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Home My WebLink About201-176Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 06/14/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL TBU M-12 (PTD 201-176) PERF 04/12/2022 Please include current contact information if different from above. 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$/$6.$2,/$1'*$6&216(59$7,21&200,66,21 $33/,&$7,21)25681'5<$33529$/6 $$& $'/ 0F$UWKXU5LYHU)LHOG0LGGOH.HQDL*DV3RRO &2$7UDGLQJ%D\8QLW0 &HQWHUSRLQW'ULYH6XLWH +LOFRUS$ODVND//& $QFKRUDJH$. /HQJWK 6L]H a a / 79' %XUVW SVL 0' SVL a 3HUIRUDWLRQ'HSWK0'IW U\ 6WDWX )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Samantha Carlisle at 7:21 am, Mar 29, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH 6)'%-0 '65 GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.04.12 14:38:17 -08'00' RBDMS SJC 041422 tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůůEĂŵĞ͗dƌĂĚŝŶŐĂǇhŶŝƚDͲϭϮ W/EƵŵďĞƌ͗ ϱϬͲϳϯϯͲϮϬϱϬϱͲϬϬͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗'ĂƐtĞůů >ĞŐ͗ͲϮ;EĐŽƌŶĞƌͿ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍ϰϬϯ ĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗:ƵĂŶŝƚĂ>ŽǀĞƚƚ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϬϭͲϭϳϲ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗<ĂƚŚĞƌŝŶĞK͛ŽŶŶŽƌ KĨĨŝĐĞ͗ϵϬϳͲϳϳϳͲϴϯϳϲ Ğůů͗ϮϭϰͲϲϴϰͲϳϰϬϬ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗ŚĂĚ,ĞůŐĞƐŽŶ Ğůů͗ϵϬϳͲϮϮϵͲϰϴϮϰ Current Bottom Hole Pressure:300 psi @ 3458’ TVD 0.087 psi/ft gas gradient to surface Maximum Expected BHP:375 psi @ 2835’ TVD 0.132 psi/ft water gradient to surface Maximum Potential Surface Pressure:347 psi ƌŝĞĨtĞůů^ƵŵŵĂƌǇ͗ tĞůůDͲϭϮŝƐĂŐĂƐǁĞůůĐŽŵƉůĞƚĞĚŝŶƚŚĞ͕͕ĂŶĚƐĂŶĚƐ͘dŚĞǁĞůůŚĂĚĂZtKŝŶƐƵŵŵĞƌϮϬϮϬĂŶĚ ƉĞƌĨŽƌĂƚŝŽŶƐĂĚĚĞĚŝŶƚŽƚŚĞ͕ĂŶĚƐĂŶĚƐ͘dŚĞŽďũĞĐƚŝǀĞŽĨƚŚŝƐƉƌŽŐƌĂŵŝƐƚŽƐŚŽŽƚŝŶĨŝůůƉĞƌĨƐŝŶƚŚĞ ϲƐĂŶĚďĞůŽǁƚŚĞƚƵďŝŶŐƚĂŝů͘^ůŝĐŬůŝŶĞƌĞĐĞŶƚůǇďĂŝůĞĚĞŶŽƵŐŚ ƐĂŶĚͬĨŝůůŽƵƚŽĨƚŚĞƚƵďŝŶŐƚĂŝůƚŽĂůůŽǁ ĂĐĐĞƐƐƚŽƚŚĞƉĞƌĨŽƌĂƚŝŽŶƐ͘ ͲůŝŶĞWƌŽĐĞĚƵƌĞ͗ ϭ͘ D/ZhͲůŝŶĞ͕WdůƵďƌŝĐĂƚŽƌƚŽϭ͕ϱϬϬƉƐŝ,ŝϮϱϬ>Žǁ͘ Ϯ͘ WĞƌĨŽƌĂƚĞǁŝƚŚǁĞůůĨůŽǁŝŶŐƉĞƌƉƌŽŐƌĂŵ͘ ϯ͘ ZͲůŝŶĞ͘ ϰ͘ dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƵƌƌĞŶƚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ hƉĚĂƚĞĚďǇ͗:>>ϬϰͲϬϲͲϮϭ ^,Dd/ ^ƚĞĞůŚĞĂĚWůĂƚĨŽƌŵ tĞůů͗DͲϭϮ ƐŽŵƉůĞƚĞĚ͗ϬϲͬϬϲͬϮϬϮϬ Wd͗ϮϬϭͲϭϳϲ W/͗ϱϬͲϳϯϯͲϮϬϱϬϱͲϬϬͲϬϬ WĞƌĨŽƌĂƚŝŽŶĞƚĂŝů KEdŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿƚŵ;dsͿ&d^ŚŽƚĂƚĞ Ͳϯϯ͕ϮϱϬΖϯ͕ϮϲϳΖϮ͕ϳϱϰΖϮ͕ϳϲϱΖϭϳΖϱ^W&ϬϯͬϭϮͬϮϭ Ͳϯϯ͕ϯϬϱΖϯ͕ϯϭϬΖϮ͕ϳϵϭΖϮ͕ϳϵϱΖϱΖϱ^W&ϬϯͬϭϮͬϮϭ Ͳϯϯ͕ϯϮϬΖϯ͕ϯϯϱΖϮ͕ϴϬϮΖϮ͕ϴϭϮΖϭϱΖϱ^W&ϬϯͬϭϮͬϮϭ ͲϰhƉƉĞƌϯ͕ϯϲϲΖϯ͕ϯϳϮΖϮ͕ϴϯϰΖϮ͕ϴϯϴΖϲΖϱ^W&ϬϯͬϭϭͬϮϭ Ͳϰϯ͕ϯϵϭΖϯ͕ϰϭϬΖϮ͕ϴϱϭΖϮ͕ϴϲϰΖϭϵΖϱ^W&ϬϯͬϭϭͬϮϭ Ͳϰϯ͕ϰϭϲΖϯ͕ϰϮϲΖϮ͕ϴϲϴΖϮ͕ϴϳϱΖϭϬΖϱ^W&ϬϯͬϭϭͬϮϭ Ͳϰϯ͕ϰϯϵΖϯ͕ϰϱϴΖϮ͕ϴϴϰΖϮ͕ϴϵϴΖϭϵΖϱ^W&ϬϯͬϭϭͬϮϭ Ͳϱϯ͕ϰϲϴΖϯ͕ϰϳϱΖϮ͕ϵϬϱΖϮ͕ϵϭϬΖϳΖϭϬͬϴͬϮϬϮϬ Ͳϱϯ͕ϰϴϵΖϯ͕ϱϬϬΖϮ͕ϵϭϵΖϮ͕ϵϮϳΖϭϭΖϭϬͬϴͬϮϬϮϬ Ͳϱϯ͕ϱϬϱΖϯ͕ϱϭϯΖϮ͕ϵϯϭΖϮ͕ϵϯϲΖϴΖϭϬͬϲͬϮϬϮϬ Ͳϱϯ͕ϱϮϬΖϯ͕ϱϱϵΖϮ͕ϵϰϭΖϮ͕ϵϲϵΖϯϵΖϭϬͬϲͬϮϬϮϬ Ͳϭϯ͕ϴϲϰ͛ϯ͕ϵϰϰ͛ϯ͕ϭϴϯ͛ϯ͕Ϯϯϵ͛ϴϬ͛ϳͬϭϯͬϮϬϮϬ Ͳϯϯ͕ϵϵϮ͛ϰ͕ϭϭϬ͛ ϯ͕ϮϳϮ͛ ϯ͕ϯϱϯ͛ ϭϭϴ͛ ϲͬϮϭͲϲͬϮϮΘ ϳͬϭϯͬϮϬ Ͳϱϰ͕ϯϲϰ͛ϰ͕ϰϭϯ͛ϯ͕ϱϮϲ͛ϯ͕ϱϱϵ͛ϰϵ͛ϲͬϮϭͬϮϬϮϬ Ͳϱϰ͕ϰϯϱ͛ϰ͕ϰϰϵ͛ϯ͕ϱϳϯ͛ϯ͕ϱϴϯ͛ϭϰ͛ϲͬϮϭͬϮϬϮϬ Ͳϭϰ͕ϴϭϴΖϰ͕ϴϯϯΖϯ͕ϴϯϬΖϯ͕ϴϰϬΖϭϱΖϭϬͬϱͬϮϬϮϬ Ͳϭϰ͕ϴϰϮ͛ϰ͕ϴϳϬ͛ϯ͕ϴϰϲ͛ϯ͕ϴϲϰ͛Ϯϴ͛ϲͬϮϭͬϮϬϮϬ Ͳϭϰ͕ϴϴϲ͛ϰ͕ϵϬϬ͛ϯ͕ϴϳϱ͛ϯ͕ϴϴϰ͛ϭϰ͛ϲͬϮϬͬϮϬϮϬ Ͳϯϱ͕ϬϲϬ͛ϱ͕Ϭϴϳ͛ϯ͕ϵϵϯ͛ϰ͕ϬϭϮ͛Ϯϳ͛ϲͬϮϬͬϮϬϮϬ ĂƐŝŶŐĞƚĂŝů ^ŝǌĞdǇƉĞtƚ'ƌĂĚĞŽŶŶdŽƉƚŵ Ϯϴ͟^ƚƌƵĐƚƵƌĂůϭϯϯyͲϱϲƌŝǀĞ^ƵƌĨΕϰϴϬ͛ ϭϴͲϱͬϴ͟^ƵƌĨĂĐĞϵϲ͘ϴyͲϱϲYͲϲϬ^ƵƌĨϴϲϯ͛ ϭϯͲϯͬϴ͟^ƵƌĨĂĐĞϲϴ<ͲϱϱƵƚƚ^ƵƌĨϭ͕ϱϭϱ͛ ϵͲϱͬϴ͟^ƵƌĨĂĐĞϰϳ>ͲϴϬƵƚƚ^ƵƌĨϲ͕ϱϱϲ͛ ϯͲϭͬϮ͟>ŝŶĞƌϵ͘Ϯ>ͲϴϬ/dϲ͕ϯϴϰ͛ϭϬ͕ϳϯϭ͛ dƵďŝŶŐĞƚĂŝů ϯͲϭͬϮ͟WƌŽĚƵĐƚŝŽŶϵ͘ϯ>ͲϴϬ/d^ƵƌĨϯ͕ϴϮϰ͛ :ĞǁĞůƌǇĞƚĂŝů EŽ͘ĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ/K/ƚĞŵ ϳϲ͘ϵϬ͛ϳϲ͘ϵϬ͛ ,ĂŶŐĞƌ/t^^DϭϯϱͬϴΗϲ͘ϯϳϱΗůĞĨƚ,ĂŶĚƐƚƵďůŝĨƚŽŶůǇǁŝƚŚ^^D ƌƵŶŶŝŶŐƚŽŽů͕ϵΕƚƵƌŶƐƚŽƌĞůĞĂƐĞϰϭͬϮΗ/dƐƵƐƉĞŶĚ͕ϯΗƚǇƉĞΗ,Η WsƉƌŽĨŝůĞ 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xϭϬͬϬϳͬϮϬʹϲ͕ϰϬϬ͛Ͳ&ŝƐŚůĞĨƚŝŶŚŽůĞ͗ZŽƉĞƐŽĐŬĞƚϭϳͬϭϲΗϭϯͬϴΗ&EϭΖyϭ͘ϰϰΗ͕dŝƚĂŶ ŐĂŵŵĂϲ͘ϯΖǆϭ͘ϲϵΗ͕WŝŶƚŽWŝŶ͘ϱϬΖyϭ͘ϲϵΗ͕^ŚŽĐŬƐƵďϭ͘ϱΖyϭ͘ϲϵΗ͕tƚďĂƌϱΖyϭ͘ϲϵΗ͕tƚ ďĂƌϱΗyϭ͘ϲϵΖ͕dĞĂƌĚƌŽƉ͕ƚŽƉƐƵď͕ďůĂƐƚƐůĞĞǀĞ͕ƚĂŶĚĞŵƐƵďϮ͘ϮΖyϮ͘ϯϴΗ͕ϮϯͬϴΗƐƉĞŶƚƉĞƌĨ ŐƵŶϮ͘ϱΗǆϭϭΖ͕ƵůůƉůƵŐ͘ϮΖǆϮϯͬϴΗdK>сϯϮ͘ϳΖ xϭϬͬϬϵͬϮϬʹϲ͕ϯϱϬ͛^>Dʹ&ŝƐŚůĞĨƚŝŶŚŽůĞ͗ZŽƉĞƐŽĐŬĞƚ͕ϭϳͬϭϲ;ϭΗϯͬϴĨŝƐŚŝŶŐŶĞĐŬͿ;ϭΖy ϭΗͿ͕WƌŽďĞŐƵŶŐĂŵŵĂ;ϲ͘ϯΖyϭ͘ϲϵΗͿWŝŶƚŽƉŝŶ;͘ϱϬΖyϭ͘ϲϵΖͿƐŚŽĐŬƐƵď;ϭ͘ϱΖyϭ͘ϲϵΗͿ͕ ǁĞŝŐŚƚďĂƌ;ϱΖyϮΗͿ͕dƵďĞũĂƌƐ;ϱΖǆϮΗͿ͕dĞĂƌƌŽƉdŽƉ^Ƶď͕ůĂƐƚ^ůĞĂǀĞdĂŶĚĞŵ^Ƶď;Ϯ͘ϮΖy Ϯ͘ϯϴΗͿϮϯͬϴΗƉĞƌĨŐƵŶ;&ŝƌĞĚͿƵůůƉůƵŐ;Ϯ͘ϯϳϱΗyϭϭΖͿdK>сϯϯ͘ϳΖ EŽƚĞ͗ xdŚĞϮϴ͟ƌŝǀĞƉŝƉĞŝƐĐƌŽƐƐĞĚŽǀĞƌƚŽϯϰ͟KƉŝƉĞďĞůŽǁΕϵϱ͘ϱ͛Z< xdŚĞƌŝůůĞĚdǁĂƐƌĞĐŽƌĚĞĚĂƚϭϬ͕ϳϭϱ͛͘dŚĞƌĞĐŽƌĚĞĚƚƵďŝŶŐƚĂŐĂƚdǁĂƐƌĞĐŽƌĚĞĚĂƐ ϭϬ͕ϳϯϱ͛͘dŚĞƚƵďŝŶŐĚĞƉƚŚƐĂƌĞƌĞƉŽƌƚĞĚĂƐƉĞƌŵĞĂƐƵƌĞŵĞŶƚƐŽĨƚŚĞƚƵďŝŶŐƐƚƌĂƉ͘ /ƐŽůĂƚĞĚͲWĞƌĨŽƌĂƚŝŽŶĞƚĂŝů KEdŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ^ŚŽƚĂƚĞ ͲϭϬϳ͕ϬϵϳΖϳ͕ϭϭϯΖϱ͕ϰϬϴΖϱ͕ϰϭϵΖϲ/ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ ͲϭϬϳ͕ϭϱϬΖϳ͕ϭϳϳΖϱ͕ϰϰϰΖϱ͕ϰϲϯΖϲ/ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ ͲϭϮϳ͕ϰϬϮΖϳ͕ϰϮϰΖϱ͕ϲϮϭΖϱ͕ϲϯϳΖϲ/ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲϳ͕ϴϴϳΖϳ͕ϵϬϬΖϱ͕ϵϴϯΖϱ͕ϵϵϯΖϲ/ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲϳ͕ϵϭϰ͛ϳϵϯϵ͛ϲ͕ϬϬϱΖϲ͕ϬϮϲΖϲ/ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲϳ͕ϵϭϴ͛ϳϵϯϯ͛ϲ͕ϬϬϴΖϲ͕ϬϮϭΖϲ/ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲϳ͕ϵϯϯ͛ϳϵϰϯ͛ϲ͕ϬϮϭΖϲ͕ϬϮϵΖϲ/ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲϳ͕ϵϯϵ͛ϳϵϱϯ͛ϲ͕ϬϮϲΖϲ͕ϬϯϳΖϲ/ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲϳ͕ϵϰϯ͛ϳϵϱϮ͘ϱ͛ϲ͕ϬϮϵΖϲ͕ϬϯϳΖϱ/ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲϳ͕ϵϱϮ͘ϱ͛ϳϵϲϮ͛ϲ͕ϬϯϳΖϲ͕ϬϰϱΖϱ/ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲϳ͕ϵϱϯ͛ϳϵϱϴ͛ϲ͕ϬϯϳΖϲ͕ϬϰϮΖϲ/ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϴ͕ϮϮϴ͛ϴ͕Ϯϱϴ͛ϳ͕ϰϱϯ͛ϳ͕ϰϳϱ͛/ƐŽůĂƚĞĚ Ͳϭϴ͕Ϯϵϯ͛ϴ͕ϯϮϮ͛ϳ͕ϱϬϬ͛ϳ͕ϱϮϭ͛/ƐŽůĂƚĞĚ ͲϮϴ͕ϰϯϴ͛ϴ͕ϰϲϬ͛ϲ͕ϰϲϵ͛ϲ͕ϰϵϬ͛/ƐŽůĂƚĞĚ Ͳϰϴ͕ϱϲϯ͛ϴ͕ϱϴϬ͛ϲ͕ϱϵϬ͛ϲ͕ϲϬϳ͛/ƐŽůĂƚĞĚ ϱϴ͕ϳϭϬΖϴ͕ϳϯϴΖϲ͕ϳϯϰΖϲ͕ϳϲϮΖ/ƐŽůĂƚĞĚ Ͳϳϴ͕ϵϰϯΖϴ͕ϵϲϬΖϲ͕ϵϲϮΖϲ͕ϵϳϵΖϰ/ƐŽůĂƚĞĚ 'KͲϭϭϬ͕ϰϬϲ͛ϭϬϰϭϬ͛ϴ͕ϯϵϳΖϴ͕ϰϬϬΖϲ/ƐŽůĂƚĞĚ 'KͲϯϭϬ͕ϱϯϬ͛ϭϬϱϱϬ͛ϴ͕ϱϭϵΖϴ͕ϱϯϴΖϲ/ƐŽůĂƚĞĚ 'KͲϱϭϬ͕ϲϭϲ͛ϭϬϲϮϭ͛ϴ͕ϲϬϰΖϴ͕ϲϬϴΖϲ/ƐŽůĂƚĞĚ hƉĚĂƚĞĚďǇ:>>ϬϯͬϮϴͬϮϮ WZKWK^ ^ƚĞĞůŚĞĂĚWůĂƚĨŽƌŵ tĞůů͗DͲϭϮ ƐŽŵƉůĞƚĞĚ͗ϬϲͬϬϲͬϮϬϮϬ Wd͗ϮϬϭͲϭϳϲ W/͗ϱϬͲϳϯϯͲϮϬϱϬϱͲϬϬͲϬϬ WĞƌĨŽƌĂƚŝŽŶĞƚĂŝů KEdŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ;dsͿ &d ^ŚŽƚ ĂƚĞ Ͳϯ ϯ͕ϮϱϬΖ ϯ͕ϮϲϳΖ Ϯ͕ϳϱϰΖ Ϯ͕ϳϲϱΖ ϭϳΖ ϱ^W& ϬϯͬϭϮͬϮϭ Ͳϯ ϯ͕ϯϬϱΖ ϯ͕ϯϭϬΖ Ϯ͕ϳϵϭΖ Ϯ͕ϳϵϱΖ ϱΖ ϱ^W& ϬϯͬϭϮͬϮϭ Ͳϯ ϯ͕ϯϮϬΖ ϯ͕ϯϯϱΖ Ϯ͕ϴϬϮΖ Ϯ͕ϴϭϮΖ ϭϱΖ ϱ^W& ϬϯͬϭϮͬϮϭ ͲϰhƉƉĞƌ ϯ͕ϯϲϲΖ ϯ͕ϯϳϮΖ Ϯ͕ϴϯϰΖ Ϯ͕ϴϯϴΖ ϲΖ ϱ^W& ϬϯͬϭϭͬϮϭ Ͳϰ ϯ͕ϯϵϭΖ ϯ͕ϰϭϬΖ Ϯ͕ϴϱϭΖ Ϯ͕ϴϲϰΖ ϭϵΖ ϱ^W& ϬϯͬϭϭͬϮϭ Ͳϰ ϯ͕ϰϭϲΖ ϯ͕ϰϮϲΖ Ϯ͕ϴϲϴΖ Ϯ͕ϴϳϱΖ ϭϬΖ ϱ^W& ϬϯͬϭϭͬϮϭ Ͳϰ ϯ͕ϰϯϵΖ ϯ͕ϰϱϴΖ Ϯ͕ϴϴϰΖ Ϯ͕ϴϵϴΖ ϭϵΖ ϱ^W& ϬϯͬϭϭͬϮϭ Ͳϱ ϯ͕ϰϲϴΖ ϯ͕ϰϳϱΖ Ϯ͕ϵϬϱΖ Ϯ͕ϵϭϬΖ ϳΖ ϭϬͬϴͬϮϬϮϬ Ͳϱ ϯ͕ϰϴϵΖ ϯ͕ϱϬϬΖ Ϯ͕ϵϭϵΖ Ϯ͕ϵϮϳΖ ϭϭΖ ϭϬͬϴͬϮϬϮϬ Ͳϱ ϯ͕ϱϬϱΖ ϯ͕ϱϭϯΖ Ϯ͕ϵϯϭΖ Ϯ͕ϵϯϲΖ ϴΖ ϭϬͬϲͬϮϬϮϬ Ͳϱ ϯ͕ϱϮϬΖ ϯ͕ϱϱϵΖ Ϯ͕ϵϰϭΖ Ϯ͕ϵϲϵΖ ϯϵΖ ϭϬͬϲͬϮϬϮϬ Ͳϭ ϯ͕ϴϲϰ͛ ϯ͕ϵϰϰ͛ ϯ͕ϭϴϯ͛ ϯ͕Ϯϯϵ͛ ϴϬ͛ ϳͬϭϯͬϮϬϮϬ Ͳϯ ϯ͕ϵϵϮ͛ ϰ͕ϭϭϬ͛ ϯ͕ϮϳϮ͛ ϯ͕ϯϱϯ͛ ϭϭϴ͛ ϲͬϮϭͲϲͬϮϮΘ ϳͬϭϯͬϮϬ Ͳϱ ϰ͕ϯϲϰ͛ ϰ͕ϰϭϯ͛ ϯ͕ϱϮϲ͛ ϯ͕ϱϱϵ͛ ϰϵ͛ ϲͬϮϭͬϮϬϮϬ Ͳϱ ϰ͕ϰϯϱ͛ ϰ͕ϰϰϵ͛ ϯ͕ϱϳϯ͛ ϯ͕ϱϴϯ͛ ϭϰ͛ ϲͬϮϭͬϮϬϮϬ ͲϲhƉƉĞƌ цϰ͕ϰϵϬ͛ цϰ͕ϱϯϱ͛ цϯ͕ϲϭϬ͛ цϯ͕ϲϰϬ͛ ϰϱΖ WƌŽƉŽƐĞĚ Ͳϲ>ŽǁĞƌ цϰ͕ϱϲϴ͛ цϰ͕ϱϴϴ͛ цϯ͕ϲϲϮ͛ цϯ͕ϲϳϱ͛ ϮϬΖ WƌŽƉŽƐĞĚ Ͳϭ ϰ͕ϴϭϴΖ ϰ͕ϴϯϯΖ ϯ͕ϴϯϬΖ ϯ͕ϴϰϬΖ ϭϱΖ ϭϬͬϱͬϮϬϮϬ Ͳϭ ϰ͕ϴϰϮ͛ ϰ͕ϴϳϬ͛ ϯ͕ϴϰϲ͛ ϯ͕ϴϲϰ͛ Ϯϴ͛ ϲͬϮϭͬϮϬϮϬ Ͳϭ ϰ͕ϴϴϲ͛ ϰ͕ϵϬϬ͛ ϯ͕ϴϳϱ͛ ϯ͕ϴϴϰ͛ ϭϰ͛ ϲͬϮϬͬϮϬϮϬ Ͳϯ ϱ͕ϬϲϬ͛ ϱ͕Ϭϴϳ͛ ϯ͕ϵϵϯ͛ ϰ͕ϬϭϮ͛ Ϯϳ͛ ϲͬϮϬͬϮϬϮϬ 7' ¶0'¶79' 3%7' ¶0'¶79' 0$;+2/($1*/( 2 #¶ * ´ ) ' *2 *2 *2 RKB:80.15’, RKB to MSL: 160.2’, RKB to Mudline: 345’ ´ ´ ´ % 7RSRIFHPHQW ¶ + , - . 7RSRIFHPHQW ¶ ( ( 7RSRIFHPHQW ¶ 7RSRIFHPHQW ¶ ( ( ( ' ' (7RSRIFHPHQW ¶ $ % % % & & $ $8SSHU $ ; 0LOOHG%ULGJH 3OXJ#¶ 7RSRIILOO ¶ 6/05.% ĂƐŝŶŐĞƚĂŝů ^ŝǌĞ dǇƉĞ tƚ 'ƌĂĚĞ ŽŶŶ dŽƉ ƚŵ Ϯϴ͟ ^ƚƌƵĐƚƵƌĂů ϭϯϯ yͲϱϲ ƌŝǀĞ ^ƵƌĨ ΕϰϴϬ͛ ϭϴͲϱͬϴ͟ ^ƵƌĨĂĐĞ ϵϲ͘ϴ yͲϱϲ YͲϲϬ ^ƵƌĨ ϴϲϯ͛ ϭϯͲϯͬϴ͟ ^ƵƌĨĂĐĞ ϲϴ <Ͳϱϱ Ƶƚƚ ^ƵƌĨ ϭ͕ϱϭϱ͛ ϵͲϱͬϴ͟ ^ƵƌĨĂĐĞ ϰϳ >ͲϴϬ Ƶƚƚ ^ƵƌĨ ϲ͕ϱϱϲ͛ ϯͲϭͬϮ͟ >ŝŶĞƌ ϵ͘Ϯ >ͲϴϬ /d ϲ͕ϯϴϰ͛ ϭϬ͕ϳϯϭ͛ dƵďŝŶŐĞƚĂŝů ϯͲϭͬϮ͟ WƌŽĚƵĐƚŝŽŶ ϵ͘ϯ >ͲϴϬ /d ^ƵƌĨ ϯ͕ϴϮϰ͛ :ĞǁĞůƌǇĞƚĂŝů EŽ͘ĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ / K /ƚĞŵ ϳϲ͘ϵϬ͛ ϳϲ͘ϵϬ͛ ,ĂŶŐĞƌ/t^^DϭϯϱͬϴΗϲ͘ϯϳϱΗůĞĨƚ,ĂŶĚƐƚƵďůŝĨƚŽŶůǇǁŝƚŚ^^D ƌƵŶŶŝŶŐƚŽŽů͕ϵΕƚƵƌŶƐƚŽƌĞůĞĂƐĞϰϭͬϮΗ/dƐƵƐƉĞŶĚ͕ϯΗƚǇƉĞΗ,Η WsƉƌŽĨŝůĞ ϭ ϰϯϲ͛ ϰϯϲ͛ Ϯ͘ϴϭϬ ϱ͘ϭϲϬ dZ^s Ϯ Ϯ͕ϭϴϱ͛ Ϯ͕ϬϮϬ͛ Ϯ͘ϴϲϳ ϱ͘ϵϲϴ ^&KͲϮ'>DηϭͲ>ŝǀĞ Ϯ͕ϵϲϲ͛ Ϯ͕ϱϱϴ͛ Ϯ͘ϴϲ͟ ϱ͘ϵϲϴ ^&KͲϮ'>DηϮͲKƌŝĨŝĐĞ ϯ ϯ͕Ϭϭϵ͛ Ϯ͕ϱϵϱ͛ ϯ͘ϬϬϬ ϴ͘ϮϱϬ WĂĐŬĞƌʹdƌŝƉŽŝŶƚ,ǇĚƌĂƵůŝĐZĞƚƌŝĞǀĂďůĞ ϰ ϯ͕Ϭϲϱ͛ Ϯ͕ϲϮϲ͛ Ϯ͘ϴϭϬ ϰ͘ϮϱϬ yͲEŝƉƉůĞǁͬƉůƵŐ ϱ ϯ͕ϴϮϰ͛ ϯ͕ϭϱϱ͛ ϯ͘ϮϱϬ ϯ͘ϳϬϬ t>' ϲ ϲ͕ϰϬϯ͛ ϰ͕ϵϮϯ͛ ĂŬĞƌyWWĂĐŬĞƌǁͬyͲKĂŶĚƉƵƉũƚ͘ ϳ ϲ͕ϱϬϬ͛ ϰ͕ϵϵϭ͛ ƌŝĚŐĞWůƵŐǁͬϮϴ͛ŽĨĐĞŵĞŶƚĚƵŵƉďĂŝůĞĚŽŶƚŽƉ;dKϲ͕ϰϳϮ͛Ϳ /ƐŽůĂƚĞĚ:ĞǁĞůƌǇĞƚĂŝů ϳ͕ϵϭϮ͛ ϲ͕ϬϬϯ͛ ƌŝĚŐĞWůƵŐ & ϴ͕ϲϵϱ͛ ϲ͕ϳϮϬ͛ ƌŝĚŐĞWůƵŐ͕^Ğƚϰͬϵͬϭϰ ' ϴ͕ϴϳϴ͛ ϲ͕ϴϵϵ͛ /W͕^ĞƚϰͬϭϮͬϭϰ , ϭϬ͕ϯϲϬ͛ ϴ͕ϯϱϭ͛ ĂŬĞƌEƌŝĚŐĞWůƵŐ͕ƐĞƚϭϮͬϭϴͬϬϭ / ϭϬ͕ϰϴϬ͛ ϴ͕ϰϲϵ͛ ĂŬĞƌEƌŝĚŐĞWůƵŐͲ^ƚƵĐŬ͕ƐĞƚΛϭϬ͕ϰϴϬ͛ŽŶϭϮͬϱͬϬϭƚŽďĞĂďůĞƚŽ ƐĞƚWηϳĂƚƉƌŽƉĞƌĚĞƉƚŚ͘ : ϭϬ͕ϰϵϬ͛ ϴ͕ϰϳϵ͛ ĂŬĞƌEƌŝĚŐĞWůƵŐ͕ƐĞƚϭϭͬϮϴͬϬϭ < ϭϬ͕ϱϵϬ͛ ϴ͕ϱϳϴ͛ ĂŬĞƌEƌŝĚŐĞWůƵŐ͕ƐĞƚϭϭͬϮϯͬϬϭ hƉĚĂƚĞĚďǇ͗:>>ϬϯͬϮϴͬϮϮ WZKWK^ ^ƚĞĞůŚĞĂĚWůĂƚĨŽƌŵ tĞůů͗DͲϭϮ ƐŽŵƉůĞƚĞĚ͗ϬϲͬϬϲͬϮϬϮϬ Wd͗ϮϬϭͲϭϳϲ W/͗ϱϬͲϳϯϯͲϮϬϱϬϱͲϬϬͲϬϬ &/^,͗ x ϭϬͬϬϭͬϭϰʹ/WƉƵƐŚĞĚĚŽǁŶƚŽϴ͕ϭϰϵ͛ x ƌŝĚŐĞƉůƵŐǁĂƐŵŝůůĞĚǁŝƚŚdĨŽƌϮϯ͘ϱŚƌƐΛϳ͕ϴϮϭ͛dDŽŶϭϮͬϭϰͬϬϭ͘:ƵŶŬǁĂƐƉƵƐŚĞĚƚŽ ϭϬ͕ϰϴϬ͛ x ϲͬϮϮͬϮϬʹϯƉĞƌĨŐƵŶƐ;ϰϬ͕͛ϯϵ͕͛ϯϳ͘ϱ͛ͿĐŽŵƉůĞƚĞǁŝƚŚ>н'ĂŵŵĂϭ͘ϬϬ͟ĨŝƐŚŝŶŐŚĞĂĚ x ϭϬͬϬϳͬϮϬʹϲ͕ϰϬϬ͛Ͳ&ŝƐŚůĞĨƚŝŶŚŽůĞ͗ZŽƉĞƐŽĐŬĞƚϭϳͬϭϲΗϭϯͬϴΗ&EϭΖyϭ͘ϰϰΗ͕dŝƚĂŶ ŐĂŵŵĂϲ͘ϯΖǆϭ͘ϲϵΗ͕WŝŶƚŽWŝŶ͘ϱϬΖyϭ͘ϲϵΗ͕^ŚŽĐŬƐƵďϭ͘ϱΖyϭ͘ϲϵΗ͕tƚďĂƌϱΖyϭ͘ϲϵΗ͕tƚ ďĂƌϱΗyϭ͘ϲϵΖ͕dĞĂƌĚƌŽƉ͕ƚŽƉƐƵď͕ďůĂƐƚƐůĞĞǀĞ͕ƚĂŶĚĞŵƐƵďϮ͘ϮΖyϮ͘ϯϴΗ͕ϮϯͬϴΗƐƉĞŶƚƉĞƌĨ ŐƵŶϮ͘ϱΗǆϭϭΖ͕ƵůůƉůƵŐ͘ϮΖǆϮϯͬϴΗdK>сϯϮ͘ϳΖ x ϭϬͬϬϵͬϮϬʹϲ͕ϯϱϬ͛^>Dʹ&ŝƐŚůĞĨƚŝŶŚŽůĞ͗ZŽƉĞƐŽĐŬĞƚ͕ϭϳͬϭϲ;ϭΗϯͬϴĨŝƐŚŝŶŐŶĞĐŬͿ;ϭΖy ϭΗͿ͕WƌŽďĞŐƵŶŐĂŵŵĂ;ϲ͘ϯΖyϭ͘ϲϵΗͿWŝŶƚŽƉŝŶ;͘ϱϬΖyϭ͘ϲϵΖͿƐŚŽĐŬƐƵď;ϭ͘ϱΖyϭ͘ϲϵΗͿ͕ 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EŽ͘ĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ/K/ƚĞŵ ϳϲ͘ϵϬ͛ϳϲ͘ϵϬ͛ ,ĂŶŐĞƌ/t^^DϭϯϱͬϴΗϲ͘ϯϳϱΗůĞĨƚ,ĂŶĚƐƚƵďůŝĨƚŽŶůǇǁŝƚŚ^^D ƌƵŶŶŝŶŐƚŽŽů͕ϵΕƚƵƌŶƐƚŽƌĞůĞĂƐĞϰϭͬϮΗ/dƐƵƐƉĞŶĚ͕ϯΗƚǇƉĞΗ,Η WsƉƌŽĨŝůĞ ϭϰϯϲ͛ϰϯϲ͛Ϯ͘ϴϭϬϱ͘ϭϲϬdZ^s ϮϮ͕ϭϴϱ͛Ϯ͕ϬϮϬ͛Ϯ͘ϴϲϳϱ͘ϵϲϴ^&KͲϮ'>DηϭͲ>ŝǀĞ Ϯ͕ϵϲϲ͛Ϯ͕ϱϱϴ͛Ϯ͘ϴϲ͟ϱ͘ϵϲϴ^&KͲϮ'>DηϮͲKƌŝĨŝĐĞ ϯϯ͕Ϭϭϵ͛Ϯ͕ϱϵϱ͛ϯ͘ϬϬϬϴ͘ϮϱϬWĂĐŬĞƌʹdƌŝƉŽŝŶƚ,ǇĚƌĂƵůŝĐZĞƚƌŝĞǀĂďůĞ ϰϯ͕Ϭϲϱ͛Ϯ͕ϲϮϲ͛Ϯ͘ϴϭϬϰ͘ϮϱϬyͲEŝƉƉůĞǁͬƉůƵŐ ϱϯ͕ϴϮϰ͛ϯ͕ϭϱϱ͛ϯ͘ϮϱϬϯ͘ϳϬϬt>' ϲϲ͕ϰϬϯ͛ϰ͕ϵϮϯ͛ĂŬĞƌyWWĂĐŬĞƌǁͬyͲKĂŶĚƉƵƉũƚ͘ ϳϲ͕ϱϬϬ͛ϰ͕ϵϵϭ͛ƌŝĚŐĞWůƵŐǁͬϮϴ͛ŽĨĐĞŵĞŶƚĚƵŵƉďĂŝůĞĚŽŶƚŽƉ;dKϲ͕ϰϳϮ͛Ϳ /ƐŽůĂƚĞĚ:ĞǁĞůƌǇĞƚĂŝů ϳ͕ϵϭϮ͛ϲ͕ϬϬϯ͛ƌŝĚŐĞWůƵŐ &ϴ͕ϲϵϱ͛ϲ͕ϳϮϬ͛ƌŝĚŐĞWůƵŐ͕^Ğƚϰͬϵͬϭϰ 'ϴ͕ϴϳϴ͛ϲ͕ϴϵϵ͛/W͕^ĞƚϰͬϭϮͬϭϰ ,ϭϬ͕ϯϲϬ͛ϴ͕ϯϱϭ͛ĂŬĞƌEƌŝĚŐĞWůƵŐ͕ƐĞƚϭϮͬϭϴͬϬϭ /ϭϬ͕ϰϴϬ͛ϴ͕ϰϲϵ͛ĂŬĞƌEƌŝĚŐĞWůƵŐͲ^ƚƵĐŬ͕ƐĞƚΛϭϬ͕ϰϴϬ͛ŽŶϭϮͬϱͬϬϭƚŽďĞĂďůĞƚŽ ƐĞƚWηϳĂƚƉƌŽƉĞƌĚĞƉƚŚ͘ :ϭϬ͕ϰϵϬ͛ϴ͕ϰϳϵ͛ĂŬĞƌEƌŝĚŐĞWůƵŐ͕ƐĞƚϭϭͬϮϴͬϬϭ <ϭϬ͕ϱϵϬ͛ϴ͕ϱϳϴ͛ĂŬĞƌEƌŝĚŐĞWůƵŐ͕ƐĞƚϭϭͬϮϯͬϬϭ hƉĚĂƚĞĚďǇ͗ϬϰͬϬϲͬϮϭ ^,Dd/ ^ƚĞĞůŚĞĂĚWůĂƚĨŽƌŵ tĞůů͗DͲϭϮ ƐŽŵƉůĞƚĞĚ͗ϬϲͬϬϲͬϮϬϮϬ Wd͗ϮϬϭͲϭϳϲ W/͗ϱϬͲϳϯϯͲϮϬϱϬϱͲϬϬͲϬϬ &/^,͗ xϭϬͬϬϭͬϭϰʹ/WƉƵƐŚĞĚĚŽǁŶƚŽϴ͕ϭϰϵ͛ xƌŝĚŐĞƉůƵŐǁĂƐŵŝůůĞĚǁŝƚŚdĨŽƌϮϯ͘ϱŚƌƐΛϳ͕ϴϮϭ͛dDŽŶϭϮͬϭϰͬϬϭ͘:ƵŶŬǁĂƐƉƵƐŚĞĚƚŽ ϭϬ͕ϰϴϬ͛ xϲͬϮϮͬϮϬʹϯƉĞƌĨŐƵŶƐ;ϰϬ͕͛ϯϵ͕͛ϯϳ͘ϱ͛ͿĐŽŵƉůĞƚĞǁŝƚŚ>н'ĂŵŵĂϭ͘ϬϬ͟ĨŝƐŚŝŶŐŚĞĂĚ xϭϬͬϬϳͬϮϬʹϲ͕ϰϬϬ͛Ͳ&ŝƐŚůĞĨƚŝŶŚŽůĞ͗ZŽƉĞƐŽĐŬĞƚϭϳͬϭϲΗϭϯͬϴΗ&EϭΖyϭ͘ϰϰΗ͕dŝƚĂŶ ŐĂŵŵĂϲ͘ϯΖǆϭ͘ϲϵΗ͕WŝŶƚŽWŝŶ͘ϱϬΖyϭ͘ϲϵΗ͕^ŚŽĐŬƐƵďϭ͘ϱΖyϭ͘ϲϵΗ͕tƚďĂƌϱΖyϭ͘ϲϵΗ͕tƚ ďĂƌϱΗyϭ͘ϲϵΖ͕dĞĂƌĚƌŽƉ͕ƚŽƉƐƵď͕ďůĂƐƚƐůĞĞǀĞ͕ƚĂŶĚĞŵƐƵďϮ͘ϮΖyϮ͘ϯϴΗ͕ϮϯͬϴΗƐƉĞŶƚƉĞƌĨ ŐƵŶϮ͘ϱΗǆϭϭΖ͕ƵůůƉůƵŐ͘ϮΖǆϮϯͬϴΗdK>сϯϮ͘ϳΖ xϭϬͬϬϵͬϮϬʹϲ͕ϯϱϬ͛^>Dʹ&ŝƐŚůĞĨƚŝŶŚŽůĞ͗ZŽƉĞƐŽĐŬĞƚ͕ϭϳͬϭϲ;ϭΗϯͬϴĨŝƐŚŝŶŐŶĞĐŬͿ;ϭΖy ϭΗͿ͕WƌŽďĞŐƵŶŐĂŵŵĂ;ϲ͘ϯΖyϭ͘ϲϵΗͿWŝŶƚŽƉŝŶ;͘ϱϬΖyϭ͘ϲϵΖͿƐŚŽĐŬƐƵď;ϭ͘ϱΖyϭ͘ϲϵΗͿ͕ ǁĞŝŐŚƚďĂƌ;ϱΖyϮΗͿ͕dƵďĞũĂƌƐ;ϱΖǆϮΗͿ͕dĞĂƌƌŽƉdŽƉ^Ƶď͕ůĂƐƚ^ůĞĂǀĞdĂŶĚĞŵ^Ƶď;Ϯ͘ϮΖy Ϯ͘ϯϴΗͿϮϯͬϴΗƉĞƌĨŐƵŶ;&ŝƌĞĚͿƵůůƉůƵŐ;Ϯ͘ϯϳϱΗyϭϭΖͿdK>сϯϯ͘ϳΖ EŽƚĞ͗ xdŚĞϮϴ͟ƌŝǀĞƉŝƉĞŝƐĐƌŽƐƐĞĚŽǀĞƌƚŽϯϰ͟KƉŝƉĞďĞůŽǁΕϵϱ͘ϱ͛Z< xdŚĞƌŝůůĞĚdǁĂƐƌĞĐŽƌĚĞĚĂƚϭϬ͕ϳϭϱ͛͘dŚĞƌĞĐŽƌĚĞĚƚƵďŝŶŐƚĂŐĂƚdǁĂƐƌĞĐŽƌĚĞĚĂƐ ϭϬ͕ϳϯϱ͛͘dŚĞƚƵďŝŶŐĚĞƉƚŚƐĂƌĞƌĞƉŽƌƚĞĚĂƐƉĞƌŵĞĂƐƵƌĞŵĞŶƚƐŽĨƚŚĞƚƵďŝŶŐƐƚƌĂƉ͘ /ƐŽůĂƚĞĚͲWĞƌĨŽƌĂƚŝŽŶĞƚĂŝů KEdŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ^ŚŽƚĂƚĞ ͲϭϬϳ͕ϬϵϳΖϳ͕ϭϭϯΖϱ͕ϰϬϴΖϱ͕ϰϭϵΖϲ/ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ ͲϭϬϳ͕ϭϱϬΖϳ͕ϭϳϳΖϱ͕ϰϰϰΖϱ͕ϰϲϯΖϲ/ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ ͲϭϮϳ͕ϰϬϮΖϳ͕ϰϮϰΖϱ͕ϲϮϭΖϱ͕ϲϯϳΖϲ/ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲϳ͕ϴϴϳΖϳ͕ϵϬϬΖϱ͕ϵϴϯΖϱ͕ϵϵϯΖϲ/ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲϳ͕ϵϭϰ͛ϳϵϯϵ͛ϲ͕ϬϬϱΖϲ͕ϬϮϲΖϲ/ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲϳ͕ϵϭϴ͛ϳϵϯϯ͛ϲ͕ϬϬϴΖϲ͕ϬϮϭΖϲ/ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲϳ͕ϵϯϯ͛ϳϵϰϯ͛ϲ͕ϬϮϭΖϲ͕ϬϮϵΖϲ/ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲϳ͕ϵϯϵ͛ϳϵϱϯ͛ϲ͕ϬϮϲΖϲ͕ϬϯϳΖϲ/ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲϳ͕ϵϰϯ͛ϳϵϱϮ͘ϱ͛ϲ͕ϬϮϵΖϲ͕ϬϯϳΖϱ/ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲϳ͕ϵϱϮ͘ϱ͛ϳϵϲϮ͛ϲ͕ϬϯϳΖϲ͕ϬϰϱΖϱ/ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲϳ͕ϵϱϯ͛ϳϵϱϴ͛ϲ͕ϬϯϳΖϲ͕ϬϰϮΖϲ/ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϴ͕ϮϮϴ͛ϴ͕Ϯϱϴ͛ϳ͕ϰϱϯ͛ϳ͕ϰϳϱ͛/ƐŽůĂƚĞĚ Ͳϭϴ͕Ϯϵϯ͛ϴ͕ϯϮϮ͛ϳ͕ϱϬϬ͛ϳ͕ϱϮϭ͛/ƐŽůĂƚĞĚ ͲϮϴ͕ϰϯϴ͛ϴ͕ϰϲϬ͛ϲ͕ϰϲϵ͛ϲ͕ϰϵϬ͛/ƐŽůĂƚĞĚ Ͳϰϴ͕ϱϲϯ͛ϴ͕ϱϴϬ͛ϲ͕ϱϵϬ͛ϲ͕ϲϬϳ͛/ƐŽůĂƚĞĚ ϱϴ͕ϳϭϬΖϴ͕ϳϯϴΖϲ͕ϳϯϰΖϲ͕ϳϲϮΖ/ƐŽůĂƚĞĚ Ͳϳϴ͕ϵϰϯΖϴ͕ϵϲϬΖϲ͕ϵϲϮΖϲ͕ϵϳϵΖϰ/ƐŽůĂƚĞĚ 'KͲϭϭϬ͕ϰϬϲ͛ϭϬϰϭϬ͛ϴ͕ϯϵϳΖϴ͕ϰϬϬΖϲ/ƐŽůĂƚĞĚ 'KͲϯϭϬ͕ϱϯϬ͛ϭϬϱϱϬ͛ϴ͕ϱϭϵΖϴ͕ϱϯϴΖϲ/ƐŽůĂƚĞĚ 'KͲϱϭϬ͕ϲϭϲ͛ϭϬϲϮϭ͛ϴ͕ϲϬϰΖϴ͕ϲϬϴΖϲ/ƐŽůĂƚĞĚ hƉĚĂƚĞĚďǇDϭϮͲϬϵͲϮϭ WZKWK^ ^ƚĞĞůŚĞĂĚWůĂƚĨŽƌŵ tĞůů͗DͲϭϮ ƐŽŵƉůĞƚĞĚ͗ϬϲͬϬϲͬϮϬϮϬ Wd͗ϮϬϭͲϭϳϲ W/͗ϱϬͲϳϯϯͲϮϬϱϬϱͲϬϬͲϬϬ WĞƌĨŽƌĂƚŝŽŶĞƚĂŝů KEdŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿƚŵ;dsͿ&d^ŚŽƚĂƚĞ Ͳϯϯ͕ϮϱϬΖϯ͕ϮϲϳΖϮ͕ϳϱϰΖϮ͕ϳϲϱΖϭϳΖϱ^W&ϬϯͬϭϮͬϮϭ Ͳϯϯ͕ϯϬϱΖϯ͕ϯϭϬΖϮ͕ϳϵϭΖϮ͕ϳϵϱΖϱΖϱ^W&ϬϯͬϭϮͬϮϭ Ͳϯϯ͕ϯϮϬΖϯ͕ϯϯϱΖϮ͕ϴϬϮΖϮ͕ϴϭϮΖϭϱΖϱ^W&ϬϯͬϭϮͬϮϭ ͲϰhƉƉĞƌϯ͕ϯϲϲΖϯ͕ϯϳϮΖϮ͕ϴϯϰΖϮ͕ϴϯϴΖϲΖϱ^W&ϬϯͬϭϭͬϮϭ Ͳϰϯ͕ϯϵϭΖϯ͕ϰϭϬΖϮ͕ϴϱϭΖϮ͕ϴϲϰΖϭϵΖϱ^W&ϬϯͬϭϭͬϮϭ Ͳϰϯ͕ϰϭϲΖϯ͕ϰϮϲΖϮ͕ϴϲϴΖϮ͕ϴϳϱΖϭϬΖϱ^W&ϬϯͬϭϭͬϮϭ Ͳϰϯ͕ϰϯϵΖϯ͕ϰϱϴΖϮ͕ϴϴϰΖϮ͕ϴϵϴΖϭϵΖϱ^W&ϬϯͬϭϭͬϮϭ Ͳϱϯ͕ϰϲϴΖϯ͕ϰϳϱΖϮ͕ϵϬϱΖϮ͕ϵϭϬΖϳΖϭϬͬϴͬϮϬϮϬ Ͳϱϯ͕ϰϴϵΖϯ͕ϱϬϬΖϮ͕ϵϭϵΖϮ͕ϵϮϳΖϭϭΖϭϬͬϴͬϮϬϮϬ Ͳϱϯ͕ϱϬϱΖϯ͕ϱϭϯΖϮ͕ϵϯϭΖϮ͕ϵϯϲΖϴΖϭϬͬϲͬϮϬϮϬ Ͳϱϯ͕ϱϮϬΖϯ͕ϱϱϵΖϮ͕ϵϰϭΖϮ͕ϵϲϵΖϯϵΖϭϬͬϲͬϮϬϮϬ Ͳϭϯ͕ϴϲϰ͛ϯ͕ϵϰϰ͛ϯ͕ϭϴϯ͛ϯ͕Ϯϯϵ͛ϴϬ͛ϳͬϭϯͬϮϬϮϬ Ͳϯϯ͕ϵϵϮ͛ϰ͕ϭϭϬ͛ ϯ͕ϮϳϮ͛ ϯ͕ϯϱϯ͛ ϭϭϴ͛ ϲͬϮϭͲϲͬϮϮΘ ϳͬϭϯͬϮϬ Ͳϱϰ͕ϯϲϰ͛ϰ͕ϰϭϯ͛ϯ͕ϱϮϲ͛ϯ͕ϱϱϵ͛ϰϵ͛ϲͬϮϭͬϮϬϮϬ Ͳϱϰ͕ϰϯϱ͛ϰ͕ϰϰϵ͛ϯ͕ϱϳϯ͛ϯ͕ϱϴϯ͛ϭϰ͛ϲͬϮϭͬϮϬϮϬ ͲϲhƉƉĞƌцϰ͕ϰϵϬ͛цϰ͕ϱϯϱ͛цϯ͕ϲϭϬ͛цϯ͕ϲϰϬ͛ϰϱΖWƌŽƉŽƐĞĚ Ͳϲ>ŽǁĞƌцϰ͕ϱϲϴ͛цϰ͕ϱϴϴ͛цϯ͕ϲϲϮ͛цϯ͕ϲϳϱ͛ϮϬΖWƌŽƉŽƐĞĚ Ͳϭϰ͕ϴϭϴΖϰ͕ϴϯϯΖϯ͕ϴϯϬΖϯ͕ϴϰϬΖϭϱΖϭϬͬϱͬϮϬϮϬ Ͳϭϰ͕ϴϰϮ͛ϰ͕ϴϳϬ͛ϯ͕ϴϰϲ͛ϯ͕ϴϲϰ͛Ϯϴ͛ϲͬϮϭͬϮϬϮϬ Ͳϭϰ͕ϴϴϲ͛ϰ͕ϵϬϬ͛ϯ͕ϴϳϱ͛ϯ͕ϴϴϰ͛ϭϰ͛ϲͬϮϬͬϮϬϮϬ Ͳϯϱ͕ϬϲϬ͛ϱ͕Ϭϴϳ͛ϯ͕ϵϵϯ͛ϰ͕ϬϭϮ͛Ϯϳ͛ϲͬϮϬͬϮϬϮϬ ĂƐŝŶŐĞƚĂŝů ^ŝǌĞdǇƉĞtƚ'ƌĂĚĞŽŶŶdŽƉƚŵ Ϯϴ͟^ƚƌƵĐƚƵƌĂůϭϯϯyͲϱϲƌŝǀĞ^ƵƌĨΕϰϴϬ͛ ϭϴͲϱͬϴ͟^ƵƌĨĂĐĞϵϲ͘ϴyͲϱϲYͲϲϬ^ƵƌĨϴϲϯ͛ ϭϯͲϯͬϴ͟^ƵƌĨĂĐĞϲϴ<ͲϱϱƵƚƚ^ƵƌĨϭ͕ϱϭϱ͛ ϵͲϱͬϴ͟^ƵƌĨĂĐĞϰϳ>ͲϴϬƵƚƚ^ƵƌĨϲ͕ϱϱϲ͛ 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Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,732 feet See schematic feet true vertical 8,717 feet See schematic feet Effective Depth measured 6,472 feet 3,019 & 6,403 feet true vertical 4,971 feet 2,595 & 4,923 feet Perforation depth Measured depth 3,250 - 5,087 feet True Vertical depth 2,905 - 4,012 feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3 / L-80 3,824 MD 3,155 TVD Hyd Pkr 3,019 (MD) 2,595 (TVD Packers and SSSV (type, measured and true vertical depth)ZXP Pkr 6,403 (MD) 4,923 (TVD) TRSV 436 (MD) 436 (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: Senior Engineer: Senior Res. Engineer: Daniel E. Marlowe Operations Manager Burst 1,950psi3,450psi 907 777-8376 6,870psi 859 1,491 5,026 8,715 Katherine O'Connor Katherine.oconnor@hilcorp.com 863 1,515 Conductor Surface 4,760psi 18-5/8" 13-3/8" 6,556 Size 81 Production Casing Structural Liner 4,347 Length ~480 Intermediate N/A Junk 5. Permit to Drill Number: 1,089 McArthur River Field / Middle Kenai Gas PoolN/A measured 0 Gas-Mcf 77 N/A Oil-Bbl 1,062 Water-Bbl Tubing Pressure 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-089 60 Authorized Signature with date: Authorized Name: 0 WINJ WAG STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-176 50-733-20505-00-00 Plugs ADL0018730 Trading Bay Unit M-12 Hilcorp Alaska, LLC 2. Operator Name 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 600 Casing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 9-5/8" 3-1/2" 28" 6,556 MD ~480 863 1,515 10,731 TVD ~479 measured true vertical Packer Other: measured Collapse Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:41 am, Apr 07, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.04.07 06:11:27 -08'00' Dan Marlowe (1267) SFD 4/7/2021 RBDMS HEW 4/7/2021 DSR-4/7/21BJM 5/5/21 Updated by: JLL 04-06-21 SCHEMATIC Steelhead Platform Well: M-12 As Completed: 06/06/2020 PTD: 201-176 API: 50-733-20505-00 Perforation Detail ZONE Top (MD) Btm (MD) Top (TVD)Btm (TVD) FT Shot Date A-3 3,250' 3,267' 2,754' 2,765' 17' 5 SPF 03/12/21 A-3 3,305' 3,310' 2,791' 2,795' 5' 5 SPF 03/12/21 A-3 3,320' 3,335' 2,802' 2,812' 15' 5 SPF 03/12/21 A-4 Upper 3,366' 3,372' 2,834' 2,838' 6' 5 SPF 03/11/21 A-4 3,391' 3,410' 2,851' 2,864' 19' 5 SPF 03/11/21 A-4 3,416' 3,426' 2,868' 2,875' 10' 5 SPF 03/11/21 A-4 3,439' 3,458' 2,884' 2,898' 19' 5 SPF 03/11/21 A-5 3,468' 3,475' 2,905' 2,910' 7' 10/8/2020 A-5 3,489' 3,500' 2,919' 2,927' 11' 10/8/2020 A-5 3,505' 3,513' 2,931' 2,936' 8' 10/6/2020 A-5 3,520' 3,559' 2,941' 2,969' 39' 10/6/2020 B-1 3,864’ 3,944’ 3,183’ 3,239’ 80’ 7/13/2020 B-3 3,992’ 4,110’ 3,272’ 3,353’ 118’ 6/21 -6/22 & 7/13/20 B-5 4,364’ 4,413’ 3,526’ 3,559’ 49’ 6/21/2020 B-5 4,435’ 4,449’ 3,573’ 3,583’ 14’ 6/21/2020 C-1 4,818' 4,833' 3,830' 3,840' 15' 10/5/2020 C-1 4,842’ 4,870’ 3,846’ 3,864’ 28’ 6/21/2020 C-1 4,886’ 4,900’ 3,875’ 3,884’ 14’ 6/20/2020 C-3 5,060’ 5,087’ 3,993’ 4,012’ 27’ 6/20/2020 TD = 10,735’ MD / 8,721’ TVD PBTD = 6,472’ MD / 4,971’ TVD MAX HOLE ANGLE = 54.6O @ 2400’ 1 G 18-5/8” F 3 D-16 GO-1 GO-3 GO-5 RKB: 80.15’, RKB to MSL: 160.2’, RKB to Mudline: 345’ 9-5/8” 13-3/8” 3-1/2” Top of cement 10,695’ H I J K Top of cement 10,360’ E-7 E-5 2 Top of cement 8,670’ Top of cement 8,853’ E-4 E-2 E-1 D-12 D-10 ETop of cement 7,902’ 4 6 7 A-5 B-1 B-3 B-5 C-1 C-3 5 A-3 A-4 Upper A-4 X Milled Bridge Plug @ 10,480’ Top of fill 9,011’ (SLM RKB) Casing Detail Size Type Wt Grade Conn Top Btm 28” Structural 133 X-56 Drive Surf ~480’ 18-5/8” Surface 96.8 X-56 DQ E-60 Surf 863’ 13-3/8” Surface 68 K-55 Butt Surf 1,515’ 9-5/8” Surface 47 L-80 Butt Surf 6,556’ 3-1/2” Liner 9.2 L-80 IBT 6,384’ 10,731’ Tubing Detail 3-1/2” Production 9.3 L-80 IBT Surf 3,824’ Jewelry Detail No.Depth (MD) Depth (TVD)ID OD Item 76.90’ 76.90’ Hanger CIW SSMC 13 5/8" 6.375" left Hand stub lift only with SSMC running tool, 9 ~turns to release 4 1/2" IBT suspend, 3" type "H" BPV profile 1 436’ 436’ 2.810 5.160 TRSV 2 2,185’ 2,020’ 2.867 5.968 SFO-2 GLM #1 - Live 2,966’ 2,558’ 2.86” 5.968 SFO-2 GLM #2 - Orifice 3 3,019’ 2,595’ 3.000 8.250 Packer – Tripoint Hydraulic Retrievable 4 3,065’ 2,626’ 2.810 4.250 X-Nipple w/plug 5 3,824’ 3,155’ 3.250 3.700 WLEG 6 6,403’ 4,923’ Baker ZXP Packer w/ X-O and pup jt. 7 6,500’ 4,991’ Bridge Plug w/ 28’ of cement dump bailed on top (TOC 6,472’) Isolated Jewelry Detail E 7,912’ 6,003’ Bridge Plug F 8,695’ 6,720’ Bridge Plug, Set 4/9/14 G 8,878’ 6,899’ CIBP, Set 4/12/14 H 10,360’ 8,351’ Baker N Bridge Plug, set 12/18/01 I 10,480’ 8,469’ Baker N Bridge Plug - Stuck, set @ 10,480’on 12/5/01 to be able to set BP#7 at proper depth. J 10,490’ 8,479’ Baker N Bridge Plug, set 11/28/01 K 10,590’ 8,578’ Baker N Bridge Plug, set 11/23/01 ()()() A-3 3,250' 3,267' 2,754' 2,765' 17' 5 SPF 03/12/21 A-3 3,305' 3,310' 2,791' 2,795' 5' 5 SPF 03/12/21 A-3 3,320' 3,335' 2,802' 2,812' 15' 5 SPF 03/12/21 A-4 Upper 3,366' 3,372' 2,834' 2,838' 6' 5 SPF 03/11/21 A-4 3,391' 3,410' 2,851' 2,864' 19' 5 SPF 03/11/21 A-4 3,416' 3,426' 2,868' 2,875' 10' 5 SPF 03/11/21 A-4 3,439' 3,458' 2,884' 2,898' 19' 5 SPF 03/11/21 (MD)(MD)(TVD) Updated by: 04/06/21 SCHEMATIC Steelhead Platform Well: M-12 As Completed: 06/06/2020 PTD: 201-176 API: 50-733-20505-00 FISH: x 10/01/14 – CIBP pushed down to 8,149’ x Bridge plug was milled with CT for 23.5hrs @ 7,821’ CTM on 12/14/01. Junk was pushed to 10,480’ x 6/22/20 – 3 perf guns (40’,39’,37.5’) complete with CCL + Gamma 1.00” fishing head x 10/07/20 – 6,400’ - Fish left in hole: Rope socket 1 7/16" 1 3/8" FN 1' X 1.44", Titan gamma 6.3' x 1.69", Pin to Pin .50' X 1.69", Shock sub 1.5' X 1.69", Wt bar 5' X 1.69", Wt bar 5" X 1.69', Tear drop, top sub, blast sleeve, tandem sub 2.2' X 2.38", 2 3/8" spent perf gun 2.5" x 11', Bull plug .2' x 2 3/8" TOL= 32.7' x 10/09/20 – 6,350’ SLM – Fish left in hole: Rope socket, 1 7/16 ( 1" 3/8 fishing neck)(1' X 1"), Probe gun gamma (6.3' X 1.69") Pin to pin ( .50' X 1.69') shock sub (1.5' X 1.69"), weight bar (5' X 2"), Tube jars (5' x 2"), Tear Drop Top Sub, Blast Sleave Tandem Sub(2.2' X 2.38") 2 3/8" perf gun (Fired) Bull plug (2.375" X 11') TOL=33.7' Note: x The 28” Drive pipe is crossed over to 34” OD pipe below ~95.5’ RKB x The Drilled TD was recorded at 10,715’. The recorded tubing tag at TD was recorded as 10,735’. The tubing depths are reported as per measurements of the tubing strap. Isolated - Perforation Detail ZONE Top (MD) Btm (MD) Top (TVD) Btm (TVD)Shot Date D-10 7,097' 7,113' 5,408' 5,419' 6 Isolated 06/19/20 D-10 7,150' 7,177' 5,444' 5,463' 6 Isolated 06/19/20 D-12 7,402' 7,424' 5,621' 5,637' 6 Isolated 06/19/20 D-16 7,887' 7,900' 5,983' 5,993' 6 Isolated 06/19/20 D-16 7,914’ 7939’ 6,005' 6,026' 6 Isolated 06/19/20 D-16 7,918’ 7933’ 6,008' 6,021' 6 Isolated 06/19/20 D-16 7,933’ 7943’ 6,021' 6,029' 6 Isolated 06/19/20 D-16 7,939’ 7953’ 6,026' 6,037' 6 Isolated 06/19/20 D-16 7,943’ 7952.5’ 6,029' 6,037' 5 Isolated 06/19/20 D-16 7,952.5’ 7962’ 6,037' 6,045' 5 Isolated 06/19/20 D-16 7,953’ 7958’ 6,037' 6,042' 6 Isolated 06/19/20 E-1 8,228’ 8,258’ 7,453’ 7,475’ Isolated E-1 8,293’ 8,322’ 7,500’ 7,521’ Isolated E-2 8,438’ 8,460’ 6,469’ 6,490’ Isolated E-4 8,563’ 8,580’ 6,590’ 6,607’ Isolated E5 8,710' 8,738' 6,734' 6,762' Isolated E-7 8,943' 8,960' 6,962' 6,979' 4 Isolated GO-1 10,406’ 10410’ 8,397' 8,400' 6 Isolated GO-3 10,530’ 10550’ 8,519' 8,538' 6 Isolated GO-5 10,616’ 10621’ 8,604' 8,608' 6 Isolated Rig Start Date End Date Eline 3/11/21 3/12/21 Arrive at Heliport, Check in, Get Covid Screening. All Cleared to fly. Take off for Steelhead. Arrive on platform. Check in, PTW, PJSM. MIRU AK E-line. Make up GR/CCL, Test wire, good test. Make up Gun #1, 19', 2 3/8", 5spf, 60* phase 11gram Low swell gun. PT WLV/Lub low/high 250/1500 good test. Open well, WHP 65, flowing at 1MM. RIH, @ 3600' Pull log up to 3200'. Send log to town for correlation. Correct pass with a +1.5' correction. Send back to town. Approval to shoot A4 3439'-3458' (Geologist). RIH to 3500', PU getting on CCL depth @ 3430', CCL t/top shot 9', CCL t/bottom shot 28', Shoot A4 3439'-3458', ITP 65 psi, no change in pressure. Log up 200', POOH, Tagged up, swab shut, bleed down, pop off well. All shots fired, Dry gun. Make up Gun #2 10', 2 3/8", 11 gram, 60* phase 5spf, low swell gun. Stab on well, Open up, RIH, @ 3600' pull log up to 3250', send log to town for correlation. Approval to shoot A4 3416'-3426' (Geologist). RIH to 3500', PU getting on CCL depth @ 3406.8', CCL t/top shot 9.2', CCL t/bottom shot 19.2'. Shoot A4 3416'-3426'. ITP 65, FTP same. No change in psi or rate. Log up 200', POOH, Tagged up, swab shut, bleed down, pop off well, All shots fired, Dry gun. Make up Gun #3, 19' 2 3/8", 5 spf, 60* phase 11 gram Razor gun, Stab on well, Open up, RIH, @ 3500' pull log up to 3150', send log to town for correlation. On Depth per (Geologist) RIH to 3500', pu getting on CCL depth @ 3381.1', CCL t/top shot 9.9', CCL t/bottom shot 28.9'. Shoot A4 3391'-3410', Log up 200' ITP 65psi, FTP 65 psi, POOH,Tagged up, swab shut, bleed down, pop off well, All shots fired, Dry gun. Make up Gun # 4, 6', 2 3/8", 5 spf, 60* phase 11 gram low swell Razor gun. Stab on well, Open up. RIH, @ 3500' log up to 3150', Send log to town for correlation. On depth to shoot A4 upper 3366'-3372' per Geologist. RIH to 3500', pu getting on CCL depth @ 3352.8', CCL t/top shot 13.2', CCL t/bottom shot 19.2', Shoot A4 upper zone 3366'-3372'. Didnt get any indicaition gun fired, POOH check tools. Tagged up, swab shut, bleed down, pop off well. Tested tools, had a short in the wt bar. Replace wt bar, test communicatin with tools. Good test. Make up Gun # 4 Re Run, 6', 2 3/8", 5 spf, 60* phase 11 gram low swell Razor gun. Stab on well, Open up. RIH, @ 3500' pu getting on CCL depth @ 3350.8', CCL t/top shot 15.2', CCL t/bottom shot 21.2', Shoot A4 upper zone 3366'-3372'. Log up 200' ITP 69psi, FTP 69psi. POOH,Tagged up, swab shut, bleed down, pop off well, All shots fired, Dry gun. Stack down for the night. Job in progress. 03/12/21 - Friday Morning meeting, PTW and PJSM. Make up GR/CCL, test communication. Good test. Make up Gun #5, 15', 2 3/8", 5 spf, 60* phase, 11 gram razor gun. Stab on well, Open up. RIH, @ 3500', pull log up to 3150', Send log to town for correlation. Approval to shoot A3 3320'- 3335' (Geologist). RIH to 3400', pu getting on CCL depth @ 3307', CCL t/top shot 13', CCL t/bottom shot 28'. Shoot A3 3320'-3335'. ITP 60 psi, FTP 60, log up 200', POOH, Tagged up, swab shut, bleed down, pop off well. All shots fired. Dry gun. Make up Gun #6, 5', 2 3/8", 5spf, 60* phase, 11 gram razor gun. Stab on well, Open up, RIH, @ 3450' log up to 3100', Send log to town for correlation. Thumbs up to shoot A3 3305'-3310' (Geologist). RIH to 3420', PU getting on CCL depth @ 3289', CCL t/top shot 16', CCL t/bottom shot 21', Shoot A3 3305'- 3310', ITP 60 psi, FTP 60, no change, log up 200', POOH, Tagged up, swab shut, bleed down, pop off well. All shots fired, Dry gun. Make up Gun # 7, 17', 2 3/8", 5 spf, 60* phase, 11 gram low swell razor gun. Stab on well, Open up. RIH, @ 3350' pull log up to 3150', correlation looks good and were on depth. Shoot A3 3250'-3267', ITP 60 psi, FTP 60 psi, Flow rate 1.4mm, no change. Log up 200', POOH,Tagged up, swab shut, bleed down, pop off well. All shots fired, Dry gun. RDMO AK E-line. Fly crew back to beach. Job complete. 03/11/21 - Thursday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Trading Bay Unit M-12 50-733-20505-00-00 201-176 Shoot A4 3416'-3426' Shoot A4 3391'-3410', Shoot A3 3305'- 3310', Shoot A3 3320'-3335' Shoot A3 3250'-3267', Shoot A4 3439'-3458', Shoot A4 upper zone 3366'-3372'. Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 04/05/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL TBU M-12 (201-176) PERF 03/12/2021 Please include current contact information if different from above. 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0LOOHG%ULGJH 3OXJ#¶ 7RSRIILOO ¶ 6/05.% ĂƐŝŶŐĞƚĂŝů ^ŝǌĞ dǇƉĞ tƚ 'ƌĂĚĞ ŽŶŶ dŽƉ ƚŵ Ϯϴ͟ ^ƚƌƵĐƚƵƌĂů ϭϯϯ yͲϱϲ ƌŝǀĞ ^ƵƌĨ ΕϰϴϬ͛ ϭϴͲϱͬϴ͟ ^ƵƌĨĂĐĞ ϵϲ͘ϴ yͲϱϲ YͲϲϬ ^ƵƌĨ ϴϲϯ͛ ϭϯͲϯͬϴ͟ ^ƵƌĨĂĐĞ ϲϴ <Ͳϱϱ Ƶƚƚ ^ƵƌĨ ϭ͕ϱϭϱ͛ ϵͲϱͬϴ͟ ^ƵƌĨĂĐĞ ϰϳ >ͲϴϬ Ƶƚƚ ^ƵƌĨ ϲ͕ϱϱϲ͛ ϯͲϭͬϮ͟ >ŝŶĞƌ ϵ͘Ϯ >ͲϴϬ /d ϲ͕ϯϴϰ͛ ϭϬ͕ϳϯϭ͛ dƵďŝŶŐĞƚĂŝů ϯͲϭͬϮ͟ WƌŽĚƵĐƚŝŽŶ ϵ͘ϯ >ͲϴϬ /d ^ƵƌĨ ϯ͕ϴϮϰ͛ :ĞǁĞůƌǇĞƚĂŝů EŽ͘ĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ / K /ƚĞŵ ϳϲ͘ϵϬ͛ ϳϲ͘ϵϬ͛ ,ĂŶŐĞƌ/t^^DϭϯϱͬϴΗϲ͘ϯϳϱΗůĞĨƚ,ĂŶĚƐƚƵďůŝĨƚŽŶůǇǁŝƚŚ^^D ƌƵŶŶŝŶŐƚŽŽů͕ϵΕƚƵƌŶƐƚŽƌĞůĞĂƐĞϰϭͬϮΗ/dƐƵƐƉĞŶĚ͕ϯΗƚǇƉĞΗ,Η WsƉƌŽĨŝůĞ ϭ ϰϯϲ͛ ϰϯϲ͛ Ϯ͘ϴϭϬ ϱ͘ϭϲϬ dZ^s Ϯ Ϯ͕ϭϴϱ͛ Ϯ͕ϬϮϬ͛ Ϯ͘ϴϲϳ ϱ͘ϵϲϴ ^&KͲϮ'>DηϭͲ>ŝǀĞ Ϯ͕ϵϲϲ͛ Ϯ͕ϱϱϴ͛ Ϯ͘ϴϲ͟ ϱ͘ϵϲϴ ^&KͲϮ'>DηϮͲKƌŝĨŝĐĞ ϯ ϯ͕Ϭϭϵ͛ Ϯ͕ϱϵϱ͛ ϯ͘ϬϬϬ ϴ͘ϮϱϬ WĂĐŬĞƌʹdƌŝƉŽŝŶƚ,ǇĚƌĂƵůŝĐZĞƚƌŝĞǀĂďůĞ ϰ ϯ͕Ϭϲϱ͛ Ϯ͕ϲϮϲ͛ Ϯ͘ϴϭϬ ϰ͘ϮϱϬ yͲEŝƉƉůĞǁͬƉůƵŐ ϱ ϯ͕ϴϮϰ͛ ϯ͕ϭϱϱ͛ ϯ͘ϮϱϬ ϯ͘ϳϬϬ t>' ϲ ϲ͕ϰϬϯ͛ ϰ͕ϵϮϯ͛ ĂŬĞƌyWWĂĐŬĞƌǁͬyͲKĂŶĚƉƵƉũƚ͘ ϳ ϲ͕ϱϬϬ͛ ϰ͕ϵϵϭ͛ ƌŝĚŐĞWůƵŐǁͬϮϴ͛ŽĨĐĞŵĞŶƚĚƵŵƉďĂŝůĞĚŽŶƚŽƉ;dKϲ͕ϰϳϮ͛Ϳ /ƐŽůĂƚĞĚ:ĞǁĞůƌǇĞƚĂŝů ϳ͕ϵϭϮ͛ ϲ͕ϬϬϯ͛ ƌŝĚŐĞWůƵŐ & ϴ͕ϲϵϱ͛ ϲ͕ϳϮϬ͛ ƌŝĚŐĞWůƵŐ͕^Ğƚϰͬϵͬϭϰ ' ϴ͕ϴϳϴ͛ ϲ͕ϴϵϵ͛ /W͕^ĞƚϰͬϭϮͬϭϰ , ϭϬ͕ϯϲϬ͛ ϴ͕ϯϱϭ͛ ĂŬĞƌEƌŝĚŐĞWůƵŐ͕ƐĞƚϭϮͬϭϴͬϬϭ / ϭϬ͕ϰϴϬ͛ ϴ͕ϰϲϵ͛ ĂŬĞƌEƌŝĚŐĞWůƵŐͲ^ƚƵĐŬ͕ƐĞƚΛϭϬ͕ϰϴϬ͛ŽŶϭϮͬϱͬϬϭƚŽďĞĂďůĞƚŽ ƐĞƚWηϳĂƚƉƌŽƉĞƌĚĞƉƚŚ͘ : ϭϬ͕ϰϵϬ͛ ϴ͕ϰϳϵ͛ ĂŬĞƌEƌŝĚŐĞWůƵŐ͕ƐĞƚϭϭͬϮϴͬϬϭ < ϭϬ͕ϱϵϬ͛ ϴ͕ϱϳϴ͛ ĂŬĞƌEƌŝĚŐĞWůƵŐ͕ƐĞƚϭϭͬϮϯͬϬϭ hƉĚĂƚĞĚďǇ͗:>>ϭϬͬϮϯͬϮϬ ^,Dd/ ^ƚĞĞůŚĞĂĚWůĂƚĨŽƌŵ tĞůů͗DͲϭϮ ƐŽŵƉůĞƚĞĚ͗ϬϲͬϬϲͬϮϬϮϬ Wd͗ϮϬϭͲϭϳϲ W/͗ϱϬͲϳϯϯͲϮϬϱϬϱͲϬϬ &/^,͗ x ϭϬͬϬϭͬϭϰʹ/WƉƵƐŚĞĚĚŽǁŶƚŽϴ͕ϭϰϵ͛ x ƌŝĚŐĞƉůƵŐǁĂƐŵŝůůĞĚǁŝƚŚdĨŽƌϮϯ͘ϱŚƌƐΛϳ͕ϴϮϭ͛dDŽŶϭϮͬϭϰͬϬϭ͘:ƵŶŬǁĂƐƉƵƐŚĞĚƚŽ ϭϬ͕ϰϴϬ͛ x ϲͬϮϮͬϮϬʹϯƉĞƌĨŐƵŶƐ;ϰϬ͕͛ϯϵ͕͛ϯϳ͘ϱ͛ͿĐŽŵƉůĞƚĞǁŝƚŚ>н'ĂŵŵĂϭ͘ϬϬ͟ĨŝƐŚŝŶŐŚĞĂĚ x ϭϬͬϬϳͬϮϬʹϲ͕ϰϬϬ͛Ͳ&ŝƐŚůĞĨƚŝŶŚŽůĞ͗ZŽƉĞƐŽĐŬĞƚϭϳͬϭϲΗϭϯͬϴΗ&EϭΖyϭ͘ϰϰΗ͕dŝƚĂŶ ŐĂŵŵĂϲ͘ϯΖǆϭ͘ϲϵΗ͕WŝŶƚŽWŝŶ͘ϱϬΖyϭ͘ϲϵΗ͕^ŚŽĐŬƐƵďϭ͘ϱΖyϭ͘ϲϵΗ͕tƚďĂƌϱΖyϭ͘ϲϵΗ͕tƚ ďĂƌϱΗyϭ͘ϲϵΖ͕dĞĂƌĚƌŽƉ͕ƚŽƉƐƵď͕ďůĂƐƚƐůĞĞǀĞ͕ƚĂŶĚĞŵƐƵďϮ͘ϮΖyϮ͘ϯϴΗ͕ϮϯͬϴΗƐƉĞŶƚƉĞƌĨ ŐƵŶϮ͘ϱΗǆϭϭΖ͕ƵůůƉůƵŐ͘ϮΖǆϮϯͬϴΗdK>сϯϮ͘ϳΖ x ϭϬͬϬϵͬϮϬʹϲ͕ϯϱϬ͛^>Dʹ&ŝƐŚůĞĨƚŝŶŚŽůĞ͗ZŽƉĞƐŽĐŬĞƚ͕ϭϳͬϭϲ;ϭΗϯͬϴĨŝƐŚŝŶŐŶĞĐŬͿ;ϭΖy ϭΗͿ͕WƌŽďĞŐƵŶŐĂŵŵĂ;ϲ͘ϯΖyϭ͘ϲϵΗͿWŝŶƚŽƉŝŶ;͘ϱϬΖyϭ͘ϲϵΖͿƐŚŽĐŬƐƵď;ϭ͘ϱΖyϭ͘ϲϵΗͿ͕ ǁĞŝŐŚƚďĂƌ;ϱΖyϮΗͿ͕dƵďĞũĂƌƐ;ϱΖǆϮΗͿ͕dĞĂƌƌŽƉdŽƉ^Ƶď͕ůĂƐƚ^ůĞĂǀĞdĂŶĚĞŵ^Ƶď;Ϯ͘ϮΖy Ϯ͘ϯϴΗͿϮϯͬϴΗƉĞƌĨŐƵŶ;&ŝƌĞĚͿƵůůƉůƵŐ;Ϯ͘ϯϳϱΗyϭϭΖͿdK>сϯϯ͘ϳΖ EŽƚĞ͗ x dŚĞϮϴ͟ƌŝǀĞƉŝƉĞŝƐĐƌŽƐƐĞĚŽǀĞƌƚŽϯϰ͟KƉŝƉĞďĞůŽǁΕϵϱ͘ϱ͛Z< x dŚĞƌŝůůĞĚdǁĂƐƌĞĐŽƌĚĞĚĂƚϭϬ͕ϳϭϱ͛͘dŚĞƌĞĐŽƌĚĞĚƚƵďŝŶŐƚĂŐĂƚdǁĂƐƌĞĐŽƌĚĞĚĂƐ ϭϬ͕ϳϯϱ͛͘dŚĞƚƵďŝŶŐĚĞƉƚŚƐĂƌĞƌĞƉŽƌƚĞĚĂƐƉĞƌŵĞĂƐƵƌĞŵĞŶƚƐŽĨƚŚĞƚƵďŝŶŐƐƚƌĂƉ͘ /ƐŽůĂƚĞĚͲWĞƌĨŽƌĂƚŝŽŶĞƚĂŝů KEdŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ ^ŚŽƚ ĂƚĞ ͲϭϬ ϳ͕ϬϵϳΖ ϳ͕ϭϭϯΖ ϱ͕ϰϬϴΖ ϱ͕ϰϭϵΖ ϲ /ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ ͲϭϬ ϳ͕ϭϱϬΖ ϳ͕ϭϳϳΖ ϱ͕ϰϰϰΖ ϱ͕ϰϲϯΖ ϲ /ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ ͲϭϮ ϳ͕ϰϬϮΖ ϳ͕ϰϮϰΖ ϱ͕ϲϮϭΖ ϱ͕ϲϯϳΖ ϲ /ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲ ϳ͕ϴϴϳΖ ϳ͕ϵϬϬΖ ϱ͕ϵϴϯΖ ϱ͕ϵϵϯΖ ϲ /ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲ ϳ͕ϵϭϰ͛ ϳϵϯϵ͛ ϲ͕ϬϬϱΖ ϲ͕ϬϮϲΖ ϲ /ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲ ϳ͕ϵϭϴ͛ ϳϵϯϯ͛ ϲ͕ϬϬϴΖ ϲ͕ϬϮϭΖ ϲ /ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲ ϳ͕ϵϯϯ͛ ϳϵϰϯ͛ ϲ͕ϬϮϭΖ ϲ͕ϬϮϵΖ ϲ /ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲ ϳ͕ϵϯϵ͛ ϳϵϱϯ͛ ϲ͕ϬϮϲΖ ϲ͕ϬϯϳΖ ϲ /ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲ ϳ͕ϵϰϯ͛ ϳϵϱϮ͘ϱ͛ ϲ͕ϬϮϵΖ ϲ͕ϬϯϳΖ ϱ /ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲ ϳ͕ϵϱϮ͘ϱ͛ ϳϵϲϮ͛ ϲ͕ϬϯϳΖ ϲ͕ϬϰϱΖ ϱ /ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭϲ ϳ͕ϵϱϯ͛ ϳϵϱϴ͛ ϲ͕ϬϯϳΖ ϲ͕ϬϰϮΖ ϲ /ƐŽůĂƚĞĚϬϲͬϭϵͬϮϬ Ͳϭ ϴ͕ϮϮϴ͛ ϴ͕Ϯϱϴ͛ ϳ͕ϰϱϯ͛ ϳ͕ϰϳϱ͛ /ƐŽůĂƚĞĚ Ͳϭ ϴ͕Ϯϵϯ͛ ϴ͕ϯϮϮ͛ ϳ͕ϱϬϬ͛ ϳ͕ϱϮϭ͛ /ƐŽůĂƚĞĚ ͲϮ ϴ͕ϰϯϴ͛ ϴ͕ϰϲϬ͛ ϲ͕ϰϲϵ͛ ϲ͕ϰϵϬ͛ /ƐŽůĂƚĞĚ Ͳϰ ϴ͕ϱϲϯ͛ ϴ͕ϱϴϬ͛ ϲ͕ϱϵϬ͛ ϲ͕ϲϬϳ͛ /ƐŽůĂƚĞĚ ϱ ϴ͕ϳϭϬΖ ϴ͕ϳϯϴΖ ϲ͕ϳϯϰΖ ϲ͕ϳϲϮΖ /ƐŽůĂƚĞĚ Ͳϳ ϴ͕ϵϰϯΖ ϴ͕ϵϲϬΖ ϲ͕ϵϲϮΖ ϲ͕ϵϳϵΖ ϰ /ƐŽůĂƚĞĚ 'KͲϭ ϭϬ͕ϰϬϲ͛ ϭϬϰϭϬ͛ ϴ͕ϯϵϳΖ ϴ͕ϰϬϬΖ ϲ /ƐŽůĂƚĞĚ 'KͲϯ ϭϬ͕ϱϯϬ͛ ϭϬϱϱϬ͛ ϴ͕ϱϭϵΖ ϴ͕ϱϯϴΖ ϲ /ƐŽůĂƚĞĚ 'KͲϱ ϭϬ͕ϲϭϲ͛ ϭϬϲϮϭ͛ ϴ͕ϲϬϰΖ ϴ͕ϲϬϴΖ ϲ /ƐŽůĂƚĞĚ hƉĚĂƚĞĚďǇ͗:>>ϬϮͬϭϵͬϮϭ WZKWK^ ^ƚĞĞůŚĞĂĚWůĂƚĨŽƌŵ tĞůů͗DͲϭϮ ƐŽŵƉůĞƚĞĚ͗ϬϲͬϬϲͬϮϬϮϬ Wd͗ϮϬϭͲϭϳϲ W/͗ϱϬͲϳϯϯͲϮϬϱϬϱͲϬϬ WĞƌĨŽƌĂƚŝŽŶĞƚĂŝů KEdŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ;dsͿ &d ^ŚŽƚ ĂƚĞ Ͳϯ цϯ͕ϮϱϬΖ цϯ͕ϮϲϳΖ цϮ͕ϳϱϰΖ цϮ͕ϳϲϱΖ цϭϳΖ &ƵƚƵƌĞ Ͳϯ цϯ͕ϯϬϱΖ цϯ͕ϯϭϬΖ цϮ͕ϳϵϭΖ цϮ͕ϳϵϱΖ цϱΖ &ƵƚƵƌĞ Ͳϯ цϯ͕ϯϮϬΖ цϯ͕ϯϯϱΖ цϮ͕ϴϬϮΖ цϮ͕ϴϭϮΖ цϭϱΖ &ƵƚƵƌĞ ͲϰhƉƉĞƌ цϯ͕ϯϲϲΖ цϯ͕ϯϳϮΖ цϮ͕ϴϯϰΖ цϮ͕ϴϯϴΖ цϲΖ &ƵƚƵƌĞ Ͳϰ цϯ͕ϯϵϭΖ цϯ͕ϰϭϬΖ цϮ͕ϴϱϭΖ цϮ͕ϴϲϰΖ цϭϵΖ &ƵƚƵƌĞ Ͳϰ цϯ͕ϰϭϲΖ цϯ͕ϰϮϲΖ цϮ͕ϴϲϴΖ цϮ͕ϴϳϱΖ цϭϬΖ &ƵƚƵƌĞ Ͳϰ цϯ͕ϰϯϵΖ цϯ͕ϰϱϴΖ цϮ͕ϴϴϰΖ цϮ͕ϴϵϴΖ цϭϵΖ &ƵƚƵƌĞ Ͳϱ ϯ͕ϰϲϴΖ ϯ͕ϰϳϱΖ Ϯ͕ϵϬϱΖ Ϯ͕ϵϭϬΖ ϳΖ ϭϬͬϴͬϮϬϮϬ Ͳϱ ϯ͕ϰϴϵΖ ϯ͕ϱϬϬΖ Ϯ͕ϵϭϵΖ Ϯ͕ϵϮϳΖ ϭϭΖ ϭϬͬϴͬϮϬϮϬ Ͳϱ ϯ͕ϱϬϱΖ ϯ͕ϱϭϯΖ Ϯ͕ϵϯϭΖ Ϯ͕ϵϯϲΖ ϴΖ ϭϬͬϲͬϮϬϮϬ Ͳϱ ϯ͕ϱϮϬΖ ϯ͕ϱϱϵΖ Ϯ͕ϵϰϭΖ Ϯ͕ϵϲϵΖ ϯϵΖ ϭϬͬϲͬϮϬϮϬ Ͳϭ ϯ͕ϴϲϰ͛ ϯ͕ϵϰϰ͛ ϯ͕ϭϴϯ͛ ϯ͕Ϯϯϵ͛ ϴϬ͛ ϳͬϭϯͬϮϬϮϬ Ͳϯ ϯ͕ϵϵϮ͛ ϰ͕ϭϭϬ͛ ϯ͕ϮϳϮ͛ ϯ͕ϯϱϯ͛ ϭϭϴ͛ ϲͬϮϭͲϲͬϮϮΘ ϳͬϭϯͬϮϬ Ͳϱ ϰ͕ϯϲϰ͛ ϰ͕ϰϭϯ͛ ϯ͕ϱϮϲ͛ ϯ͕ϱϱϵ͛ ϰϵ͛ ϲͬϮϭͬϮϬϮϬ Ͳϱ ϰ͕ϰϯϱ͛ ϰ͕ϰϰϵ͛ ϯ͕ϱϳϯ͛ ϯ͕ϱϴϯ͛ ϭϰ͛ ϲͬϮϭͬϮϬϮϬ Ͳϭ ϰ͕ϴϭϴΖ ϰ͕ϴϯϯΖ ϯ͕ϴϯϬΖ ϯ͕ϴϰϬΖ ϭϱΖ ϭϬͬϱͬϮϬϮϬ Ͳϭ ϰ͕ϴϰϮ͛ ϰ͕ϴϳϬ͛ ϯ͕ϴϰϲ͛ ϯ͕ϴϲϰ͛ Ϯϴ͛ ϲͬϮϭͬϮϬϮϬ Ͳϭ ϰ͕ϴϴϲ͛ ϰ͕ϵϬϬ͛ ϯ͕ϴϳϱ͛ ϯ͕ϴϴϰ͛ ϭϰ͛ ϲͬϮϬͬϮϬϮϬ Ͳϯ ϱ͕ϬϲϬ͛ ϱ͕Ϭϴϳ͛ ϯ͕ϵϵϯ͛ ϰ͕ϬϭϮ͛ Ϯϳ͛ ϲͬϮϬͬϮϬϮϬ 7' ¶0'¶79' 3%7' ¶0'¶79' 0$;+2/($1*/( 2#¶ * ´ ) ' *2 *2 *2 RKB: 80.15’, RKB to MSL: 160.2’, RKB to Mudline: 345’ ´ ´ ´ 7RSRIFHPHQW ¶ + , - . 