W 3823.68 N 7641.99 W 4768.82 156.70 4915.53 146.70 5031.65 116.13 5121.25 89.60 5193.37 72.12 11705 6448.80 6400.00 11861 6548.80 6500.00 12011 6648.80 6600.00 12154 6748.80 6700.00 12292 6848.80 6800.00 3881.24 N 7757.90 W 3935.65 N 7863.53 W 3987.46 N 7963.42 W 4034.46 N 8053.30 W 4079.08 N 8138.01 W 5256.95 63.58 5312.26 55.31 5362.84 50.57 5405.29 42.45 5443.74 38.45 Sr~.RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 9 ~RED SERVICES DRILLING ,~ILNE PT/MPF-01 500292255200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 4/95 DATE OF SURVEY: 042895 JOB NUMBER: AK-MM-950418 KELLY BUSHING ELEV. = 48.80 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 12429 6948.80 6900.00 12564 7048.80 7000.00 12698 7148.80 7100.00 12829 7248.80 7200.00 12941 7333.76 7284.96 4121.99 N 8220.84 W 5480.49 36.75 4164.34 N 8301.87 W 5515.99 35.49 4205.22 N 8380.64 W 5549.69 33.71 4244.46 N 8456.44 W 5581.17 31.47 4277.79 N 8519.68 W 5607.24 26.08 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS WELL LOG TRANSMITTAL To: State of Alaska / October 30, 1995 Alaska Oil and Gas Conservation Comm. Atto: Larry Grant 45 3001 Porcupine Drive / Anchorage, Alaska 99501 RE: Shifted-LDWG Formatted MWD Data- MP F-01, AK-MM-950418 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 Shifted-LDWG Formatted LIS Tape. 1 LDWG Verification Listing.. OCT b 1995 ~laska Oil & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn: Larry Grant 3001 Porcupine Drive Anchorage, Alaska 99501 WELL LOG TRANSMITT~/~q/ September 12, 1995 RE: MWD Formation Evaluation Logs - MP F-01, AK-MM-950418 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, J/G, Anchorage, AK 99518 2" x 5" MD Resistivity and Gamma Ray Logs: 2" x 5" TVD Resistivity and Gamma Ray Logs' 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 2" x 5" MD Neutron and Density Logs' 1 Blueline 1 Rev. Folded Sepia 2" x 5" TVD Neutron and Density Logs: 1 Blueline 1 Rev. Folded Sepia Alaska Oil & (~as c~,,~. Anchorage 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE Date: RE: 18 July 1995 Transmittal of Data ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: Enclosed, Tapes/Diskettes: ECC #: 6456.00 Sent by: PRIORITY MAIL Data: GR/CCL MPF-01 MILNE POINT NORTH SLOPE, AK~ please find the data as describe~ ~e~w: ~ 1 LDWG TAPE + LIS Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street _ _ ~~ ~nchorage, AK 99518 O~FAX to (907) 563-7803 Date: ECEIvE-b '~laska 0il & ~as Co',~s .,' ' LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 17 July 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: 5 1 PFC/PERF FINAL BL+RF MPF-01/ ' 1 GR/CCL FINAL BL+RF ECC No. Run # 1 6282.01 Run # 1 6456.01 Run # 1 Run # 1 6456.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services [~ .~C~/ ~-- ~~ ~ 5600 B Street ,~..~, or ~x ~o (~o~)~-~o~ %~0//~uL *~Z~'cu Received : Date: ',6~8,~ . 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 16, 1995 Adrian Clark Drilling Engineering Supervisor BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPF-01 Rev. BP Exploration (Alaska) Inc. Permit No. 9545 Sur Loc 1711'NSL, 2801'WEL, Sec. 6, T13N, R10E, UM Btmhole Loc 830'NSL, 937'WEL, Sec. 35, T14N, R9E, UM Dear Mr. Clark: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated April 12, 1995 are in effect for this revision. ChairmanX'x~_~ . BY ORDER OF THE COMNIISSION dlf/EnClosures CC: Department of Fish & Game, Habitat Section W/o encl Department of Environmental Conservation w/o encl STATE OF ALASKA ~/~VlSION-06/06/95 ALASKA OIL AND GAS CONSERVATION COMMISSf6~.~ ~ PERMIT TO DRILL 2O AAC 25.005 ila. Type of work Drill [] Redrilll-Illb. Type of well. ExploratoryE] Stratigraphic Testi-i Development Oil[i] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 32.5' feet Milne Point-Kuparuk Sands 3. Address 6. Property Designation P. 0. Box 196612, Anchorage, Alaska 99519-6612 ADL 355018 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1711' NSL, 2801' WEL, SEC. 6, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 694' NSL, 701' WEL, SEC. 35, T14N, RSE MPF-01 2S100302630-277 At total depth 9. Approximate spud date Amount 830' NSL, 937' WEL, SEC. 35, T14N, RSE 4/14/95 $200,000. O0 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 355023-911' feet No close approach feet 2560 12859' MD/7587' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth ~ooo feet Maximum hole angle 66 o Maximum sur[ace 2906 psig At total depth (TVD) 7260'/3634 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.1# NT8OLHE Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 B TRC 6114' 31' 31' 6145' 4426' 1188 sx PF "E"/250 sx "G"/250 sx PF "E" 8-1/2" 7" 26# L-80 BTRC 12829' 30' 30' 12859' 7587' 175 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural RECEIVED Conductor Surface Intermediate JUN - 7 1995 Production Liner Alaska (J~l & Gas Cons. Commission Perforation depth: measured Anchor~ .~ true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid pro. gram [] Time vs depth plot [] Refraction analysis l-I Seabed report[] 20 AAC 25.050 requirementsCI 21. I hereby c¢~tify that ~%foregoing is true and correct to the best of my knowledge Signed ~,¢~ ~.,~'~..~¢/~ ~..4~--,,'~~_ ~ Title Drillin~l En~tineerin~l Supervisor Date ~/~.,~1" Commission Use Only Permit Numb6~' IAPI number Approyal date (¢ '"" See cover letter 95-45 ~ 5 0-029_22552 I ~ --,/~-- ~.,.~ for other requirements Condit' o mples req~'Cn',~d.,,..,q~Yes 'l~No Mud Icg required [] Yes ,J~ No /H~ogen sulfij;~~~s ~ _Y_es [] ~ Dir'~tional survey required ,[~ Yes [] No OM; I-I15M; ~ ~¢f~r~v~b~~ _~ by order of Commissioner ~ne commission Date~:~ -/-~--~: / Form 10-401 Rev. 12~..~ Submit in triplicate -. BP EXPLORATION To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: David Johston, Chairman Date: April 28, 1991 COMM ~ COMM L~ RES ENG ~ SR ENG SR FNG ENG ASST I ENG ASST I SR GEOL iGEOL ASSTI GEOL ASSTI, STAT TEC~ I¢ Subject: Milne Point Unit Drilling Operations - Clarification Per our conversation with Blair Wondzell on April 26, we would like to clarify our drilling operations at Milne Point unit F and L pads. MPL-17 (Permit # 94-169). Drilled surface hole and set 9-5/8" surface casing at 3650'. Drilled to 8788' MD and set 7" casing across the Kuparuk sands. The well was suspended with source water in the casing and a 7" retrievable bridge plug set at 3025'. The well will be perforated, hydraulically sand frac'd and cleaned out with coiled tubing without a rig on the well. The well will be completed by a rig as an. ESP completion with 2-7/8" tubing at a later date. MPL-29 (Permit # 95-009). Drilled surface hole and set 9-5/8" surface casing at 7676' in January, 1995. The well was suspended with a dry hole tree in order to move N27E to the newly set MPF-pad and drill several development wells before break-up and pad compacting operations commenced. N27E will be moving back to MPL-29 in early May to complete drilling operations on this well. The well will be completed with 3-1/2" tubing by N27E as a Kuparuk water injection well. MPF-25 (Permit # 95-16). Drilled surface hole and set 9-5/8" surface casing at 3425'MD. Drilled to 11502'MD and set 7" casing across the Kuparuk sands. The well was perforated and hydraulically sand frac'd without a rig and will be cleaned out with coiled tubing. The well will be completed by a rig as an ESP completion with 2-7/8" tubing this fall. MPF-13 (Permit # 95-27). Drilled surface hole and set 9-5/8" surface casing at 3968'MD. Drilled to 10975'MD and set 7" casing across the Kuparuk sands. The well was perforated and hydraulically sand frac'd without a rig and will be cleaned out with coiled tubing. The well will be completed by a rig as an ESP completion with 2-7/8" tubing this fall. REEEIVED MAY -2_. 