7RSRIFHPHQW ¶ ( ( 7RSRIFHPHQW ¶ 7RSRIFHPHQW ¶ ( ( ( ' ' (7RSRIFHPHQW ¶ $ % % % & & $ $8SSHU $ ; 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Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,732 feet See schematic feet true vertical 8,717 feet See schematic feet Effective Depth measured 6,472 feet 3,019 & 6,403 feet true vertical 4,971 feet 2,595 & 4,923 feet Perforation depth Measured depth 3,468 - 5,087 feet True Vertical depth 2,905 - 4,012 feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3 / L-80 3,824 MD 3,155 TVD Hyd Pkr 3,019 (MD) 2,595 (TVD Packers and SSSV (type, measured and true vertical depth)ZXP Pkr 6,403 (MD) 4,923 (TVD) TRSV 436 (MD) 436 (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: TVD ~479 measured true vertical Packer Other: measured Collapse 9-5/8" 3-1/2" 28" 6,556 MD ~480 863 1,515 10,731 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 250 Casing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-176 50-733-20505-00-00 Plugs ADL0018730 Trading Bay Unit M-12 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-337 79 Authorized Signature with date: Authorized Name: 0 WINJ WAG 0 Gas-Mcf 46 N/A Oil-Bbl 1,018 Water-Bbl Intermediate N/A Junk 5. Permit to Drill Number: 1,093 McArthur River Field / Middle Kenai Gas PoolN/A measured 6,556 Size 95 Production Casing Structural Liner 4,347 Length ~480 863 1,515 Conductor Surface 4,760psi 18-5/8" 13-3/8" 907 777-8376 6,870psi 859 1,491 5,026 8,715 Katherine O'Connor Katherine.oconnor@hilcorp.com Tubing Pressure 1,950psi3,450psi Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: Daniel E. Marlowe Operations Manager Burst Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:22 pm, Oct 28, 2020 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.10.28 12:54:52 -08'00' Dan Marlowe (1267) RBDMS HEW 10/28/2020 DSR-10/28/2020 Perforate gls 11/16/20 SFD 11/18/2020 Updated by: JLL 10/23/20 SCHEMATIC Steelhead Platform Well: M-12 As Completed: 06/06/2020 PTD: 201-176 API: 50-733-20505-00 Perforation Detail ZONE Top (MD) Btm (MD)Top (TVD) Btm (TVD)FT Shot Date A-5 3,468' 3,475' 2,905' 2,910' 7' 10/08/20 A-5 3,489' 3,500' 2,919' 2,927' 11' 10/08/20 A-5 3,505' 3,513' 2,931' 2,936' 8' 10/06/20 A-5 3,520' 3,559' 2,941' 2,969' 39' 10/06/20 B-1 3,864’ 3,944’ 3,183’ 3,239’ 80’ 7/13/2020 B-3 3,992’ 4,110’ 3,272’ 3,353’ 118’ 6/21 -6/22 & 7/13/20 B-5 4,364’ 4,413’ 3,526’ 3,559’ 49’ 6/21/2020 B-5 4,435’ 4,449’ 3,573’ 3,583’ 14’ 6/21/2020 C-1 4,818' 4,833' 3,830' 3,840' 15' 10/05/20 C-1 4,842’ 4,870’ 3,846’ 3,864’ 28’ 6/21/2020 C-1 4,886’ 4,900’ 3,875’ 3,884’ 14’ 6/20/2020 C-3 5,060’ 5,087’ 3,993’ 4,012’ 27’ 6/20/2020 TD = 10,735’ MD / 8,721’ TVD PBTD = 6,472’ MD / 4,971’ TVD MAX HOLE ANGLE = 54.6O @ 2400’ 1 G 18-5/8” F 3 D-16 GO-1 GO-3 GO-5 RKB: 80.15’, RKB to MSL: 160.2’, RKB to Mudline: 345’ 9-5/8” 13-3/8” 3-1/2” Top of cement 10,695’ H I J K Top of cement 10,360’ E-7 E-5 2 Top of cement 8,670’ Top of cement 8,853’ E-4 E-2 E-1 D-12 D-10 ETop of cement 7,902’ 4 6 7 A-5 B-1 B-3 B-5 C-1 C-3 5 X Milled Bridge Plug @ 10,480’ Top of fill 9,011’ (SLM RKB) Casing Detail Size Type Wt Grade Conn Top Btm 28” Structural 133 X-56 Drive Surf ~480’ 18-5/8” Surface 96.8 X-56 DQ E-60 Surf 863’ 13-3/8” Surface 68 K-55 Butt Surf 1,515’ 9-5/8” Surface 47 L-80 Butt Surf 6,556’ 3-1/2” Liner 9.2 L-80 IBT 6,384’ 10,731’ Tubing Detail 3-1/2” Production 9.3 L-80 IBT Surf 3,824’ Jewelry Detail No.Depth (MD) Depth (TVD)ID OD Item 76.90’ 76.90’ Hanger CIW SSMC 13 5/8" 6.375" left Hand stub lift only with SSMC running tool, 9 ~turns to release 4 1/2" IBT suspend, 3" type "H" BPV profile 1 436’ 436’ 2.810 5.160 TRSV 2 2,185’ 2,020’ 2.867 5.968 SFO-2 GLM #1 - Live 2,966’ 2,558’ 2.86” 5.968 SFO-2 GLM #2 - Orifice 3 3,019’ 2,595’ 3.000 8.250 Packer – Tripoint Hydraulic Retrievable 4 3,065’ 2,626’ 2.810 4.250 X-Nipple w/plug 5 3,824’ 3,155’ 3.250 3.700 WLEG 6 6,403’ 4,923’ Baker ZXP Packer w/ X-O and pup jt. 7 6,500’ 4,991’ Bridge Plug w/ 28’ of cement dump bailed on top (TOC 6,472’) Isolated Jewelry Detail E 7,912’ 6,003’ Bridge Plug F 8,695’ 6,720’ Bridge Plug, Set 4/9/14 G 8,878’ 6,899’ CIBP, Set 4/12/14 H 10,360’ 8,351’ Baker N Bridge Plug, set 12/18/01 I 10,480’ 8,469’ Baker N Bridge Plug - Stuck, set @ 10,480’on 12/5/01 to be able to set BP#7 at proper depth. J 10,490’ 8,479’ Baker N Bridge Plug, set 11/28/01 K 10,590’ 8,578’ Baker N Bridge Plug, set 11/23/01 A-5 3,468' 3,475' 2,905' 2,910' 7' 10/08/20 A-5 3,489' 3,500' 2,919' 2,927' 11' 10/08/20 A-5 3,505' 3,513' 2,931' 2,936' 8' 10/06/20 A-5 3,520' 3,559' 2,941' 2,969' 39' 10/06/20,,,//, A-5 ttail 3824' perf thru tubing C-1 4,818'4,833'3,830'3,840'15'10/05/20 C-1 new perfs Updated by: JLL 10/23/20 SCHEMATIC Steelhead Platform Well: M-12 As Completed: 06/06/2020 PTD: 201-176 API: 50-733-20505-00 FISH: x 10/01/14 – CIBP pushed down to 8,149’ x Bridge plug was milled with CT for 23.5hrs @ 7,821’ CTM on 12/14/01. Junk was pushed to 10,480’ x 6/22/20 – 3 perf guns (40’,39’,37.5’) complete with CCL + Gamma 1.00” fishing head x 10/07/20 – 6,400’ - Fish left in hole: Rope socket 1 7/16" 1 3/8" FN 1' X 1.44", Titan gamma 6.3' x 1.69", Pin to Pin .50' X 1.69", Shock sub 1.5' X 1.69", Wt bar 5' X 1.69", Wt bar 5" X 1.69', Tear drop, top sub, blast sleeve, tandem sub 2.2' X 2.38", 2 3/8" spent perf gun 2.5" x 11', Bull plug .2' x 2 3/8" TOL= 32.7' x 10/09/20 – 6,350’ SLM – Fish left in hole: Rope socket, 1 7/16 ( 1" 3/8 fishing neck)(1' X 1"), Probe gun gamma (6.3' X 1.69") Pin to pin ( .50' X 1.69') shock sub (1.5' X 1.69"), weight bar (5' X 2"), Tube jars (5' x 2"), Tear Drop Top Sub, Blast Sleave Tandem Sub(2.2' X 2.38") 2 3/8" perf gun (Fired) Bull plug (2.375" X 11') TOL=33.7' Note: x The 28” Drive pipe is crossed over to 34” OD pipe below ~95.5’ RKB x The Drilled TD was recorded at 10,715’. The recorded tubing tag at TD was recorded as 10,735’. The tubing depths are reported as per measurements of the tubing strap. Isolated - Perforation Detail ZONE Top (MD) Btm (MD) Top (TVD) Btm (TVD)Shot Date D-10 7,097' 7,113' 5,408' 5,419' 6 Isolated 06/19/20 D-10 7,150' 7,177' 5,444' 5,463' 6 Isolated 06/19/20 D-12 7,402' 7,424' 5,621' 5,637' 6 Isolated 06/19/20 D-16 7,887' 7,900' 5,983' 5,993' 6 Isolated 06/19/20 D-16 7,914’ 7939’ 6,005' 6,026' 6 Isolated 06/19/20 D-16 7,918’ 7933’ 6,008' 6,021' 6 Isolated 06/19/20 D-16 7,933’ 7943’ 6,021' 6,029' 6 Isolated 06/19/20 D-16 7,939’ 7953’ 6,026' 6,037' 6 Isolated 06/19/20 D-16 7,943’ 7952.5’ 6,029' 6,037' 5 Isolated 06/19/20 D-16 7,952.5’ 7962’ 6,037' 6,045' 5 Isolated 06/19/20 D-16 7,953’ 7958’ 6,037' 6,042' 6 Isolated 06/19/20 E-1 8,228’ 8,258’ 7,453’ 7,475’ Isolated E-1 8,293’ 8,322’ 7,500’ 7,521’ Isolated E-2 8,438’ 8,460’ 6,469’ 6,490’ Isolated E-4 8,563’ 8,580’ 6,590’ 6,607’ Isolated E5 8,710' 8,738' 6,734' 6,762' Isolated E-7 8,943' 8,960' 6,962' 6,979' 4 Isolated GO-1 10,406’ 10410’ 8,397' 8,400' 6 Isolated GO-3 10,530’ 10550’ 8,519' 8,538' 6 Isolated GO-5 10,616’ 10621’ 8,604' 8,608' 6 Isolated Rig Start Date End Date Eline 10/5/20 10/9/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Trading Bay Unit M-12 50-733-20505-00-00 201-176 Morning PJSM, get permit signed. Make up upper sheave, pick up 30' lubricator. Make up Gun #3, 19', 2.375", 6 spf, 60* phasing, 10.8 gram razor charge. Open well, RIH @3500' Pull log up to 3200'. Download and send to town Engineers for approval to Shoot Tyonek A5 sands 3520'-3539'. Got approval to Shoot Tyonek A5 sands 3520'-3539' (Geologist). RIH to 3500' PU to CCL Depth 3510'. CCL t/top shot 10', CCL t/Bottom shot 29', Shoot Tyonek A5 sands 3520'-3539'. ITP 85, FTP 84, Log up 200'. POOH, Tagged up, swab shut, bleed down, pop off well. All shots fired. Lay down lubricator and grease head. Cut 100' wire. Re-head wire, make up GR/CCL. Test communication. Good test. Make up Gun #4, 8', 2.375", 6 spf, 60* phasing, 10.8 gram razor charge. Stab on well. Open well, RIH @ 3500' pull log up to 3300', download and send to town engineers for approval to shoot Tyonek A5 3505'-3513'. Got approval to shoot Tyonek A5 sands 3505'-3513' (Geologist). RIH to 3500' PU to CCL depth 3484'. CCL t/top shot 21', CCL t/bottom shot 29'. Perf the Tyonek A5 sands 3505-3513'. ITP 85, FTP 84. log up 200' POOH. Pulled heavy at 3040', work wire up/down at different speeds and pulled different weights. Pinched the well in, shut the well in, pumped gas down well still no movement of wire. Decision made to pull out of rope socket. Pulled 2340lbs over pu wt, Pulled out of rope socket. At surface, well shut in, rig down and prep for slickline. Slickline arrive on Platform. PJSM & Permits. Position SLU, PU sheave, 40' lubricator, make up tools and 2.74" LIB. Secure well and drill deck. SDFN MIRU, put riser on well up to drill deck. Stab wireline valves on riser. Make up Gun #1, 15', 2.375" Low Swell, 5 spf, 60* phasing, razor gun, Stab on well. Pt Lub/WLV 250/1500, Open swab 15, WHP 40, IA 45, OA 130, RIH. @ 5050', pull log up to 4600', download and send to town Engineer for approval to shoot Tyonek C1 sands 4818'-4833'. Got approval to shoot Tyonek C1 Sands 4818'-4833' ( Geologist). Rih t/5000', pu getting on CCL depth 4804'. CCL t/top shot 14', CCL t/bottom shot 29'. Shoot Tyonek C1 4818'-4833'. ITP 40, FTP 38. Log up 200', POOH, Tagged up, swab shut, bleed down, pop off well. All shots fired, break down spent gun. Make up Gun #2, 20', 2.375" Low Swell, 6 spf, 60* phasing, razor gun. Stab on well. RIH t/3700', Log up to 3300', download and send log to town engineer for approval to shoot Tyonek A5 sands 3539'-3559'. Got approval to shoot Tyonek A5 sands 3539'-3559' (Geologist). RBIH to 3700', PU to CCL depth 3529.5', CCL t/top shot 9.5', CCL t/bottom shot 29.5'. Perf Tyonek A5 sands 3539'-3559', ITP 25, FTP 25.2. Log up 200', POOH, Tagged up, swab shut, bleed down, pop off well. All shots fired, Dry gun. Stack down, secure well and drill deck. SDFN 10/06/20 - Tuesday 10/05/20 - Monday Shoot Tyonek C1 4818'-4833' Tyonek A5 sands 3539'-3559' Shoot Tyonek A5 sands 3520'-3539' t Tyonek A5 sands 3505'-3513' Rig Start Date End Date Eline 10/5/20 10/9/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Trading Bay Unit M-12 50-733-20505-00-00 201-176 10/08/20 - Thursday Move bridge over to M-12. Pu riser and land it on M-12. Make up Gun #5, 11', 2 3/8", 5spf, 60* phase, 10.8 gram razor gun. Stab on well, PT low/high 250/2500. Open well, swab 25, T/IA/OA = 85/95/0. RIH to 3700', log up to 3250', send log to town for approval to shoot Tyonek A5 sands 3489'-3500'. Got Approval to shoot Tyonek A5 sands 3489'-3500' (Geologist). RIH to 3500', PU getting on CCL depth 3469', CCL t/top shot 20', CCL t/ bottom shot 31'. Perf Tyonek A5 sands 3489'-3500'. ITP 116, FTP 116. Well SI while perforating. Log up 200' POOH. Tagged up, swab shut, bleed down, pop off well. All shots fired, Dry gun. Make up Gun #6, 7', 2 3/8", 5spf, 60* phase, 10.8 gram razor gun. Stab on well, open up, RIH, @ 3500' Log up to 3250', send log to town for approval to shoot Tyonek A5 3468'-3475'. Got approval to shoot Tyonek A5 sands 3468'-3475' (Geologist) RIH to 3500', PU to CCL depth 3447.7' CCL t/top shot 20.3', CCL t/bottom shot 27.3'. Shoot Tyonek A5 sands 3468'-3475'. ITP 116, ** Miss fire on Gun #6** POOH with live gun. Tagged up, swab shut, bleed down, pop off well. Inspect firing head, found short in Tear drop. Make up new firing head, stab back on well, re-run Gun #6. Open up, RIH, @ 3500' log up pass to 3250', send in for approval. Got approval to shoot Tyonek A5 sands 3468'-3475' (Geologist) RIH to 3500', PU to CCL depth 3447.7' CCL t/top shot 20.3', CCL t/bottom shot 27.3', Shoot Tyonek A5 sands 3468'-3475'. ITP 116. Log up 200', POOH @ 3065' started to pull heavy, rbih to try and work gun. Worked tools up and down for 2 hrs still could not make it through x-nipple. Pull out of rope socket. POOH, at surface, rig down lubricator, secure well and drill deck for the night. Job in progress. 10/07/20 - Wednesday PJSM & Permits. Pick up SL lubricator, stab on well, PT Lub/WLV 250/2500. WHP 110, IA 150. RIH with 2.74" LIB, Tag fish @ 3034' RKB, POOH, OOH with lib, good picture of rope socket. Make up 2" SB Pulling tool. Stab back on well. RIH, Latch fish @ 3040', got overpull and jar hit. Sheared SD pulling tool. OOH put on 2" JD. Stab back on well, Open up, RIH. Did not find fish in the Tubing. Drifted down into 9 5/8" casing. Try to latch fish. No luck. POOH, OOH, JD was not sheared but dogs were rolled. Swap out JD, stab back on well, Open up, RIH. Latch fish at 6400' SLM. Got good over pull and slipped off fish. Could not get latched back on fish. POOH, OOH, JD looked good, break down and check shear pin. Pin was good. Take Knuckle off, put 2" JD back on, Stab on well, Open well RIH. Tag fish at 6400', got latched up but could not stay latched up. POOH, RD SLU. (Fish left in hole.**Rope socket 1 7/16" 1 3/8" FN 1' X 1.44", Titan gamma 6.3' x 1.69", Pin to Pin .50' X 1.69", Shock sub 1.5' X 1.69", Wt bar 5' X 1.69", Wt bar 5" X 1.69', Tear drop, top sub, blast sleeve, tandem sub 2.2' X 2.38", 2 3/8" spent perf gun 2.5" x 11', Bull plug .2' x 2 3/8" TOL= 32.7'**)FISH (Fish left in hole.**Rope socket 1 7/16" 1 3/8" FN 1' X 1.44", Titan gamma 6.3' x 1.69", Pin to Pin .50' X 1.69", Shock sub 1.5' X 1.69", Wt bar 5' X 1.69", Wt bar 5" X 1.69', Tear drop, top sub, blast sleeve, tandem sub 2.2' X 2.38", 2 3/8" spent perf gun 2.5" x 11', Bull plug .2' x 2 3/8" TOL= 32.7'**)#1 Rig Start Date End Date Eline 10/5/20 10/9/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Trading Bay Unit M-12 50-733-20505-00-00 201-176 10/09/20 - Friday SL crew arrived at Steelhead. PJSM & permits. MIRU SLU, make up tools, stab on well. PT lub/WLV 250/1500. RIH with 2.60" LIB to fish. Sit down 50 lbs @ 3031.3' RKB top of fish. Fish is 33.7' long putting tools at 3065' RKB. RBIH to confirm fish still in place, run past 3031.5' fish moved down hole. POOH, Tagged up, swab shut, bleed down, pop off well. LIB has perfect picture of rope socket. Make up slickline tools and 1" JD. Stab on well, open well, RIH. Poke the tubing drift down to 6350' SLM, Latched onto one of 5 fish. Jarred/spange for 1hr no movement. Shear off, POOH, RDMO SLU. **Fish left in hole, Rope socket, 1 7/16 ( 1" 3/8 fishing neck)(1' X 1"), Probe gun gamma (6.3' X 1.69") Pin to pin ( .50' X 1.69') shock sub (1.5' X 1.69"), weight bar (5' X 2"), Tube jars (5' x 2"), Tear Drop Top Sub, Blast Sleave Tandem Sub(2.2' X 2.38") 2 3/8" perf gun (Fired) Bull plug (2.375" X 11') TOL=33.7'. *Fish left in hole, Rope socket, 1 7/16 ( 1" 3/8 fishing neck)(1' X 1"), Probe gun gamma (6.3' X 1.69") Pin to pin ( .50' X 1.69') shock sub (1.5' X 1.69"), weight bar (5' X 2"), Tube jars (5' x 2"), Tear Drop Top Sub, Blast Sleave Tandem Sub(2.2' X 2.38") 2 3/8" perf gun (Fired) Bull plug (2.375" X 11') TOL=33.7'. Fish #2 left in hole...e... ( Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 10/01/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL TBU M-12 (201-176) Cement Bond Log 06/05/2020 Please include current contact information if different from above. Received by the AOGCC 10/01/2020 PTD: 2011760 E-Set: 34020 Abby Bell 10/01/2020 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,732 feet See schematic feet true vertical 8,717 feet 10,480 feet Effective Depth measured 6,472 feet 3,019 & 6,500 feet true vertical 4,971 feet 2,595 & 4,991 feet Perforation depth Measured depth 3,864 - 5,087 feet True Vertical depth 3,183 - 4,012 feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3 / L-80 3,824 MD 3,155 TVD Hyd Pkr 3,019 (MD) 2,595 (TVD Packers and SSSV (type, measured and true vertical depth)ZXP Pkr 6,500 (MD) 4,991 (TVD) TRSV 436 (MD) 436 (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: Daniel E. Marlowe Operations Manager Burst kkozub@hilcorp.com Tubing Pressure 1,950psi3,450psi 907 777-8384 6,870psi 859 1,491 5,026 8,715 Karson Kozub 863 1,515 Conductor Surface 4,760psi 18-5/8" 13-3/8" 6,556 Size 50 Production Casing Structural Liner 4,347 Length 480 Intermediate N/A Junk 5. Permit to Drill Number: 1,124 McArthur River Field / Middle Kenai Gas PoolN/A measured 0 Gas-Mcf 300 N/A Oil-Bbl 0 Water-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-209 30 Authorized Signature with date: Authorized Name: 0 WINJ WAG STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-176 50-733-30505-00-00 Plugs ADL0018730 Trading Bay Unit M-12 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 1600 Casing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 9-5/8" 3-1/2" 28" 6,556 MD 480 863 1,515 10,731 TVD 479 measured true vertical Packer Other: G/L Completion& N2 Operations measured Collapse &&& PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:32 pm, Aug 11, 2020 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.08.11 12:51:57 -08'00' Dan Marlowe (1267) DSR-8/11/2020gls 9/9/20 RBDMS HEW 8/11/2020 SFD 8/12/2020 Updated by: KDK 08/10/20 SCHEMATIC Steelhead Platform Well: M-12 As Completed: 06/06/2020 PTD: 201-176 API: 50-733-20505-00 TD = 10,735’ MD / 8,721’ TVD PBTD = 7,902’ MD / 5,995’ TVD MAX HOLE ANGLE = 54.6O @ 2400’ 1 G 18-5/8” F 3 D-16 GO-1 GO-3 GO-5 RKB: 80.15’, RKB to MSL: 160.2’, RKB to Mudline: 345’ 9-5/8” 13-3/8” 3-1/2” Top of cement 10,695’ H I J K Top of cement 10,360’ E-7 E-5 2 Top of cement 8,670’ Top of cement 8,853’ E-4 E-2 E-1 D-12 D-10 ETop of cement 7,902’ 4 6 7 B-1 B-3 B-5 C-1 C-3 5 X Milled Bridge Plug @ 10,480’ Top of fill 9,011’ (SLM RKB) Casing Detail Size Type Wt Grade Conn Top Btm 28” Structural 133 X-56 Drive Surf ~480’ 18-5/8” Surface 96.8 X-56 DQ E-60 Surf 863’ 13-3/8” Surface 68 K-55 Butt Surf 1,515’ 9-5/8” Surface 47 L-80 Butt Surf 6,556’ 3-1/2” Liner 9.2 L-80 IBT 6,384’ 10,731’ Tubing Detail 3-1/2” Production 9.3 L-80 IBT Surf 3,824’ Jewelry Detail No.Depth (MD) Depth (TVD)ID OD Item 76.90’ 76.90’ Hanger CIW SSMC 13 5/8" 6.375" left Hand stub lift only with SSMC running tool, 9 ~turns to release 4 1/2" IBT suspend, 3" type "H" BPV profile 1 436’ 436’ 2.810 5.160 TRSV 2 2,185’ 2,020’ 2.867 5.968 SFO-2 GLM #1 - Live 2,966’ 2,558’ 2.86” 5.968 SFO-2 GLM #2 - Orifice 3 3,019’ 2,595’ 2.441 2.875 Packer – Tripoint Hydraulic Retrievable 4 3,065’ 2,626’ 2.810 4.250 X-Nipple w/plug 5 3,824’ 3,155’ 3.250 3.700 WLEG 6 6,403’ 4,923’ Baker ZXP Packer w/ X-O and pup jt. 7 6,500’ 4,991’ Bridge Plug w/ 28’ of cement dump bailed on top (TOC 6,472’) Isolated Jewelry Detail E 7,912’ 6,003’ Bridge Plug F 8,695’ 6,720’ Bridge Plug, Set 4/9/14 G 8,878’ 6,899’ CIBP, Set 4/12/14 H 10,360’ 8,351’Baker N Bridge Plug, set 12/18/01 I 10,480’ 8,469’ Baker N Bridge Plug - Stuck, set @ 10,480’on 12/5/01 to be able to set BP#7 at proper depth. J 10,490’ 8,479’Baker N Bridge Plug, set 11/28/01 K 10,590’ 8,578’Baker N Bridge Plug, set 11/23/01 Perforation Detail ZONE Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Shot Date B-1 3,864’ 3,944’ 3,183’ 3,239’ 80’ 07/13/20 B-3 3,992’ 4,110’ 3,272’ 3,353’ 118’ 6/21 -6/22 & 7/13/20 B-5 4,364’ 4,413’ 3,526’ 3,559’ 49’ 06/21/20 B-5 4,435’ 4,449’ 3,573’ 3,583’ 14’ 06/21/20 C-1 4,842’ 4,870’ 3,846’ 3,864’ 28’ 06/21/20 C-1 4,886’ 4,900’ 3,875’ 3,884’ 14’ 06/20/20 C-3 5,060’ 5,087’ 3,993’ 4,012’ 27’ 06/20/20 B-1 B-3 B-5 C-1 C-3 3019ft Fish in well B-1 3,864’ 3,944’ 3,183’ 3,239’ 80’ 07/13/20 B-3 3,992’ 4,110’ 3,272’ 3,353’ 118’ 6/21 -6/22 & 7/13/20 B-5 4,364’ 4,413’ 3,526’ 3,559’ 49’ 06/21/20 B-5 4,435’ 4,449’ 3,573’ 3,583’ 14’ 06/21/20 C-1 4,842’ 4,870’ 3,846’ 3,864’ 28’ 06/21/20 C-1 4,886’ 4,900’ 3,875’ 3,884’ 14’ 06/20/20 C-3 5,060’ 5,087’ 3,993’ 4,012’ 27’ 06/20/20 isolated . Updated by: KDK 08/10/20 SCHEMATIC Steelhead Platform Well: M-12 As Completed: 06/06/2020 PTD: 201-176 API: 50-733-20505-00 FISH: x 10/01/14 – CIBP pushed down to 8,149’ x Bridge plug was milled with CT for 23.5hrs @ 7,821’ CTM on 12/14/01. Junk was pushed to 10,480’ x 6/22/20 – 3 perf guns (40’,39’,37.5’) complete with CCL + Gamma 1.00” fishing head Note: x The 28” Drive pipe is crossed over to 34” OD pipe below ~95.5’ RKB x The Drilled TD was recorded at 10,715’. The recorded tubing tag at TD was recorded as Isolated - Perforation Detail ZONE Top (MD) Btm (MD) Top (TVD) Btm (TVD)Shot Date D-10 7,097' 7,113' 5,408' 5,419' 6 Isolated 06/19/20 D-10 7,150' 7,177' 5,444' 5,463' 6 Isolated 06/19/20 D-12 7,402' 7,424' 5,621' 5,637' 6 Isolated 06/19/20 D-16 7,887' 7,900' 5,983' 5,993' 6 Isolated 06/19/20 D-16 7,914’ 7939’ 6,005' 6,026' 6 Isolated 06/19/20 D-16 7,918’ 7933’ 6,008' 6,021' 6 Isolated 06/19/20 D-16 7,933’ 7943’ 6,021' 6,029' 6 Isolated 06/19/20 D-16 7,939’ 7953’ 6,026' 6,037' 6 Isolated 06/19/20 D-16 7,943’ 7952.5’ 6,029' 6,037' 5 Isolated 06/19/20 D-16 7,952.5’ 7962’ 6,037' 6,045' 5 Isolated 06/19/20 D-16 7,953’ 7958’ 6,037' 6,042' 6 Isolated 06/19/20 E-1 8,228’ 8,258’ 7,453’ 7,475’ Isolated E-1 8,293’ 8,322’ 7,500’ 7,521’ Isolated E-2 8,438’ 8,460’ 6,469’ 6,490’ Isolated E-4 8,563’ 8,580’ 6,590’ 6,607’ Isolated E5 8,710' 8,738' 6,734' 6,762' Isolated E-7 8,943' 8,960' 6,962' 6,979' 4 Isolated GO-1 10,406’ 10410’ 8,397' 8,400' 6 Isolated GO-3 10,530’ 10550’ 8,519' 8,538' 6 Isolated GO-5 10,616’ 10621’ 8,604' 8,608' 6 Isolated 6/22/20 – 3 perf guns (40’,39’,37.5’) complete with CCL + Gamma 1.00” fishing head Rig Start Date End Date HAK 404/WL/EL 5/29/20 7/13/20 Rig lines to pump and pits. Set doghouse. Level carrier. Assist welder with modifying stairs to carrier and over strong backs. Prepare to raise mast. Connect air lines. Electrician repaired crown light. Continue assisting welder with modifying carrier stairs. Run and connect Koomey umbilical control line from unit to remote panel in doghouse. R/U FIW line from upper well bay to rig pits. R/U carrier to Production air supply. Service carrier transmission, coolant and chain case. Raise mast. String drilling line (2 1/2 layers on drum). String up tuggers and man rider lines. Install weight on man rider cable. Lower mast back onto stand. Function lock down screws on Halstrip head. Reroute FIW line to pits from upper well bay to center bay of platform. Run 2 ea. 2" high pressure lines to well head, stage valves and fittings in well head room for tie-in of high pressure line s to M-12. Hook up remote control to Super Choke. Stage Pollard wireline equipment. 05/30/2020 - Saturday 05/31/2020 - S unday Make up 1502 flange to annulus. Remove tree cap. Continue with rig up miscellaneous projects. Rig Pollard slick line. Test lubricator at 1500 psi. Assist with rigging up Quadco equipment. Run #1: 2.76 gauge ring to 6500'. Run #2: 3" GS tool with AD 2 stop and set at 6450'. Run #3: 3" GS w/ Weathe rford pack-off w/top load plug and set @ 6448'. Run #4: 3" GS w/ 3 1/2" G slip stop to 6405' set down would not fall POOH w/ stop pin sheared. Run #5: Re-run of 3" GS w/ 3 1/2"G slip stop w/ steel pin and set @ 6446'. Run #6 : 2" SB w/prong to 6444' POOH w/ prong (pin did not shear). Run #7 : 2" SB w/prong to 6444' POOH w/ prong (metal marks on b ottom of prong, grind bottom of prong to bull nose, redress R/T). Run #8 : 2" SB w/redressed prong set @ 6444'. Ru n # 9: 3" GS w/ catcher sub to 6441' POOH w/ only top sub of GS. Discuss options. Call town for tools. Run#10: 2.5" LIB to 6440' POOH ( impression of core of GS. Wait on wireline tools. Gather, dress and clean up BOP bolts for up coming nipple up. Run #11: 2.80 grapple would not go through SSSV POOH. Run #12: 2.50" magnet to 6440' POOH w/ fish. Run #13: 3.5" Kick Over Tool attempt to latch up on valve - No Go (multiple marks on tool, possibly wire?). Run #14: 3.5" Kick Over Tool w/ split skirt latch onto and jar up. POOH (No Go). R/D slick line send slickline crew to bed. 05/29/2020 - Friday Hold PJSM. Set and assemble base beams. Assist with crane and welder as needed. Deck organization and assisting with crane operations while waiting on boat with rig package. Offload work boat. Set carrier on base beams and begin rigging up carrier components. Spot carrier, drawworks and A-legs. Run power to electrical distribution panel and 2 conexs. Assist crane crew with organizing deck in preparation for next boat load of parts and rig equipment. Continue organizing deck. Work on suction line valving for pits. Set sills in preparation for setting pits. Offload work boat. Set and pin mast to carrier. Pin lifting rams to mast. Prep mast to raise. Prep to set pits and mud pump. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Trading Bay Unit M-12 50-733-20505-00-00 201-176 Make up 1502 flange to annulus. Remove tree cap. C Rig Start Date End Date HAK 404/WL/EL 5/29/20 7/13/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Trading Bay Unit M-12 50-733-20505-00-00 201-176 Prep wellhead, test run xo/pulling tool into hanger, good. Install Fastlock adaptor spool. N/U BOPE. Tq. flanges. Prep & stand mast. Cont. prep & scope derrick up. Install rig floor. Install support legs from rig floor to pipe rack. Install beaver slide and D.S. stairs on rig mat base. P/U Gil power tongs. HPU running backwards, had electrician rewire same for proper rotation. Function test BOPE - GOOD. Bring handling equipment and test tools to rig floor. Dress slips w/ 3 1/2" inserts. M/U HP hose f/ mud pump to stand pipe manifold. Make up 3 1/2" test joint consisting of "Fastlock" pulling tool w/ X/O to 4 1/2 IBT, Blanked and ported sub (4 1/2 IBT X 3 1/2 IBT), X/O (3 1/2 IBT X PH-6), 2 es 3 1/2 PH-6 pup jt.s, 1 jt. 3 1/2 PH-6, PH-6 side entry sub, Ph-6 FOSV and PH-6 IBOP valve. Attempt to run pulling tool in the hole, could not get past the annular (element not fully rel axed). Work Annular and lubricate same with FIW to clean out debris from around element with blind rams closed. Vac debris and fluids from top of blind rams. Sit running tool on annular element with ~1000 lb. down wt and tool fell through element. P/U and inspect running tool - Good. RIH with running tool on test jt. Cont. Housekeeping & maintenance. R/u test pump. Fill tubing & test t/ 1500psi, good. M/u riser spools & adaptor, m/u mud cross. Cont. housekeeping & maintenance while wireline crew rests. Rig slickline back up. Run #15, 16, & 17: RIH w/ 3.5" Kickover tool to attempt to latch up on GLM #3 valve @ 5342' - No Go. Run #18 & 19: RIH w/ 3.5" Kickover tool to attempt to latch up on GLM #2 valve @ 3884' - Successful. Pump 52 bbl FIW into annulus @ 1 bpm w/ 0 psi. Run # 20: RIH and retrieve catcher sub @ 6440'. POOH. Top off pits w/ FIW while RIH. Rig down Pollard wireline. Pump 151 bbl FIW down a nnulus @ 3.9 bpm w/ 0 psi. (Total of 203 bbl. pumped). Top off pits w/ FIW, swap hoses to pump down tubing and out annulus. Pump 20 bbl FIW down tubing @ 3.9 bpm w/ 200 psi and get full returns out annulus. (total pumped down annulus and tubing = 223 bbl ). Shut down pump and monitor tubing and annulus. (STATIC). R/D circulating hoses and valving to wellhead. Set BPV, Nipple down tree. Clean and prep tubing spool and seal area for installation of Fast Lock adapter spool. 48 hour notice for BOP test submitted to AOGCC 5/31/2020 @ 18:13 hr. AOGCC witness waived by Mr. James Regg 6/1/2020 @ 20:30 hr. 06/02/2020 - Tuesday 06/01/2020 - Monday Rig Start Date End Date HAK 404/WL/EL 5/29/20 7/13/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Trading Bay Unit M-12 50-733-20505-00-00 201-176 06/03/2020 - Wednesday M/U landing Jt with running tool to hanger, fill surface eq. w/ test fluid, shell test t/2500 good. Test BOPE as per Hilcorp & AOGCC requirements. AOGCC Witness waived by inspector Jim Regg 6-1 @ 20:30. Tested w/3 1/2" tj, 250/2500psi good. Break down test eq. M/u landing jt, finish r/u floor, install beaver slide, & toe boards. Pull BPV plug & BPV. Install landing jt, unable to get more than 4 turns, pulled joint found scale on leading edge. R/U drain stack, flush & suck out. RIH w/ pulling tool and attempt to make up to hanger. Got 8 1/2 turns (takes 11 turns to release dogs) when lower PH-6 connection came loose due to high torque. POOH and tighten all connections. Inspect pulling tools and cleaned debris out of tool. Retried with same results. Flush and vac out hanger area. Attempt to make up to hanger. At 8 1/2 turns the IBT connection broke. POOH with running tool. Center rig over hole. Install BPV. Center rig over hole, pull center floor plat e, RIH with pulling tool. L/D elevators and R/U to pick up BOPE with blocks. Continue rigging up to pick BOPE. Put accumulator controls in neutral and bleed off pressure. Remove flow line hose. Back out LDS on fast connect wellhead adapter. Station hands in well head room, upper well head room and in cellar. Pick up BOPE with rig and secure same. P/U landing jt. and pulling tool into riser. Clean and inspect hanger and pulling tool. Lower pulling tool onto hanger and make up 7 1/2 turns by hand. Rig up come-a-long and 60" pipe wrench and continue making up running tool 9 turns where 6 5/8 FH connection broke on X/O to tool. Moved wrench to neck of running tool and got another 1/4 turn. 06/04/2020- Thursday Work on rig maint. & projects while waiting on boat & larger handling tools, unload boat. R/U & break running tool from hanger, inspect & clean threads, place markers on running tool & hanger to see ingaugement depth, m/u running tool 8 1/2 turns & back off, appears to be making contact with split ring & have 3/16" from full engagement. M/U running tool to hanger 8 3/4 turns, lower stack & m/u Fastlock connection, fill stack test break 250/2500 good. R/D test eq, prep to pull hanger. Pull hanger free @ 40k, cont. pulling seals free @ 80k, break down landing jt, & l/d, c/o handling equip. Hook up flow line hose Remove control lines from hanger, Break off and lay down hanger and running tool. POOH (SLM) standing back 3.5", 9.2#, L-80, IBT tu bing f/ 6421' to 2461' (stood back 61 std / 3890') L/D SSSV, Chemical Injection Mandrel and 2 GLM's. (Spooled up SSSV (441') and Chemical Injection Mandrel (525') control lines. Removed 56 bands) Hole fill: Calculated =13.7 bbl, Actual =14 bbl. Service rig. Continue POOH f/ 2461' L/D 3.5" tubing , 2 ea. GLM's , Baker "X" Nipple, Seal Locator, Seal Assembly and WLEG. Clear rig floor. P/U and stage 9 5/8" scraper tools on floor. Strap and caliper 9 5/8 scraper assembly. Test BOPE l hanger free @ 40k, cont. pulling seals free @ 80k, M/U landing Jt with running tool to han ger, fill surface eq. w/ test fluid, shell test t/2500 good. Test BOPE as per Hilcorp & AOGCC requirements. AOGCC Witness waived by inspector Jim Regg 6-1 @ 20:30. Tested w Rig Start Date End Date HAK 404/WL/EL 5/29/20 7/13/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Trading Bay Unit M-12 50-733-20505-00-00 201-176 P/U BHA, 8 1/2" Bit, 9 5/8" scraper, bit sub, xo = 9.89' change out dies in tongs. TIH w/ c/o assy on 3 1/2" IBT tubing from derrick t/ 3266'. R/U rev circulate CBU clean @ 4bpm, 120 psi, POOH. Stand back total of 56 stands in derrick, l/d 10 joints & BHA. R/U e-line. RIH w/ GR, CCL, CBL tools. RIH w/ GR, CCL, CBL tools t/6400' WLM, Log up to surface. (Performed Free Pipe Pass 200'-300' on TIH). L/D GR, CCL, CBL tools, R/D e-line. M/U WLEG and RIH with 3 1/2", 9.3#, L- 80, IBT MOD completion string to 1182'. = WLEG, 12 std. 3 1/2" tbg, x-nipple, single. 