1995 Alaska .0il & Gas Cons. Commission ~chorage MPF-37 (Permit # 95-25). Drilled surface hole and set 9-5/8" surface casing at 6621'MD. Drilled to 12915'MD and set 7" casing across the Kuparuk sands. The well was perforated and hydraulically sand frac'd without a rig and will be cleaned out with coiled tubing. The well will be completed by a rig as an ESP completion with 2-7/8" tubing this fall. MPF-01 (Permit #95-45). Drilled surface hole and set 9-5/8" surface casing at 7124'MD. Drilled to 12941'MD and set 7" casing across the Kuparuk sands. The well will be perforated and hydraulically sand frac'd without a rig and then cleaned out with coiled tubing. The well will be completed by a rig as an ESP completion with 2-7/8" tubing this fall. Yours Sincerely, A~'rian Clark Drilling Engineer Supervisor cc. Well file .. RECEIVED MAY -2 1995 Alaska Oil & Gas Cons. Commission Anchorag8 AlaSKA OIL AND GAS CONSERVATION CO~IMISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (90?) 276-7542 April 12, 1995 Adrian Clark Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Milne Point Unit MPF-O1 BP Exploration (Alaska), Inc. Permit No: ' 95-45 Sur. Loc. 1711'NSL, 2801'WEL, Sec. 6, T13N, RiOE, UM Btmhole Loc. 911'NSL, 4202'WEL, Sec. 35, T14N, R9E, UM Dear Mr. Clark: 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) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Commis s loner BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. · ($a7) ~$1~11~ March 24, 1995 ARCO Alaska Inc. . Atto; Scott Kerr, KuParUk Development Ma P. O, Box lO0360 Anchorage, AK 99510-0360 Re: Letter of Non-Objection for MPF-I Well . ,. Gentlemen: Post-It'" brand fax transmittal memo 7671 1 The AOGCC has requested that we obtain a letter of non-objection from ARCO for the drilling of our MPF-.1 well as ~e wellborn will cmsa the northeast portion. 'of ADL 355023, which is owned by ARCO. We would aJso like to nc)fa that BP is in negotiation w~ ARCO to acquire me eastern portion of this lease. As part of these discussions, BP has agreed to let ARCO revlew.SP's well ~ta lust offsetting tt~ Ieee inoluding MPF-1. if the.foregoing is -acceptablei ' please 'so indir, ate by signing' and returning thi~ letter agreement to the undersigned, Thank you f~r your p~mp! ~tt~mtion ~o ~, mawr. - ' Sincerely, Telephone 564-5672 Fax 564-4440 Accepted and agreed.to this day of~ ARCO Alasi~ in¢, // By: .c~~'~"/T ,---~-- Date:./-, ~/./~/.~:-_ /// ,----[ Gas Cons. Commis~~ I Anchor[ .. ....,.. .. , .--, ~,, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] RedrillF'l lb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen[] Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 32.5' feet Milne Point-Kuparuk Sands 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 355018 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1711'NSL, 2801' WEL, SEC. 6, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 694' NSL, 4578' WEL, SEC. 35, T14N, R9E MPF-01 2S100302630-277 At total depth 9. Approximate spud date Amount 911' NSL, 4202' WEL, SEC. 35, T14N, R9E 4/14/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 355023-911' feet No close approach feet 2560 12859' MD/7587' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth ~ooo feet Maximum hole angle 66 o Maximum surface 2906 psig At total depth (TVD) 7260~sig 18. Casing program Specifications Setting Depth size Top Bottom Quantity of cement cf Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.1# NT8OLHE Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 B TRC 6114' 31' 31' 6145' 4426' 1188 sx PF "E"/250 sx "G"/250 sx PF "E" 8-1/2" 7" 26# L-80 BTRC 12829' 30' 30' 12859' 7587' 175 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Surface Intermediate Production APR - 5 1995 Liner Perforation depth: measured Alaska 0il & Gas Cons. Commi~lon true vertical Anchora 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid prograr~ [] Time vs desth plot [] Refraction analysis [] Seabed reportl--1 20 AAC 25.050 requirements[] 21. I hereby certify//th, a!. ,t4'fe/~oregoiC'g is true and correct to the best of my knowledge Signed /~,¢ ~ "~/~k.~ Title Dn'llin~lEn~lineerSupervisor Date_~'~ ~/(,.~,¢'~ Commission Use Only Permit Number APl number Appro. v~l d~e ISee cover letter ~;;~.~"- ,¢~'~" 5 O- 0 ~.- ¢-- ~ ;~. ~-.~'.