3 1/2" tbg, TRIPOINT 9 5/8 DLH Packer, single 3 1/2 tbg, GLM #1, 5 std. 3 1/2" tbg. Drift 2 si ngles picked up. Continue RIH w/ 3 1/2" completion string f/ 1182' to 3378' = 7 std. 3 1/2" tbg, GLM #2, 27 std. 3 1/2 tb g. Drift last 5 stands out of derrick. M/U TRSV. Connect and test control line w/ 5000 psi - Good test. Continue RIH w/ 3 1/2" completion string banding control line to every other connection. = 5 std. 3 1/2" tbg, single 3 1/2" tbg, tubing hanger. M/U hanger, thread control line through hanger and begin termination of same. 06/06/2020 - Saturday M/U hanger running tool 9 turns, m/u SSSV line & pressure up t/5k & lock in, r/u RIH w/hanger to 1.5' above tubing spool, break circulation to flush spool. Land hanger, up wt 31k, dn wt 27k, leaving tubing tail @ 3824'. Drop Bar, pressure up t/3800 psi hold 30 min, set packer @ 3019' test tub ing t/2500 psi, bled down t/1200psi in 30 min. R/U test packer/annulus t/1500psi, pressure dropped below 1500, re-test 1500 good. R/U suck out stack. Attempt tubing test while monitoring landing joint, had 200 psi leakoff in 5 min, o bserved no leak on landing joint/running tool or IA. Back out landing joint w/running tool, pull & breakdown, l/d same. Clear rig floor, set BPV. R/D floor, prep & scope down mast, layover same, organize decks & prep for rig move. Ni pple down BOPE. Laid down and secure on deck Annular w/ stripper head, dbl gate w/ mud cross, riser section and 13 5/8 5M flange by Fastlock connection adapter. N/U Tree. Clean tubing hanger neck, well head and adapter spool . Install test plug in BPV. Terminate control. Install SRL seal in adapter spool and work over hanger neck. Cont. N/U Tree. M/U adapter spool and set tree. Test void 500/5000 Good Test. M/U SSV, 90° elbow and manual valve. Test t ree w/ 250/5000 psi Good Test. P/U T-Bar and pull BPV. R/U Pollard Wireline. 06/05/2020 - Friday MIT-T MIT-IA (leak at tubing ball seat?) Run 3.5" COMPLETION pressure up t/3800 psi hold 30 min, set packer @ 3019' test tubi ng t/2500 psi, bled down t/1200psi in 30 min. R/U tes t packer/annulus t/1500psi, pressure dropped below 1500, re-test 1500 good. R/ R/U e-line. RIH w/ GR, CCL, CBL tools. RIH w/ GR, CCL, CBL too ls t/6400' WLM, Log up to surface. Rig Start Date End Date HAK 404/WL/EL 5/29/20 7/13/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Trading Bay Unit M-12 50-733-20505-00-00 201-176 06/19/2020 - Friday Arrive on Steelhead. PJSM. MIRU Eline and SLB N2. Eline stabbed on well, line up to PT Lubricator, low 250, high 3500 psi. Open well, RIH GPT logging tool. Found FL at 2476' RKB, CRIH to 3800', wait for fluid to pass tool, whp 1480 psi, fluid passed 3800', rih to 5100', whp 2850 psi, good indicatio n fluid passed, drift down cleanly to 6550' RKB. POOH to pu CIBP. Swab shut, bleed down whp, blow down stack, pop off we ll. Redress setting tool for CIBP. Test electrical connections, make up setting tool, and 3.5" CIBP ( OD= 2.70') CCL TO TOP CIBP 12.5', TO MID ELEMENT 13', TO BOTTOM OF CIBP 13.5'. Stab on well, T= 1500, IA= 1500. RIH. Op en well, RIH TO 6550' CCL, LOG UP TO 6200' CCL. Make +6.5' correction (correlate to 6/5/20 CBL log). Go back down t o 6550' CCL, log up to 6487' CCL + 13'. Set CIBP ME @ 6500' rkb. Wait 10 min stack 400lbs down on plug. PUH off CIBP clean. Log up 200' & POOH. Tagged up, swab shut, bleed down, pop off well. OOH w/ 3.5" CIBP set in 3-1/2" Liner. Setting tool looked good, break down tools, make up 30' dump bailer, mix up 3.89 gal of cement. Open well, rih with 2" OD dump bailer and 3.89 gal 15.8 ppg cement. Tag wireline entry guide at 6400', could not get down with 30' bail er. POOH. At surface, bullnose on bailer was sheared & cement dumped trying to pass 3-1/2" liner top. Removed 10' of bailer. Stabbed back on well, start in the hole 2" x 20' dump bailer. Eline would not fall. Pop off well, add 5' Wt bar. Stabbed back on well, RIH. Tools not wanting to fall free. Job in Progress. 06/07/2020 - S unday R/U to test tubing through tree. Pressure up to 2800 psi w/ no joy. R/U Pollard wireline and RIH with D&D Hole finder to plug in X-nipple @ 3064', pick up 2 ' and attempt to pressur e test to 2500 psi w/ no joy. Assist wireline as needed. Install skid rams on upper sub base. Position Koomey unit for f luid change out, blow down Koomey control lines into used oil container. Inspect crown fall arrest. Continue wireline work setting plug @ various depths in attempt to get pressure test. Assist wireline as needed. Drain and flush Koomey unit. R/U and skid rig 6'6" south. Welder build skid plates for jacking rig east. RIH w/ wireline plug to ~2950', se t plug and test tubing to 2750 psi - Good test. POOH re-pin tool and RIH to 3033' set plug and test tubing to 2750 psi for 30 min charted - Good test. POOH, RIH to retrieve prong @ 6441'. Made 2 attempts @ retrieving prong with no success. As sist wireline as needed. Welder finished skid plates. Skid rig 12'5" east. Install storm clamps. Clean up ski d beams and area around M-12 cellar area. Wireline retrieved prong @ 6442, g-slip stop @ 6445', plug @ 6446' and AD-2 Stop @ 6447'. RIH w/ wireline plug to ~2950', set plug and test tubing to 2750 p Rig Start Date End Date HAK 404/WL/EL 5/29/20 7/13/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Trading Bay Unit M-12 50-733-20505-00-00 201-176 06/20/2020 - Saturday ELU TIH to 6465' CCL. (CCL-to- Bottom of Dump Bailer = 25'). PUH 4', fire tool to dump cement. PU, working wire, placing 2.6 gal (7' in 3-1/2" Liner) of 15.8 ppg cement in 3-1/2" Liner. POOH. OOH w/ empty bailer. T/IA = 1500/1500. Load 2" x 20' dump bailer w/ 2.6 gal. 15.8 ppg cement. CCL-to-Bottom of Bailer = 25'' Move to well, open swab & RIH. Tool suite falling slowly, will not free fall while RIH. TIH to 6375' CCL (+ 25' = 6400' RKB) resistance depth. Work wire gently attempting to drift into 3-1/2" liner top @ 6400'. Multiple attempts, NO LOVE. POOH. OOH w/ loaded dump bailer. Purge & clean bailer of cement. Blend 15.8 ppg cement while adding 10' of bailer sub for 30' bailer w/ tapered, aluminum bull nose @ bottom of bailer. Move to well, open swab & RIH w/ 2" x 30' dump bailer loaded w/ 3.9 gal cement (= 10.7' in 3-1/2" Liner). CCL-to-Bottom of bailer = 35',RIH w/ 2" x 30' dump bailer to 6447' CCL, log up to 6200' CCL for correlation pass. RBIH to 6441' CCL (+35' = 6476' RKB). Fire to dump bailer. PUH working wire & placing 10.7' of cement in 3-1/2" liner. Log up 200' & POOH. OOH w/ empty bailer. 3-1/2" Liner Plug = 3500' CIBP + 28' of 15.8 cement on top of CIBP. Top of cement +/- 6472' RKB. Initial T/IA 1500/1580. Drawdown to 167/166 for Negative Test of CIBP/Cement . Final T/IA = 167/166 - Negative Test Pass. RIH with GPT tool to find fluid top. Found fluid at 5770'. Log up from 5900'- 3600' for correlation pass. OOH break down GPT Tool. Send correlation pass log for review & approval. Log confirmed & approved. Make up 2.375" X 27' Razor 10.8 grams, 5 spf, 60 degree phasing perf gun#1. (CCL-To- Top shot 10') CCL TBS 37'. Initial T/IA 167/166. RIH to 5200' log up to 5050' ccl depth. CCL TTS= 10'. Top shot at 5060'-5087' RKB. Good indica tion @ surface that Gun#1 fired. POOH, could not make it up into 3.5" at 3824'. Pull out of rope socket leaving spent gun IH. Rehead Eline, makeup 2.375" x 14' razor 10.8 gram, 5 spf, 60* phasing gun, stabbed on well. Open well, INITI AL T/IA, 138/143. RIH. Log up from 5114.7' to 4686' we were on depth, Park at 4877.8'. (CCL to top shot 8.2') TS 4886'- BS 4900'. Got good indication gun fired. POOH. OOH w/ all shots fired & dry gun. Job in Progress Rig Start Date End Date HAK 404/WL/EL 5/29/20 7/13/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Trading Bay Unit M-12 50-733-20505-00-00 201-176 Surface test GR/CCL & FH. MU Perf Gun#3: 2-3/8" X 28' GeoDynami cs carrier, 5 spf, 60* phase, 10.8 gm RDX Razor charges. CCL-to-Top shot = 9'. CCL-to-Bottom Shot = 37'. T/IA = 99/99. RIH w/ Perf Gun#3 to 5107' CCL, log up to 4636' CCL. Correct +0.6'. RBIH to 5051' CCL, log up to 4833' CCL to place shots on depth (4833' + 9' = 4842' Top Shot). Fire Perf Gun#3 to perf Zone Tyonek C1 4842' - 4870' RKB. Log up 200' & P OOH. OOH w/ all shots fired & dry gun. Surface test GR/CCL & FH. MU Perf Gun#4: 2-3/8 X 14' GeoDynamic carrier, 5 spf, 60* phase, 10.8 gm Razor charges. CCL-to-Top Shot = 8.2'. CCL-to-Bottom Shot =22.8'. T/IA = 91/91. RIH w/ Pe rf Gun#4 to 4712' CCL, log up to 4100' CCL for correlation pass. Correct +2'. Send log for review. Correction approved & confirmed. RBIH to 4568' CCL, log up to 4426.8' CCL to place shots on depth (4426.8 + 8.2 = 4435' TS). Fire Perf Gun#4 to perf Zone Tyonek B5 4435' - 4449' RKB. Log up 200' & POOH. OOH w/ all shots fired. Surface test GR/CCL & FH. MU Perf Gun#5: 2-3/8 X 24' GeoDynamic carrier, 5 spf, 60* phase, 10.8 gm Razor charges. CCL-to-Top Shot = 9'. CCL-to-Bott om Shot = 33.2'. T/IA = 87/87 psi. RIH w/ Perf Gun#5 to 4400' CCL, log up to 3700' for Tyonek B1 & B3 correlation pass. Send correlation pass for review & approval. RBIH to 4600' CCL, log up to 4184' CCL for correlation pass. Correct +1'. RBIH to 4447' CCL, log up to 4380' CCL to place shots on depth (4380 + 9 = 4389' TS). Fire Perf Gun#5 to perf Tyonek B5 4389' - 4413' RKB. Log up 200' & POOH. OOH w/ all shots fired & dry gun,Surface test GR/CCL & FH. MU Perf Gun#6: 2-3/8 X 25' GeoDynamic carrier, 5 spf, 60* phase, 10.8 gm Razor charges. CCL-to-Top Shot = 8.2'. CCL-to-Bottom Shot = 33.2'. T/IA = 83/83 psi. RIH w/ Perf Gun#6 to 4600' CCL, log up to 4094' CCL. Correct -0.25'. RBIH to 4454' CCL, log up to 4355.8' CCL to place shots on depth ( 4355.8 + 8.2 = 4364' TS). Fire Perf Gun#6 to perf Zone Tyonek B5. Log up 200' & POOH. OOH w/ Perf Gun#6, BOTTOM 10' OF 25' TANDEM GUN MIS-FIRED & DID NOT SHOOT. Perf Gun #6 perforated Zone Tyonek B3 4364' - 4379' RKB. Surface test GR/CCL & FH. MU Perf Gun#7: 2-3/8 X 10' GeoDynamic carrier, 5 spf, 60* phase, 10.8 gm Razor charges. CCL-to-Top Shot =8.2'. CCL-to- Bottom Shot =18.2'. T/IA = 82/82 psi. RIH w/ Perf Gun#7 to 4573' CCL, log up to 4192' CCL. Correct -1'. RBIH to 4528' CCL, log up to 4370.8' CCL to place shots on depth ( 4370.8 + 8.2 = 4379' TS). Fire Perf Gun#7 to perf Zone Tyonek B3 4379' - 4389' RKB. Log up 200 & POOH. OOH w/ all shots fired. Surface test GR/CCL & FH. MU Perf Gun#8: 2-3/8 X 27' GeoDynamic carrier, 5 s pf, 60* phase, 10.8 gm Razor charges. CCL-to-Top Shot = 9'. CCL-to-Bottom Shot =36' T/IA =82/82. Rih to 4262' lo g up to 3900' CCL. Correct -1. RBIH to 4262' CCL. Log up to 4074' CCL to place shots on depth (4074' + 9'= 4083' TS ) Fire Perf Gun #8 to Perf Tyonek B3 Zone 4083'-4110' RKB. Log up 200' & POOH. OOH w/ all shots fired. Surface test GR/CCL & F H. MU Perf Gun#9: 2-3/8 X 27' GeoDynamic carrier, 5 spf, 60* phase, 10.8 gm Razor charges. RIH to 4200' CCL, log up to 3980' CCL. Correct -.5. RBIH to 4200' CCL. Log up to 4047' CCL to place shots on depth (4047' + 9'= 4056' TS) Fire P erf Gun #9 to perf Tyonek B3 Zone. 4056'-4083' RKB, POOH got hung up at 3787'. Try to work gun up and down with no succe ss. CCL-TTS= 9'. CCL TBS= 36'. T/IA= 82/82. Still hung up at 3787' CCL, Tried to pressure up the well with gas trying to get gun to move. No Love. Pump 4 bbls diesel down the well trying to lube the hole up still no love. Cycle wire f or 15 min every hour. 06/21/2020 - S unday Rig Start Date End Date HAK 404/WL/EL 5/29/20 7/13/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Trading Bay Unit M-12 50-733-20505-00-00 201-176 MIRU ELU. Make up riser to WH. 06/22/2020 - Monday Detained @ 3787' CCL. End of Perf Gun#9 BHA ~ 3824' (CCL-to-Bottom of Gun = 36.8) End of Tubing @ 3823' RKB. Work wire from 400# slacked & up to 1800#. NO LOVE. Pump to tubing 5 gal. LUBE776 in 200 gal. of diesel. Continue to work wire 400# slacked to 1800# up. NO LOVE. Inc. PUW in 100# increments, slacking 400# between. Pull thru RS weak point @ 2400#. POOH. Recovered all wire to RS tattle-tale. Call for SL crew & tools. ELU Rehead. RIH w/ 1-11/16" X 10' WB w/ 2-1/8" X 1' CCL. Drifted out end of tubing, NO PERF GUN, & continued drifting to 4300' w/o resistance. POOH. CCL log indicates perforations 4056' - 4083' - Perf Gun#9 shots fired. Gun #10. P/U 2 3/8" X 20' Razor, 5 spf, 60* phase, 10.8 gram gun. RIH to 4213' CCL, Log up to 3807' ccl. Correction= +0.75'. RBIH to 4150' CCL. Log up to 4032.6' ccl + 3.4'=4036' TS. Fire gun. Perforating Tyonek B3 4036'-4056' RKB. Good Indication @ surface that shots fired. Log up 200', POOH. Over pull 300# @ 3810' CCL, RBIH, Repeat 5 times, N O LOVE. RIH to 5800' to get gun wet. POOH & into tbg getting hung up. Overpull in 100# increments, jars firing @ 1500#, 800# over. Work up to 3805' w/jar hits. Detained, work jars, NO LOVE. Call town. Work wire to weak point release @ 2400 lbs. POOH recovering all wire to RS tattle- tale. RD ELU, RU SLU. RIH w/ 2.49" BB. 3819' KB, set down on top of fish. W/T tapping down. 1 tap, fish falls. Drift to 4300' w/ no resistance. POOH. RD SLU. Secure well. Turn well o ver to Production. Clean and secure drill deck and upper well room from ELU & SLU units and tools. Fly EL & SL cre ws back to land. Job suspended for plan forward. 07/12/2020 - S unday Perforating Tyonek B3 4036'-4056' RKB. Rig Start Date End Date HAK 404/WL/EL 5/29/20 7/13/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Trading Bay Unit M-12 50-733-20505-00-00 201-176 07/13/2020 - Monday Morning meeting with ops. Get permit signed. PJSM. Rig up and test wire connections. Make up Gun #1, 24', 2", 6spf, 60*, 11grm razor gun. Stab on well, PT WLV & Lubricator. 250/2500. Open well, swab 20. WHP 30, IA 45, OA 0. RIH to 4650' log up to 3550' to get our tie in pass. Download and send off to engineers for approval. Got approval to shoot B3-B1 sands. (Geologist). RIH to 4100', PU to 3996.5' CCL depth. CCL-to-top shot 15.5', CCL-to-bottom shot 39.5'. Shoot Tyonek B3 4012'-4036'. No change in WHP. Log up 200'. POO H, Tagged up, swab shut, bleed down, pop off well. All shots fired. Make up Gun #2, 20', 2", 6spf, 60*, 11grm razor gun. Stab on well, open swab 20, WHP 30, IA 45, OA 0. RIH to 4300', log up to CCL depth 3979.4'. CCL-to-top shot 12.6', CCL-to-bottom shot 32.6' Shoot Tyonek B3 3992'- 4012'. No change in WHP. Log up 200'. POOH, Tagged up, swab shu t, bleed down, pop off well. All shots fired. Make up Gun #3, 20', 2", 6spf, 60*, 11grm razor gun. Stab on well, open swab 20 turns, Whp 30, IA 45, OA 0, RIH to 4100'. PU getting on depth. CCL depth 3911.4', CCL-to-top shot 12.6', CCL-to-bottom shot 32.6'. Shoot Tyonek B1 zone 3924'- 3944'. No change In whp. Log up 200'. POOH. Tagged up, swab shu t, bleed down, pop off well. All shots fired. Test wire. Make up Gun #4. 20', 2", 6spf, 60*, 11grm razor gun. Stab on well. Open swab 20, whp 30, IA 45, OA 0. RIH to 4100', log up getting on depth to CCL depth 3891.4'. CCL-to-top shot 12.6, CCL-to-bottom shot 32.6'. Shoot Tyonek B1 3904'-3924'. No change In WHP. Log up 200'. POOH, Tagged up, sw ab shut, bleed down, pop off well. All shots fired. Test wire. Make up Gun #5. 20', 2", 6spf, 60*, 11grm razor gun. Stab on well, open swab 20, WHP 30, IA 45, OA 0. RIH to 4100'. Log up getting on depth. CCL Depth 3871.4'. CCL-to-top shot 12.6', CCL-to-bottom shot 32.6'. Shoot Tyonek B1 3884'-3904'. No change in WHP. Log up 200', POOH. Tagged up, sw ab shut, bleed down, pop off well. All shots fired. Gamma tool stopped working owooh. Break down tools and wait for new Gamma to get flown in. New gamma on deck. Re-head wireline, Test tools and wire. Make up Gun #6, 20', 2", 6spf, 60*, 11grm razor gun. Stab on well, open swab 20 turns, WHP 30, IA 45, OA O. RIH to 4100', log up getti ng on depth. CCL depth 3851.4'. CCL-to-top shot 12.6', CCL-to-bottom shot 32.5'. Shoot Tyonek B1 3864'-3884', No chang e in WHP. Log up 200', POOH. Tagged up, swab shut, bleed down, pop off well. All shots fired. RD ELU, stage equipment and lubricator on east side of drill deck. Secure gun rack and ready it for next boat to the beach. Turn well over to production. Job complete 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 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): McArthur River Field / Middle Kenai Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,732'10,480' Casing Collapse Structural Conductor Surface 1,950 psi Intermediate Production 4,760 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Signature: Operations Manager Katherine O'Connor Other: CO 228A PRESENT WELL CONDITION SUMMARY Length Size COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 201-176 50-733-20505-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC Trading Bay Unit M-12 See schematic8,717'6,472'4,971'228 psi 480'479' 9.3 / L-80 TVD Burst 3,824 6,870 psi MD 3,450 psi 859' 1,491' 863' 1,515' 480'28" 18-5/8" 13-3/8" 863' 4,347' 1,515' 6,556' Perforation Depth MD (ft): 3-1/2" 3,864 - 5,087 6,556' 3,019 (MD) 2,595 (TVD) 6,500 (MD) 4,991 (TVD) & 436 (MD) 436 (TVD) Tubing Grade:Tubing MD (ft): 3,183 - 4,012 Perforation Depth TVD (ft): Tubing Size: 5,026'9-5/8" 10,731' 8,715' Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 8/28/2020 3-1/2" Daniel E. Marlowe Hyd Pkr, ZXP Pkr & TRSV Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Jody Colombie at 11:28 am, Aug 14, 2020 320-337 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.08.14 10:49:42 -08'00' Dan Marlowe (1267) GAS DSR-8/17/2020SFD 8/14/2020 Perforate gls 8/24/20 10-404 dts 8/24/2020 8/24/2020 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2020.08.24 11:09:00 -08'00' RBDMS HEW 8/24/2020 Well Work Prognosis Well Name:Trading Bay Unit M-12 API Number: 50-733-20505-00 Current Status:Gas Well Leg:B-2 (NE corner) Estimated Start Date:8/28/2020 Rig:E-Line Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:201-176 First Call Engineer:Katherine O’Connor Office: 907-777-8376 Cell: 214-684-7400 Second Call Engineer:Karson Kozub Cell: 907-570-1801 Current Bottom Hole Pressure:128 psi @ 3120’ TVD 0.041 psi/ft water gradient to surface Maximum Expected BHP:228 psi @ 3120’ TVD 0.073 psi/ft water gradient to surface Maximum Potential Surface Pressure:228 psi Brief Well Summary: Well M-12 is a gas well completed in the B and C sands. The well had a recent RWO in June to recomplete the well to access new sands. The RWO isolated the sands from the D-10 down, which were poor producers, and access the A through C sands. The objective of this program is to perforate the C1 sand and add perforations into the A2, A3, A4 and A5 sand. E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. Perforate with well flowing per program. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Updated by: KDK 08/10/20 SCHEMATIC Steelhead Platform Well: M-12 As Completed: 06/06/2020 PTD: 201-176 API: 50-733-20505-00 TD = 10,735’ MD / 8,721’ TVD PBTD = 7,902’ MD / 5,995’ TVD MAX HOLE ANGLE = 54.6O @ 2400’ 1 G 18-5/8” F 3 D-16 GO-1 GO-3 GO-5 RKB: 80.15’, RKB to MSL: 160.2’, RKB to Mudline: 345’ 9-5/8” 13-3/8” 3-1/2” Top of cement 10,695’ H I J K Top of cement 10,360’ E-7 E-5 2 Top of cement 8,670’ Top of cement 8,853’ E-4 E-2 E-1 D-12 D-10 ETop of cement 7,902’ 4 6 7 B-1 B-3 B-5 C-1 C-3 5 X Milled Bridge Plug @ 10,480’ Top of fill 9,011’ (SLM RKB) Casing Detail Size Type Wt Grade Conn Top Btm 28” Structural 133 X-56 Drive Surf ~480’ 18-5/8” Surface 96.8 X-56 DQ E-60 Surf 863’ 13-3/8” Surface 68 K-55 Butt Surf 1,515’ 9-5/8” Surface 47 L-80 Butt Surf 6,556’ 3-1/2” Liner 9.2 L-80 IBT 6,384’ 10,731’ Tubing Detail 3-1/2” Production 9.3 L-80 IBT Surf 3,824’ Jewelry Detail No.Depth (MD) Depth (TVD)ID OD Item 76.90’ 76.90’ Hanger CIW SSMC 13 5/8" 6.375" left Hand stub lift only with SSMC running tool, 9 ~turns to release 4 1/2" IBT suspend, 3" type "H" BPV profile 1 436’ 436’ 2.810 5.160 TRSV 2 2,185’ 2,020’ 2.867 5.968 SFO-2 GLM #1 - Live 2,966’ 2,558’ 2.86” 5.968 SFO-2 GLM #2 - Orifice 3 3,019’ 2,595’ 2.441 2.875 Packer – Tripoint Hydraulic Retrievable 4 3,065’ 2,626’ 2.810 4.250 X-Nipple w/plug 5 3,824’ 3,155’ 3.250 3.700 WLEG 6 6,403’ 4,923’ Baker ZXP Packer w/ X-O and pup jt. 7 6,500’ 4,991’ Bridge Plug w/ 28’ of cement dump bailed on top (TOC 6,472’) Isolated Jewelry Detail E 7,912’ 6,003’ Bridge Plug F 8,695’ 6,720’ Bridge Plug, Set 4/9/14 G 8,878’ 6,899’ CIBP, Set 4/12/14 H 10,360’ 8,351’Baker N Bridge Plug, set 12/18/01 I 10,480’ 8,469’ Baker N Bridge Plug - Stuck, set @ 10,480’on 12/5/01 to be able to set BP#7 at proper depth. J 10,490’ 8,479’Baker N Bridge Plug, set 11/28/01 K 10,590’ 8,578’Baker N Bridge Plug, set 11/23/01 Perforation Detail ZONE Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Shot Date B-1 3,864’ 3,944’ 3,183’ 3,239’ 80’ 07/13/20 B-3 3,992’ 4,110’ 3,272’ 3,353’ 118’ 6/21 -6/22 & 7/13/20 B-5 4,364’ 4,413’ 3,526’ 3,559’ 49’ 06/21/20 B-5 4,435’ 4,449’ 3,573’ 3,583’ 14’ 06/21/20 C-1 4,842’ 4,870’ 3,846’ 3,864’ 28’ 06/21/20 C-1 4,886’ 4,900’ 3,875’ 3,884’ 14’ 06/20/20 C-3 5,060’ 5,087’ 3,993’ 4,012’ 27’ 06/20/20 Updated by: KDK 08/10/20 SCHEMATIC Steelhead Platform Well: M-12 As Completed: 06/06/2020 PTD: 201-176 API: 50-733-20505-00 FISH: x 10/01/14 – CIBP pushed down to 8,149’ x Bridge plug was milled with CT for 23.5hrs @ 7,821’ CTM on 12/14/01. Junk was pushed to 10,480’ x 6/22/20 – 3 perf guns (40’,39’,37.5’) complete with CCL + Gamma 1.00” fishing head Note: x The 28” Drive pipe is crossed over to 34” OD pipe below ~95.5’ RKB x The Drilled TD was recorded at 10,715’. The recorded tubing tag at TD was recorded as Isolated - Perforation Detail ZONE Top (MD) Btm (MD) Top (TVD) Btm (TVD)Shot Date D-10 7,097' 7,113' 5,408' 5,419' 6 Isolated 06/19/20 D-10 7,150' 7,177' 5,444' 5,463' 6 Isolated 06/19/20 D-12 7,402' 7,424' 5,621' 5,637' 6 Isolated 06/19/20 D-16 7,887' 7,900' 5,983' 5,993' 6 Isolated 06/19/20 D-16 7,914’ 7939’ 6,005' 6,026' 6 Isolated 06/19/20 D-16 7,918’ 7933’ 6,008' 6,021' 6 Isolated 06/19/20 D-16 7,933’ 7943’ 6,021' 6,029' 6 Isolated 06/19/20 D-16 7,939’ 7953’ 6,026' 6,037' 6 Isolated 06/19/20 D-16 7,943’ 7952.5’ 6,029' 6,037' 5 Isolated 06/19/20 D-16 7,952.5’ 7962’ 6,037' 6,045' 5 Isolated 06/19/20 D-16 7,953’ 7958’ 6,037' 6,042' 6 Isolated 06/19/20 E-1 8,228’ 8,258’ 7,453’ 7,475’ Isolated E-1 8,293’ 8,322’ 7,500’ 7,521’ Isolated E-2 8,438’ 8,460’ 6,469’ 6,490’ Isolated E-4 8,563’ 8,580’ 6,590’ 6,607’ Isolated E5 8,710' 8,738' 6,734' 6,762' Isolated E-7 8,943' 8,960' 6,962' 6,979' 4 Isolated GO-1 10,406’ 10410’ 8,397' 8,400' 6 Isolated GO-3 10,530’ 10550’ 8,519' 8,538' 6 Isolated GO-5 10,616’ 10621’ 8,604' 8,608' 6 Isolated Updated by: JLL 08/12/20 PROPOSED Steelhead Platform Well: M-12 As Completed: 06/06/2020 PTD: 201-176 API: 50-733-20505-00 Perforation Detail ZONE Top (MD) Btm (MD)Top (TVD) Btm (TVD)FT Shot Date A-2 ±3,110' ±3,196' ±2,658' ±2,717' ±86' FUTURE A-3 ±3,320' ±3,335' ±2,802' ±2,812' ±15' FUTURE A-4 ±3,391' ±3,410' ±2,851' ±2,864' ±19' FUTURE A-4 ±3,439' ±3,458' ±2,884' ±2,898' ±19' FUTURE A-5 ±3,468' ±3,475' ±2,905' ±2,910' ±7' FUTURE A-5 ±3,489' ±3,500' ±2,919' ±2,927' ±11' FUTURE A-5 ±3,505' ±3,513' ±2,931' ±2,936' ±8' FUTURE A-5 ±3,520' ±3,559' ±2,941' ±2,969' ±39' FUTURE B-1 3,864’ 3,944’ 3,183’ 3,239’ 80’ 7/13/2020 B-3 3,992’ 4,110’ 3,272’ 3,353’ 118’ 6/21 -6/22 & 7/13/20 B-5 4,364’ 4,413’ 3,526’ 3,559’ 49’ 6/21/2020 B-5 4,435’ 4,449’ 3,573’ 3,583’ 14’ 6/21/2020 C-1 ±4,818' ±4,833' ±3,830' ±3,840' ±15' FUTURE C-1 4,842’ 4,870’ 3,846’ 3,864’ 28’ 6/21/2020 C-1 4,886’ 4,900’ 3,875’ 3,884’ 14’ 6/20/2020 C-3 5,060’ 5,087’ 3,993’ 4,012’ 27’ 6/20/2020 TD = 10,735’ MD / 8,721’ TVD PBTD = 7,902’ MD / 5,995’ TVD MAX HOLE ANGLE = 54.6O @ 2400’ 1 G 18-5/8” F 3 D-16 GO-1 GO-3 GO-5 RKB: 80.15’, RKB to MSL: 160.2’, RKB to Mudline: 345’ 9-5/8” 13-3/8” 3-1/2” A-2 Top of cement 10,695’ H I J K Top of cement 10,360’ E-7 E-5 2 Top of cement 8,670’ Top of cement 8,853’ E-4 E-2 E-1 D-12 D-10 ETop of cement 7,902’ 4 6 7 A-3 A-5 B-1 B-3 B-5 C-1 C-3 5 A-4 X Milled Bridge Plug @ 10,480’ Top of fill 9,011’ (SLM RKB) Casing Detail Size Type Wt Grade Conn Top Btm 28” Structural 133 X-56 Drive Surf ~480’ 18-5/8” Surface 96.8 X-56 DQ E-60 Surf 863’ 13-3/8” Surface 68 K-55 Butt Surf 1,515’ 9-5/8” Surface 47 L-80 Butt Surf 6,556’ 3-1/2” Liner 9.2 L-80 IBT 6,384’ 10,731’ Tubing Detail 3-1/2” Production 9.3 L-80 IBT Surf 3,824’ Jewelry Detail No.Depth (MD) Depth (TVD)ID OD Item 76.90’ 76.90’ Hanger CIW SSMC 13 5/8" 6.375" left Hand stub lift only with SSMC running tool, 9 ~turns to release 4 1/2" IBT suspend, 3" type "H" BPV profile 1 436’ 436’ 2.810 5.160 TRSV 2 2,185’ 2,020’ 2.867 5.968 SFO-2 GLM #1 - Live 2,966’ 2,558’ 2.86” 5.968 SFO-2 GLM #2 - Orifice 3 3,019’ 2,595’ 2.441 2.875 Packer – Tripoint Hydraulic Retrievable 4 3,065’ 2,626’ 2.810 4.250 X-Nipple w/plug 5 3,824’ 3,155’ 3.250 3.700 WLEG 6 6,403’ 4,923’ Baker ZXP Packer w/ X-O and pup jt. 7 6,500’ 4,991’ Bridge Plug w/ 28’ of cement dump bailed on top (TOC 6,472’) Isolated Jewelry Detail E 7,912’ 6,003’ Bridge Plug F 8,695’ 6,720’ Bridge Plug, Set 4/9/14 G 8,878’ 6,899’ CIBP, Set 4/12/14 H 10,360’ 8,351’Baker N Bridge Plug, set 12/18/01 I 10,480’ 8,469’ Baker N Bridge Plug - Stuck, set @ 10,480’on 12/5/01 to be able to set BP#7 at proper depth. J 10,490’ 8,479’Baker N Bridge Plug, set 11/28/01 K 10,590’ 8,578’Baker N Bridge Plug, set 11/23/01 NOTE : tubing tail at 3824 ft. 3824' Updated by: JLL 08/12/20 PROPOSED Steelhead Platform Well: M-12 As Completed: 06/06/2020 PTD: 201-176 API: 50-733-20505-00 FISH: x 10/01/14 – CIBP pushed down to 8,149’ x Bridge plug was milled with CT for 23.5hrs @ 7,821’ CTM on 12/14/01. Junk was pushed to 10,480’ x 6/22/20 – 3 perf guns (40’,39’,37.5’) complete with CCL + Gamma 1.00” fishing head Note: x The 28” Drive pipe is crossed over to 34” OD pipe below ~95.5’ RKB x The Drilled TD was recorded at 10,715’. The recorded tubing tag at TD was recorded as Isolated - Perforation Detail ZONE Top (MD) Btm (MD) Top (TVD) Btm (TVD)Shot Date D-10 7,097' 7,113' 5,408' 5,419' 6 Isolated 06/19/20 D-10 7,150' 7,177' 5,444' 5,463' 6 Isolated 06/19/20 D-12 7,402' 7,424' 5,621' 5,637' 6 Isolated 06/19/20 D-16 7,887' 7,900' 5,983' 5,993' 6 Isolated 06/19/20 D-16 7,914’ 7939’ 6,005' 6,026' 6 Isolated 06/19/20 D-16 7,918’ 7933’ 6,008' 6,021' 6 Isolated 06/19/20 D-16 7,933’ 7943’ 6,021' 6,029' 6 Isolated 06/19/20 D-16 7,939’ 7953’ 6,026' 6,037' 6 Isolated 06/19/20 D-16 7,943’ 7952.5’ 6,029' 6,037' 5 Isolated 06/19/20 D-16 7,952.5’ 7962’ 6,037' 6,045' 5 Isolated 06/19/20 D-16 7,953’ 7958’ 6,037' 6,042' 6 Isolated 06/19/20 E-1 8,228’ 8,258’ 7,453’ 7,475’ Isolated E-1 8,293’ 8,322’ 7,500’ 7,521’ Isolated E-2 8,438’ 8,460’ 6,469’ 6,490’ Isolated E-4 8,563’ 8,580’ 6,590’ 6,607’ Isolated E5 8,710' 8,738' 6,734' 6,762' Isolated E-7 8,943' 8,960' 6,962' 6,979' 4 Isolated GO-1 10,406’ 10410’ 8,397' 8,400' 6 Isolated GO-3 10,530’ 10550’ 8,519' 8,538' 6 Isolated GO-5 10,616’ 10621’ 8,604' 8,608' 6 Isolated Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE 5/29/2020 To: AOGCC Abby Bell 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL M-12 Files uploaded to the FTP site M-12 CDR-Resistivity MD.tif M-12 CDR-Resistivity MD.tif M-12 VISION Density Neutron MD.tif M-12 VISION Density Neutron MD.tif Please include current contact information if different from above. Received by the AOGCC on 05/29/2020 Abby Bell 05/29/2020 PTD: 2011760 Data previously downloaded and stored in T21694 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 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): McArthur River Field / Middle Kenai Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,732'10,480' Casing Collapse Structural Conductor Surface 1,950 psi Intermediate 4,760 psi Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:mmckinley@hilcorp.com Contact Phone: (907) 777-8387 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Signature: Operations Manager Mark McKinley Other: G/L Completion & N2 Operations CO 228A PRESENT WELL CONDITION SUMMARY Length Size 6,870 psi COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 201-176 50-733-20505-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC Trading Bay Unit M-12 See schematic 480' 479' 9.2 / L-80 TVD Burst 6,421 MD 3,450 psi 859' 1,491' 5,026' 863' 1,515' 480' 28" 18-5/8" 13-3/8" 863' 9-5/8"6,556' 1,515' Perforation Depth MD (ft): 6,556' 7,097 - 7,900 See schematic & 439 (MD) 439 (TVD) Tubing Grade:Tubing MD (ft): 5,408 - 5,993 Perforation Depth TVD (ft): Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 6/14/2020 3-1/2" Daniel E. Marlowe See schematic & Baker TRSSSV Tubing Size: 8,717' 7,902' 5,995' 1,784 psi 4,347' 3-1/2" 10,731' 8,715' && Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:01 am, May 26, 2020 320-209 Digitally signed by Daniel Marlowe DN: cn=Daniel Marlowe, ou=Users Date: 2020.05.22 14:56:50 -08'00' Daniel Marlowe 10-404 DSR-5/26/2020 Pull Tubingll Tubing X * 2500 PSI BOPE Test * CBL required in 9 5/8" casing ... results to AOGCC by email prior to perforating. GAS G/L Completion Plug Perforations Perforate N2 Operations gls 5/28/20 X DLB 05/29/2020 Comm ion Required? Yes 5/29/2020 dts 5/29/2020 RBDMS HEW 6/4/2020 Well Work Prognosis Well Name:M-12 API Number:50-733-20505-00 Current Status:SI Gas Producer Leg:Leg A1, SW Corner Estimated Start Date:6/14/2020 Rig:HAK 404 Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:201-176 First Call Engineer:Mark McKinley Office: 907-777-8387 Cell: 907-953-2685 Second Call Engineer:Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Current Bottom Hole Pressure:2,341 psi @ 5,408 ’ TVD 0.433 psi/ft water gradient to surface Maximum Expected BHP:2,341 psi @ 5,408’ TVD 0.433 psi/ft water gradient to surface Maximum Potential Surface Pressure:1,784 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)( 4) Well History: M-12 was producing 2-3 mmcfd from the D16 sands prior to the E7 add perf in 2012 which resulted in an initial rate increase but went into severe decline in 2013 due to water influx. Isolation of the E7 and additional perfs in the E5, E3, E2, and E1L were unsuccessful in producing gas and additional water/sand was found in the wellbore following the E2 perfs. In 2014, a bridge plug was placed to protect existing D16 perfs and perforations were added in the D10/D12 sands. After obtaining no production from the D10/D12 sands, the well was shut in. This proposed work will isolate the sands from D-10 down and recomplete the well up hole to access the A through C sands. Safety Concerns: x Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. x Consider tank placement based on wind direction and current weather forecast (venting methane and Nitrogen during this job) x Ensure all crews are aware of stop job authority (Review Standard Well Procedure – Nitrogen Operations) Wellbore Notes: x Slickline will remove SSSV, #4GLM, and set a retrievable (rupture disk) plug at ±6,440’ Procedure: 1. MIRU HAK 404 2. Test BOP’s to 250psi low/2,500psi high /2,500psi annular. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 3. Workover fluid will be brine. BOP’s will be closed as needed to circulate the well. 4. Pull upper completion, fishing tubing and cleaning out as needed to ±6,403’. a. Contingent if seal bore doesn’t pull free. i. Rig up E-line. ii. RIH with tubing cutter. Cut tubing ±6,400’. RD E-line. 5. RIH with casing scraper to ±3,000’. Circulate clean. POOH. 6. RU E-line CBL Logging tool. RIH with tool. Log ±6,400’ to TOC. POOH – Send log to AOGCC 7. RIH with 3-1/2” gas lift completion (live valves), SSSV, chemical injection mandrel, and packer assembly. See proposed schematic for details and set depths. 8. Set Packer / Pressure test completion: a. Pressure up and set packer b. Test tubing against plug in X nipple to ш2,500psig and chart for 30 minutes. c. Test IA to 1,500 psi and chart for 30 minutes (This will pressure up tubing also). (WLEG at 6421') 95/8"CBL RU E-line CBL Logging tool. RIH with tool. Log ±6,400’ to TOC. POOH – Send log to AOGCC Test BOP’s to 250psi low/2,500psi high /2,500psi a (by email) CMIT Well Work Prognosis d. Pull prong and plug in X-Nipple. 9. Set BPV. NU tree, test same. 10. RD HAK 404 11. Pressure up to burst rupture disk at ±6,440’ and push workover fluid into the D sands a. Nitrogen may be used if higher pressure is needed. b. Coil tubing may be used to blow the well dry if pushing fluid into formation doesn’t work. 12. RU and RIH with slickline to verify fluid level is below ±5,200’ and liner is clean to ±6,500’ 13. RIH and set plug with ±10’ of cement at ±6,490’ 14. E-line perforate per program. 15. Turn over to production. 16. Schedule SVS testing with AOGCC as per regulations Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram 5. BOP Stack 6. Standard Well Procedure – Nitrogen Operations 7. Flow Diagrams 8. RWO Sundry Revision Change Form (recover Rupture plug body at 6440 ft. ) Plug perfs. (approx 3000') (see proposed schematic) Updated by: JLL 09/26/17 SCHEMATIC Steelhead Platform Well: M-12 As Completed: 12-21-01 PTD: 201-176 API: 50-733-20505-00 TD = 10,735’ MD / 8,721’ TVD PBTD = 7,902’ MD / 5,995’ TVD MAX HOLE ANGLE = 54.6O @ 2400’ 1 10 18-5/8” @ 863’ 9 5-6 D-16 GO-1 GO-3 GO-5 KB 80.15’ (KB to Top of Conductor flange) 9-5/8” @ 6,550’ 13-3/8” @1,515’ 3-1/2” @ 10,730’ GLM #4 GLM #1 GLM #2 GLM #3 4 7 Top of cement 10,695’ 11 12 13 14 Top of cement 10,360’ E-7 E-5 2 3 Top of cement 8,670’ Top of cement 8,853’ E-4 E-2 E-1 D-12 D-10 8Top of cement 7,902’ Milled Bridge Plug @ 10,480’ Top of fill 9,011’ (SLM RKB) Casing Detail Size Type Wt Grade Conn Top Btm 28” Structural 133 X-56 Drive 74’ ~480’ 18-5/8” Surface 96.8 X-56 DQ E-60 74’ 863’ 13-3/8” Surface 68 K-55 Butt 74’ 1,515’ 9-5/8” Surface 47 L-80 Butt 74’ 6,556’ 3-1/2” Liner 9.2 L-80 IBT 6,384’ 10,731’ Tubing Detail 3-1/2” Production 9.2 L-80 IBT 74’ 6,421’ Jewelry Detail No.Depth (MD) Depth (TVD)ID OD Item 1 439’ 439’ 2.810 5.375 Baker TRSSSV 2 517’ 517’ 2.867 5.500 SFO-1 chem inj mandrel 3 2,170’ 2,009’ 2.867 5.968 SFO-2 GLM #1 3,900’ 3,207’ 2.867 5.968 SFO-2 GLM #2 5,352’ 4,197’ 2.867 5.968 SFO-2 GLM #3 6,335’ 4,875’ 2.867 5.968 SFO-2 GLM #4 4 6,403’ 4,922’ Baker ZXP Packer w/ X-O and pup jt. 5 6,411’ 4,928’ 2.810 4.250 Baker “X” Profile Nipple 6 6,413’ 4,929’ 3.00 4.00 Baker Seal Assembly w/ 10 ea 90H Nitrile Seals 7 6,421’ 4,935’ Modified ½ MS w/ WLEG 8 7,912’ 6,003’ Bridge Plug 9 8,695’ 6,720’ Bridge Plug, Set 4/9/14 10 8,878’ 6,899’ CIBP, Set 4/12/14 11 10,360’ 8,351’ Baker N Bridge Plug, set 12/18/01 12 10,480’ 8,469’ Baker N Bridge Plug - Stuck, set @ 10,480’on 12/5/01 to be able to set BP#7 at proper depth. 13 10,490’ 8,479’ Baker N Bridge Plug, set 11/28/01 14 10,590’ 8,578’ Baker N Bridge Plug, set 11/23/01 Perforation Detail ZONE Top (MD) Btm (MD)Top (TVD) Btm (TVD) Shot Date D-10 7,097' 7,113' 5,408' 5,419' 6 10/08/2014 D-10 7,150' 7,177' 5,444' 5,463' 6 10/07/2014 D-12 7,402' 7,424' 5,621' 5,637' 6 10/09/2014 D-16 7,887' 7,900' 5,983' 5,993' 6 10/06/2014 CBL on 9 5/8" required tubing cut rupture disk pull GLV Updated by: JLL 09/26/17 SCHEMATIC Steelhead Platform Well: M-12 As Completed: 12-21-01 PTD: 201-176 API: 50-733-20505-00 FISH: x 10/01/14 – CIBP pushed down to 8,149’ x Bridge plug was milled with CT for 23.5hrs @ 7,821’ CTM on 12/14/01. Junk was pushed to 10,480’ Note: x The 28” Drive pipe is crossed over to 34” OD pipe below ~95.5’ RKB x The Drilled TD was recorded at 10,715’. The recorded tubing tag at TD was recorded as 10,735’. The tubing depths are reported as per measurements of the tubing strap. Isolated - Perforation Detail ZONE Top (MD) Btm (MD) Top (TVD) Btm (TVD)Shot Date D-16 7,914’ 7939’ 6,005' 6,026' 6 12/21/2001 D-16 7,918’ 7933’ 6,008' 6,021' 6 07/23/2008 (DIL) D-16 7,933’ 7943’ 6,021' 6,029' 6 07/22/2008 (DIL) D-16 7,939’ 7953’ 6,026' 6,037' 6 04/18/2002 D-16 7,943’ 7952.5’ 6,029' 6,037' 5 07/22/2008 (DIL) D-16 7,952.5’ 7962’ 6,037' 6,045' 5 07/21/2008 (DIL) D-16 7,953’ 7958’ 6,037' 6,042' 6 12/20/2001 E-1 8,228’ 8,258’ 7,453’ 7,475’ 04/13/2014 E-1 8,293’ 8,322’ 7,500’ 7,521’ 04/13/2014 E-2 8,438’ 8,460’ 6,469’ 6,490’ 04/13/2014 E-4 8,563’ 8,580’ 6,590’ 6,607’ 04/13/2014 E5 8,710' 8,738' 6,734' 6,762' 04/11/2014 (Isolated) E-7 8,943' 8,960' 6,962' 6,979' 4 06/01/2012 GO-1 10,406’ 10410’ 8,397' 8,400' 6 11/28/2001 GO-3 10,530’ 10550’ 8,519' 8,538' 6 11/23/2001 GO-5 10,616’ 10621’ 8,604' 8,608' 6 11/19/2001 Updated by: JLL 05/22/20 PROPOSED Steelhead Platform Well: M-12 As Completed: FUTURE PTD: 201-176 API: 50-733-20505-00 TD = 10,735’ MD / 8,721’ TVD PBTD = 7,902’ MD / 5,995’ TVD MAX HOLE ANGLE = 54.6O @ 2400’ 1 G 18-5/8” F B,C,D 3 D-16 GO-1 GO-3 GO-5 KB 80.15’ (KB to Top of Conductor flange) 9-5/8” 13-3/8” 3-1/2” A-2 A Top of cement 10,695’ H I J K Top of cement 10,360’ E-7 E-5 2 Top of cement 8,670’ Top of cement 8,853’ E-4 E-2 E-1 D-12 D-10 ETop of cement 7,902’ 4 6 7 A-3 A-5 B-1 B-3 B-5 B-6 C-1 C-3 5 X Milled Bridge Plug @ 10,480’ Top of fill 9,011’ (SLM RKB) X Casing Detail Size Type Wt Grade Conn Top Btm 28” Structural 133 X-56 Drive Surf ~480’ 18-5/8” Surface 96.8 X-56 DQ E-60 Surf 863’ 13-3/8” Surface 68 K-55 Butt Surf 1,515’ 9-5/8” Surface 47 L-80 Butt Surf 6,556’ 3-1/2” Liner 9.2 L-80 IBT 6,384’ 10,731’ Tubing Detail 3-1/2” Production 9.3 L-80 IBT Surf ±3,700’ Jewelry Detail No.Depth (MD) Depth (TVD)ID OD Item Hanger 1 ±439’ ±439’ 2.313” SSSV 2 ±2,170’ ±2,009’ GLM #1 ±2,870’ ±2,490’ GLM #2 3 ±3,070’ ±2,630’ Packer 4 ±3,100’ ±2,650’ X-Nipple 5 ±3,800’ ±3,138’ WLEG 6 ±6,400’ ±4,920’ 2.441” 3.500” E-line cut 3.5”9.2# L-80 IBT tubing (remains if pull isn’t successful) A 6,403’ 4,922’ Baker ZXP Packer w/ X-O and pup jt. B 6,411’ 4,928’ 2.81” 4.250” Baker “X” Profile Nipple (remains if pull isn’t successful) C 6,413’ 4,929’ 3.000” 4.000” Baker Seal Assembly w/ 10 ea 90H Nitrile Seals (remains if pull isn’t successful) D 6,421’ 4,935’ Modified ½ MS w/ WLEG (remains if pull isn’t successful) 7 ±6,490’ ±4,984’ Bridge Plug w/ >25’ of cement dump bailed on top Isolated Jewelry Detail E 7,912’ 6,003’ Bridge Plug F 8,695’ 6,720’ Bridge Plug, Set 4/9/14 G 8,878’ 6,899’ CIBP, Set 4/12/14 H 10,360’ 8,351’ Baker N Bridge Plug, set 12/18/01 I 10,480’ 8,469’ Baker N Bridge Plug - Stuck, set @ 10,480’on 12/5/01 to be able to set BP#7 at proper depth. J 10,490’ 8,479’ Baker N Bridge Plug, set 11/28/01 K 10,590’ 8,578’ Baker N Bridge Plug, set 11/23/01 Perforation Detail ZONE Top (MD) Btm (MD)Top (TVD) Btm (TVD) Shot Date A-2 ±3,110’ ±3,196’ ±2,657’ ±2,717’ FUTURE A-3 ±3,391’ ±3,410’ ±2,851’ ±2,864’ FUTURE A-5 ±3,520’ ±3,559’ ±2,941’ ±2,968’ FUTURE B-1 ±3,862’ ±3,962’ ±3,181’ ±3,251’ FUTURE B-3 ±3,992’ ±4,110’ ±3,272’ ±3,353’ FUTURE B-5 ±4,364’ 4,413’ ±3,526’ ±3,559’ FUTURE B-5 ±4,435’ ±4,449’ ±3,573’ ±3,583’ FUTURE B-6 ±4,490’ ±4,535’ ±3,610’ ±3,640’ FUTURE C-1 ±4,818’ ±4,900’ ±3,830’ ±3,884’ FUTURE C-3 ±5,057’ ±5,085’ ±3,991’ ±4,010’ FUTURE SSSV Seal assembly may be fished out. Proposed Perforations 1 ±4,818’±4,900’±3,830’±3,884’FUTURE C-3 ±5,057’±5,085’±3,991’±4,010’FUTURE CIBP ISO perfs A-2 ±3,110’±3,196’±2,657’±2,717’FUTURE A-3 ±3,391’±3,410’±2,851’±2,864’FUTURE A-5 ±3,520’±3,559’±2,941’±2,968’FUTURE B-1 ±3,862’±3,962’±3,181’±3,251’FUTURE B-3 ±3,992’±4,110’±3,272’±3,353’FUTURE B-5 ±4,364’4,413’±3,526’±3,559’FUTURE B-5 ±4,435’±4,449’±3,573’±3,583’FUTURE B-6 ±4,490’±4,535’±3,610’±3,640’FUTURE C-1 Updated by: JLL 05/22/20 PROPOSED Steelhead Platform Well: M-12 As Completed: FUTURE PTD: 201-176 API: 50-733-20505-00 FISH: x 10/01/14 – CIBP pushed down to 8,149’ x Bridge plug was milled with CT for 23.5hrs @ 7,821’ CTM on 12/14/01. Junk was pushed to 10,480’ Note: x The 28” Drive pipe is crossed over to 34” OD pipe below ~95.5’ RKB x The Drilled TD was recorded at 10,715’. The recorded tubing tag at TD was recorded as 10,735’. The tubing depths are reported as per measurements of the tubing strap. Isolated - Perforation Detail ZONE Top (MD) Btm (MD) Top (TVD) Btm (TVD)Shot Date D-10 7,097' 7,113' 5,408' 5,419' 6 Isolated D-10 7,150' 7,177' 5,444' 5,463' 6 Isolated D-12 7,402' 7,424' 5,621' 5,637' 6 Isolated D-16 7,887' 7,900' 5,983' 5,993' 6 Isolated D-16 7,914’ 7939’ 6,005' 6,026' 6 Isolated D-16 7,918’ 7933’ 6,008' 6,021' 6 Isolated D-16 7,933’ 7943’ 6,021' 6,029' 6 Isolated D-16 7,939’ 7953’ 6,026' 6,037' 6 Isolated D-16 7,943’ 7952.5’ 6,029' 6,037' 5 Isolated D-16 7,952.5’ 7962’ 6,037' 6,045' 5 Isolated D-16 7,953’ 7958’ 6,037' 6,042' 6 Isolated E-1 8,228’ 8,258’ 7,453’ 7,475’ Isolated E-1 8,293’ 8,322’ 7,500’ 7,521’ Isolated E-2 8,438’ 8,460’ 6,469’ 6,490’ Isolated E-4 8,563’ 8,580’ 6,590’ 6,607’ Isolated E5 8,710' 8,738' 6,734' 6,762' Isolated E-7 8,943' 8,960' 6,962' 6,979' 4 Isolated GO-1 10,406’ 10410’ 8,397' 8,400' 6 Isolated GO-3 10,530’ 10550’ 8,519' 8,538' 6 Isolated GO-5 10,616’ 10621’ 8,604' 8,608' 6 Isolated Steelhead Platform M-12 Current 10/02/2017 Current tree SSV Steelhead Platform M-12 Proposed 05/22/2020 Starting head, Cameron 30'͛300 MSS x 28'͛butt-weld Housing, lower casing head, SSMC, 20 ¾ 3M #18 hub x 18 5/8 Buttress casing bottom, w/ 2- 4 1/16 5M SSO Assy, Compact Spool SSMC, 20 ¾ 3M API hub bottom x 13 5/8 5M Fastlock hub top, w/ 4- 2 1/16 5M SSO, bottom prep for 13 3/8 hanger seal neck, 1- control line block exit w/ dual ports Tubing hanger, Cameron SSMC, 13 5/8 x 4 ½ IBT susp x 6.375 LH stub acme lift threads, w/ 5 ½͛͛SRL seal prep, 2- ¼ control line ports Adapter, Cameron, 13 5/8 5M Flangelock-CF-13 x 4 1/16 5M studded top, prepped for SRL seal Steelhead Platform M-12 28 x 18 5/8 x 13 3/8 x 9 5/8 x 3 1/2 Valve, Master, WKM-M 4 1/16 5M FE, HWO, EE trim Valve, Swab, CIW-FLS 4 1/16 5M FE, HWO, EE trim BHTA, Bowen, 4 1/16 5M FE x 7'͛SA bowen quick union 28'͛ 18 5/8'͛ 13 3/8'͛ 9 5/8'͛ 3 ½͛͛ Valve, wing, SSV, WKM-M, 4 1/16 5M FE, w/ MA-18 operator Valve, Master, WKM-M 4 1/16 5M FE, HWO, EE trim BOP Stack Rig 404 STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. Valve Position(O/C)Standpipe PumpManifold1(PM1) OManifold PumpManifold2(PM2) OPumpManifold3(PM3) CPumpManifold4(PM4) OPumpManifold5(PM5) CMud KillLine1OCross KillLine2OHCRvalve(ChokeLine1) CChokeLine2OChoke ChokeManifold1(CM1) OManifold ChokeManifold2(CM2) CChokeManifold3(CM3) OChokeManifold4(CM4) CChokeManifold5(CM5) OChokeManifold6(CM6) CChokeManifold7(CM7) OChokeManifold8(CM8) CChokeManifold9(CM9) CChokeManifold10(CM10) OSuperChoke CManualChoke CRigFloor SafetyValve O Valve Position(O/C)Standpipe PumpManifold1(PM1) OManifold PumpManifold2(PM2) CPumpManifold3(PM3) OPumpManifold4(PM4) CPumpManifold5(PM5) OMud KillLine1OCross KillLine2OHCRvalve(ChokeLine1) CChokeLine2OChoke ChokeManifold1(CM1) OManifold ChokeManifold2(CM2) CChokeManifold3(CM3) OChokeManifold4(CM4) CChokeManifold5(CM5) OChokeManifold6(CM6) CChokeManifold7(CM7) OChokeManifold8(CM8) CChokeManifold9(CM9) CChokeManifold10(CM10) OSuperChoke CManualChoke CRigFloor SafetyValve O Rig 404 BOP Test Procedure Attachment #1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Rig 404, WO Program – Oil Producers, Gas Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. x Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. 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. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing (test) joint to lift-threads d) For ESP wells - Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and / or a penetrator leaks, 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. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE 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 anywhere at surface.) 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.) Rig 404 BOP Test Procedure Attachment #1 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. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests (i.e. Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same- RIH with test plug on joint of tubing. Install a pump-in sub w/ test line plus an open TIW or lower Kelly valve in top of test joint w/ open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump- install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder (test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 1 st valve on standpipe manifold, close valves 1, 2, 10 on choke manifold and close the annular preventer, open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and xxx psi (see sundry) high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer, close safety valve and open IBOP on test joint, close outside valve on kill side of mud cross, open 1st valve of standpipe, close valves 3, 4 & 9 on choke manifold, open valves 1 & 2 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve / open outside valve on kill side of mud cross, close valves 5 & 6 / open valves 3 & 4 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke / open valves 5 & 6 on choke manifold. Pressure up to ~ 1200 psi and bleed off 200 – 300 #s recording change and stabilization. If passes after 5 minutes, bleed off pressure back to tank. f) Close HCR (outside valve on choke side of mud cross), open manual & super choke. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. Rig 404 BOP Test Procedure Attachment #1 g) Close inside valve / open outside valve (HCR) on choke side of mud cross. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off- open pipe rams and pull test joint leaving test plug / 2-way check in place. Close blind rams and attach test line to valve 10 on choke manifold, close valve 7 & 8 / open valve 10 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves (TIW or Lower Kelly Valve) and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record “Accumulator Pressure”. It should be +/- 3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2 nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read “10 bottles at 2,150 psi”). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/- 3,000 psi). Note: Make sure the electric pump is turned to “Auto”, not “Manual” so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well Trading Bay Unit M-12 (PTD 201-176)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date STATE OF ALASKAt AL, A OIL AND GAS CONSERVATION COMI ;ION REPORT OF SUNDRY WELL OPERATIONS Mi'j' 2 �4?O ii.1. 1.Operations Abandon El Repair Well 0 Plug Perforations Q Perforate❑ Other❑ A OG• , Performed: Alter Casing❑ Pull Tubing❑ Stimulate-Frac 0 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❑ 201-176 # 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service❑ 6.API Number: • Anchorage,AK 99503 50-733-20505-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018730 • Trading Bay Unit/M-12 it 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): .• McArthur River Field/Middle Kenai Gas Pool 11.Present Well Condition Summary: Total Depth measured • 10,732 feet Plugs measured See Schematic feet true vertical 8,717 feet Junk measured 10,480 feet Effective Depth measured 10,360 feet Packer measured 6,403 feet true vertical 8,351 feet true vertical 4,922 feet Casing Length Size MD TVD Burst Collapse Structural 406' 28" 480' 479' Conductor 789' 18-5/8" 863' 859' Surface 1,441' 13-3/8" 1,515' 1,491' 3,450 psi 1,950 psi Intermediate 6,476' 9-5/8" 6,550' 5,026' 6,870 psi 4,760 psi Production Liner 4,380' 3-1/2" 10,730' 8,715' Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet SCORED Iv1AY 2 7 2O V Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 6,422'(MD) (TVD) Packers and SSSV(type,measured and true vertical depth) Baker ZXP Packer 6,403'(MD)4,922'(TVD) Baker TRSSSV 439'(MD)439'(TVD) 12.Stimulation or cement squeeze summary: Intervals treated(measured): RBDMS .MAY 2 0 2014 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 142 0 201 12 Subsequent to operation: 0 0 0 379 70 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development . Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ • Gas J WDSPL❑ GSTOR El WINJ 0 WAG El GINJ 0 SUSP❑ SPLUGD 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: 314-196 Contact Ted Kramer Email tkramerat7hilcorp.com Printed Name Ted Kramer Title Operations Engineer Signature ,1* 4- ��_ Phone (907)777-8420 Date 5/20/2014 Fnrm 10-404 Revised 10/2012 I) . Submit Original Only Steelhead Platform Well: M-12 II SCHEMATIC As Completed: 12-21-01 PTD:201-176 Hilcora Alaska.LLC API:50-733-20505-00 KB 80.15'(KB to Top of Conductor flange) .. Casing Detail 'stir Size Type Wt/Grade/Conn Top Btm r' 1 :'` 28" Structural 133#,X-56,Drive 74' ^'480' . * `°.44 96.8#,X-56,DQ E- 2 a k 18-5/8" Surface 60 74' 863' 18-5/8" }r '. 13-3/8" Surface 68#,K-55,Butt 74' 1,515' @863 �' GLM#1 • 4. 9-5/8" Surface 47#,L-80, Butt 74' 6,550' 13-3/8" 1,515' 3-1/2" Liner 9.2#,L-80, Butt-Imp 6,350' 10,730' Tubing Detail GLM#2 3-1/2" Production 9.2#,L80,Butt-Imp 74' 6,422' 3 Jewelry Detail No. Depth ID OD Item 11 GLM#3 1 439' 2.81 5.375 3-1/2" Baker TRSSSV 2 517' 2.867 5.5 3-1/2"SFO-1 chem inj mandrel 2,170' 2.867 5.968 3-1/2" SFO-2 GLM#1 GLM#4 3 3,900' 2.867 5.968 3-1/2" SFO-2 GLM#2 1 5,352' 2.867 5.968 3-1/2" SFO-2 GLM#3 •!407;...:a0/144 6,335' 2.867 5.968 3-1/2" SFO-2 GLM#4 . a 5-6 4 6,403' Baker ZXP Packer w/X-0 and pup jt. 7 5 6,411' 2.81 4.25 Baker"X"Profile Nipple 9-5/8"@ 6,550' D-1s 6 6,413' 3 4 Baker Seal Assembly w/10 ea 90H Nitrile Seals E-1.. 7 6,421' Modified Y.MS w/WLEG E-2 E-4 8,695' Bridge Plug,Set 4/9/14 3 Top of cement 25 8 9 8,878' CIBP,Set 4/12/14 8,670' c;5ka _E-5 10 10,360' Baker N Bridge Plug,set 12/18/01 Top of ceent-05 , 9 f s,e53'mBaker N Bridge Plug-Stuck,set @ 10,480'on 12/5/01 to _E-7 11 10,480' be able to set BP#7 at proper depth. 4-Top of fill 12 10,490' Baker N Bridge Plug,set 11/28/01 Top of cement .. 9,011' 10,360' (SLM RKB) 13 10,590' Baker N Bridge Plug,set 11/23/01 10 GO-1 Perforation Detail Milled Bridge-1.4%, ZONE Top(MD) Btm(MD) Top(ND) Btm(TVD) Shot Date g 4s4 0-16 7,914' 7939' 6,005' 6,026' 6 12/21/2001 Plug @ 10,480' "�+d �' 11 D-16 7,918' 7933' 6,008' 6,021' 6 7/23/08(DIL) D-16 7,933' 7943' 6,021' 6,029' 6 7/22/08(DIL) MK 12 D-16 7,939' 7953' 6,026' 6,037' 6 4/18/2002 D-16 7,943' 7952.5' 6,029' 6,037' 5 7/22/08(DIL) D-16 7,952.5' 7962' 6,037' 6,045' 5 7/21/08(DIL) GO-3 D-16 7,953' 7958' 6,037' 6,042' 6 12/20/2001 E-1 8,228' 8,258' 7,453' 7,475' 04/13/14 E, 13 E-1 8,293' 8,322' 7,500' 7,521' 04/13/14 -GO-5 E-2 8,438' 8,460' 6,469' 6,490' 04/13/14 E-4 8,563' 8,580' 6,590' 6,607' 04/13/14 Top of cement E5 8,710' 8,738' 6,734' 6,762' 04/11/14(Isolated) 10,695' E-7 8,943' 8,960' 6,962' 6,979' 4 6/1/2012 3-1/2"@ 10,730' GO-1 10,406' 10410' 8,397' 8,400' 6 11/28/2001 00-3 10,530' 10550' 8,519' 8,538' 6 11/23/2001 TD=10,732' MD=8,722' GO-5 10,616' 10621' 8,604' 8,608' 6 11/19/2001 MAX HOLE ANGLE=54.6°(tD_2400' NOTE: • The 28"Drive pipe is crossed over to 34"OD pipe below-95.5'RKB • The Drilled TD was recorded at 10,715'.The recorded tubing tag at TD was recorded as 10,735'.The tubing depths are reported as per measurements of the tubing strap. • Bridge plug was milled with CT for 23.5hrs @ 7,821'CTM on 12/14/01.Junk was pushed to 10,480' Updated by: JLL 05/19/14 Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M-12 507332050500 201-176 4/9/14 4/21/14 Daily Operations: 04/09/14-Wednesday Wireline rigging up on M-12.Wireline pressure test surface equipment to 2500 psi. RIH with 2.75 gauge ring to drift tubing. Set down high at 8,881'.Set bridge plug @ 8,878'. Dump bail 25'of cement on bridge plug. Stand by for cement to set up. 04/10/14-Thursday Continue to stand by for cement to set up. Pressure test lubricator to 2500 psi. E-line logs down to 8,767'and tie in for perforation. Tie in successful. Perform static pressure/Temp.survey for 20 min.Shoot gun. Pull up hole 30 ft. perform another pressure/temp survey monitoring for changes.After 20 minute survey start out of the hole. Immediately begin pulling heavy and find that we are stuck.Work tools for 20 minutes. Pull 3500#bind on line.Wire begins coming out of hole with very little weight. Once back at surface we find that pressure temp gauge parted above the temp censor. Rig down E-line for the night.Call out slickline crew. Stand by for slickline crew. 04/11/14-Friday Pressure test lubricator to 2500 psi.Slick line rig up on M-12 with 2.75 LIB. Slick line tags top of fish with LIB at 8,820'. LIB showed picture of 4 prong temp probe plug in connector. Review and discuss findings from LIB run. Decision is made to leave fish in the hole and complete perfing zone E5 from 8,710'-8,738'. Rig down slick line. Rig up Eline. Pressure test lubricator to 2500 psi. RIH with 2.5 RTG and perf 8,710'-8,738'with gamma rav'ccl. POOH and lay down for the night. Turn well over to production for the night. Production to try and flow well. 04/12/14-Saturday Rig up Eline to run CIBP. Pressure test lubricator to 2500 psi. RIH and set 2.75 CIBP at 8,695'with gamma ray ccl. Made 2 trips in with 2" dump bailer and dumped 25 ft.of cement on top of CIBP.Top of cement is at 8,670'. Rig down E-line. Stand by for cement to set up. 04/13/14-Sunday Rig up Eline to perf zone E4. RIH with 17'of 2.5" RTG. Perf from 8,563'-8,580'with gamma ray ccl. POOH.Turn well over to production. Production attempts to flow well. No pressure build up.Well won't flow. Decision is made not to run CIBP and cement.Continue perfing zones. RIH with 22' of 2.5" RTG. Perf zone E2 from 8,438'-8,460'with gamma ray ccl. POOH.Turn well over to production. Production attempts to flow well. No pressure build up.Well won't flow. Decision is made to perf zone El. RIH with 29'of 2.5" RTG. Perf lower section of zone El from 8,293'-8,322'with gamma ray ccl. POOH. Observe our wire coming back wet at around 6,100'.Once at surface we find dark gray formation sand on tools. Decision is made to complete zone El perfs. RIH with 30' of 2.5" RTG. Perf lower section of the second stage of zone E1 from 8,228'-8,258'with gamma ray ccl. POOH. Prepare for upper section of second stage of zone El. RIH with 24"of 2.5" RTG to perf upper section of the second stage of zone El.Sat down solid at 5,975'. Pulled up and made a couple of attempts to drop down past 5,975'. No go. POOH. Perf from 8,204'-8,228' not completed. Rig down Eline. Decision is made to try and flow well overnight and attempt to clear obstruction. • 11 Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M-12 507332050500 201-176 4/9/14 4/21/14 Daily Operations: 04/14/14-Monday Unable to clear obstruction. Decision is made to call out slickline. Slickline crew arrives, rigs up and pressure tests lubricator to 2500 psi. RIH with 2.5" drive down bailer.Saw no obstructions.Sat down at 8,448'. POOH.Attempt to flow well. No flow. RIH with 2.72"gauge ring.Sat down at 8,312',worked tools and made it down to 8,436'. RIH with 2.78" swedge to locate fluid level. Hit fluid level at 1,965'. Rig down slick line for the evening. Order kick over tools and gas lift valves. Stand by for gas lift tools. 04/15/14-Tuesday Rig up slick line on M-12. Pressure test lubricator to 2500 psi. Change out gas lift design.Stations 1,2,3 pulled.Station 4 is still in the pocket. Made 3 attempts to pull station 4 with no luck. Lay slickline down for the night. 04/16/14-Wednesday PJSM. Rig up slickline. Pressure test lubricator 190 psi low/2500 psi high. RIH with Daniels K/0 tool and 1-1/2" LIB to see if station 4 valve is in the pocket. Pulled station 4 and set all 4 new design valves back in the hole.Turn well over to production to try and flow well. 04/17/14-Thursday No operations to report. 04/18/14-Friday No operations to report. 04/19/14-Saturday No operations to report. 04/20/14-Sunday No operations to report. 04/21/14-Monday Rig up slick line. Pressure test lubricator to 2500 psi,good test. RIH w/2" DD bailer(8')to 8,318' KB,set down. Tag sand @ 8,318' KB. POOH with full bailer of sand. RD slickline. 4§','"11/7%�,,, THE STATE A_ R E a n 1.1 e, ;`v ,� � oer ; STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 2 8 ?.014 APPLICATION FOR SUNDRY APPROVALS 20_AAC 25280 1.Type of Request: Abandon 0 Plug for Redrill 0 Perforate New Pod 0 Repair Well 0 0QQ,Caogrem 0 Suspend 0 Plug Perforations d 7.9./y Perforate 9 Pull Tubing 0 Time Extension 0 Operations Shutdown 0 Re-enter Susp.Well 0 Stimulate 0 Alter Casing 0 Other. 0 2.Operator Name: 4.Current Wed pass: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory 0 Development 9 . 201-176 , 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20505-00 . 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A I Will planned perforations require a spacing exception? Yes 0 No 0• Trading Bay Unit/M-12 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018730 - McArthur River/Middle Kenai Gas • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10,732 8,717 10,360 8,351 See Schematic ' • 10,480 Casing Length Size MD TVD Burst Collapse Structural 406' 28" 480' 479' Conductor 789' 18-5/8" 863' 859' Surface 1,441' 13-3/8" 1,515' 1,491' 3,450 psi 1,950 psi Intermediate 6,476' 9-5/8" 6,550' 5,026' 6,870 psi 4,760 psi Production Liner 4,380' 3-1/2" 10,730' 8,715' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic i See Schematic 3-1/2" 9.2#/L-80 6,422 Packers and SSSV Type: • Packers and SSSV MD(ft)and TVD(ft): Baker ZXP Packer/Baker TRSSSV 6,403'(MD)4,922'(ND)/439'(MD)439'(ND) 12.Attachments: Description Summary of Proposal 9 • 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0, Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/1/2014 Oil 0 Gas 0. WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG 0 Abandoned 0 Commission Representative: GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramer@hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature ��✓ • � . �'—Phone (907) 777-8420 Date 3/28/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: - v--k.- a Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ❑ Location Clearance 0 Other: RBDMS MAY 1 0 2014 Spacing Exception Required? Yes 0 No DV Subsequent Form Required: /Q— goy 0._ APPROVED BYII //Approved by: r (t_-- COMMISSIONER THE COMMISSION Date:Com—/) '/`�14 1, /4- ,P9/1 icy ,, v��'y I /// t� �I A Submit Form and Form 10-403(Revised 10/2012) App I \pl 61INiirt2 months from the date of approval. Attachments in Duplicate Well Work Plan Well: M-12 Hilcora Alaska,LU Date:03/28/2014 Well Name: M-12 API Number: 50-733-2050-00 Current Status: SI Gas Producer Leg: Leg Al,SW Corner Estimated Start April 1, 2014 Rig: NA Date: Reg.Approval March 31, 2014 Date Reg.Approval Req'd: Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill 201-176 Number: First Call Engineer: Ted Kramer (907)777-8420 (0) (985)867-0665 (M) Second Call Jim Young (907)777-8404(0) (907)903-8010 (M) Engineer: AFE Number: Current Bottom Hole Pressure: 602 psi @ 5800' TVD (From 8/25/12 survey) Maximum Expected BHP: 2517 psi @ 5800'ND (expected original E5 pressure) ' Max.Anticipated Surface Pressure: 1,937 psi (Using 0.1 psi/ft to surface) . Well Summary M-12 was producing 2-3 mmcfd from the D16 sands prior to the E7 add perf in 2012 which resulted in an initial rate increase but went into severe decline in 2013 due to water influx. The water is suspected to be cross-flowing from a cement channel to wet sands in nearby offset M-32B which will be addressed later this year. Since there are other options to capture remaining E7 gas from offset wells after the water source is isolated, a bridge plug is proposed to protect existing D16 perfs and add perfs in the E5 sand. Procedure: 1. MIRU wireline unit. Set bridge plug in mid-joint above the E7 perfs at +1- 8930'. 2. PU dump bailer and dump bail 25' of cement on top of the bridge plug. 3. PU pressure gauge, RIH performing stops to determine any fluid gradient changes. Open well with the D-16 perfs open and allow the well to stabilize. 4. Shut-in and record static BHP for 5, 10, 15 and 30 minutes. POOH. 5. PU Perf guns with pressure gauge on top. RIH and perforate the E-5 interval from 8,710 — 8768' (58') according to the correlation log. 6. Note BHP and monitor increase for 5, 10, and 15 minutes after each gun run. Then slowly open the well to production. 7. The following intervals may also be perforated depending upon the pressure reponse from the initial perforations (plugs will be set between perf intervals as needed) starting from the bottom and working upward: Well Work Plan Well: M-12 Hikorp Alaska,LL Date:03/28/2014 Contingent Proposed intervals to be perforated: Btm. Bench Top MD MD / D17 8066 8090 El 8204 8258 El 8293 8322 E2 8438 8460 E4 8563 8580 8. Continue working up the perf schedule until the well produces >2mmcfd at 500psi WHP. The remaining perforations will then be deferred to allow longer term monitoring of the new perforations. Attachments: 1. As-built Schematic 2. Proposed Schematic Steelhead Platform AWell: M-12 ted: • SCHEMATIC PTD:201-176 12-21-01 Hikorp Alaska,LLC API:50-733-20505-00 KB 80.15'(KB to Top of Conductor flange) f ��. _ Casing Detail toi ' Size Type Wt/Grade/Conn Top Btm ' . 1 f W 1 28" Structural 133#,X-56,Drive 74' –480' 96.8#,X-56,DQ E- 2 18-5/8" Surface 60 74' 863' a a l 1 tl ` 18-5/8 r 13-3/8" Surface 68#,K-55,Butt 74' 1,515' @ 863 r iII GLM#1 9-5/8" Surface 47#,L 80, Butt 74' 6,550' lig 13-3/8"0,515' r 3-1/2" Liner 9.2#,L-80, Butt-Imp 6,350' 10,730' Tubing Detail lirliounts2 3-1/2" Production 9.2#,L80,Butt-Imp 74' 6,422' Jewelry Detail No. Depth Length ID OD Item liGLMIp ( 1. 439' 2.8 2.81 5.375 3-1/2" Baker TRSSSV 2. 517' 7.41 2.867 5.5 3-1/2"SFO-1 chem inj mandrel GLM#1. 2,170' 8.92 2.867 5.968 3-1/2" SFO-2 GLMs ;.....II GLM#2. 3,900' 8.93 2.867 5.968 3-1/2" SFO-2 GLMs 3 �I CEA 44 GLM#3. 5,352' 8.93 2.867 5.968 3-1/2" SFO-2 GLMs t ,, 4 GLM#4. 6,335' 8.92 2.867 5.968 3-1/2" SFO-2 GLMs 3. 6,403' 19.41 Baker ZXP Packer w/X-0 and pup jt. 4. 4. 6,411' 1.53 2.81 4.25 Baker"X"Profile Nipple 9-5/8"@ 6,550' 6 5. 6,413' 7.65 3 4 Baker Seal Assembly w/10 ea 90H Nitrile Seals 6. 6,421' 0.53 Modified'A MS w/WLEG 7. 10,360' Baker N Bridge Plug,set 12/18/01 D-16 8. 10,480' Baker N Bridge Plug-Stuck,set @ 10,480'on 12/5/01 to be able to set BP#7 at proper depth. E-7 9. 10,490' Baker N Bridge Plug,set 11/28/01 Top of fill 10. 10,590' Baker N Bridge Plug,set 11/23/01 9,011' Top of cement 10,360' �; (SLM RKB) Perforation Data ". ZONE TOP BTM Shot Condition ! — 7,914' 7939' 6 12/21/2001 —GO-1 7,918' 7933' 6 7/23/08(DIL) Milled Bridgeyy Plug @ 10,480' MEt 8 7,933' 7943' 6 7/22/08(DIL) D-16 7,939' 7953' 6 4/18/2002 t MC g 7,943' 7952.5' 5 7/22/08(DIL) 7,952.5' 7962' 5 7/21/08(DIL) 00-3 7,953' 7958' 6 12/20/2001 10 E-7 8,943 8,960 4 6/1/2012 =GO-5 GO-1 10,406' 10410' 6 11/28/2001 Top of cement GO-3 10,530' 10550' 6 11/23/2001 10,695' GO-5 10,616' 10621' 6 11/19/2001 3-1/2"@ 10,730' NOTE: TD=10,732' MD=8,722' MAX HOLE ANGLE=54.6° an 2400' • The 28"Drive pipe is crossed over to 34"OD pipe below–95.5'RKB • The Drilled TD was recorded at 10,715'.The recorded tubing tag at TD was recorded as 10,735'.The tubing depths are reported as per measurements of the tubing strap. • Bridge plug was milled with CT for 23.5hrs @ 7,821'CTM on 12/14/01.Junk was pushed to 10,480' M-12 WBD 06.26.2012 Updated by TDF Steelhead Platform 14Well: M-12 PROPOSED Al-s e1 201 176: 12-21-01 Hileorp Alaska,LLC API:50-733-20505-00 KB 80.15'(KB to Top of Conductor flange) a -A Casing Detail ,a1. � Size Type Wt/Grade/Conn Top Btm v!:" 1 a `''t 28" Structural 133#,X-56,Drive 74' -480' 10 1 4 96.8#,X-56,DQ E- 4,.,y,A�,4- 2 18-5/8" Surface 60 74' 863' 18-5/8" a> A 13-3/8" Surface 68#,K-55,Butt 74' 1,515' @863 nGLM#1 41 •i 9-5/8" Surface 47#,L-80, Butt 74' 6,550' 13-3/8"@1,515' I', 3-1/2" Liner 9.2#,L-80, Butt-Imp 6,350' 10,730' `n Tubing Detail V-GLM#2 3,31/2" Production 9.2#,L80,Butt-Imp 74' 6,422' Jewelry Detail No. Depth Length ID OD Item I1 GLM#3 II 1. 439' 2.8 2.81 5.375 3-1/2" Baker TRSSSV 2. 517' 7.41 2.867 5.5 3-1/2"SFO-1 chem inj mandrel GLM#1. 2,170' 8.92 2.867 5.968 3-1/2" SFO-2 GLMs 1GLM#4 GLM#2. 3,900' 8.93 2.867 5.968 3-1/2" SFO-2 GLMs 3 GLM#3. 5,352' 8.93 2.867 5.968 3-1/2" SFO-2 GLMs 4 GLM#4. 6,335' 8.92 2.867 5.968 3-1/2" SFO-2GLMs 3. 6,403' 19.41 Baker ZXP Packer w/X-0 and pup jt. ' 4. 6,411' 1.53 2.81 4.25 Baker"X"Profile Nipple 9.5/8"@ 6,550 6 5. 6,413' 7.65 3 4 Baker Seal Assembly w/10 ea 90H Nitrile Seals - D-16 6. 6,421' 0.53 Modified''/MS w/WLEG 7. 10,360' Baker N Bridge Plug,set 12/18/01 E-58, 10,480' Baker N Bridge Plug-Stuck,set @ 10,480'on 12/5/01 to ffliEbe able to set BP#7 at proper depth. -E-7 9. 10,490' Baker N Bridge Plug,set 11/28/01 Top of fill 10. 10,590' Baker N Bridge Plug,set 11/23/01 'i # 9,011' Top of cement ',VI.� (SLM RKB) 10,360' :4:-,.• Perforation Detail 7 ZONE Top(MD) Btm(MD) Top(TVD) Btm(TVD) Shot Date D-16 7,914' 7939' 6,005' 6,026' 6 12/21/2001 -GO-1 D-16 7,918' 7933' 6,008' 6,021' 6 7/23/08(DIL) D-16 7,933' 7943' 6,021' 6,029' 6 7/22/08(DIL) Milled Bridge_,44D-16 7,939' 7953' 6,026' 6,037' 6 4/18/2002 Plug @ 10,480' 8 D-16 7,943' 7952.5' 6,029' 6,037' 5 7/22/08(DIL) D-16 7,952.5' 7962' 6,037' 6,045' 5 7/21/08(DIL) :EC 9 D-16 7,953' 7958' 6,037' 6,042' 6 12/20/2001 i * E5 ±8,710' ±8,768' ±6,734' ±6,791' Future E-7 8,943' 8,960' 6,962' 6,979' 4 6/1/2012 GO-3 GO-1 10,406' 10410' 8,397' 8,400' 6 11/28/2001 GO-3 10,530' 10550' 8,519' 8,538' 6 11/23/2001 10 GO-5 10,616' 10621' 8,604' 8,608' 6 11/19/2001 -GO-5 Top of cement 10,695' 1 3-1/2"@ 10,730' TD=10,732' MD=8,722' MAX HOLE ANGLE=54.6°O.2400' NOTE: • The 28"Drive pipe is crossed over to 34"OD pipe below"'95.5'RKB • The Drilled TD was recorded at 10,715'.The recorded tubing tag at TD was recorded as 10,735'.The tubing depths are reported as per measurements of the tubing strap. • Bridge plug was milled with CT for 23.5hrs @ 7,821'CTM on 12/14/01.Junk was pushed to 10,480' Updated by: JLL 03/20/14 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, April 08, 2014 9:46 AM To: 'Ted Kramer'; Ferguson, Victoria L (DOA) Subject: RE: undry Application -Verbal Requested ozO i7 Ted, You have verbal approval to set plug and perf as proposed.... Sundry should be ready in a day or two. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Ted Kramer fmailto:tkramer©hilcorp.com] Sent: Tuesday, April 08, 2014 9:37 AM To: Schwartz, Guy L (DOA); Ferguson, Victoria L (DOA) Subject: M-12 Sundry Application -Verbal Requested Guy, We currently have a crew on the Steelhead platform ready to begin operations to set the plug and perforate the above well. If you see not issues with the application, could you possibly issue Hilcorp a verbal to proceed? Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 1 • • Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777 -8337 Hilrurp Alaska. t,I.c; Fax: 907 777 -8510 E -mail: doudean @hilcorp.com DATE 7/20/2012 To: AOGCC Makana Bender 333 W. 7 Ave. Ste# 100 Anchorage, AK 99501 DATA TRANSMITTAL M -12 M'12 CDR - Resistivity MD - NNED MAY U 2 2 °13 M -12 CDR - Resistivity TVD — M-12 VISION Density Neutron MD M -12 VISION Density Neutron ND M -12 Formation Mudlog - EOW Letter M- 12.doc -- CD: Final Well Data ASCII M -12 AND LAS Data MadPass.las M -12 CDR LAS Data MadPass.las - M-12 GR LAS Data.las — Surveys M -12 Final Survey.doc M -12 Final Survey.txt — PDS Logs CDR Resistivity_MD.pds — CDR Resistivity_TVD.pds - Vision Density Neutron_MD.pds - Vision Density Neutron)TVD.pds TIFF Logs CDR Resistivity_MD.tif - CDR Resistivity_TVD.tif - Vision Density Neutron_MD.tif Vision Density Neutron)TVD.tif — Formation Mudlogaef Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By:( Date: C 2N, -)J3 STATE OF ALASKA • AKA OIL AND GAS CONSERVATION COMMISSION JUN 2 6 Loa— REPORT OF SUNDRY WELL OPERATIONS Oil Ga : ;, T Commission 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ . Other Enchnr 0t? Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Welll❑ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development EI ' Exploratory ❑ 201.176 • 3. Address: 3800 Centerpoint Drive, STE 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99503 50- 733 - 20505 -0000 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018730 / Steelhead Platform • Trading Bay Unit M -12 • 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): McArthur River Field / Middle Kenai Gas ' 11. Present Well Condition Summary: Total Depth measured 10,732 ` feet Plugs measured See Schematic feet true vertical 8,717 • feet Junk measured 10,480 feet Effective Depth measured 10,360 feet Packer measured 6,403 feet true vertical 8,351 feet true vertical 4 feet Casing Length Size MD TVD Burst Collapse Structural 406' 28" 480' 479' Conductor 789' 18 -5/8" 863' 859' Surface 1,441' 13 -3/8" 1,515' 1,491' 3,450 psi 1,950 psi Intermediate 6,476' 9 -5/8" 6,550' 5,026' 6,870 psi 4,760 psi Production Liner 4,380' 3 -1/2" 10,730' 8,715' Liner Perforation depth Measured depth 7,914' - 7,962' feet True Vertical depth 6,004' - 6,045' feet Tubing (size, grade, measured and true vertical depth) 3 -1/2" L -80 9.2# -•- -- '•^6142! f ur - 4,936' (TVD) Baker ZXP Packer 6,403' (MD) 4,922' (TVD) Packers and SSSV (type, measured and true vertical depth) Baker TRSSSV 439' (MD) 439' (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A $ LAMED JUL 2 4 2012 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 1299 0 85 35 Subsequent to operation: 0 4640 0 86 1166 0 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development IEI • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gasp • 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: Contact Ted E. Kramer Printed Name Ted E. Kramer Title Operations Engineer Signature � co, ° J — - Phone 907 - 777 -8420 Date 6/26/2012 ■ 7yg v -/ 7//z-ii - z-- I7( , 1 ,.4 (2...- Form 10 -404 Revised 11/2011 Submit Original Only II • Steelhead Platform Well M -12 Last Completed 12 -21 -01 AS B U I LT PTD: 201 -176 Hilcorp Alaska, 1.L1, API: 50 - 733 - 20505 - KB 80.15' (KB to Top of Conductor flange) r Casing Detail r.:03*: t- Size Type Wt/ Grade/ Conn Top Btm .. 1 . Structural 133# X -56 Drive 74' — 480' a lt * . : 2 8 S tru ct �i 4 ,Z 1 4, , r01/11 96.8 #, X -56, DQ E- 2 18-5/8 Surface 60 74 863' 18 l j � GLM #1 + .ri 13 - 3/8" Surface 68 #, K - 55, Butt 74' 1,515' J ' 9 -5/8 ii Surface 47 #, L -80, Butt 74' 6,550' 133/8 "@1,515' 3 -1/2" Liner 9.2 #, L -80, Butt -Imp 6,350' 10,730' Tubing Detail 11 GLM #2 �� 3 - 1/2" Production 9.2 #, L80, Butt -Imp 74' 6,422' Jewelry Detail No. Depth Length ID OD Item 'IiGLM #3 1. 439' 2.8 2.81 5.375 3 -1/2" Baker TRSSSV 2. 517' 7.41 2.867 5.5 3 -1/2" SFO -1 them inj mandrel ``r�� GLM# 1. 2,170' 8.92 2.867 5.968 3 -1/2" SFO -2 GLMs ,II GLM #4 GLM# 2. 3,900' 8.93 2.867 5.968 3 -1/2" SFO -2 GLMs 3 GLM# 3. 5,352' 8.93 2.867 5.968 3 -1/2" SFO -2 GLMs 4 GLM# 4. 6,335' 8.92 2.867 5.968 3 -1/2" SFO -2 GLMs L 3. 6,403' 19.41 Baker ZXP Packer w/ X -0 and pup jt. 4. 6,411' 1.53 2.81 4.25 Baker "X" Profile Nipple 9 @6,550' n 6 5. 6,413' 7.65 3 4 Baker Seal Assembly w/ 10 ea 90H Nitrile Seals 6. 6,421' 0.53 Modified'''/ MS w/ WLEG _ 7. 10,360' Baker N Bridge Plug, set 12/18/01 D g 10,480' Baker N Bridge Plug - Stuck, set @ 10,480'on 12/5/01 to be able to set BP #7 at proper depth. — E - 9. 10,490' Baker N Bridge Plug, set 11/28/01 Top of fill 10. 10,590' Baker N Bridge Plug, set 11/23/01 9,011' Top of „ (SLM RKB) cement _0 10 „ Perforation Data ii 7 ZONE TOP BTM Shot Condition G0 7,914' 7939' 6 12/21/2001 Milled Bridge a 7,918' 7933' 6 7/23/08 (DIL) Plug @10,480' 8 7,933' 7943' 6 7/22/08(DIL) D -16 7,939' 7953' 6 4/18/2002 ZEIC 9 7,943' 7952.5' 5 7/22/08 (DIL) 7,952.5' 7962' 5 7/21/08 (DIL) — G0 3 7,953' 7958' 6 12/20/2001 MEI 10 E -7 8,943 8,960 4 6/1/2012 1/ GO GO -1 10,406' 10410' 6 11/28/2001 Top of cement GO -3 10,530' 10550' 6 11/23/2001 3-1/2" @ 10,730 r /16,01:0 ';- 10,E GO -5 10,616' 10621' 6 11/19/2001 NOTE: TD = 10,732' MD = 8,722' MAX HOLE ANGLE = 54.6 @ 2400' • The 28" Drive pipe is crossed over to 34" OD pipe below — 95.5' RKB • The Drilled TD was recorded at 10,715'. The recorded tubing tag at TD was recorded as 10,735'. The tubing depths are reported as per measurements of the tubing strap. • Bridge plug was milled with CT for 23.5hrs @ 7,821' CTM on 12/14/01. Junk was pushed to 10,480' M -12 Well Schematic 06.26.2012 Updated by TDF I • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M -12 507332050500 201 -176 5/31/12 6/1/12 wily Operations: P . 05/31/12 - Thursday Rig up lubricator pressure test to 250 psi low and 3,500 psi high. RIH with CCL /GR, 2.72" gauge ring and tie into SLB CDR Resistivity log dated 9/17/01. Tag fill at 9,011'. POOH. Make up 2- 1/2 "x5' strip gun loaded with 3 perf pods. Spot shot. ✓ from with perf pods at 8,951', 8,953' and 8,955' fired shot. POOH. RIH w/ 2 -1/2 "x17' HC, 4 spf, 60 deg phase and perf the 17' zone and go down 7,850'. Pick up and get tool weight (1,200 Ib) Start back down hole and tools stop at 7,923' (13' into top of D -16 sand). Could not go up or down. Guns stuck in hole. SDFN. 06/01/12 - Friday Went out to E -line unit. We had lost about 120 Ibs of line wt and well looked like it had stablized. Slacked line off and saw movement. Picked back up and pulled about 100 Ibs over tool wt and was free. RIH w/ 2 -1/2 "x17' HC, 4 spf, 60 deg phase. Tie into SLB CDR Resistivity log dated 9/17/2001. Tools set down at 7,923'. Pick up tools and had 100 Ib overpull. Went back down and got thru tight spot. Spotted perf gun from 8,943' to 8,960' per Final Approved Perforation Request " Form dated 25- May -12 and fired guns. POOH. Bleed lubricator, rig down off well and turn over to production. STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMII~ION REPORT OF SUNDRY WELL OPERATIONS ~. 1. Operations Abandon Repair Well Plug Perforations Stimulate Other Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension^ Change Approved Program ^ Operat. Shutdown^ Perforate Q • Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory^ 201-176 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic^ Service^ 6. API Number: 50-733-20505-00 7. KB - levation (ft): 9~Well Name and Number: 80.15' Trading Bay Unit M-12 . 8. Property Designation: 0. Field/Pool(s): ADL0018730 [Steelhead Platform] McArthur River /Middle Kenai Gas 11. Present Well Condition Summary: Total Depth measured 10,732 feet Plugs (measured) See Attached Schematic true vertical 8,717 feet Junk (measured) 10,480' Effective Depth measured 10,360 feet true vertical 8,351 feet Casing Length Size MD TVD Burst Collapse Structural 406' 28" 480' 479' Conductor 789' 18-5/8" 863' 859' Surface 1,441' 13-3/8" 1,515' 1,491' 3450 psi 1950 psi Intermediate 6,476' 9-5/8" 6,550' 5,026' 6870 psi 4760 psi Production Liner 4,380' 3-1/2" 10,730' 8,715' 10160 psi 10540 psi ~F# ,; r rF '' Perforation depth: Measured depth: 7,914' - 7,962' `i asi.~~~~. `' True Vertical depth: 6,004' - 6,045' Tubing: (size, grade, and measured depth) 3-1/2" L-80 9.2# 6,422' Packers and SSSV (type and measured depth) Baker ZXP Packer @ 6,403' & Baker TRSSSV @ 439' 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): e Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 2300 2 110 280 Subsequent to operation: 0 2900 2 120 330 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development^ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil^ Gas^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager ~ ~ ~«'~~ Signature ~ ,, Phone 276-7600 Date 8/6/2008 Form 10-404 Revised 04/2006 ~~r~~n~/~~ ~ ~ ~ ~' " y Submit Original Only ~ ~r~~~ EVYO Steelhead Platform Steelhead Platform Well M-12 M-1 ~ Last Completed 12-21-01 to ~~ 133 sa TD =10,732' MD = 8,722' MAX HOLE ANGLE =54.8° a(a. 2400' Casing and Tubing Detail Size Type Wt/ Grade/ Conn Top Btm 28" Structural 133#, X-56, Drive 74' --480' 18-5/8" Surface 96.8#, X-56, DO E-60 74' 863' 13-3/8" Surface 68#, K-55, Butt 74' 1,515' 9-5/8" Surface 47#, L-80, Butt 74' 6,550' 3-1/2" Liner 9.2#, L-80, Butt-Im 6,350' 10,730' Tubing 3-1/2" Production 9.2#, L80, Butt-Imp 74' 6,422' Jewelry Detail # Depth Length ID OD Item 1. 439' 2.80 2.810 5.375 3-l/2" Baker TRSSSV 2. S l7' 7.41 2.867 5.5 3-l/2" SFO-1 chem inj mandrel GLM# 1. 2,170' 8.92 2.867 5.968 3-l/2" SFO-2 GLMs GLM# 2. 3,900' 8.93 2.867 5.968 3-l/2" SFO-2 GLMs GLM# 3. 5,352' 8.93 2.867 5.968 3-l/2" SFO-2 GLMs GLM# 4. 6,335' 8.92 2.867 5.968 3-1/2" SFO-2 GLMs 3. 6,403' 19.41 Baker ZXP Packer w/ X-O and pup jt. 4. 6,411' 1.53 2.810 4.250 Baker "X" Profile Nipple 5. 6,413' 7.65 3.000 4.000 Baker Seal Assembly w/ 10 ea 90H Nitrite Seals 6. 6,421' 0.53 Modified %MS w/ WLEG 7. 10,360' Baker N Bridge Plug, set 12/18/01 8. 10,480' Baker N Bridge Plug -Stuck, set @ 10,480'on l2/5/Ol to be able to set BP#7 at proper depth. 9. 10,490' Baker N Bridge Plug, set 11/28/01 l0. 10,590' Baker N Bridge Plug, set 11/23/01 Perforation D ata ZONE TOP BTM Shot Condition 7,914' 7939' 6 12/21/01 7,918' 7933' 6 7/23/08 (DIL ' 7,933' 7943' 6 7/22/08 DIL D-16 7,939' 7953' 6 4/18/02 7,943' 7952.5' S 7/22/08 (DIL 7,952.5' 7962' S 7/21/08 DIL 7,953' 7958' 6 12/20/01 GO-1 10,406' 10410' 6 11/28/01 GO-3 10,530' 10550' 6 11/23/01 GO-5 10,616' 10621' 6 11/19/01 NO'T'E: • The 28" Drive pipe is crossed over to 34' OD pipe below 95.5' RKB • The Drilled TD was recorded at 10,715'. The recorded tubing tag at TD was recorded as 10,735'. The tubing depths aze reported as per measurements ofthe tubing strap. • Bridge plug was milled with CT for 23.Shrs @ 7,821' CTM on 12/14/01. Junk was pushed to 10,480' Well Schematic M-12 7-23-08.doc Updated by CVK KB 80.15' (KB to Tap of Conductor flange) Chevron Chevron -Alaska Daily Operations Summary Well Name M-12 Field Name Trading Bay Unit API/UWI 507332050500 Lease/Serial ADL18730 CHEVNO HE4291 License No./Props... 2011760 Orig KB Elev (ftK8) 160.0 Water Depth (ft) 278.00 -_ _ _ _ __ _ Jobs _--- - Job Cat Type AFE No. _ _ OC Eng Well Service Perforating UWDAK-R8036 -- ------ - -- Dail _Operations __ 7/9/2008 00:00 - 7/10/2008 00:00 Operations Summary Run 2.7" GR and Dumm Gun to to of fill at 9057' RKB SLM. 7/21/2008 00:00 - 7/22/2008 00:00 Operations Summary Run 2.5" Power Spiral guns and Perf lower D16-C Sand @ 7952.5' - 7962' 5spf 7/22/2008 00:00 - 7/23/2008 00:00 Operations Summary Run 2 1/8" Power Spiral Enerjets to reperforate D16C sands 7933' - 7943' 5spf and 7943' - 7952.5' 6spf. 7/23/2008 00:00 - 7/24/2008 00:00 Operations Summary Run 2 1/8"' Power Spiral Enerjets perf @ 7918' - 7933 6spf . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc ~ tJ ~~ ~ö~ 'i DATA SUBMITTAL COMPLIANCE REPORT 1/6/2004 Permit to Drill 2011760 Well Name/No. TRADING BAY UNIT M-12 Operator UNION OIL CO OF CALIFORNIA Sf~ API No. 50-733-20505-00-00 MO 1 0732 ,--- TVO 8722 Completion Date 12/20/2001 r- Completion Status 1-GAS Current Status 1-GAS UIC N -- - ---- --- -.- - --..- REQUIRED INFORMATION Mud Log No Samples No Directional Survey No ----- u_-- --- - --- ------- ---- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) --- Log/ Data Type /í Log I Electr Digital Dataset Med/Frmt Number Name Log Log Run Scale Media No 5 8M 1 Interval Start Stop 7700 8050 CHI CH Received Case 5/6/2002 Comments ------ Well Cores/Samples Information: ,. Name Cuttings Interval Start Stop 4700 10710 Sent Received Sample Set Number Comments 0751 -- - --- ----- ADDITIONAL INFORMATION Well Cored? V@ Daily History Received? ~/N cj/N Chips Received'2 V / N - Formation Tops Analysis Received? ~ -~.~- NIJ ~ t4 ~ - ~ I"-A... ~ /:' vn.-:l<-¿ 6~v ~ ;2./ J"", ~<.( --- ~ ------ --- ------- ---- ---- -- . Comments: /IJ D ----- -- --- - - ----. ----- --- Compliance Reviewed By: Date: ;<'1 J "'v'>--~- '-I J~ ~ /))~ M J) ~ Trtû C l") ý:\ - fu-~ll ffi '* : ~ M IJ ~ ÌÏI ¡J ß t. Gl- ( (' Unocal Alaska 909 W. 9th Avenue Anchorage. AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: haITisonb@unocal.com UNOCAL8 Beverly Harrison Business Ventures Assistant May 2, 2002 To: Lisa l.e¡}i:e 'We.. e.p°, e... AOGCC 333 W. 7th Ave, #100 Anchorage, AK 99501 DATA TRANSMITTAL - TRADING BAY UNIT / CJd- 05¿;) WELL .- lOG TYPE . SCALE LOG DATE INTERVAL CO MEDIUM G-29RD TCP CORRELATION / GR / CCL 51NCH 4/29/2002 11120-11520 1 Film TCP CORRELATION / GR / CCl 51NCH 4/29/2002 11120-11520 1 B-Line M-12 COMPLETION RECORD /2 1/8" POWER EJ 6 SPF 51NCH 4/18/2002 7700-8050 1 B-Line COMPLETION RECORD /21/8" POWER EJ 6 SPF 51NCH 4/18/2002 7700-8050 1 Film ~OJ-/l(P Please acknowledge receipt by signing and returning one copy of this transmi Received 80 Date: t~Y 0 6 2002 Alaska Oil & Gas Cons. ComInIion Ancborage ~ Unocal Alaska ( 909 W. 9th Avenue (i Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb@ unocaLcom UNO CALi) Beverly Harrison Business Ventures Assistant February 5, 2002 DATA TRANSMITTAL To: From: Lisa Weepie Beverly Harrison Alaska Oil & Gas Unocal Alaska 333 W 7th Ave, #100 909 W. 91n Avenue Anchorage, AK 99501-3539 Anchorage, AK 99501 Transmittin the followin : ">..'..:,:.:::.:.lOG:TYPE.o...,,,:, . . SCALE., LOG DATE., INTERVAL..:. COPIES,... Well " Medium Î ¡COMPLETION RECORD 51NCH i 1/18/2002! 10500-11419 t 1 .;K-12RD2 I Film 1)7<6-05 rcÖMP[ËffÕÑ"Ã'EC5ÖÃ'Ö'.' ! .5'.Tt~icFr."."".'...'..171"ã72oÖ2r....'1'Ö5ÕÕ:.1'.1'¡.Üf.T"""'.'."'1'..'..'.".'.n<=f2R"o2.""...'rï3=Ürl.ë"'....1 j" ¡gg]~t~~:§~'~I-ð!g~:~":fH~grr:~:~~)H~~~~~~=~~ro~~~~~fT::.:T::::f~~~=~~~1T~r~~Nn:~': :-tr' ~ ~ fgl~~g[Hg~}gl~~~~~:i~f~g~'I:î~~t~~~%}I:::~~~~~-:'I:îl~:~:~~g:::I~~~~~: fì DJ-/8 9 r CÕMP'[ET'íë5r\i'Ã-EC'ÕÃ'D.'.""'M"^¡5TÑ'c~:r-'-r~'^,_m'^"'17872ÕÕ2T.'-"M53ÕÕ='6~î'1"ä."".""'r^-"'--r""- š-ÃU" 1 '2':'1-5-'._' I B:Üñë'-.'."ll, ~~-I~I~r-OYI lð§~~~~~~~:~~ðg~g:"j~:~-g~:F::1~*~~ID:=:~~~~~~1~]:I"~::.:I~~~:~~~~~ll~~&::=~ Igg~~~~~g~~~%g~~~:~:¡~æ~~::+::::~}f~~~~~F~l~~!~~H~~~:::1:~:F:I~f~gF:I~~s;,~::[ C) 1- 00 9 ~..cÖM.pLE.ffÕÑ....R.Ë.CÖ.Ãtf........m..'.J.5'..fÑcR.'...'....'..........'..'.1l1'5j2(jQ"2.1.......1.Ó26õ:1.1..~iSS'.'.'.¡........'.........1....."'.......¡...R:..1.¿.RO2........ "Fi I m .....'.'.....1 /7 cg -05 ., ",..."...~.,w_,,~--------,._._--_._w-,...1^,-~-^w~"-m'.'.~-M_'.m_"",,_,_._,_m.""¡_".'.'.'._'.WM"'__.W'--"'-"-'.."'-".'."-.""""--._.'.."M'.\_._.W""'-....'_._..M'.__"".'--'-,,-_._w~'w, ¡COMPLETION RECORD ¡5INCH i 1/15/20021 10200-11455 ¡ 1 I,K-12RD2 ¡ B-Line ~ rBÃ K Ë ÃMÑ-:2BR I D G E-pTUGwYš-ïÑ'c HM-"MrM1172.ã72ÕÕ1.T-'Mw"'.Mw'""_"m__~,^,_,_.._w,:,w..mM-"."'1^.,w--"-rM:'1'2'WM'.'W,.w"""-".n=ITm~""'_m~ 01- I ï Ie ~ì~EJt~~~~~~êKQ[ ts~§~" F:HIï~~~F:~:~;~~~~~~:: i::::~F::::I~~~~~::::::: I~~~Di:::j;D 1- I ~ 9 ¡.MÖ.ouLÄÃ.Ö'{"NiÚv1ï"c...........................¡s.."ïi,J"C.H....I......1"¿/26j¿OÓ1.r.... .107á~5ä3õ".............i........1....' ......lÄ:.15F{"Ö......... B - Lirl"ë..' .....Il I'. .FÖR.MÄf"ïö.N....M.fci~~Ö...............................",....TN.CH.................1"¿/2¿j¿OÖ1""I","...'.......0:.1.Ö73"...'.............")......"'....1............¡.,OA:.1..SRÖ.".......... '".'"..Þil.m....................'.....I. [: ËQ.äM.~1IÞ '~,,:,:M( C t3.Q:^,:^"^",:,:':.:~^,:"J§J,,~ç_ti,:.::^,,L^,,:,,:I?lgZlgQþjJ^""::.:,^"',,,::QjQZ~,~,~,,:^,,,'^,~I:^,,:~,,=i.,:.~: ,'^,^,[8~i§:8Q:~::"""",:^,~ ,Lê_~~ i 6~~:,~j and returning one copy of this transmittal or FAX ~~elv.ED Received b : Date: f.., ,~D 0 :~ 2002 ¡;'\; \ q. Alaska 0;1 & Gas Cons. Commission AnMnrM.o. I" ~. Unocal Corporation if P.O. Box 196247 '\ Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL8 Dan Williamson Drilling Manager Monday, January 14, 2002 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Anchorage, Alaska 99501 Attn: Commissioner Julie Heusser RECEIVED ,IAN 22 2002 Re: Well Completion Report (Form 407a) McArthur River Field Steel head Platform, Well M-12 Alaska 011 & Gas Co'os. Commission Anchorage Commissioner Heusser: Enclosed for your review is the Well Completion Report for the Steelhead Well #M-12. This well was drilled to a TO of 10,732' MD (8722' tvd) and was completed as a gas producer in the Grayling Gas Sands. The end of operations for this well was December 21,2001. If there are any questions, please contact Larry Buster at 263-7804. Sincerely, ~ Drilling Manager Unocal Alaska DS/lb ORIGiNAL ( STATE OF ALASKA l( ALASKA O'L AND GAS CONSERVATION' JMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 . Status of Well Classification of Service Well OIL: GAS: x 2. Name of Operator Unocal 3. Address P. O. Box 196247 Anchorage, AK 99519-6247.,._-.. . 4. Location of well at surface . '~.'. 4240' FSL and 4822' FEL Sec. 33, T9N, R13 W, SM ; /2..2.;.~.-c-{ ~lD"'"S~¡&. ~~~I.I At Top ~roducing Interv,al (7914' md) ~'--:.---- '-- - -.. ~. ~~'fflZj J 3185 FSL and 2885 FEL, Sec. 28, T9N, R13W, SM ~.', '-"," iP'n =...' ..$t.' It . J. At Total Depth (10,732' md) ;1.8 <\~.~.",4V ~, ~~-'T ~ 3559' FSL and 3219' FEL Sec.-3iT9N, R13W, SM ;~~...'.~:::~: 5. Elevation in feet (indicate KB, D~, etc.) 6. Lease Designation and Serial No. 160' KB ADL-18730 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions Sept. 17,01 Oct. 24, 01 Dec. t( 01 .l-v 278 feet MSL 1 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 10732' 10335' Yes: x No: 439 feet MD N/A 22. Type Electric or Other Logs Run LWD - Density Neutron, Compensated Dual Resistivity CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM 28" 133 X-56 74' 480' 18-5/8" 97 X-56 74' 863' 13-3/8" 68 K-55 74' 1515' 9-5/8" 47 L-80 74' 6550' 3-1/2" 9.2 L-80 6422' 10730' 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) SUSPENDED: ABANDONED: SERVICE: 7. Permit Number 201-176 8. API Number 50- 733-20505-00 9. Unit or Lease Name Trading Bay Unit 10. Well Number M-12 11. Field and Pool Grayling Gas Sands 23. HOLE SIZE Drive 24" 17-1/2" 12-1/4" 8-1/2" 25. CEMENTING RECORD N/A 1152 sxs 744 sxs 1296 sxs 1685 sxs TUBING RECORD DEPTH SET (MD) 6422' AMOUNT PULLED SIZE 3-1/2" PACKER SET (MD) 6413' D-16 Sand - 7914' - 7939' (6005' - 6025' tvd) 6spf D-16 Sand - 7953' - 7958' (6036' - 6040' tvd) 6spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 12/28/01 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF 1/7/02 24 TEST PERIOD => 0 5480 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF Press. 307 360 24-HOUR RATE => 0 5480 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE WA TER-BBL 2 WA TER-BBL 2 CHOKE SIZE GAS-OIL RATIO - na OIL GRAVITY-API (corr) na RFCEIVED 0 ~...." \ r' 7 I 't".;;:' . ~.~.; \ l i, .,. ~ . I: i ¡:.:. II t ~ Ii.,. , fA" I 'J 2 ~"" 1\, G- ?~n? ,~ If,~t! D1i~9:.t\:: Df~ :'j¡. ~~mmi~ó:t; - w "'~ B H Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE RBOMS BFl ~~N 24 2I1œ Submit in duplicate ,I ,I 29. 30. ( FORMATION TESTS GEOLOGIC MARKERS MEAS.DEPTH Include interval tested, pressure data, all fluids recovered and gravity, TRUE VERT. DEPTH GOR, and time of each phase. NAME GO-5 Sand 10616' - 10621' 8603' - 8608' No Flow. GO-3 Sand 10530' - 10550' 8518' - 8537' No Flow. GO-1 Sand 10406' - 10410' 8397' - 8401' No Flow. 31. LIST OF ATTACHMENTS Daily Report Summary, Well Schematic and Survey Report. 32. I hereby certify that the t ring is true and correct to the best of my knowledge Signed Title Date 1'- t 7-07- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 UNoCAL8 STEELHl. JPLATFORM WELL # 1\1-12 Grass Roots Gas Well KB = 80,15' (KB to Top Conductor flange) 18-5/8" @ 863' 2 3-3/8" @ 1515' 3 9-5/8" @ 6550' 0-16 TOC @ 10,335' 10,360' GO-I 10,480' 10,490' GO-3 10,590' GO-5 3-1/2" @ 10730' TD = 10732' MD/8722' TVD MAX HOLE ANGLE = 54.6° @ 2400' Well Schematic M-12 Fina1.doc CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BTM 28" 133 X-56 Drive 74' -480' 18-5/8" 96.79 X-56 DO E-60 74' 863' 13-3/8" 68 K-55 Butt 74' 1515' 9-5/8" 47 L-80 Butt 74' 6550' Liner 3-1/2' 9.2 L-80 Butt-Imp 6350' 10730' Tubing 3-1/2" 9.2 L-80 Butt-Imp 74' 6422' NOTE: . The 28" Drive pipe is crossed over to 34" OD pipe below -95.5' RKB . The Drilled TD was recorded at 10,715'. The recorded tubing tag at TO was recorded as 10,735'. The tubing depths are reported as per measurements of the tubing strap. JEWELRY DETAIL Item Depth Len2th ID OD Description I. 439' 3-1/2" Baker TRSSSV 2. 517' 3-1/2" SFO-l chern inj mandrel GLM# 1 2170' 3-1/2" SFO-2 GLMs GLM# 2 3900' 3-1/2" SFO-2 GLMs GLM# 3 5352' 3-1/2" SFO-2 GLMs GLM# 4 6335' 3-1/2" SFO-2 GLMs 3. 6411' "X" Profile Nipple 4. 6413' Baker Seal Assembly w/ 10 ea 90H Nitrile Seals 5. 6421' Modified Y2 MS wI WLEG PERFORATION DATA Zone Interval SPF DATE COMMENTS GO-5 10616' - 10621' 6 11/19/01 GO-3 10530' - 10550' 6 11/23/01 GO-l 10406' -10410' 6 11/28/01 0-16 7953' - 7958' 6 12/20/01 Shoot zone 2 times D-16 7914' - 7939' 6 12/21/0 I REVISED: 12/31/01 BY: LWB ~. j , Steelhead Well M-12 Dailv Summary Unocal Alaska Drilling Daily Summary Report M-12 Grassroots Gas Well 9/13/01 to 12/21/01 9/13/01 Accept rig and proceed to R/U 30" Diverter and 16" overboard lines. 9/14/01 Continue with R/U of 30" Diverter. 9/15/01 Install Bell Nipple on 30" Diverter. Drift riser with Casing Hanger. 9/16/01 Finish N/U of 30" Diverter. Test Diverter w/ AOGCC witness Mr. Jeff Jones. M/U Clean-out BHA, 9/17/01 Clean out Driven Conductor to 500' with 9,2 ppg gel mud. M/U 17-1/2" BHA. 9/18/01 Drill and survey with Gyro from 500' to 870' with 9,2 ppg gel mud. POOH. 9/19/01 Unsatisfied with directional position. Decide to plug well back, RIH to 870'. Mix and pump cement plug, Wait on cement. RIH to 535'. 9/20/01 Wait on cement. Drill off of cement plug to 764'. 9/21/01 Drill to casing point at 870' with 17-1/2" bit. POOH. M/U 26" Hole Opener Assembly and open hole to 26" to 870' with 9,2 ppg gel mud. Condition hole. 9/22/01 POOH and L/D BHA. Run and cement 18-5/8" casing with cement returns to surface. 9/23/01 Proceed to N/D 30" Diverter. 9/24/01 Weld wellhead starter head and allow to cool down, Install studs and wing valves on well head. Start with N/U of 16-3/4" BOP. 9/25/01 Make modifications as required to deck grating and continue to N/U 16-3/4" BOP. 9/26/01 Finish with N/U of 16-3/4" BOP Stack. M/U test plug and tested stack, manifold, choke and kill lines to 250 psi low and 3000 psi high. Problems getting wear bushing thru bell nipple, 9/27/01 Dress bell nipple. Run and set wear bushing. M/U 12-1/4" BHA. RIH to 847'. Drill float collar, float shoe, rat hole and 12' of new hole to 882'. Circulate bottoms up and perform a 12,2 ppg equivalent mud weight leak off test. POOH, M/U new 12-1/4" drilling assembly. RIH and drill from 882' to 1004' with 9.2 ppg gel mud and gyro surveys, 9/28/01 Continue to directionally drill 12-1/4" hole to 1157'. Encounter +/- 300 bph mud losses, Pump 60 bbl LCM pill and losses decrease to less then 8 bph and continue lower Drill from 1175' to 1531' with zero static losses. Spot 30 bbl LCM pill on bottom and pull out of hole, P/U 17-1/2" Underreamer assembly and RIH to 18-5/8" casing - 1 - Steelhead Well M-12 ( End of the Well Summary ( shoe. Underream 12-1/4" hole to 17-1/2" from 863' to 1160' with mud losses averaging 2 bbl/hr. 9/29/01 Continue to underream hole to 17-1/2" to 1531'. Mud losses reported as zero. Circulate bottoms up and POOH to 18-5/8" shoe. Re-ream hole to 1531'. Pump 25 bbl sweep and circulate bottoms up, Spot 50 bbl LCM pill on bottom and POOH, RlU to run13-3/8" casing. 