~.. ~//J'Z./~ ~Jfor other requirements Conditions'of approval Samples required [] Yes [] No Mud log required []Yes ~ No Hydrogen sulfide measures [] Yes [] No Directional survey required ~] Yes [] No Required working pressure for BOPE [] 2¥1;,.,.I-13M;,, [~]5M; I-IIOM; []15M; Other: Urig~na~ ~lgneo ~y by order of David W. Johnston Approved by Commissioner tne commission . Form 10-401 Rev. 12-1-85 Submit ir ~licate [Well Name: [MPF-01 Well Plan Summary [Type of Well (producer or injector): [KupamkProducer I Surface Location: 1711' FSL 2801' FEL Sec 06 T13N R10E UM., AK. Target Location: 694' FSL 4578' FEL Sec 35 T14N R9E UM., AK. Bottom Hole 911' FSL 4202' FEL Sec 35 T14N R9E UM., AK. Location: [AFE Number: [330138 I I Estimated Start Date: [ April 14' [1995 [ Rig: ] Nabors 27E IOperating days to drill and case: 16 IKBE: 132.5' IWell Design (conventional, slimhole, etc.): Ultra Slimhole Formation Markers: Formation Tops MD TVD (ss) Formation Pressure/EMW base permafrost 1810' 1750' n/a MA n/a n/a n/a NA (Top Schrader) 4962' 3900' 1643 psig / 8.0 ppg OA 5418' 4100' 1718 psig / 8.0 ppg Base Schrader Bluff 5945' 4300' 1830 psig / 8.0 ppg Top HRZ truncated truncated n/a Base HRZ truncated truncated n/a Kupark D Shale 12188' 7068' n/a Top Kuparuk A 12425' 7235' 3634 psig / 9.6 ppg Target 12425' 7235' 3634 psig / 9.6 ppg Total D~pth 12859' 7587' n/a Casing/Tubing Program: Hole Csg/ Wt/Ft Grade Con Length Top Btm Size Tbg n MD/TVD MD/TVD O.D. 30" 20" 91.1# NT80LHE weld 80 32/32 112/112 12 1/4" 9 5/8" 40# L-80 btrc 6114 31/31 6145/4426 8 1/2" 7" 26# L-80 btrc 12829 30/30 12859/7587 N/A (tbg) 3-1/2" 9.3# L-80 EUE 12521 29/29 12225/7139 8rd REcEiVED APR - 5 1995 Alaska 0il & Gas Cons. Commission Anchora ,, Internal yield pressure of the 7" 264~ casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7260' TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3634 psi is 2906 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: ]Open Hole Logs: Surface Intermediate Final Cased Hole Logs: None GR/Resistivity None LWD GR/Resistivity/Neutron/Density None A gamma ray log will be obtained from surface to TD. Mud Logging is not required. RECEIVED APR - 5 ]995 Aiaska Oil & Qas Cons. Commission Anchore ,- Mud Program: ISpecial design considerations INone- LSND freshwater mud Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.6 90 35 15 30 10 15 Intermediate Mud Properties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 to to to to to to to 10.2 50 15 10 20 9.5 4-6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, B OPE and drilling fluid system schematics on file with AOGCC. Directional: [KOP: 11000' Maximum Hole Angle: 1 66 degrees Close Approach Well:]None There are no close approach wells for drilling MPF-01. Disposal: Cuttings Handling: CC2A Fluid Handling: The other wells on this pad are MPF-25, MPF-13, MPF-37 and MPF- 46 (No. Point #1). MPF-46 has had it's annulus arctic packed making it unavailable for injection. Consequently the only annulus available for annular injection will be the 9-5/8" x 7" annulus on MPF-25, MPF-13 and MPF-37. The PEs may be perforating and fracing any of the wells on this pad while MPF-01 is being drilled. Check with the PE supervisor prior to injecting waste fluid down any other annulus to ensure injection will not interfere with their operations. After cementing the 7" casing on this well, MPF-01, and allowing the cement to cure 6 hours the annulus may be used for fluid disposal. Ensure the annulus is freeze protected after injecting any fluids. RECEIVED APR -5 1995 At~ska 0il & Gas Cons. Commission Anchor~:: ,- Annular Injection: All cuttings from this well (MPF-01) will require trucking to CC2 for processing and disposal. Fluids may be injected into the 7" x 9-5/8" annulus on MPF- 25, MPF-13 and MPF-37. MPF-0 l's annulus may be used after allowing the cement on the 7" casing cement job to cure 6 hours following CIP. AREA WELL PREV VOL PERMITTED PERMITTED DATES INJECTED (BBL) VOL (BBL) Milne Point F-25 0 35,000 1/1/95-1'2/31/95 Milne Point F-13 0 35,000 1/1/95-12/31/95 Milne Point F-37 0 35,000 1/1/95-12/31/95 FREEZE PROTECTION: Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are kept open by ensuring that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practice is used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to each other the last time the annunlus was injected into to avoid freezing. RECEIVED APR -.5 1995 Ai~ska Oil & Gas Cons. Commission Anchort... MP F-01 Proposed Summary of Operations I, . o 4, o , . 