9/30/01 Realign rig over stack and continue to R/U to run 13-3/8" casing. Run and land 13- 3/8" casing with shoe at 1515'. R/U and cement 13-3/8" casing with good returns to surface, 10/1/01 RID cement equipment. Prepare to break stack to install upper wellhead section, 10/2/01 Continue with installation of upper wellhead section and N/U of 16-3/4" BOP. 10/3/01 Finish N/U of BOP and test BOPE, Change out Annular Element. 10/4/01 Finish installation of new Annular Element. Test BOPE to 250 psi low and 3000 psi high OK. M/U 12-1/4" BHA. RIH 1430', Drill float equipment, rat hole and 11' of new hole to 1542'. Circulate bottoms up and perform a 13,5 ppg emw formation integrity test. Directionally drill 12-1/4" hole from 1542' to 1626' with 9.2 ppg gel mud. 10/5/01 Continue to directionally drill 12-1/4" hole from 1626' to 2522' with 9.3 ppg gel mud while surveying with MWD and LWD, 10/6/01 Continue to directionally drill 12-1/4" hole from 2522' to 3770' with 9.5 ppg gel mud while surveying with MWD and LWD, 10/7/01 Continue to directionally drill 12-1/4" hole from 3770' to 5530' with 9.5 ppg gel mud while surveying with MWD and LWD, CBU and prepare to POOH to change BHA configuration, 10/8/01 POOH working pipe as required. Start to M/U new 12-1/4" BHA assembly. 10/9/01 Finish M/U BHA and RIH to 5530', Circulate bottoms up. Drill 12-1/4" hole from 5530' to 5589'. Start loosing 5 bbl/hr mud to the hole with mud weight at 9.4 ppg, Mix and pump LCM and reduce losses to less then 3 bbl/hr. Continue drilling from 5589' to 6047' with minimal losses, 10/10/01 Drill 12-1/4" hole from 6047' to casing point at 6568' with losses ranging up to 12 bbls/hr. Continue to treat hole with LCM. Circulate bottoms up and then mix and pump 30 bbl LCM pill at 6568'. POOH to 5350'. 10/11/01 Continue to POOH. Change upper rams to 9-5/8" and install test plug. Start BOPE test. 10/12/01 Finish BOPE test. Rig up casing crews and hole pre-job safety meeting. Run 9-5/8" casing to 3150'. - 2- ~ Steel head Well M-12 . End of the Well Summary .,' ,,/ \ 10/13/01 Continue to run 9-5/8" casing. P/U casing hanger and land hanger washing the last joint down, Break circulation and circulate while RlU cement unit. Mix and pump 10.5 ppg mud push followed by 248 bbls 11.8 ppg lead and 155 bbls tail cement. Maintained good returns while mixing and displacing cement. Bumped top plug with 2500 psi and had no flow back. RID casing and cement equipment. Change top pipe rams to 5". 10/14/01 Test BOPE equipment with Mr. John Spaulding as the witness. P/U 5" drill pipe. M/U 8-1/2" BHA. 10/15/01 RIH with BHA to 6386'. Test 9-5/8" csing to 3000 psi for 15 minutes. Drill out float equipment, rat hole and new hole to 6578'. CBU and conduct FIT to 13.2 ppg EMW. Drill 8-1/2" hole from 6578' to 6983' with 9.3 ppg gel mud. 10/16/01 Drill 8-1/2" hole from 6983' to 7305'. CBU, flow check and POOH for bit change. M/U new bit and change out MWD, 10/17/01 Finish making up new BHA. RIH to 7305'. Drill 8-1/2" hole from 7305' to 8055' with 9.3 ppg gel mud, 10/18/01 Continue to directionally and rotary drill 8-1/2" hole from 8055' to 8932' with 9.4 ppg gel mud, 10/19/01 Drill 8-1/2" hole from 8932' to 9093'. CBU, flow check and POOH for bit change. M/U new bit and RIH to 9-5/8" casing shoe. Slip and cut drill line. Continue in hole to 9093'. Drill 8-1/2" hole from 9093' to 9192' with 9.4 ppg gel mud. 10/20/01 Directionally and rotary drill 8-1/2" hole from 9192' to 9808' with 9.4 ppg gel mud. 10/21/01 Directionally and rotary drill 8-1/2" hole from 9808' to 10403' with 9.5 ppg gel mud. CBU, flow check and POOH to 7799'. 10/22/01 Continue to POOH with hole acting tight. M/U new bit and BHA. 10/23/01 Ream in hole working tight spots to 10403' Rotary drill 8-1/2" hole from 10403' to 10680' with 9.4 ppg gel mud. 10/24/01 Rotary drill 8-1/2" hole from 10680' to 10715' (Well TD) with 9.5 ppg gel mud. Pump sweep and circulate hole clean. Flow check and POOH, R/U to make "Mad Pass" with LWD tools. RIH with "Mad Pass" BHA to 5433'. 10/25/01 Run LWD tools to TD, Pump hi-vis sweep at TD, 10/26/01 POOH and download LWD data. Change out bottom pipe rams from 5" to 3-1/2" and test same. R/U to run 3-1/2" tubing liner. M/U and run liner hanger. 10/27/01 Continue to run 3-1/2" liner. Tag hole bottom with liner and P/U 5' off bottom. Break circulation and circulate hole clean. Drop ball and set liner hanger, Release from hanger and proceed to pump 354 bbls (1988 cu ft) of 15,8 ppg cement displaced with 3% KCL completion fluid, Bump plug and pressure test tubing to 4000 psi. Release - 3 - Steelhead Well M-12 ,( End of the Well Summary ;1.' "\ from hanger and set external liner top packer. Circulate +1- 1 0 bbls cement to surface and circulate annulus clean. POOH with 5" drill pipe. 10/28/01 Continue to POOH with 5" drill pipe. R/U to run 3-1/2" tubing tie-back string. 10129/01 M/U 3-1/2" tubing tie-back seals and RIH with GLM's completion tie-back string. Tag top of liner and circulate annulus to completion fluid. Space out and M/U tubing hanger. Land hanger and pressure test tubing and seals to 3000 psi. Release and LID tubing hanger landing joint. Start to N/D BOPE. 10/30/01 Continue to N/D BOPE and perform general clean-up, Install and test X-mas tree to 5000 psi. Function test SSSV. Release rig from M-12. 11/11/01 RIU Coil Tubing unit on well. Test BOP to 40001250 psi. M/U BHA for clean-out run of tubing, 11/12/01 RIH with 2.8" 00 clean-out mill and clean out tubing to 10,695' with filtered sea water. POOH. R/U jet blaster and RIH blasting tubing to a depth of 10695'. Sweep tubing with polymer sweep and circulate clean. 11/13/01 Continue to circulate tubing clean, Displace tubing to a 30/0 KCL completion brine. POOH and RID coil tubing, 12/14/01 R/U Coil Tubing unit on well. Test BOP to 45001250 psi. RIH with 2.8" 00 mill to mill up tubing bridge plug set at 7281'. Proceed to mill up bridge plug. 12/15/01 Continue to mill up bridge plug. POOH to change mills. RIH and mill on bridge plug at 7281' with filtered brine. 12/16/01 POOH with mill. RIH with 2-1/4" pump bailer. Bail and then POOH recovering small amount of metal shavings, M/U new 2.8" 00 mill and RIH. Mill on bridge plug at 7282'. 12/17/01 Continue milling and able to mill up bridge plug. Continue in hole to 10380'. Circulate hole clean and POOH. R/U and run 3-1/2" tubing bridge plug on coil. 12118/01 RIH and set 3-1/2" tubing bridge plug at 10360'. Pressure test bridge plug to 3500 psi. POOH and RID coil tubing unit. R/U electric line crew. RIH and to 10360' with cement dump bailer. Dump bail cement and POOH, 12/19/01 RIH with 2nd dump bailer run and dump bail cement. Estimated Top of cement at 10335'. POOH and wait on cement. 12/20/01 RIH with electric line and perforate 0-16 zone sands from 7953' to 7958' 12/21/01 Continue to perforate 0-16 zone sands from 7914' to 7939'. POOH and RID electric line crew. Well turned over to Production Group, - 4- ANADRILL SCHLUMBERGER Survey report Client........ ..... .... ..: UNOCAL Field......... ..... .... ..: McArthur River Well. . . . . . . . . . . . . . . . . . . . .: M-12 API number... ..... ..... ..: 50-733-20505-00 Engineer... ....... ..... ..: Leafstedt COUNTY: . . . . . . . . . . . . . . . . . . : STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS.... .......: Mason & Taylor ----- Depth reference ----------------------- Permanent datum... .......: MEAN SEA LEVEL Depth reference.. ...... ..: Driller's pipe tally GL above permanent.......: 0.0 ft KB above permanent..... ..: n/a DF above permanent..... ..: 160.0 ft ----- Vertical section origin---------------- Latitude (+N/S-) .........: 0.00 ft Departure (+E/W-). ... ....: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-)... .... ..: -999.25 ft Departure (+E/W-). .......: -999.25 ft Azimuth from rotary table to target: 18.33 degrees 22-0ct-200114:56:36 Spud date................: Last survey date.. .......: Total accepted surveys...: MD of first survey.......: MD of last survey... .....: Page 1 of 5 09-17-2001 21-0ct-01 117 0.00 ft 10340.73 ft ~. ----- Geomagnetic data ---------------------- Magnetic model.... .......: BGGM version 2000 Magnetic date..... .... ...: 20-Sep-2001 Magnetic field strength..: 1107.14 HCNT Magnetic dec (+E/W-) .....: 20.77 degrees Magnetic dip...... ... ....: 73.51 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G..............: H......,......,: Dip....,.......: of G...........: of H...........: of Dip.........: Criteria --------- 1002.03 mGal 1107.14 HCNT 73.51 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees þ-~-- ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 20.75 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 20.75 degrees (Total az corr = magnetic dec - grid con v) Sag applied (Y/N), .......: No degree: 0.00 ANADRILL SCHLUMBERGER Survey Report 22-0ct-200114:56:36 Page 2 of 5 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) lOOt) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 100.00 0.05 184.68 100.00 100.00 -0.04 -0.04 -0.00 0.04 184.68 0.05 GYR 3 200.00 0.01 265.25 100.00 200.00 -0.09 -0.09 -0.02 0.09 190.22 0.05 GYR 4 300.00 0.18 232.11 100.00 300.00 -0.22 -0.18 -0.15 0.24 218.77 0.17 GYR 5 400.00 0.07 338.24 100.00 400.00 -0.31 -0.22 -0.30 0.37 232.72 0.21 GYR 6 454.00 0.16 332.09 54.00 454.00 -0.23 -0.13 -0.34 0.37 249.61 0.17 GYR .-=-, 7 500.00 1.37 340.14 46.00 499.99 0.25 0.45 -0.56 0.72 308.60 2.63 GYR 8 550.00 5.70 347.23 50.00 549.89 2.85 3.43 -1.31 3.67 339.08 8.69 GYR 9 600.00 6.82 344.50 50.00 599.59 7.44 8.71 -2.65 9.11 343.06 2.32 GYR 10 650.00 7.28 337.70 50.00 649.21 12.31 14.51 -4.65 15.23 342.23 1.90 GYR 11 700.00 7.72 318.84 50.00 698.79 16.42 19.97 -8.06 21.53 338.01 4.98 GYR 12 750.00 8.55 301.65 50.00 748.29 18.98 24.45 -13.44 27.90 331.20 5.12 GYR 13 806.00 9.29 293.33 56.00 803.62 20.33 28.42 -21.13 35.42 323.37 2.65 GYR 14 860.00 9.39 292.05 54.00 856.90 21.00 31.80 -29.22 43.18 317.42 0.43 GYR 15 900.00 9.46 288.07 40.00 896.36 21.20 34.05 -35.37 49.09 313.91 1.64 GYR 16 950.00 9.06 296.33 50.00 945.71 21.72 37.07 -42.80 56.62 310.89 2.77 GYR 17 1000.00 8.81 306.53 50.00 995.11 23.47 41.09 -49.41 64.26 309.75 3.20 GYR 18 1050.00 8.93 323.10 50.00 1044.52 26.88 46.47 -54.82 71.87 310.29 5.10 GYR 19 1100.00 9.94 339.39 50.00 1093.85 32.45 53.62 -58.67 79.48 312.43 5.69 GYR 20 1150.00 11.10 351.76 50.00 1143.02 40.11 62.42 -60.87 87.19 315.72 5.06 GYR -,~ 21 1199.00 11.95 359.78 49.00 1191.03 49.14 72.16 -61.57 94.86 319.53 3.70 GYR 22 1291.00 15.31 11.44 92.00 1280.45 70.24 93.60 -59.20 110.75 327.69 4.70 GYR 23 1387.00 19.00 21.36 96.00 1372.18 98.44 120.60 -50.99 130.93 337.08 4,89 GYR 24 1472.20 23.07 23.12 85.20 1451.69 128.94 148.88 -39.37 154.00 345.19 4,83 MWD 6-axis 25 1545.82 24.28 27.07 73.62 1519.11 158.28 175.62 -26.82 177.66 351.32 2,71 MWD IFR 26 1640.53 29.20 30.80 94.71 1603.67 200.11 212.83 -6.12 212.92 358.35 5,49 MWD IFR 27 1735.03 33.33 31.29 94.50 1684.43 247.94 254.84 19.18 255.56 4.30 4.38 MWD IFR 28 1826.75 37.82 29.92 91.72 1759.02 300.07 300.77 46.31 304.31 8.75 4.97 MWD IFR 29 1924.42 42.48 27.61 97.67 1833.65 361.99 355.98 76.55 364.11 12.14 5.01 MWD IFR 30 2012.25 45.11 24.69 87.83 1897.05 422.20 410.54 103.30 423.34 14.12 3.78 MWD IFR ANADRILL SCHLUMBERGER Survey Report 22-0ct-200114:56:36 Page 3 of 5 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 31 2107.12 44.53 25.08 94.87 1964.35 488.63 471.20 131.43 489.19 15.59 0.68 MWD IFR 32 2196.98 45.02 25.84 89.86 2028.14 551.43 528.35 158.64 551.65 16.71 0.81 MWD IFR 33 2292.05 48.67 24.68 95.07 2093.15 620.27 591.07 188.21 620.31 17.66 3.94 MWD IFR 34 2383.94 49.05 23.84 91.89 2153.61 689.10 654.16 216.65 689.10 18.32 0.80 MWD IFR 35 2476.03 48.09 22.35 92.09 2214.54 757.90 717.66 243.73 757.92 18.76 1.60 MWD IFR 36 2569.55 46.17 22.36 93.52 2278.17 826.27 781.05 269.80 826.33 19.06 2.05 MWD IFR ~- 37 2663.68 44.79 23.97 94.13 2344.17 893.14 842.75 296.19 893.29 19.36 1.91 MWD IFR 38 2758.55 45.01 24.44 94.87 2411.37 959.75 903.83 323.65 960.03 19.70 0.42 MWD IFR 39 2854.53 45.32 24.03 95.98 2479.04 1027.46 965.89 351.59 1027.89 20.00 0.44 MWD IFR 40 2949.94 45.67 23.67 95.41 2545.92 1095.18 1028.13 379.10 1095.79 20.24 0.45 MWD IFR 41 3039,56 45.84 23.42 89.62 2608.45 1159.12 1086.98 404.74 1159.89 20.42 0.28 MWD IFR 42 3133.50 46.26 22.99 93.94 2673.65 1226.51 1149.14 431.39 1227.45 20.58 0.56 MWD IFR 43 3226,06 46.64 22.87 92.56 2737.42 1293.37 1210.93 457.53 1294.48 20.70 0.42 MWD IFR 44 3318.00 47.08 22.64 91.94 2800.29 1360.26 1272.79 483.48 1361.53 20.80 0.51 MWD IFR 45 3412.64 46.03 24.12 94.64 2865.37 1428.70 1335.86 510.73 1430.17 20.92 1.59 MWD IFR 46 3505.70 45.02 26.70 93.06 2930.57 1494.59 1395.84 539.21 1496.37 21.12 2.26 MWD IFR 47 3598.19 45.10 27.31 92.49 2995.90 1559.31 1454.17 568.94 1561.50 21.37 0.47 MWD IFR 48 3692.32 45.47 27.34 94.13 3062.13 1625.38 1513.59 599.64 1628.05 21.61 0.39 MWD IFR 49 3784.89 45.46 27.34 92.57 3127.05 1690.55 1572.21 629.95 1693.72 21.83 0.01 MWD IFR 50 3970.82 45.97 27.21 185.93 3256.87 1822.03 1690.51 690.94 1826.26 22.23 0.28 MWD IFR "'-~-., 51 4067.00 46.29 27.13 96.18 3323.53 1890.55 1752.20 722.60 1895.35 22.41 0.34 MWD IFR 52 4160.55 46.81 26.91 93.55 3387.87 1957.68 1812.70 753.46 1963.05 22.57 0.58 MWD IFR 53 4249,53 47.23 26.87 88.98 3448.53 2022.05 1870.76 782,90 2027.97 22.71 0.47 MWD IFR 54 4342.84 47.69 26.89 93.31 3511.61 2090.04 1932.08 813,98 2096.55 22.85 0.49 MWD IFR 55 4531,03 48.54 26.73 188.19 3637.26 2228.61 2057.13 877.17 2236.34 23.09 0.46 MWD IFR 56 4624.04 47.25 25.15 93.01 3699.62 2297.00 2119.17 907.37 2305.25 23.18 1.87 MWD IFR 57 4718.01 47.73 24.52 93.97 3763.12 2365.83 2182.03 936.46 2374.50 23.23 0.71 MWD IFR 58 4814.08 48.80 24.05 96.07 3827.07 2437.13 2247.38 965.94 2446.17 23.26 1.17 MWD IFR 59 4904.55 48.33 23.70 90.47 3886.94 2504.64 2309.40 993.39 2513.99 23.28 0.59 MWD IFR 60 4997.74 46.42 23.97 93.19 3950.04 2572.89 2372.12 1021.10 2582.56 23.29 2.06 MWD IFR ANADRILL SCHLUMBERGER Survey Report 22-0ct-200114:56:36 Page 4 of 5 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 61 5091.65 46.96 24.11 93.91 4014.46 2640.88 2434.53 1048.94 2650.89 23.31 0.59 MWD IFR 62 5188.02 44.74 25.23 96.37 4081.58 2709.60 2497.36 1077.78 2720.01 23.34 2.45 MWD IFR 63 5278.72 45.44 25.37 90.70 4145.62 2773.36 2555.44 1105.23 2784.21 23.39 0.78 MWD IFR 64 5372.98 46.59 25.14 94.26 4211.08 2840.69 2616.78 1134.17 2851.99 23.43 1.23 MWD IFR 65 5467.29 47.21 25.10 94.31 4275.52 2909.07 2679.12 1163.40 2920.82 23.47 0.66 MWD IFR -'- 66 5561.78 46.94 25.48 94 . 49 4339.87 2977.75 2741.68 1192.96 2989.98 23.51 0.41 MWD IFR 67 5657.14 46.80 25.28 95.36 4405.06 3046.81 2804.56 1222.79 3059.54 23.56 0.21 MWD IFR 68 5751.65 46.40 25.42 94.51 4470.00 3114.97 2866.62 1252.19 3128.17 23.60 0.44 MWD IFR 69 5846.22 46.26 25.33 94.57 4535.30 3182.86 2928.42 1281.50 3196.55 23.63 0.16 MWD IFR 70 5940.73 46.11 24.94 94.51 4600.73 3250.57 2990.16 1310.47 3264.72 23.67 0.34 MWD IFR 71 6032.38 45.61 24.48 91.65 4664.56 3315.93 3049.91 1337.96 3330.48 23.69 0.65 MWD IFR 72 6129.74 46.11 24.54 97.36 4732.36 3385.40 3113.48 1366.95 3400.34 23.70 0.52 MWD IFR 73 6221.98 46.06 24.43 92.24 4796.34 3451.46 3173.95 1394.49 3466.78 23.72 0.10 MWD IFR 74 6320.35 45.93 24.15 98.37 4864.68 3521.83 3238.44 1423.59 3537.53 23.73 0.24 MWD IFR 75 6412.51 45.48 24.38 92.16 4929.04 3587.44 3298.58 1450.70 3603.49 23.74 0.52 MWD IFR 76 6502.32 44.79 24.20 89.81 4992.39 3650.75 3356.60 1476.89 3667.15 23.75 0.78 MWD IFR 77 6583.79 46.04 27.46 81.47 5049.59 3708.26 3408.80 1502.18 3725.11 23.78 3.24 MWD IFR 78 6683.95 46.07 31.28 100.16 5119.11 3779.02 3471.63 1537.53 3796.87 23.89 2.75 MWD IFR 79 6777.20 45.81 31.64 93.25 5183.96 3844.28 3528.79 1572.51 3863.30 24.02 0.39 MWD IFR 80 6868.09 45.67 31.22 90.89 5247.39 3907.68 3584.33 1606.45 3927.86 24.14 0.37 MWD IFR ~~ 81 6963.73 45.40 30.94 95.64 5314.38 3974.25 3642.79 1641.69 3995.63 24.26 0,35 MWD IFR 82 7059.87 45.79 29.47 96.14 5381.66 4041.46 3702.14 1676.24 4063.94 24.36 1,17 MWD IFR 83 7154.66 46.02 28.10 94.79 5447.62 4108.40 3761.81 1709.01 4131.82 24.43 1.07 MWD IFR 84 7242.73 45.77 27.45 88.07 5508.91 4170.79 3817.76 1738.48 4194.95 24.48 0,60 MWD IFR 85 7342.60 44.99 27.27 99.87 5579.06 4240.99 3880.89 1771.15 4265.95 24.53 0.79 MWD IFR 86 7436.51 44.25 26.99 93.91 5645.90 4306.17 3939.60 1801.23 4331.84 24.57 0.82 MWD IFR 87 7530.84 44.41 24.67 94.33 5713.39 4371.52 3998.92 1829.95 4397.74 24.59 1,73 MWD IFR 88 7620.08 43.91 24.03 89.24 5777.41 4433.35 4055.56 1855.58 4459.90 24.59 0.75 MWD IFR 89 7715.01 41.98 24.25 94.93 5846.89 4497.69 4114.58 1882.03 4524.57 24.58 2.04 MWD IFR 90 7807.85 36.73 23.44 92.84 5918.65 4556.26 4168.39 1905.84 4583.42 24.57 5.68 MWD IFR ANADRILL SCHLUMBERGER Survey Report 22-0ct-200114:56:36 Page 5 of 5 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 91 7898,32 35.15 21.13 90.47 5991.90 4609.22 4217.51 1925.99 4636.47 24.54 2.30 MWD IFR 92 7997.87 32.25 14.38 99.55 6074.74 4664.38 4270.00 1942.93 4691.26 24.47 4.75 MWD IFR 93 8091.96 30.54 13.24 94.09 6155.06 4713.23 4317.59 1954.64 4739.43 24.36 1.92 MWD IFR 94 8188.76 28.88 13.42 96.80 6239.13 4761.02 4364.27 1965.70 4786.53 24.25 1.72 MWD IFR 95 8279.92 25.19 11.17 91.16 6320.32 4802.22 4404.73 1974.57 4827.07 24.15 4.20 MWD IFR - 96 8376.13 19.34 9.82 96.21 6409.31 4838.32 4440.55 1981.26 4862.49 24.05 6,10 MWD IFR 97 8466.66 13.79 359.97 90.53 6496.07 4863.41 4466.13 1983.81 4886.91 23.95 6,85 MWD IFR 98 8562.61 11.56 338.87 95.95 6589.73 4881.70 4486.55 1980.34 4904.17 23.82 5,32 MWD IFR 99 8655.91 11.17 311.71 93.30 6681.26 4892.51 4501.29 1970.22 4913.59 23.64 5,70 MWD IFR 100 8753.51 12.40 278.04 97.60 6776.91 4894.40 4509.06 1952.76 4913.74 23.42 7.05 MWD IFR 101 8845.69 12.18 269.87 92.18 6866.99 4889.55 4510.42 1933.24 4907.27 23.20 1,90 MWD IFR 102 8940.34 10.87 271.46 94.65 6959.73 4883.80 4510.63 1914.33 4900.04 23.00 1.42 MWD IFR 103 9026.04 11.15 266.11 85.70 7043.85 4878.32 4510.27 1897.98 4893.35 22.82 1.24 MWD IFR 104 9129.68 12.24 262.75 103.64 7145.34 4869.78 4508.20 1877.09 4883.37 22.61 1.24 MWD IFR 105 9226.05 12.51 265.67 96.37 7239.47 4861.35 4506.13 1856.54 4873.59 22.39 0.71 MWD IFR 106 9318.05 12.80 270.89 92.00 7329.24 4854.46 4505.53 1836.42 4865.41 22.18 1.28 MWD IFR 107 9413.15 12.79 284.11 95.10 7422.00 4850.53 4508.26 1815.67 4860.15 21.94 3.07 MWD 6-axis 108 9512.30 12.29 289.74 99.15 7518.79 4849.98 4514.50 1795.09 4858.30 21.68 1.33 MWD 6-axis 109 9605.25 11.24 291.85 92.95 7609.79 4850.78 4521.21 1777.37 4858.03 21.46 1.22 MWD IFR 110 9699.90 10.18 292.04 94.65 7702.79 4851.89 4527.79 1761.06 4858.21 21.25 1.12 MWD IFR ~, 111 9792.10 10.22 291.75 92.20 7793.53 4852.90 4533.87 1745.91 4858.42 21.06 0.07 MWD IFR 112 9886.13 11.99 290.43 94.03 7885.79 4853.76 4540.38 1729.01 4858.44 20.85 1,90 MWD IFR 113 9980.30 11.87 290.26 94.17 7977.93 4854.44 4547.14 1710.76 4858.31 20.62 0.13 MWD IFR 114 10074.41 11.17 292.53 94.11 8070.14 4855.43 4553.99 1693.26 4858.59 20.40 0.89 MWD IFR 115 10166.02 10.39 294.16 91.61 8160.14 4856.92 4560.77 1677.52 4859.50 20.19 0.91 MWD IFR 116 10256.10 10.20 294.58 90.08 8248.77 4858.62 4567.41 1662.86 4860.69 20.01 0.23 MWD IFR 117 10340.73 9.64 295.02 84.63 8332.13 4860.26 4573.53 1649.62 4861.93 19.83 0.67 MWD 6-axis Projected to TD 118 10715.00 9.64 295.02 374.27 8701.12 4867.56 4600.03 1592.83 4868.00 19.10 0.00 MWD Projected { Unocal Alaska ( 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb@ unocal.com UNoCAL€; Beverly Harrison Business Ventures Assistant January 17, 2002 DATA TRANSMITTAL To: From: Lisa Weepie Beverly Harrison 333 W 7th Ave, #100 909 W, 9th Avenue Anchorage, AK 99501-3539 Anchorage, AK 99501 Alaska Oil & Gas Unocal Alaska Transmitting the following: lOGTYPE.:.':.,:.. ... .ISCALE..ILOG'. . .UNTERVAL.lcOPy..IWell . ... . ¡Medium :.\ aO)-d/5 ¡2 AXIS CALIPER ¡5INCH 112/19/2001 10-2156 ¡ 1 NNA-1 ¡Film ¡ ,,~ ¡-¿-AX I ŠMëÃLI p~ËFr^_M_',^"NM~"'."^M'M__",^_"N_.Tir I Nc¡:r-'l^12lf972'õ'0 r'.-rõ:ri 56"^'^,,^^_'M__¡'--'-r"'-']"ÑÑÃ=r"""M""'""_"".' ",."". _..Mr.î3=Gn'e'W.Mwm.,",w",! I, ~. 01 S~~~~Ç~~.~9.~'~.~~~~.~~~,'.,,':,,::','::'::~'.=.~.^t?,.T~.~.8..,..~.'~n.:~!~?!??§~:':,,""T~~~,Þ:~?'~~,,~.~."~::I~":"'.=I.~',,..,,:J'~~i~~~~.~:~~T~~}~9~,~::':',,[~:¡.!:~','~:'.~.:""...,,'~':~,] Jt' ¡ COMPLETION RECORD ¡ 2 INCH ¡ 10/22/2001 ! 4500-6255 ! 1 i Lewis River C-1 RD ¡ B-Line ! ¡ COMPLËfiÖÑ...Ã.ËCORD"......'.....'. \ 2 INCH 12/19/2001........Tg-fáó=Ùi3"1..¿......."...r..........'.f........."!'"rvï":.1.2.........................................'.............:..ä~Un.e.'."..........."'."'1 \It ~'ÃR'ÃÃY.TÑÖÜCTï5Ñ;"'f\fËÜfR5Ñ.......'.l27!rïÑ.cH....".11.õ¡3¡2Òó'1..........."..j..24Õ5=6~ï5Õ.. ..'.......W'. .'...........'.1........'......:..Lewis..Ãiver..c=i.ÃD............1. .ä=U i).e"..........".... ... ....1 5' D ( .. a - ~-Ãr~!~)\Y~I~~U~,!¡ÕÑ:~Ñ.~u!~~Õ~~~J~l~TÑ~~H~]]3Z~,~~lg~~i:~~~:CÕ-?M~w~~="."'~^W_^"L^."W~~:::~~]~~~::~=~~~~~=~~~:~,~=,~:,~~]~,~~:==~=~~::J J ~!~!~~~;;~~~~~~;;~~~~:m1i~-¡I¡I¡i=j:i';1~~~l..~~.t¡i~~~:~~:=.~::::~:il::~:._::~:~1 ! MEMORY pSP PRODUCTION ¡ 2 INCH! 11/18/2001 ; 13244-13984! 1 ¡ K-24RD2 i B-Line ; í"MEMÖÃV'P 815.. .PRÖ'õÙ cfíÖ~r.. ...""T ~f ï Ñ'cH."... r 11/19 ï2ÓÒ f".¡- "1'6 7f5~.1.1.. 4 7 õ"... w¡....w.. .1.... {k= 1.2 RD..."..... -...' T B =Üne...... - .. .". I ~o 1-- I ï lp tëOMPIÊfíÕÑ"í~ËëõRÖ."W".w'^""'-"-"'-!2TÑèH"'~""^!N1I5}:r6õI"".'MW^H.rj650~8020~-~w,"MT".-"w'n,,1:12w,-w.'M..""""'W"^"'-"'Mw"""""TFilm",."""",wMN.".W^ì J" ¡ë'õMP^CËTf(j"N"REC"ÕRï5'"'N.'",,'M'"N,,^~wl^2íNCH"W"""T1Î5¡¿ÕO2W^,W'"-W.T:¡"6.5Õ:ãõ¿õ--^-.",,"'W""T"'" "nvrr2:'.^-"'" ""w",w'N",.ww.^_W^w.'"'.'^""'B:[iñ'eWM'~""~"'M'" . ....... ..,.........,.,...,.........,...."..............,...............'....'..'.............'.....'..............'............................,.....,......,.........,...,.....,...........,........................................................,.........,................................................,......,....,........................,...............,.,..,.,..........,...,...,..."."...'.....'.."..'.............'...........'.....".'..........................,.,.......,.,., RECEIVED Date: AJaska ~, Unocal Alaska ( 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb@unocaLcom UNO CALi> Beverly Harrison Business Ventures Assistant January 17, 2002 DATA TRANSMITTAL To: From: Lisa Weepie Beverly Harrison 333 W 7th Ave, #100 909 W. 9th Avenue Anchorage~ AK 99501-3539 Anchorage, AK 99501 Alaska Oil & Gas Unocal Alaska Transmitting the following: . <:.:>......'.:':." LOG:.TYPE::.-'.. ;'..:. .,....SCALE.. LOG'DATE' lNTERVAL. C .'.:Well...:: .:Medium:: ~ D I j q 3 Ccoo RR RR EE LLAATT II 00 NN LL09GG.""~~"m,".,,,..,-,._,^.,"....^~,t5~ II-NN.""CC ~H'~"'I.J1,J1."'../{11.7Z/(22~"OQ.o0.,.J1'N^"'~\,,^44~'~55_9~66~ ~ 55' o066'"'OQwN""",.-"'.'N"j1'"'!,Pp",Jr"ee".Jt.'t!Y~Cc"~.Mrree'^'.~k^J.Ju,w"J1n)Itt,":,44w"..,w,,+FB.J~L~I"n.'."e"'"""W'---wI,... '--_W_~-',"_.'~-'"~--_..~'-_W" ' .,^,,-"_."^"".M_~.wm~_'_'~~'.._-'~","'..'_W,"-'..~-'.'.';'..."'N,^.'.'M".^,MW'_'W_.Yw_,w._'-'-'.'.~'_'.'~'M'_. . ."..,,; dO/- rì lp RF RECORD ¡5INCH 111/18/2001 10-96 ,1 i M-12 . Film ¡ i.,.,........",.,.....,..................,...,....,.................'......'......."..'.......'....'........................,................1......,...........,..""......."....i,..................,..,.........,....,.,...,.....",.........;..,....:"...,..".",.......,.....m................!........,.......,:.........:.......................,....,....,...................,................................¡.....,:......,.!n~......,...........1 a OJ,. I q 3 tG.Q.B.B.~.bAIJ.9.N...bQG...........,....,..,.....................J.§.J.N.Ç.H.....,...tJ11.?4/?99..1........J.?~.9.Q.:.44.4.9......J,.....J.:.Pr~tty...Çr~.~.k.................,................lfiJ.m...................,......1 1 l~g~~i~~~~~î~:gEJI_",~l&g~jl~i~~ó~lj~~~~í~iij:.:Jj~i~~~gi:.:t:::::F.j!~~~:::1 \.". ,., g,; .;~J;....E. .;. Bf., ç.~.M..§..N. I .,......... .. .,. .... . ..,' J..9... .!. N.Ç,H.,. ,.. ..J..1 J.t 1,.Q.(?QQ .1.,.,.,. J .9.4.9 ,Q:.§§ZZ... ,.. .1. .", ... ... .1... L. Pr ~t!y.. "Ç.r~.~.k.. ...., .,. ,.... ... ... .......... ..W' ,I .,ê.:. b.i.D~.., ,........ .... ¡ l, ~ ~ 0 Î 5 ; T H FiQwv.9J:LIV.?.LN9..""E.~1tg"",,,,"-,,"J§..L~ CJ:LJ!1lJ.§/?_Q.Ql,j,§:!§J27wç9_~~w._,,¡_^J¡.,b~"~!êJ3jy~~LQ -1 BQ,^"jf i I ~,.."",""'m^,.~.'¡ ~ ,THROUGH TUBING PLUG is INCH 111/15/2001 i 5450-6038 . 1, Lewis River C-1 RD ; B-Line I "-_'__~_M_'."MW^""""."'."_.WN'._.'.M"'._N.'W.'~.'W^'."M..'......, ."^'.'._M.'~"'_"^"'" "...,"..."-,,,,"'^.,"'."'._"M".'MW.."'^,'.'^'~"'-_W._~"..._.,"",..,.^,."._",~.'.^""...",...'M..,.'_.^"'M.""".,".."'.w_.w'""'...."""M"~_"W'*"'_W.'.,.wM.'.."NN~^.'..^.'......^" ~Ol-Iíip !PDCLOG 5 INCH 11/18/2001 10-96 . .'JiM-12 .......... .... ¡Film. .! 1 !.'.'p'tfc..'.'Io"'.'.Q'.'.".."...'..".'."^.'......,...,........,.,...'.,..,..,.....,....,.........,..".....'...."..-'1..5 INCH i.11/.'1.8'...'/"2ÕO1'.."'..'i..'.Õ=ii6'............................'...."......i."'...1l.'.M.:f2.....'."."'..."'.'...'...."..fï3=Lin.ë"."'.."'1 .....) ""Äë"K.Ë'.Ff.Ñ.:2'äRi.ÕGi~"pLLiG.w.w.'..!!5'.'.rÑcH'.."I'1'1723Î2ÖÕr"','91'9Õ':'fõ6'1'^i5'¡....'.....1.1.fv1:'1'2...'..'.'.......'...'.."'....'..........."..'..,..... Fi 1m! ê.ð.Ç,K. .ê.B N .:g.. ê.ôIþg..:g:.:: Þ"b"QG::..::.:'::r $:.J N:ç:H .::: r i jig~lgÞ.Þ:i:: :::..1 ~:f~ Þ: ~j: 9:$1:. $:::r.::::: ::j. '. &Ei: :?::::,:::::: :... ... ::.~.. :.::.::.:::.::..:.::. ::: :.:, :... í ê:~ ÇfO:~:: ',::::. ::.:J RECEIVED one copy of this transmittal or F~ð~olß~~8. Alaska 0;1 & Gas Cons Comm- n Date: 'IWI I' ( l 7~ t:',i"" 6~ $ eo/).s z. 7 ¡; - 7 S-lt G Alask(. )gion Domestic Production P.o. Box 196168 Anchorage AK 99519-6168 Telephone 907/561-5311 November 19,2001 Geologic Materials Center 18205 Fish Hatchery Rd, Eagle River, AK 99577 A TTN : John Reeder LETTER OF TRANSMITTAL Hand Delivered RE: Marathon Steelhead Dear Mr. Reeder 115~ Mi- L L. Enclosed are the following samples collected for Marathon's Steelhead Well M-12. Steelhead Well M-12 ~. - Dry Samples Depth From Depth To (Feet) (Feet) Box No. 471 1610 1 1610 3080 2 3080 4640 3 4640 6200 4 6200 7740 5 7740 9600 6 9600 10710 7 Enclosed are the following samples collected for Marathon's Steelhead Well M-4 Depth From (Feet) 1473 2440 Box No, 1 2 ----- 4210 5410 A subsidiary of USX Corporation ;).O~~ / 7G . j1- /)! L <{ tV tlV M~\ ~.D~ Environmentally aware for the long run. Re: M-12 Perforating & plugback sequencing ~ ( Subject: Re: M-12 Peñorating & plugback sequencing Date: Fri, 16 Nov 2001 12:22:55 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Smetanka, Jeff W' <smetankaj@unocaLcom> dO\- \'l ~ Jeff, Thanks for your note following up our conversation. You are correct in your assessment of the plugging requirements. Given the proximity of the lower zones, isolation with a bridge plug between the zones is acceptable. Given the longer interval between the F5A and the 0-16 placing the proscribed 25' of cement is appropriate. 20 AAC 25.112 (i) allows the commission to approve a variance to the plugging requirements if the variance provides for at least equally effective plugging of the well and prevention of fluid movement into sources of hydrocarbons or fresh water. Your plan is acceptable. Hope you aren't in plugging mode soon. Tom Maunder, PE Sr. Petroleum Engineer AOGCC "Smetanka, Jeff W' wrote: > Tom, > > Thanks for your time today in discussing the plugback sequencing on the new > Steelhead gas well M-12. As we discussed, Unocal commingles many of the > individual Grayling Gas sands in its producing gas wells, Unocal set this > well up as a monobore to enable us to commingle sands and to isolate wet > sands with either a bridge plug (if the bottom sand) or a through-tubing > type isolation assembly (if a middle sand). > > As per our conversation today, Unocal intends to perforate the first sand > (GaS) in the next few days. If the zone tests wet, we propose setting a > bridge plug with electric line no more than 50' above the perforations to > isolate. The proposed bridge plug would be the Baker N-2 which is rated for > 10,000 psi differential (product information from Baker attached). We would > then perforate the next zone up in the well. We request commission approval > for this procedure for the following sands: > > GaS >GO3 >GO1 > > We also intend to perforate and test the F5A. Estimated perforation > interval is as follows: > F5A 9460 - 9474 > If this zone tests wet or after gas is depleted, we would isolate the > perforations with the N-2 bridge plug set with electric line no more than > 50' above the perforations. In addition, we would dump bail 25' of cement > on top of the plug. A pressure test of the plug will be conducted by > pressuring up with sales gas to 1200 psi (compressor limited) and holding > for 15 minutes, > > The final zone to complete in the liner portion of the well is the 016 sand. > The intended perforation interval is as follows: > 016 7920 - 7962 > > Please send me a note back to confirm your grant of a variance to the > standard plugging requirements or if you have further questions on this > request. > > Thanks and regards, > Jeff Smetanka 10616 - 10521 10530 - 10550 10406 - 10410 1 of2 11/20/01 4:56 AM Re: M-12 Perforating & plugback sequenc!Jq .~. ( > 263- 7622 > > «N-Bridge Plugs4118_3.pdf» > > ----------------------------------------------- > > > ~. Name: N-Bridge Plugs4118_3.pdf N-Bridge Plugs4118_3.pdf Type: Acrobat (application/pdt) Encoding: quoted-printable '.. ..".""..".".'.' .....,.......,...,.....-.........,.-.-...... Tom Maunder <tom_maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of2 11/20/01 4:56 AM { Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb@unocaLcom .f ~ UNoCAL(i Beverly Harrison Business Ventures Assistant November 14, 2001 DATA TRANSMITTAL To: . From: Lisa Weepie Beverly Harrison 333 W 7th Ave, #100 909 W, 9th Avenue AnchoraQe, AK 99501-3539 Anchorage, AK 99501 Alaska Oil & Gas Unocal Alaska Transmitting the following: I LOG TYPE ,VISION DENSITY NEUTRON TRUE I VERTICAL DEPTH IviS¡ÖN..ÖËNSifvNEÜTRÖN.TRÜË ..... I VERTICAL DEPTH !vfSìõÑ'Ã'EšfsrTvìT'lKíiÊÃSURE'Öww. . : DEPTH l.viš'ìõÑ"RE'šT§iYivTT'7TRÜË... ...........w,ww....:¿J§TÑÔR..ww,....... ...Y~BIlg~~q~~Tt!~..... ...'.... .. VISION DENSITY NEUTRON 'MEASURED DEPTH IViS-¡ÖNRESfS-Yi\iïTVBÓREHóLË..... ......'.¿jsINCR..... .I..P.'39.~.I..~.~..~9.§...~..ty1.P............................ ........... ... ITCP CORRELATION GR/CCL I SCALE I LOG I INTERVAL [ÇQ] Well I Medium I .2/5 INCH 9/27/2001 .480-10715 1 . TBU M-12 ! B-Linel ~D /....1 Î l.tJ : 2/5 INCH!8/¿5ï2ÖÖ1lÒ~6690 ..1:TSÜM~14RÖ. ,B-Line 'a DJ- J I J ¿/S..I NCH ............W, W.1 8/2572(501 10=6690 .....'M.. .....w....... .........'..........."riYBÜtv1:1~iRB....... ..........f§:.Liñè......'.w. I ..............,...,...............,.,.w. ..................w..........i'...'w,....w.........,........................w..............w......... .....w.w..'.... ..........................W..'W..'.........................,......................,...,.,......,.....,...,....w............w.,..,..w. i 8/25/2001 : 0-6690 1 : TBU M-14RD ; B-Line ,., .' !¿jSiNCR.....i,àï2SI¿ÖÖ1'0:669Ò.. . ...1IfBÜM.:1'4Rbï3:Une ..'sINcR. ¡...àï2SI¿OO1,Ö:S69Ò...... .....'........9/6/¿061!3576:4130...... fiTBÜM~1.4ï~Ö.. .'S-Line 1'YBÜM:14RÖ...... ......iFilm.... IYC PÖÖR.RELÄr ï Ö NC3R/CC L...... ...S.ïN.cR..... . . , . ......I....9/6/¿ÓO .1.... 3576:4130.. ............,.......................................................... .................................. 1'TBU M-14RD !B-Line I :CÞsY.SErTING.YoÖC....!KINcRlàï23/¿Ó61!2s9Ó:¿.949 ..1TfBLTM~14 I B-Line I ~~... 06 í !.CÞsT"sEfTiNGTOöc.rsiNÖ.:¡.;aj23/¿ÓÒ1.'2S9Ó:.¿949 11TfBÜM~14 " Film, t i,.ÖÖR:.'RESiSfiVifYMEÄSÙREÖ. .....r.!¿iS¡NCR :9ï27¡¿ÖÒ1!4ào~1071s .... .. .....1ITBÜM~1¿. ,B-Linei.' ~O ../"1l.,ø I DEPTH '."..'" ~-=t;~~~;:;:~ll ! MEASURED DEPTH ' ¡ .:, ,': ~=~--r~mr=~~,~,~610 J- I Î I l' : REPORT . 1 iTBU M-4 ¡PAPER i 19J),-O71 . ..... ......;.............................................RECE1Vt:: D Received b . e receipt by signing and returning one copy of this transmittal or FAX to Date: Alaska Oil & Gas Cons, CommÎssÎorr Anchorage ( It ~1f!ÆVŒ [ffi~ fA\~fA\~[K(!Æ / AlAS KA 0 IL AND GAS CONSERVAnONCO~SSION TONY KNOWLES, GOVERNOR 333 W. "JTH AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (oo?) 276-7542 Dan Williamson Drilling Manager Unocal PO Box 196247 Anchorage AK 99519-6247 Re: Trading Bay Unit M-12 Unocal Pennit No: 201-176 Sur Loc: 4240' FSL and 4822' FEL, SEC. 33, T9N, R13W, SM Btmhole Loc. 3509 FSL and 2697 FEL, SEC. 28, T9N, R13W, SM Dear Mr, Williamson: Enclosed is the approved application for pennit to drill the above referenced well. The pennit to drill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations are made, Annular disposal has not been requested as part of the Pennit to Drill application for Trading Bay Unit M- 12. Your request for an exception to 20 AAC 25.035 (C )(l)(B) to drill 17-112" with a 16" diverter line is granted. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035, Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole, Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Gt-, &Þ-e~' ~~ Cam~chsli TaylorO Chair BY ORDER OF THE COMMISSION D A TED this 11£ day of September, 2001 jj c/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. " ( ( ~1rfA\1rŒ (ID~ fA\~fA\~[\fA\ / / TONY KNOWLES, GOVERNOR ALAS IiA 0 IL AND GAS CONSERVATI ON COMMISSION 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. 228.05 Re: The application of Union Oil Company of California, operator of the Trading Bay Unit (TBU), to drill and complete the TBU M-12 Middle Kenai Gas Pool production well. Mr. Shannon Martin Project Landman U nocal Alaska POBox 196247 Anchorage, AK 99519-6247 Dear Mr. Martin: Your application of August 29, 2001, for a permit to drill and complete the TBU M-12 well r~quires exception to spacing requirements set forth in Rule 1 of Conservation Order No. 228. The drilling and completion of the TBU M-12 well is expected to provide additional gas recovery from the Middle Kenai Gas Pool in the TBU. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling and completion of the TBU M-12 well pursuant to rule 3 of Conservation Order No. 228. ~DO NE a~O(~~~jlQ ~~/ September 7, 200 1. . . '" ~. - - ~. ,/" ð'YV ð - -,.~ Ju.Lt.v M. ~ ¥'¡-I Cammy echsli Taylor Daniel T eamount, Jr. Julie M. Heusser Chair Commissioner Commissioner BY ORDER OF THE COMMISSION .~ iI:')".!" -. ~. .e"~. \j. ..(t A ~~~ ';'-. . . .' -..."s ..,. o.. ~~ ;~. ..::i;~~~" '\.."';"~:i'~i.~t[-<.).. ~. YÃI (.~:. .; II .'t fir-, '\- .". \\ :;. "\' ¡ / 0;),.:.' ).. ~ . ¡-i,i, ï I ',: .\;"7 \ ~ '. '!".'.". , 1 ,.:c. . ¡.:'q . \;,. "lof) "I.;~:,!þ-""""""'/ .,\.,' .... '.,:~;:~i~~.~;~r~:I~.~ ¡.;."?1;::~~,~~~;.~1 .~ o.<-..¿..'?'."~"¡'.:""'.!'.'.'¡'..:"."...'.....;:.:~ M.... .".t:.,:'!.. I " ¿/'. þ.",~,:..~,...",.,."",.,~.,,~ "'11.";."":' .~ C'¡'J...'~"..'..' '.'...... '. . .', ",' ,', ... .!~..,' :...,.,>",... ~ ',"" :..,;~¡ .'~n:..;';:'._"'.<;.f:<~ n ¡ ~'I.~'" ,"".,.".ì i':-;-.."--~ .'~ . ¡'~iU; k:;"::~.;:i.... }::(.;.., þ. J, :."¡ ¡ ..+r.'.."..'?..':4V. 1'1 t'.~,r; .: :.:'.?, J~hr~;¡:~;~§:::~'}~{:1~:}.r¿ ,. J ./.~';j . ... ... . r~!..'.i"..'.'.:;..'....-.i'....'..'.".".. "'...'" . oW.'."." .' ., "..' \~ ,~!g(!ti~:;':;~~.~~;:/ """4.'i"!.'r~'~"..,.;,,'...~{I' '"""'. ~"J.:.~~ ~_:?.,." .:ó;.'.. .O'.:..,...,.,.,.~.:",.."". STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well Exploratory Stratigraphic Test Development Oil Service Development Gas X Single Zone Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool 154' KB to MSL est McArthur River Field 6. Property Designation Grayling Gas Sands ADL-18730 $200,000 15 Proposed depth (MD and TVD) ~M 0 It) I "7:>5: /h..D Lease 3840 acres >' ....,~~TVD :? I 722 7VPýJlt 17. Anticipated pressure (see 20 AAC 25.035 (e)(2) / Maximum Surface 1265 psig. At total depth (TVD) 4082 psig Settina Depth Top Bottom TVD MD TVD 0 480 480 0 850' 850' 0 1 500' 1461 ' 0 6800' 4867' 4679' 10755 8722' ( ( 2>'t /P 1 a. Type of work Drill X Redrill Re-entry Deepen 2. Name of Operator Unocal 3. Address P, 0, Box 196247 Anchorage, AK 99519-6247 4. Location of well at surface 4240' F8L and 4822' FEL Sec, 33, T9N, R13W, 8M At top of productive interval 3079' FSL and 2935' FEL Sec, 28, T9N, R13W, SM At total epth ;2i:l}-l.AÞ ~n' F8L and~ FEL Sec. 28, T9N, R13W, SM 12. Distance to nearest 13. Distance to nearest well property line 692' @ 10523 (M-28) 470' 16. To be completed for deviated wells Kickoff depth 850 feet Maximum hole angle 54.6° 18. Casing proQram size Specifications Hole CasinQ WeiQht Grade CouplinQ LenQth MD exist 28" 133 X-56 Weld 480' 0 24" 18-5/8" 96.8 X-56 DQ E-60 850' 0 17.5" 13-3/8" 68 K-55 Butt 1500' 0 ~'9-5/8" 4 7 N-80 Butt 6800' 0 6" 3-1/2" 9.2 L-80 TKC Butt 4155' 6600' 19. To be completed for Redrill, Re-entry and Deepen Operations Present well condition summary Total depth: measured true verical 7. Unit or Property Name Trading Bay Unit 8. Well Number M-12 9. Approximate spud date 9/12/01 14. Number of acres in property t.ð~ feet feet Plugs (measured) Effective Depth measured true vertical Junk (measured) feet feet ~\)( .ð~,\\ù\ ð... \ ~(, éf)J3 ~ /c / 11. Type Bond (see 20AAC25.025) AK Statewide Oil & Gas Bond Number U 62-9269 Amount Quantity of cement Drive 2257 cuft Class G blend 1625 cuft Class G blend 2096 cuft Class G blend 678 cuft Class G blend Length Cemented Measured Depth True Vertical Depth RECEIV'ED Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Alaska Oil & Gas Cons. Commission true vertical ^ 20. Attach~nts: Filing Fee X Property Plat X BOP Sketch X Diverter Sketch X Drilling Program X "tV' 'V""':;1" /Dr~linQ Fluids PrQ.qr X Time vs. Depth Plot Refraction Analysis Seabed Report 20AAC25.050 Requirements X 21. I he~tp c rtif~ ~a J} e~~ re ~rj/sJ t; ~ ~~f1 correct to the best of my knowledge 4.. / '1 /Jt ~ ) Signedl~ J/(¡( v J::t ,,{fj ,AIV J 'IV¡ ...... Title: Drillina Manaaer Date 0/ (){ v{ / tY / - v Commission Use Only .. Permit Number . / API Number Approval date See cover letter ;2..CJ /.- I 7 <c' 50- 733- -- 2O5"OS: œ q { ~ - 0 \ for other requirements Conditions of approval Samples required Yes @ Mud log required Yes ~ Hydrogen Sulfide measures Yes @> Directional Survey required ~ No Required working pressure forót~na' ~e~ 5M 10M 15M ~~~~~:ved by Cammy Oechs\i Commissioner ~~~~:~~ission Date G.[ ~ - a \ Size Form 10-401 Rev, 12-1-85 ORIGINAL AUG 2 9 2001 Submit in triplicate UNO CALI> ". ( ( STEELHEAD PLATFORM WELL # M-12 Proposed Grass Roots Gas Well KB = 80,15' (KB to Top Conductor flange) 2 18-5/8" @ 850' 13-3/8" @ 1500' 9-5/8"" @ 6800' 3-1/2" @ 10755' SIZE WT 28" 133 18-5/8" 96.79 13-3/8" 68 9-5/8" 47 Liner 3-1/2' Tubin!! 3-1/2" 9.2 CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM X-56 Drive 74' -448' X-56 DQ E-60 74' 850' K-55 Butt 74' 1500' L-80 Butt 74' 6800' 9.2 L-80 10755' Butt-Imp 6600' L-80 6600' Butt-Imp 74' JEWELRY DETAIL 1. 450' 3-1/2" Baker TRSSSV 2. 490' 3-1/2" chem inj mandrel 2a 1093' 3-1/2" GLMs 2a 3. 6600' Interval 3-1/2" seal assembly in top of 3-1/2" liner top ZONE PERFORATION DATA SPF DATE COMMENTS Proposed 7400' -10700'0-12 thru G03 TD = 10755' MD/S722' TVD MAX HOLE ANGLE = 54.6° @ 2400' Well Schematic M-12.doc.doc REVISED: 08/27/01 DRAWN BY: TAB ( { Hazard Analysis Application for Permit to Drill McArthur River Field Steel head Platform M-12 A, In December 1987, the Steelhead Well M-26 blew out which resulted in a fire and explosion which caused extensive damage to the platform. The primary reason for the blowout was due to the unloading of a shallow gas sand at 2040' as the result of an underbalanced wellbore creatined during the pumping of 200 bbls of unweighted water spacer prior the cementing the 13-3/8" casing string, The well programs since that time have incorporated an additional casing String (as mandated by AOGCC Administrative Approval No. 228.1) such that a BOP stack is in place prior to drilling the gas sands which commence at approximately 1500', The well design for M-12 acconts for this extra casing string along with a surface diverter system for drilling to the surface casing point. Additional precautions taken into account to ensure drilling of the shallow gas sands in M-12 can be done in a safe manner are as follows: 1, Cement spacers will be maintained at densities that will prevent underbalancing the wellbore, 2, Mud properties will minimize swab and surge pressures, Trip speed will be monitored to minimize the effects of these pressures, 3. The fluid level in the wellbore will be monitored and not allowed to drop while drilling. 4, Loss circulation material will be available and will be pumped as required, 5. Close supervision will be maintained during each and every trip, 6, Safety meeting will be held prior to the start of all critical operations, B. Gas produced from the Grayling Gas Sands has contained no significant levels of H2S, Although it is highly unlikely that H2S gas could be encountered in this drilling operation, the rig and facility are designated as a H2S facility, and all required safety equipment and procedures for dealing with H2S gas will remain in place in case required, ( ( Hazard Analysis McArthur River Unit Well M-12 c. Well M-12 will be drilled with a 9,2 - 9.4 ppg maximum water base mud. The well is designed to be drilled from 9-5/8" shoe to TO in one bit run which will minimize formation exposure time and thus minimize the risk of such completions as stuck BHA's due to time dependent formations. Lost circulation zones are a concern and will be delt with by the addition of lost circulation material as required. 0, The maximum expected formation pressure that is expected to be encountered will be at the programed well TO of 8722' tvd with a formation pressure of 4082 psi. The maximum potentential surface pressure based on the unlikely event of full casing evacuation with a methane gradent is 1265 psi (reference the attached Anticipated Surface Pressure). 2 Sep. 7,2001 8:27AM UWì~AL CORP, ( ( ~~o,1892 P, 2 Buster, Larry W -Alaska .1 . From: Sent: To; SubJect~ Buster, Larry W -Alaska Friday, September 07, 20m 8:18 AM 'Maunder, Tom M-'2 Permit to Drill Dear Tom, Further to OUf conversatIons with reference to the Steelhead Well M-12 Permit to Drill Applioation, I have addressed the changes and omissions as follows: 1, We and not planning to drill to 18-5/811 casing point with a 24" bit. We would like to drill to casing point @ 850' md rkb wI a 17.1/211 bit and motor assy., POOH and follow-up with a 2611 hole opener. We now feel this will give us better control in steering away from existing conductors/casIng strings. Understand this is an exception to the stated diverter requirements regulations, but feel it is a prudent and safe way to get to casing point. 2. Weare planning to drill a 12-1/411 hole to Intermediate casing point not a 12-1/211 hole. 3. We are plannIng to test the 16-3/411 Stack to 3000 psi high and 260 psi low prior (rams and annular). Thank you for the Input. Regards, Larry W. Buster Advising Drilling Eng;neer Unocal Alaska (907) 263-7804 - Office (907) 263-7884 - Fax (907) 351-6730 - Mob. RECEIVED SEP 7 2001 Alaska Oil & Gas Cons. CommisSIO~ Anchorage 1 ,'.......----.......-...."........"...."........,....,...--...-..--",., " 9,ci - /7 (6 UNOCAL 76 UNOAL ALAS KA RESOURCES , INC. M -12 McARTHUR RIVER FIELD Section 33- T9N -RI3W Cook Inlet, Alaska September 4, 2001 Brian O'Fallon - Sr. Logging Geologist Brady Kilmer- Sr. Logging Geologist Doug Ottke - Logging Geologist Barry Wright- - Logging Geologist � ED la O2 Z013 U EPOCH UNOCAL 76 Unocal Alaska Resources, Inc. M -12 McArthur River Field Cook Inlet, Alaska TABLE OF CONTENTS WELL RESUME 3 LITHOLOGY SUMMARY 4 DAILY CHRONOLOGY 30 MUD RECORD 37 SURVEY RECORD 39 BIT RECORD 43 DAILY REPORTS 45 WELL LOGS APPENDIX 1 €i EPOCH 2 UNOCAL M -12 WELL RESUME UNOCAL ALASKA STEELHEAD PLATFORM M -12 WELL NAME: M -12 FIELD: McARTHUR RIVER REGION: COOK INLET, ALASKA LOCATION: SEC. 33 T9N R13W SM BOROUGH: KENAI BOROUGH STATE: ALASKA ELEVATION: RKB: 100.0' AMSL API NUMBER: #50- 733 - 20505 -00 OPERATOR: UNOCAL ALASKA RESOURCES, INC. Operator Representatives: DOUG NEIHAUS, JIM BENSON Company Geologist: ERIK GRAVEN CONTRACTOR: NABORS ALASKA DRILLING DRILLING RIG: STEELHEAD 51 MUDLOGGING COMPANY: EPOCH WELL SERVICES, INC. Logging Geologists: BRIAN O'FALLON, DOUG OTTKE BARRY WRIGHT, BRADY KILMER MUD COMPANY: M I Mud Engineers: KEITH OLSON, BRYCE MILLER MWD COMPANY: ANADRILUSCHLUMBERGER MWD Engineer: MARTIN XXXXX, XXXX XXXXXXX DIRECTIONAL COMPANY: ANADRILUSCHLUMBERGER Directional Driller: MIKE WARD, MARTY RINKE CEMENT COMPANY: DOWELUSCHLUMBERGER WIRELINE COMPANY: SCHLUMBERGER El EPOCH UNOCAL. M -12 LITHOLOGY SUMMARY CONDUCTOR PIPE TO 18 5/8" CASING DEPTH: 480' TO 870' (DRILL 17 1/2" HOLE AND OPEN HOLE TO 26 ") 520' Coal = black to grayish black to dark brownish gray; moderately firm to slightly firm; brittle; irregular to blocky fracture; massive cuttings habit; dull to moderately shiny luster; sub - bituminous to lignitic grading to carbonaceous material; no visible gas bleeds. 560' Claystone = medium light gray to light brownish gray; mushy consistency; pulverulent to malleable tenacity; irregular to blocky occasionally earthy fracture; dull to earthy with occasionally frosted luster; clayey to silty with occasionally sucrosic texture; massive structure; occasionally mottled with carbonaceous material. 605' Claystone = medium light gray to light olive gray; stiff consistency; crumbly to sectile tenacity; irregular to planar fracture; massive cuttings habit; dull to earthy luster; clayey to silty texture; laminated to massive structure. 645' Sand = medium light gray to medium gray with individual grains translucent to white; quartz framework; fine to very fine grained; well sorted; subangular to subrounded; moderate sphericity; clay matrix grain support common; fair to good estimated porosity. 685' Coal = black to grayish black to dark brownish gray; moderately firm to slightly firm; brittle; irregular to blocky fracture; massive cuttings habit; dull to moderately shiny luster; sub - bituminous to lignitic grading to carbonaceous material; no visible gas bleeds. 725' Sand /Conglomeratic sand = very light gray to light olive gray; very fine to coarse lower and often slightly scattered to locally common coarse to pebble sized grains; subangular to subrounded; moderate sphericity; estimate moderately to poorly sorted with possible locally graded bedding; probable clay matrix; 60 -70% quartz, and 30-40% dark gray to black to translucent to green to white to light brown including mostly siliceous metasediments including chert, minor partially siliceous clay, tuff, and dolomitic tuff; estimate some fair to good porosity and permeability; no oil indicators. 810' Tuff = white to very light gray; soft to firm; subblocky to angular to amorphous; aphanitic to slightly silty texture; lightly speckled carbonaceous matter; slightly siliceous in part; possibly reworked; noncalcareous; grading to and interbedded light to medium gray claystone with slight to locally moderately carbonaceous matter and flakes, some grading carbonaceous shale and coal. El EPOCH 4 UNOCAL M -12 DRILL 17 1/2" HOLE TO 870'. PLUG WITH CEMENT BACK TO 535' AFTER DETERMINE TOO CLOSE TO M -16 WELL. DRILL SOFT CEMENT DOWN TO 638'. BEGIN NEW DATA © 645', AFTER KICK -OFF CEMENT 670 Sand /conglomeratic sand = medium light gray to medium gray; very fine to coarse grains to trace pebble; subangular to subrounded; moderate shpericity; moderately sorted with clay matrix; 70% quartz, and 30% black to translucent to white fragments; estimated fair to good porosity and permeability. 715 Coal = black to dark brownish gray; moderately firm to slightly firm; irregular to blocky fracture; dull to moderately shiny; subbituminous to lignite to peat; no visible glass bleeds. 745 Tuffaceous claystone = medium light gray to light gray; mushy consistency; pulverulent to malleable tenacity; irregular fracture; dull to earthy luster; clayey to silty occasionally sucrosic texture; massive structure. 795 Conglomeratic sand /sand = medium light gray; very fine to pebble, especially medium to coarse grains; subangular to subrounded; moderate sphericity; moderately sorted with probable clay matrix; 65% quartz, and 35% black to gray to white siliceous metalithics; estimate fair to good porosity and permeability. 840 Coal = black to dark brownish gray; moderately firm to slightly firm; irregular to blocky fracture; dull to moderately shiny; subbituminous to lignite to carbonaceous matter. 18 5/8" CASING DEPTH TO 13 3/8" CASING DEPTH: 870' TO 1530' (DRILL 12 1/4" HOLE AND OPEN HOLE TO 17 1/2 ") 885 Conglomeratic sand /sand = medium light gray; very fine to pebble, especially medium to coarse grains; subangular to subrounded; moderate sphericity; moderately sorted with probable clay matrix; 65% quartz, and 35% black to gray to white siliceous metalithics; estimate fair to good porosity and permeability. 930 Conglomeratic sand /sand = medium light gray; very fine to pebble, medium to coarse grains; subangular to subrounded; moderate sphericity; moderately sorted with no matrix visible; 65% quartz, and 35% black to gray to white siliceous metalithics; estimate fair to good porosity and permeability. 975 Coal = black to dark brownish gray; moderately firm to slightly firm; irregular fracture; low grade lignite to subbituminous; no visible gas bleeds. 1015 Ui EPOCH 5 UNOCAL M -12 Conglomeratic sand /sand = medium light gray; very fine to pebble especially medium to coarse grains; subangular to subrounded; moderate sphericity; moderately sorted with possible slight clay matrix; 65% quartz, and 35% black to gray to white siliceous metalithics; estimate fair to good porosity and permeability; no oil indicators. 1065 Tuffaceous claystone = medium light gray to light gray; mushy consistency; pulverulent to malleable tenacity; irregular fracture; dull to earthy luster; clayey to silty texture; massive. 1110 Sand = light gray to light olive gray; fine to coarse lower and rare very coarse to pebble; angular to subangular; moderate sphericity; estimate moderately to poorly sorted in probable slight overall light gray to white tuffaceous clay matrix; 50% quartz, and 50% gray to black to green to dark brown partially siliceous metalithics, lithics, and chert; estimate mostly fair to good porosity and permeability; no oil indicators. 1175 Sand = very light gray to light gray; very fine to very coarse especially medium to coarse lower grains; subangular to angular; moderate sphericity; estimate moderately to poorly sorted with probable slightly overall tuffaceous clay matrix; 65% quartz, and 35% gray to dark gray to white to green metalithics, siliceous lithics, and chert; estimate fair to good porosity and permeability; no oil indicators. 1235 Coal /peat = grayish black to black to dark grayish brown; pliable to slightly brittle to brittle; soft to firm; low grade lignite grading peat including altered plant and tree matter; irregular to subfissile fracture; some clayey grading carbonaceous shale. 1275 Tuffaceous claystone = medium gray to grayish brown to very light gray; soft to slightly firm and soluble; amorphous to subplaty; silty to smooth texture; some slightly to moderately organic including flaky carbonaceous matter and grading to carbonaceous shale; non calcareous. 1320 Sand = medium light gray to light gray; very fine to very coarse especially medium to coarse and slightly scattered pebbles and fragments; subangular to subrounded and occasional bimodal subrounded to rounded; moderate sphericity; estimate moderately to poorly sorted with probable tuffaceous clay matrix; 50% quartz, and 50% mostly gray to black and minor green and trace white grains including partially siliceous metalithics including chert, siliceous lithics, and minor calcareous matter; estimate good to fair porosity and permeability; no oil indicators. 1400 Coal /peat = dark gray to black to dark grayish brown; often scours dark rusty brown; slightly firm to firm; pliable to brittle; low grade lignite to peat including woody remnants; subplaty habit with subplanar fissile fracture. 1435 Sand = medium light gray; fine to coarse lower especially medium grains with rare scattered pebbles and fragments; angular to subrounded; moderate to high sphericity; moderately €l EPOCH 6 UNOCAL M -12 to poorly sorted with probable clay matrix; 60% quartz, and 40% gray to black to light brown to green partially siliceous lithics, metalithics and tuff; possible interbedded light brown tuff; estimate good to fair porosity and permeability; no oil indicators. 1500 Tuffaceous claystone = medium gray to medium light gray; soft and soluble; smooth to slightly silty texture; some with flaky carbonaceous matter as interbedded with coal and peat; slight disseminated mica; noncalcareous. 1535 Tuffaceous claystone = medium light gray to light gray; mushy consistency; pulverulent to malleable tenacity; irregular fracture; dull to earthy luster; clayey to silty texture; massive. 13 3/8" CASING DEPTH TO 9 5/8" CASING DEPTH: 1530' TO 6568' (DRILL 12 1/4" HOLE) 1565 Tuffaceous claystone = medium gray to medium light gray; soft and soluble; smooth to slightly silty texture; some with flaky carbonaceous matter as interbedded with coal and peat; slight disseminated mica; noncalcareous. 1600 Tuffaceous claystone = medium light gray to light gray; mushy consistency; pulverulent to malleable tenacity; irregular fracture; dull to earthy luster; clayey to silty texture; massive. 1645 Tuffaceous siltstone = medium dark gray; sectile tenacity; blocky to irregular fracture; massive cuttings habit; dull to earthy luster; clayey to silty texture; massive with occasional laminations with carbonaceous flakes; non - calcareous. 1710 coal = black to dark brownish gray; mod - erately firm to slightly firm; irregular fracture; low grade lignite to subbituminous; no visible gas bleeds. 1740 Tuffaceous claystone = medium light gray to light gray; mushy consistency; pulverulent to malleable tenacity; irregular fracture; dull to earthy luster; clayey to silty texture; massive. 1770 Tuffaceous claystone = medium gray to grayish brown to very light gray; soft to slightly firm and soluble; amorphous to subplaty; silty to smooth texture; some slightly to moderately organic including flaky carbonaceous matter and grading to carbonaceous shale; non calcareous. 1815 Tuffaceous siltstone = medium dark gray; sectile tenacity; blocky to irregular fracture; massive cuttings habit; dull to earthy luster; clayey to silty texture; massive with occasional laminations with carbonaceous flakes; non - calcareous. 1855 Ell EPOCH 7 UNOCAL M -12 Tuffaceous claystone = medium light gray to medium gray; clumpy to mushy consistency; pulverulent to sectile tenacity; earthy fracture; earthy to dull luster; clayey to silty occasionally gritty texture; massive structure. 1895 Sand /sandstone = light gray to very light gray some with slight greenish hue; very fine to coarse grains especially medium to fine and some graded bedding; locally slight pebble and fragments; estimate moderately to poorly sorted in clay and silt matrix; estimate mostly matrix supported with probable thin interbeds grain supported; 65% quartz, and 35% black to gray to brownish black to rare green to white to brown metalithics and partially siliclay and carbonaceous lithics, trace calcareous cement and lithics; estimate fair to good porosity and permeabiliy in grain supported sand; no oil indicators. 1980 Tuffaceous siltstone = light gray to very light gray to light brown; soft to slightly firm; soluble and moderately hydrophilic; silty to gritty texture; some organic often with flaky carbona- ceous matter; grading to claystone and sandstone; occasionally firm and calcareous grading to tuff. 2025 Conglomeratic sand = light gray to very light gray; coarse to very fine, especially medium to fine; slightly scattered pebbles and fragments; angular to subrounded; estimate moderately to poorly sorted clay and slight silt matrix; estimate mostly grain supported; 65% quartz, and 35% brownish black to gray to rare green and white mostly siliceous metalithics, and partially siliceous clay and carbonaceous lithics; estimate some good to fair porosity and permeability; no oil indicators. 2095 Tuffaceous claystone = medium gray to grayish brown to very light gray; soft to slightly firm and soluble; amorphous to subplaty; silty to smooth texture; some slightly to moderately organic including flaky carbonaceous matter and grading to carbonaceous shale; non calcareous. 2140 Sand = light gray to very light gray; very fine to coarse grains especially medium to fine and some graded bedding; locally slight pebble and fragments; estimate moderately to poorly sorted in clay and silt matrix; estimate mostly matrix supported with probable thin interbeds grain supported; 65% quartz, and 35% black to gray to brownish black to rare green to white to brown metalithics and partially sill -clay and carbonaceous lithics, trace calcareous cement and lithics; estimate fair to good porosity and permeabiliy ingrain supported sand; no oil indicators. 2220 Coal = black to grayish black; brittle tenacity; blocky to splintery fracture; low grade lignite to peat; fissile to flaky structure. 2245 Tuffaceous siltstone = medium dark gray; sectile tenacity; blocky to irregular fracture; massive cuttings habit; dull to earthy luster; clayey to silty texture; massive mostly argillaceous matrix with some visible grains and laminations. €11 EPOCH 8 UNOCAL M -12 2285 Conglomeratic sand = light gray to very light gray; coarse to very fine, scattered pebbles and fragments; angular to subrounded; estimate moderately to poorly sorted clay and slight silt matrix; estimate mostly grain supported 65% quartz, and 35% brownish black to gray to rare green and white mostly siliceous metalithics, and partially siliceous clay and carbonaceous lithics. 2340 Tuffaceous claystone = medium light gray to medium gray; clumpy to mushy consistency; pulverulent to sectile tenacity; earthy fracture; earthy to dull luster; clayey to silty, occasionally gritty texture; massive structure. 2380 Sand = light gray to very light gray; very fine to coarse grains especially medium to fine and some graded bedding; locally slight pebble and fragments; estimate moderately to poorly sorted in clay and silt matrix; estimate mostly matrix supported with probable thin interbeds grain supported; 65% quartz, and 35% black to gray to brownish black to rare green to white to brown metalithics and partially sili -clay and carbonaceous lithics, trace calcareous cement and lithics; estimate fair to good porosity and permeabiliy in grain supported sand; no oil indicators. 2460 Coal = black to grayish black; brittle tenacity; blocky to splintery fracture; low grade lignite to peat; fissile to flaky structure. 2500 Tuffaceous siltstone = medium dark gray;sectile tenacity; blocky to irregular fracture; massive cuttings habit; dull to earthy luster; clayey to silty texture; massive mostly argillaceous matrix with some visible grains and laminations. 2540 Conglomeratic sand = light gray to very ight gray; coarse to very fine, scattered pebbles and fragments; angular to subrounded; estimate moderately to poorly sorted clay and slight silt matrix; estimate mostly grain supported; 65% quartz, and 35% brownish black to gray to rare green and white mostly siliceous metalithics, and partially siliceous clay and carbonaceous lithics. 2595 Coal = black to dark brownish gray; moderately firm to slightly firm; irregular fracture; low grade lignite to subbituminous; no visible gas bleeds. 2620 Tuffaceous claystone = medium light gray to medium gray; clumpy to mushy consistency; pulverulent to sectile tenacity; earthy fracture; earthy to dull luster; clayey to silty, occasionally gritty texture; massive structure. 2660 Tuffaceous claystone = medium light gray to light brownish gray; clumpy to curdy consistency; sectile to malleable tenacity; earthy fracture; dull to earthy luster; smooth clayey texture; massive structure; slightly hydrophylic. L1 EPOCH 9 UNOCAL M -12 2700 Sand = medium light gray; fine to coarse lower especially medium grains with rarescattered pebbles and fragments; angular to subrounded; moderate to high sphericity; moderately to poorly sorted with probable clay matrix; 60% quartz, and 40% gray to black to light brown to green partially siliceous lithics, metalithics and tuff; possible interbedded light brown tuff; estimate good to fair porosity and permeability; no oil indicators. 