10. 11. 12. Drill and Set 20" Conductor. Weld an FMC landing ring for the FMC Universal Slimhole Wellhead on conductor. Prepare location for rig move. MIRU Nabors 27E drilling rig. NU and function test 20" Diverter system. Build Spud Mud. Drill a 12-1/4" surface hole to 6145' md (4426' tvd). (Note: This hole section will be LWD logged with GR/Res). Run and cement 9-5/8" casing. ND 20" Diverter, NU and Test 13-5/8" BOPE. Run Wear Bushing. RIH w/PDC bit and turbine. Test the 9-5/8" casing to 3500 psig. Drill out float equipment and 10 feet of new formation, Perform a LOT. Drill 8-1/2" hole to TD at 12859' MD (7587' TVD). (Note: This hole section will be logged LWD with Triple Combo (GR/Res/Neu/Dens). Pull Wear Bushing, and Change Pipe Rams to 7". Run and Cement 7" casing. The 7" casing will be cemented with a single stage cement job across Kuparuk only. The 7" casing will be displaced with 10.2 ppg brine. Run and test 7" pack-off to 5000 psi. ND BOPE. Set 3-1/2" tubing hanger. NU 3-1/16" tubing head adapter and 3-1/2", 5M X-mas tree. 13. 14. 15. 16. 17. RDMO Nabors 27E drilling rig to drill MPF-45. Note: This well will be perforated and completed by Nabors 4ES MIRU Nabors 4ES. ND X-mas tree and NU BOPs. Pull tbg hanger and BOPs test to 5000 psi. RU E-line abd perforate Kuparuk Sands. Run GR/junk basket to PBTD. Run single 7" x 3-1/2" packer on 3-1/2", 9.3#, L-80, EUE 8rd tbg. Freeze protect tbg and annulus. Land hanger and set packer. Set BPV. ND BOP stack and NU tree. Pull BPV and install two check valve. Test tree to 5000 psi. Pull two way check. RDMO with Nabors 4ES. REC£1VF. D APR - ,5 !995 0il & Gas Cons. Commission Anchors'." MPF-01 WELL 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 80 deg F at 4000' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX #SACKS: 1188 THICKENING TIME: Greater than 4 hrs at 50° F. WEIGHT: 15.8 ppg APPROX #SACKS: 250 FLUID LOSS: 100-150 cc TAIL CEMENT TYPE: Premium G ADDITIVES' 0.2% CFR-3, 0.2% Halad-344, 2.0% CaC12 YIELD: 1.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TOP JOB CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD: 2.17 cu ft/sk. MIX WATER: 11.63 gal/sk APPROX NO SACKS' 250 CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on the bottom 10 joints above the FS. 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix slurry on the fly -- batch mixing is not necessary. RECEIVED APR --' 5 'i99~¢ 0[1 & 6as Cons. Commission ^nch0rz. ' CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover 623' md above the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 4. 80'md 9-5/8", 40# capacity for float joints. 5. Top Job Cement Volume is 250 sacks. RECEIVED APR - 5 1995 0i! & Gas Cons. Commission Anchor[ , MPF-01 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON THIS WILL BE A SINGLE STAGE CEMENT JOB ACROSS THE KUPARUK INTERVAL ONLY: CIRC. TEMP: 140° F BHST 170 deg F at 7260' TVDSS. SPACER: 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS: 175 THICKENING TIME: 3 1/2- 4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 min @ 140° F FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7-1/8 .... x 8-1/4" Straight Blade Turbulators -- two per joint on the bottom 21 joints of 7" Casing (34 total). This will cover 300' above the top of the Kuparuk sands. 2. Run one 7-1/8" x 8-1/4" Straight Blade Turbulator inside the 9-5/8"casing shoe. 3. Total 7-1/8 .... x 8-1/4" Straight Blade Turbulators needed is 22. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1. The cement volume is calculated to cover 1000' md above the top of the Kuparuk Sands with 30% excess over a guage hole. DRILLING HAZARDS AND RISKS: See the Milne Point F-Pad Data Sheet prepared by Pete Van Dusen for a general recap of the original No Point well (F-46) recently drilled by BPX. There are also several BHLs drilled from L-pad that can give information relavent F-pad drilling. There will be no close approaches while drilling this well. The gravel on F-pad has only recently been laid. Although frozen the gravel has a relatively high moisture content and has not been compacted. Recently the MPU asset has decided to move N27E from MPF-pad to MPL-pad before break-up. Ensure the rig crews are aware of the unstable nature of the pad during break-up conditions. The MPU Construction group will probably be installing VSMs on this pad as MPF-01 is drilled. Ensure the rig crews and contractors associated with rig operations use caution and are aware of the progress and status of operations with regard to VSM installations while working on this pad. The MPU PE group will be perforating, hydraulic fracturing and cleaning out wells with coiled tubing shortly after the rig drills and completes them. This will make the near rig area congested and as a result hazardous. Ensure personnel use caution moving around adjacent production activities. Check with the PE supervisor prior to injecting fluids down an annulus on any wells that the PE goup may be working on. Lost Circulation: No Point #1 (MPF-46) did not experience any lost circulation while drilling the only well drilled to date on F-pad. The max mud weight reached on that well was 10.3 ppg. They did experience some mud losses while cementing 7" casing. Lost circulation while drilling the production interval has been a problem on 4 different L-pad wells, the closest pad to F-pad, although none of them have BHLs in the F-pad drilling area. The Kuparuk sands and a number of shallower intervals typically are highly fractured. Wells L-07, L-08, L-09 and L-11 lost varying amounts of mud (from 70 to 220 bbls) drilling through or near the top of the Kuparuk sands. Be prepared to treat these losses initially with LCM treatments. Stuck Pipe Potential: While drilling No Point #1 the 6" BHA was stuck in 8-1/2" hole section for several hours at 6882' ss (13608' MD) before jarring free. They became stuck after tripping back to bottom following a bit trip. Lack of proper hole cleaning parameters appears to have contributed to this problem. Stuck pipe has occurred on 3 L-pad wells at the interface between the Kalubik and D-shale (called the Kuparuk cap rock). These wells and the corresponding depths at which they were stuck were: L-06 @ 6871' ss, L-07 @ 6859' ss, L-11 @ 6835' ss. Kick Tolerance: The surface casing setting depth for this well allows a kick tolerance of 102 bbl influx (Gas) based on a 12.5 ppg LOT at the 9-5/8" casing shoe and a estimated reservoir pressure of 3634 psig (9.6 ppg equivalent MW). Trip Schedules are required for all trips. All trips will be performed with a trip tank or one pit isolated for use as a trip tank. Formation Pressure: The maximum expected pore pressure for this well is 9.6 ppg EMW (3634 psi @ 7280 TVD). There has been no injection in this particular fault block. RECEIVED APR -,5 1995 ~l~.ska Oil & Gas Cons. Commission Anchor~ ~ ,l:l I~X - SI~ a r'e.d S c,Hz" v~ccs" · I) ril I i [~g Alaska St'.ale I?lal~e' Zone4 Miln. e I:)L ' MPIi' MPF- 1 Mp[c-O[ Wpl. SCALB 500 IL. / DIVISION TVD RBF: WBI,LHEAD VERTICAL SECTION REF: WELLIIEAD o.oo' ~ o s~ r~ ~ 0.00' ~ lO00 HR KElP / START Or BUILD ~ I.gO'/lO0 Ft 8.00' ~ 1800 HD 4.00° ~ 1400 ND S?ARF DF' B~ILD ~ ;~.00'/100 Ft ,0.00' ~ ,700 ~ F. ND 0¢" BUILD I~ 1936 HD SI'A~T OF CURVE ~ 8,50'/100 Ft ~ ;~136 HD ~ ~336 HD ~ ~36 MD 00' 8 ~736 HD CRITICAL POINT DATA M~ In~ AZL. TIE IN ~ 300,00' Ur BUILD ! t,O0'/tO0 Ft START OF BUILD 14004.00'300.00° E 2.00'/100 ENO Or BUILD 1700I0.00' 300.00' ~, Per~aFeost 1199I0.00' 300,00' SCAR/ Dr 1936I0.00' 3OO.O0* CURV~ ~,50'/tDO Ft END or CURVE 417666.00' 299,06' T. S¢h~aae~496866,00' 299,06' BLUFF B. SChrader39456G.0O' 299.06' BLUFF SfAqf Or 10924 66.00' 899.06' CURVE E 2,00'/100 Ft END Dr CURVE tt915 45,00' 300,00' Target I / T, 12425 45,00' 300,00' B, Kuparu~ 1~559 45.00' 300.00' TVDo N~N E/V 1400 7 N 18 1697 ~5 N 44 1795 34 ~ 59 1930 46 79 4345 1477 N 2649 6370 3606 N 6624 696~ 4110 ~ 7374 7880 4269 7650 7375 4316 N 7738 ~ 8936 ~B IT~oet Name rvD NS 40.00° ~ 3t36 ND r--'-- 45.00'E 3335 ~D J Torget[ 7200 4269 N 7650 E 3536 ND Itease Line 7~00 3589 N2351 ~ 3736 ND I 66,00' e 4L16 ND END OF CURV[i CASING POINT DATA 66.00' e 4968 HO T, Schrader BLUFF 5/08~ In 6145 66.00' 299,06' 8t34 ~ In t2859 45,00' 300.00' O0° ~ 59~5 Hg B. Sch~ade¢ BLUFF 3033 9 S/8 In OB, ~ 6145 ~D, 4486 TVD Grl~ X Grid Y ~ 534094 603939~ 539394 603~738 1565 N 2808 WI 44~61581 4428 N 7916 WI I IIOIZlZON'r^i~'II.:W (TRUE NOll'rll) SCAI.E 500.~t./ DIVISION SURVEY R~,F: I~/ELI,HEAI) · 3/24/95 9,39 BO00 7500 7000 6500 6000 5500 5000 4500 4000 3500 3000 2500 2000 tS00 1000 500 0 75B1 B4~2 5 00' E 10924 MD START Or CURVE ~ 2.00'/100 Ft .00' { 11884 HO 4.01' ~ 11584 MD 0,01' ~ 11784 MD '~.00' E 11915 MD END OF CURVE OD. ~ 18B59 M~.75B/ TV~ ~j* 4~.00 e taB59 ND 9067 -500 500 1000 i500 8000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 0500 9000 9500 10000 VERT[C^L SBCTION ["[,^Ng: g99.]9 PROPOSED BHL TVD 7587.13 ED 12858 98 VS 9087 24 N/S 44~2 51 E/W 7915.57 J Date PLotted Well Plan reasl~ Thi.q is .not an ^ppn WELL PERMIT CHECKLIST UNIT# PROGRAM: exp [] dev~ redrll [] serv [] o /oF ADMINISTRATION 1. Permit fee attached ................... ~ ~ 2. Lease number appropriate ................ 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ..... N '7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N Il. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval.. N 13. Can permit be approved before 15-day wait ....... N ENGINEERING 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 ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............ {~/ N 21. If a re-drill, has a 10-403 for abndrunnt been approved..Y N 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... .~ N 24. Drilling fluid program schematic & equip list adequate .'~ N 25. BOPEs adequate ...................... ---- ~( ~ N 26. BOPE press rating adequate; test to ~~) psig. Y~ N 27. Choke manifold complies w/API RP-53 (May 84) ....... Y N 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/_ 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports . . / . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMI SS ION: C~mments/Instructions: ,, HOW/~o - A:~ORMS~cheklist rev 03/94 WELL PERMIT CHECKLIST WELL NAME /~/~ //.F/-~iD/ PROGRAM: exp [] dev~ redrll [] ,crv U ADMINISTRATION ENGINEERING 2. Lease number appropriate ................ 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary..~y~ N ' 6. Well located proper distance from other wells ..... ~ 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party ............... 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 13. Can permit be approved before 15-day wait ....... 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 abndnmnt been approved. 22. 23. Adequate wellbore separation proposed ......... .~ N If diverter required, is it adequate .......... .~ N 24. Drilling fluid program schematic & equip list adequate N 25. BOPEs adequate .................... N 26. BOPE press rating ~dequate; test to ~-- psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... .~ N 29. Is presence of ~2s gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... 32. Seismic analysis 9f shallow gas zones .......... y N 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports .... /. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: O Z HOW/Jo - A:~FORMS~cheklist mY 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Run 1' 10 - ,July - 1995 GRGH Marked Line 12OO0 2827 WESTERN ATLA8 Logging Services rape Subfile 2 is ~ype: IS TAPE HEADER MILNE POINT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MPF-01 500292255200 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 17-JUL-95 6456.00 R. ECK D. ROBERTSON 6 13N 10E 1711 2801 48.80 47.30 13.10 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 13.375 80.0 3RD STRING 9.625 7124.0 PRODUCTION STRING 7.000 12921.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE CURVE FOR SHIFTS PBU TOOL CODE: GR PBU CURVE CODE: GRCH 1 1 10-JUL-95 WESTERN ATLAS LOGGING SERVICES BASELINE DEPTH $ REMARKS: GR/CCL. EQUIVALENT UNSHIFTED DEPTH 54.50 40.00 26.00 *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** PASS 1 (MAIN PASS) WAS NOT DEPTH SHIFTED SINCE THE MAIN PASS IS THE DEPTH REFERENCE FOR THIS WELL. LOG WAS RUN WITH MARKED LINE FOR PRIMARY DEPTH CONTROL. BASE FLANGE USED FOR DATUM, (KB-BF = 33.03'). FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 12000.0 12827 . 0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 1 (MAIN PASS). THE G~ RAY FROM THIS PASS IS THE DEPTH REFERENCE FOR THIS WELL. CN : BP EXPLORATION WN : MPF-01 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 30 310 01 1 * DATA RECORD (TYPE# 0) 1022 BYTES * Total Data Records: 14 Tape File Start Depth = 12870.000000 Tape File End Depth = 11998.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 3491 datums Tape Subfile: 2 106 records... Minimum record length: 62 bytes Maximum record length: 1022 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 12463.0 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH GRCH 12470.5 12470.5 12476.0 12475.5 12489.5 12489.5 12508 . 0 12509 . 0 12513.0 12513.5 12521.0 12521.0 12528.5 12528.5 12543.0 12544.0 12555.5 12556.0 12567.0 12568.0 12598.0 12598.5 12633.0 12633.5 12637.5 12639 . 0 12643.0 12643.5 12665.0 12666.5 12684.0 12684.0 12698.0 12698.0 12717.5 12718.0 12733.0 12733.0 12746.5 12746.5 12765.5 12766.0 12784.0 12785.0 12789.5 12790.5 12795.0 12795.0 12803.0 12805.0 12810.5 12813.0 12817.5 12817.5 12821.5 12822 . 0 $ REMARKS: PASS 2 (REPEAT PASS). for each pass in separate files. STOP DEPTH 12827.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH ......... /??MATCH1. OUT $ CN : BP EXPLORATION WN : MPF-01 FN : Mil ] POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod * DATA RECORD (TYPE# 0) 1022 BYTES * Total Data Records: 7 4 30 995 99 1 Tape File Start Depth = 12845.000000 Tape File End Depth = 12453.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1571 datums Tape Subfile: 3 66 records... Minimum record length: Maximum record length: 62 bytes 1022 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NI/MBER: 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12000.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 12867.0 10-JUL-95 FSYS REV. J001 VER. 1.1 1123 10-JUL-95 12837.0 12839.0 12000.0 12827.0 1800.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWVL SBAR PCM GR SBAR $ SINKER BAR PCM/CCL G~ RAY SINKER BAR TOOL NUMBER 3913NA 8250EA/8248EA 8220XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .000 12921.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): DIESEL/SEAWATER 8.40 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL)' MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP N'ORMALIZI~< WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN) : .0 REMARKS: PASS 1 (MAIN PASS). $ CN : BP EXPLORATION WN : MPF-01 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 70 Tape File Start Depth = 12870.000000 Tape File End Depth = 11998.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 20937 datums Tape Subfile: 4 145 records... Minimum record length' Maximum record length: 62 bytes 1006 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12463.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 12842.0 10-JUL-95 FSYS REV. J001 VER. 1.1 1103 10-JUL-95 12837.0 12839.0 12000.0 12827.0 1800.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWVL SBAR PCM GR SBAR $ SINKER BAR PCM/CCL GAMMA RAY SINKER BAR TOOL NUMBER 3913NA 8250EA/8248EA 8220XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .0O0 12921.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): DIESEL/SEAWATER 8.40 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 ,000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP N~)RMALIZI5 WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 2 (REPEAT PASS). $ CN : BP EXPLORATION WN : MPF-01 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FP~AME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 32 Tape File Start Depth = 12845.000000 Tape File End Depth = 12453.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 9417 datums Tape Subfile: 5 107 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 6 is type: LIS 95/ 7/17 01 **** REEL TRAILER **** 95/ 7/14 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 14 JLY 95 4:31p Elapsed execution time = 4.45 seconds. SYSTEM RETURN CODE = 0