2765 Coal = black to grayish black; brittle tenacity; blocky to splintery fracture; low grade lignite to peat; fissile to flaky structure. 2790 Tuffaceous claystone = medium light gray to light brownish gray; clumpy to curdy consistency; sectile to malleable tenacity; earthy fracture; dull to earthy luster; smooth clayey texture; massive structure; slightly hydrophylic. 2830 Coal = black to grayish black; brittle tenacity; blocky to splintery fracture; low grade lignite to peat; fissile to flaky structure. 2855 Tuffaceous claystone = medium light gray to light brownish gray; clumpy to curdy consistency; sectile to malleable tenacity; earthy fracture; dull to earthy luster; smooth clayey texture; massive structure; slightly hydrophylic. 2895 Tuffaceous claystone = medium light gray to medium gray; clumpy to mushy consistency; pulverulent to sectile tenacity; earthy fracture; earthy to dull luster; clayey to silty, occasionally gritty texture; massive structure. 2935 Sand = light gray to very light gray; very fine to medium and slightly scattered coarse grains; angular to subangular; moderate sphericity; estimate poorly to moderately sorted with locally graded bedding; probably mostly matrix supported in tuffaceous clay; 70% quartz, and 30% brownish black to black to gray to rare white, green, and light brown partially siliceous coal, clay, carbonaceous, and clay lithics, and metalithics; estimate mostly poor to some fair porosity and permeability; no oil indicators. 3010 Coal = black to brownish black to dark grayish brown; scours dark rusty brown; firm to slightly firm; brittle to crunchy to slightly pliable; lignite; slightly shiny to some earthy luster; irregular fracture; slight very finely disseminated micropyrite; occasionally grading carbonaceous shale. 3055 Claystone = medium gray to light gray to occasionally grayish brown; soft and soluble and hydrophilic; mostly silty to gritty texture; some slightly silty; ocasionally slightly to moderately carbonaceous including disseminated to flaky coal /carbonaceous matter; rare grading carbonaceous claystone and possible thinly bedded coal; grading to and interbedded with very fine to medium grained sandstone and some siltstone; trace calcareous matter and trace micas. €l EPOCH 10 UNOCAL M -12 3120 Sand = medium light gray to light gray; medium to very fine grained and locally scattered coarse to pebble; angular to subangular; moderate to high sphericity; estimate poorly to moderately sorted in clay and some silt matrix; probably mostly matrix supported; 70% quartz, and 30% black to gray to rare green, white, and light brown metalithics and partially siliceous coal and carbonaceous, clay and tuff lithics; estimate mostly poor to some fair porosity and permeability; no oil indicators. 3190 Coal = black to brownish black to dark grayish brown; scours dark rusty brown; firm to slightly firm; brittle to crunchy to slightly pliable; lignite; slightly shiny to some earthy luster; irregular fracture; slight very finely disseminated micropyrite; occasionally grading carbonaceous shale. 3235 Tuffaceous claystone = medium gray to medium light gray, some with brownish hue, to occasionally light grayish brown; soft and soluble and moderately hydrophilic; slightly silty to silty /gritty texture; some slightly to moderately organic including carbonaceous coal matter, grading to and interbedded with coal; some thinly bedded largely matrix supported sandstone and siltstone; trace calcareous matter. 3295 Tuffaceous claystone = medium gray to light gray, often with brownish hue, to light brownish gray; soft and soluble and moserately hydrophilic; slightly to some moderately silty /gritty texture occasionally grading to siltstone and matrix supported sandstone; often slightly to occasionally moderately organic including carbonaceous flakes; occasionaly carbonaceous shale and coal probably thinly bedded; trace calcareous matter. 3360 Tuffaceous claystone = medium gray to medium light gray, some with brownish hue, to occasionally light grayish brown; soft and soluble and moderately hydrophilic; slightly silty to silty /gritty texture; some slightly to moderately organic including carbonaceous coal matter, grading to and interbedded with coal; some thinly bedded largely matrix supported sandstone and siltstone; trace calcareous matter. 3420 Coal = black to some dark grayish brown; firm to slightly firm; moderately brittle to crunchy to slightly pliable; irregular blocky to subplanar fissile fracture; mostly lignite to some sub - bituminous; some grading to carbonaceous shale with low grade flaky coal/ carbonaceous matter; thinly bedded in mostly claystone. 3470 Tuffaceous claystone = medium gray to medium light gray, some with brownish hue, to rare light grayish brown; soft and soluble and moderately hydrophilic; slightly silty to some silty /gritty organic including carbonaceous coal to carbonaceous shale. 3520 Conglomeratic sand = very light gray to light gray; very fine to coarse and scattered very coarse and pebble; subangular to angular; moderate to high sphericity; estimate poorly to moderately sorted in clay and slight silt matrix, some grain supported; 75% quartz, and El EPOCH UH®CAL M -12 25% brownish black to black to some gray and rare brown to green to white mostly siliceous metalithics and lithics estimate some fair to good porosity and permeability; no oil indicators. 3585 Coal = black to some dark grayish brown; firm to slightly firm; moderately brittle to crunchy to slightly pliable; irregular blocky to subplanar fissile fracture; mostly lignite to some sub - bituminous; some grading to carbonaceous shale with low grade flaky coal! carbonaceous matter; massive to thinly bedded. 3635 Sand /conglomeratic sand = light gray to medium light gray; coarse to very fine grained especially fine to coarse, and slightly scattered very coarse and pebble; subrounded to subangular; moderate to high sphericity; estimate moderately to poorly sorted with clay matrix, estimate some grain supported; 65% quartz, and 35% black to some gray to brown to rare green mostly metalithics and some partially siliceous lithics; estimate some fair to good porosity and permeability; no oil indicators. 3705 Sand /conglomeratic sand = light gray to medium light gray; coarse to very fine grained especially fine to coarse, and scattered very coarse and pebble; sub- rounded to subangular; moderate to high sphericity; estimate moderately to poorly sorted with clay matrix, estimate mostly grain supported; 60% quartz, and 40% black to some gray to brown to rare green mostly metalithics and some partially siliceous lithics; estimate some fair to good porosity and permeability; no oil indicators. 3775 Coal = black to brownish black often scours dark rusty brown; slightly firm to firm; moderately brittle to crunchy to slightly pliable; lignite to low grade lignite and some interbedded carbonaceous shale; moderately shiny luster; subplanar fissile partings to irregular fracture. 3820 Conglomeratic sand /sand = light gray to medium light gray; coarse to very fine grained especially fine to coarse, and slightly scattered very coarse and pebble; subrounded to subangular; moderate to high sphericity; estimate moderately to poorly sorted with clay matrix, estimate some grain supported; 65% quartz, and 35% black to some gray to brown to rare green mostly metalithics and some partially siliceous lithics; estimate some fair to good porosity and permeability; no oil indicators. 3890 Conglomeratic sand = very light gray to light gray; very fine to coarse and scattered very coarse and pebble; subangular to angular; moderate to high sphericity; estimate poorly to moderately sorted in clay and slight silt matrix, some grain supported; 75% quartz, and 25% brownish black to black to some gray and rare brown to green to white mostly siliceous metalithics and lithics estimate some fair to good porosity and permeability; no oil indicators. 3955 Coal = black to brownish black often scours dark rusty brown; slightly firm to firm; moderately brittle to crunchy to slightly pliable; lignite to low grade lignite and some interbedded €l EPOCH 12 UNOCAL. M -12 carbonaceous shale; moderately shiny luster; subplanar fissile partings to irregular fracture. 4000 Conglomeratic sand = light gray to very light gray; coarse to very fine, scattered pebbles and fragments; angular to subrounded; estimate moderately to poorly sorted clay and slight silt matrix; estimate mostly grain supported; 65% quartz, and 35% brownish black to gray to rare green and white mostly siliceous metalithics, and partially siliceous clay and carbonaceous lithics. 4055 Conglomeratic sand /sand = light gray to medium light gray; coarse to very fine grained especially fine to coarse, and slightly scattered very coarse and pebble; subrounded to subangular; moderate to high sphericity; estimate moderately to poorly sorted with clay matrix, estimate some grain supported; 65% quartz, and 35% black to some gray to brown to rare green mostly metalithics and some partially siliceous lithics; estimate some fair to good porosity and permeability; no oil indicators. 4125 Tuffaceous claystone = medium light gray to medium gray; clumpy to mushy consistency; pulverulent to sectile tenacity; earthy fracture; earthy to dull luster; clayey to silty, occasionally gritty texture; massive structure. 4165 Sand /conglomeratic sand = light gray to medium light gray; coarse to very fine grained especially fine to coarse, and scattered very coarse and pebble; subrounded to subangular; moderate to high sphericity; estimate moderately to poorly sorted with clay matrix, estimate mostly grain supported; 60% quartz, and 40% black to some gray to brown to rare green mostly metalithics and some partially siliceous lithics. 4225 Tuffaceous claystone = medium gray to grayish brown to very light gray; soft to slightly firm and soluble; amorphous to subplaty; silty to smooth texture; some slightly to moderately organic including flaky carbonaceous matter and grading to carbonaceous shale; non calcareous. 4270 Coal = black to brownish black firm; moderately brittle to crunchy to slightly pliable; lignite to low grade lignite and some interbedded carbonaceous shale; moderately shiny luster; subplanar fissile partings to blocky fracture. 4310 Coal = black to grayish black; brittle tenacity; blocky to splintery fracture; low grade lignite to peat; fissile to flaky structure. 4335 Tuffaceous claystone = medium light gray to medium gray; clumpy to mushy consistency; pulverulent to sectile tenacity; earthy fracture; earthy to dull luster; clayey to silty, occasionally gritty texture; massive structure. 4375 Li EPOCH 13 UNOCAL M -12 Sand /conglomeratic sand = light gray to medium light gray; coarse to very fine grained especially fine to coarse, and scattered very coarse and pebble; subrounded to subangular; moderate to high sphericity; estimate moderately to poorly sorted with clay matrix, estimate mostly grain supported; 60% quartz, and 40% black to some gray to brown to rare green mostly metalithics and some partially siliceous lithics. 4435 Coal = black to brownish black occasional scours dark rusty brown; tough tenacity; splintery fracture; shiny luster; fissile; lignite to low grade lignite; no visible gas bleeds. 4480 Tuffaceous claystone = medium Tight gray to Tight brownish gray; clumpy to curdy consistency; sectile to malleable tenacity; earthy fracture; dull to earthy luster; smooth clayey texture; massive structure; slightly hydrophylic. 4520 Sand = light gray to very Tight gray; very fine to medium and slightly scattered coarse grains; angular to subangular; moderate sphericity; poorly to moderately sorted; predominantly matrix supported in tuffaceous clay; 70% quartz, and 30% black to gray with occasional white and olive pebbles; estimate poor to occasionally fair porosity and permeability; no oil indicators. 4580 Coal = black to brownish black occasional scours dark rusty brown; tough tenacity; splintery fracture; shiny luster; fissile; lignite to low grade lignite; no visible gas bleeds. 4610 Sand = light brownish gray to Tight gray; very fine to fine grains to some medium to coarse and trace pebble; subangular to angular; moderate sphericity; poorly sorted in organic and tuffaceous clay matrix; 70% quartz, and 30% carbonaceous lithics and minor partially siliceous clay, metalithics, and tuff; probably thinly interbedded with carbonaceous claystone and coal; estimate poor porosity and permeability; no oil indicators. 4675 Carbonaceous shale = grayish brown to brownish gray; mostly soft and very soluble to occasionally slightly soluble; smooth to silty /gritty texture; moderately organic with common carbonaceous flakes and interbedded low grade coal; noncalcareous except trace calcareous matter; possible thinly interbedded clayey silts and sands. 4725 Carbonaceous shale = light brownish gray to grayish brown; soft and very soluble; overall slightly silty /gritty texture; moderately to slightly organic; tuffaceous with probable thinly bedded ash fall tuff; common carbonaceous flakes including thin carbonaceous and coal stringers; possible occasional thin silt and sand zones; trace calcareous matter. 4775 Coal = black to brownish black; firm to slightly firm; moderately brittle to slightly pliable; massive lignite to occasionally subbituminous, to flaky low grade lignite in clay grading carbonaceous shale; moderately shiny to dull to earthy luster; subplanar fissle to splintery to irregular fracture. El EPOCH 14 UNOCAL M -12 4820 Sand /sandstone = light brownish gray to very light gray; very fine to coarse grains; subangular to angular; moderate sphericity; very poorly to poorly sorted in tuffaceous and slightly organic clay matrix; matrix supported grading claystone; mostly quartz, some carbonaceous matter and partially siliceous tuff and clay lithics; estimate very poor poro- sity and permeability; no oil indicated. 4875 Conglomeratic sand /sand = light gray to light brownish gray; very fine to coarse grains and slightly scattered very coarse and pebble; subangular; moderate to high sphericity; poorly sorted in very slightly to slightly organic and tuffaceous clay matrix; mostly quartz, some carbonaceous matter, and slight siliceous metalithics and lithics; estimate very poor to some fair porosity and permeability; no oil indicators. 4935 Tuffaceous claystone = light gray to light brownish gray; soft and soluble and moderately hydrophilic rehydrated; slight silty /gritty texture; slightly organic overall; some carbonaceous flakes and coal in sample indicating possible thin carbanaceous coal zones interbedded in claystone; noncalcareous. 4980 Coal = black to occasionally brownish black; moderately firm; moderately brittle to slightly pliable; lignite to subbituminous; slightly shiny luster; subplanar to irregular hackly to subsplintery fracture; massive to thinly interbedded with claystone. 5020 Tuffaceous claystone = light brownish gray to occasionally very light gray; soft and soluble and moderately hydrophilic rehydrated; slightly to some moderately silty /gritty texture including probable thin siltstone to very fine to medium grained sandy zones; occasionally grading ash fall tuff; some coal and carbonaceous matter indicating probable thin coal and caronbaceous zones; slight white calcareous matter. 5085 Tuffaceous claystone = very light gray to light gray to white; soft and soluble and moderately hydrophilic; slightly to moderately silty to fine sandy texture; grading ash fall tuff possibly kaolic; slight coal and carbonaceous matter; possible grading siltstone and sand- stone; slight white calcareous matter. 5130 Tuffaceous claystone = medium light gray to medium gray; clumpy to curdy consistency; pulverulent to malleable tenacity; dull to earthy luster; clayey texture; massive structure; soft, soluble and hydrophilic. 5165 Coal = black to brownish black occasional scours dark rusty brown; tough tenacity; splintery fracture; shiny luster; fissile; lignite to low grade lignite; no visible gas bleeds. 5195 Tuffaceous claystone = medium light gray to medium gray; clumpy to curdy consistency; pulverulent to malleable tenacity; dull to earthy luster; clayey texture; massive structure; soft, soluble and hydrophilic. El EPOCH 15 UNOCAL M -12 5230 Tuffaceous siltstone = medium gray to medium gray, occasionally light brownish gray; pulverulent to malleable tenacity; dull to earthy luster; mostly silty to gritty grading to argillaceous texture; massive structure; carbonaceous flakes common; non - calcareous. 5270 Coal = black to grayish black; brittle tenacity; blocky to splintery fracture; low grade lignite to peat; fissile to flaky structure. 5295 Sand /sandstone = light brownish gray to very light gray; very fine to coarse grains; subangular to angular; moderate sphericity; very poorly to poorly sorted in tuffaceous and slightly organic clay matrix; matrix supported grading claystone; mostly quartz, some carbonaceous matter and partially siliceous tuff and clay lithics; estimate very poor poro- sity and permeability; no oil indicated. 5310 Tuffaceous claystone = medium Tight gray to medium gray; clumpy to curdy consistency; pulverulent to malleable tenacity; dull to earthy luster; clayey texture; massive structure; soft, soluble and hydrophilic. 5380 Conglomeratic sand = very Tight gray to light gray; very fine to coarse and scattered very coarse and pebble; subangular to angular; moderate to high sphericity; estimate poorly to moderately sorted in clay and slight silt matrix some grain supported; 75% quartz, and 25% brownish lack to black to some gray and rare brown to green to white mostly siliceous metalithics and lithics. fair estimated porosity. 5440 Conglomeratic sand = light gray to very Tight gray; coarse to very fine, scattered pebbles and fragments; angular to subrounded; estimate moderately to poorly sorted clay and slight silt matrix; estimate mostly grain supported. 5515 Sand /conglomeratic sand = very light gray to light gray; very fine to medium to slight coarse and trace pebble; subangular to angular; moderately sorted in estimated overall slight clay matrix; 80% quartz, and 20% black to dark brown to trace green partially siliceous coal and carbonaceous and clay lithics, and possible metalithics; estimate mostly fair porosity and permeability; no oil indicators. 5570 Tuffaceous claystone = gray, to some white to light brown; slightly firm; slightly soluble; subplaty; some slightly to moderately organic grading carbonaceous shale; slightly calcareous; interbedded with conglomeratic sand and possibly conglomerate. 5570 Conglomeratic sand = medium light gray to Tight gray; very fine to coarse grain especially fine to medium with slightly scattered to locally common very coarse to pebble; angular to subangular including probable angular fragments in part; estimate moderately to poorly sorted in probable variable clay matrix; 75% quartz, and 25% black to dark brown to gray €l EPOCH 16 UNOCAL M -12 to minor green mostly siliceous coal, carbonaceous clay, and clay Iithics and possible metalithics; estimate mostly fair porosity and permeability; no oil indicators. 5690 Conglomeratic sand = medium light gray to Tight gray; very fine to very coarse, especially fine to medium grains, with scattered pebbles and angular fragments; subrounded to angular; estimate moderately to poorly sorted in probable variable clay matrix; 75% quartz, and 25% black to dark brown to gray to green to white Iithics and metalithics and some angular chert; estimate mostly fair to good porosity and permeability; no oil indicators. 5755 Coal = black to dark grayish brown; slightly firm to firm; pliable to crunchy to slightly brittle; irregular fracture to subplanar; massive to interlaminated with organic claystone; lignite to subbituminous grading carbonaceous shale; dull to shiny luster. 5805 Tuffaceous claystone = light brownish gray to occasionally very light gray; soft and soluble and moderately hydrophilic rehydrated; slightly to some moderately silty /gritty texture including probable thin siltstone to very fine to medium grained sandy zones; occasionally grading ash fall tuff; some coal and carbonaceous matter. 5825 Conglomeratic sand = light gray to very Tight gray; coarse to very fine, scattered pebbles and fragments; angular to subrounded; estimate moderately to poorly sorted clay and slight silt matrix; estimate mostly grain supported. 5860 Sand /conglomeratic sand = very light gray to Tight gray; very fine to medium to slight coarse and trace pebble; subangular to angular; moderately sorted in estimated overall slight clay matrix;80% quartz, and 20% black to dark brown to trace green partially siliceous coal and carbonaceous and clay Iithics, and possible metalithics; estimate mostly fair porosity and permeability. 5885 Sand = medium light gray to light gray; very fine to medium grained with scattered to locally common very coarse to pebble; angular to subangular including probable angular fragments in part; estimate moderately to poorly sorted in probable variable clay matrix; 75% quartz, and 25% black to dark brown to gray to minor green mostly siliceous coal, carbonaceous clay, and clay Iithics and possible metalithics; no oil indicators. 6025 Coal = black to brownish black firm; moderately brittle to crunchy to slightly pliable; lignite to low grade lignite and some interbedded carbonaceous shale; moderately shiny luster; subplanar fissile partings to blocky fracture. no visible gas bleeding. 6050 Tuffaceous claystone = medium Tight gray to medium gray; clumpy to curdy consistency; pulverulent to malleable tenacity; dull to earthy luster; clayey texture; massive structure; soft, soluble and hydrophilic. 6085 €1 EPOCH 17 UNOCAL M -12 Tuffaceous claystone = medium light gray to medium gray; mushy to pasty consistency; pulverulent to malleable tenacity; dull to earthy luster; clayey texture; massive structure; soft, soluble and hydrophilic. 6120 Tuffaceous claystone = very light gray to medium light gray to light brown; soft and soluble and moderately hydrophilic; overall slight silty /gritty texture including silt and to fine sand; some coal and carbonaceous matter in sample possibly occuring as flakes in claystone to thin coal streaks; some clays slightly organic; possibly grading ash fall tuff in part; trace calcareous matter. 6185 Tuffaceous claystone = very light gray to medium light gray to light brown; soft and soluble and moderately hydrophilic; overall slight silty /gritty texture including silt and to fine sand; some coal and carbonaceous matter in sample possibly occuring as flakes in claystone to thin coal streaks; some clays slightly organic to grading carbonaceous shale; possibly locally grading ash fall tuff; trace calcareous matter. 6250 Coal = black to occasionally brownish black; firm to slightly firm; slightly brittle to crunchy; moderately shiny to dull luster; irregular to subplanar fracture; lignite to subbituminous; massive to some interbedded and interlaminated medium to dark brown carbonaceous shale; very slight micropyrite. 6285 Carbonaceous shale = grayish brown to Tight grayish brown; soft and very soluble and moderately hydrophilic; smoth to slightly silty /gritty texture including silt to very fine sand; slight to moderately organic clays and abundant coal and carbonaceous flakes; possible thin beds and streaks of coal; some light gray to white tuffaceous claystone /ash fall tuff; trace calcareous matter. 6355 Tuffaceous claystone = medium Tight gray to Tight brownish gray; soft and very soluble and moderately hydrophilic; smooth to slightly silty /gritty texture including silt to fine sand; occasionally grading siltstone; slightly organic clays overall; some coal and carbonaceous flakes and disseminated matter included in clays to possible thin coal beds and carbonaceous shale; trace calcareous matter. 6405 Coal = black to some brownish black in part; scours black to some dark rusty brown; slightly firm to firm; crunchy to moderately brittle; low grade lignite to subbituminous; very slight micropyrite specs; massive to occasional thin beds and flakes in carbonaceous to tuffaceous claystone. 6435 Tuffaceous claystone = medium Tight gray to very light gray to grayish brown; soft and very soluble; smooth to very slight silty /fine sandy texture; very slightly organic to some grading to carbonaceous shale; abundant coal and carbonaceous matter in sample probably occurring as flakes in claystone and carbonaceous shale to thin coal stringers; noncalcareous. El EPOCH 18 UN ®CAL M -12 6490 Carbonaceos shale = grayish brown to Tight brownish gray; soft and very soluble; smooth to some silty /very fine sandy texture; abundant coal and carbonaceous flakes and cuttings; probable thin coal interbeds and some grading Tight gray tuffaceous claystone and tuffaceus siltstone; trace calcareous. 6590 Sand = light olive gray to medium gray; medium to fine grain size; subangular to subrounded; poorly to moderately sorted; matrix supported in tuffaceous clay; mostly quartz, some metalithics, 75% clear, and 25% black to dark brown to gray to minor green; fair to poor estimated permeability. 6630 Tuffaceous claystone = medium light gray to medium gray; soft to slightly firm; irregular, amorphous cuttings; moderately hydrophillic; clayey to silty texture; non to slightly calcareous. 6620 Sand /sandstone = light gray overall; grains dominantly clear to translucent white; dominantly fine to medium grains, occasional very fine; moderately well sorted; grains subangular to angular; moderate sphericity; predominately unconsolidated with probable clay matrix; 80% quartz, 20% black, green, gray lithics; no oil indicator. 6660 Coal = black to brownish black; firm to moderately hard; brittle to sub - brittle; irregular to conchoidal fracture; tabular cuttings habit; sub - vitreous luster; smooth to matte texture; no visible gas bleeds. 6680 Tuffaceous claystone = medium Tight gray to medium gray; soft to slightly firm; irregular, amorphous cuttings; moderately hydrophillic; clayey to silty texture; non to slightly calcareous. 6695 Sand = overall light gray to light olive gray, individual grains white translucent to transparent, occasionally greenish gray, grayish red; upper fine to lower medium grains, occasionally lower coarse; moderately sorted; angular to subangular; moderate sphericity; estimate poor porosity; predominately unconsolidated 70% quartz, 20% chert, 10% lithics; possible clay matrix w/ some grain supported; no oil indicators. 6765 Coal = black to brownish black, occasinal reddish brown; firm to hard; brittle; irregular to conchoidal fracture; dull to moderately shiny luster; lignitic; no visible escaping bubbles. 6795 Tuffaceous claystone = light gray to medium light gray with light brown secondary hues; slightly soluble to soluble and moderately hydrophilic; clayey to silty texture, occasionally smooth; occasional loose grains disseminated throughout, including angular sands and silt, probably cavings or recirculated matter; slightly to non - calcareous. 6860 �� EPOCH 19 UNOCAL. M -12 Sand /sandstone = overall light gray to medium light gray, individual grains predominantly transparent or translucent white or gray, occasionally green, red, and black; upper fine to lower medium sized grains; moderately well sorted; subrounded to subangular; dominantly unconsolidated; 60% quartz, 30% chert, 30% lithics; no oil indicators. 6940 Conglomerate /conglomeratic sand = medium gray to light brownish gray, individual grains dominantly transparent to translucent white /gray, occasionally greenish gray, grayish red; medium to coarse grained, larger grains often bit impacted on one or more sides; poorly sorted; rounded to angular; 40 to 60% quartz, 20 to 40% chert, 10 to 20% undifferentiated lithics; estimated poor porosity and permeability; no sample flourescence, no cut. 6985 Coal = black to brownish black; tough to brittle; irregular to blocky fracture; tabular to wedgelike cuttings habit; waxy to resinous luster; smooth to gritty texture; no visible gas bleeding. 7010 Tuffaceous claystone = medium light gray to light gray some with light brownish gray hue; very soluble to soluble; slightly to moderately hydrophilic; silty to smooth texture; slight carbonaceous material in matrix; non to slightly calcareous. 7045 Carbonaceous shale = brownish gray to reddish gray to medium gray; moderately firm to soft; sub - brittle to soft crumbly; irregular to blocky fracture; wedgelike cuttings habit; smooth to silt texture; well defined laminations of carbonaceous material. 7100 Sand /sandstone = light gray to medium light gray; fine to upper medium grains; subangular to angular; poorly to moderately sorted; moderate sphericity; 80 %qtz, 10 %chert, 10% green, red, and opaque lithic fragments; no oil indicators. 7150 Conglomerate /conglomeratic sand = medium gray to Tight brownish gray, individual grains dominantly transparent to translucent white /gray, occasionally greenish gray, grayish red; medium to coarse grained, larger grains often bit impacted on one or more sides; poorly sorted; rounded to angular; 40 to 60% quartz, 20 to 40% chert, 10 to 20% undifferentiated lithics; estimated poor porosity and permeability; no sample flourescence, no cut. 7210 Conglomeratic sand = light gray to medium dark gray; medium to very coarse grained with scattered pebbles; poorly to moderately sorted; angular to sub - rounded; moderate sphericity; estimated 70% quartz, 20% chert, 10% various carbonaceous, lithic fragments; impacted abrasion; no oil indicators; poor estimated porosity and permeability. 7310 Coal = black to brownish black; tough to brittle; irregular to blocky fracture; tabular to wedgelike cuttings habit; waxy to resinous luster; smooth texture; trace amber inclusions. LI EPOCH 20 UNOCAL M -12 7300 Tuffaceous claystone = medium light gray to light gray some with light brownish gray hue; very soluble to soluble; slightly to moderately hydrophilic; silty to smooth texture; slight carbonaceous material in matrix; non to slightly calcareous. 7375 Sand = light gray to medium Tight gray fine to upper medium grains tr coarse; subangular to angular; poorly to moderately sorted; moderate shpericity; 70 %qtz, 20 %chert, 10% green, red, and opaque lithic fragments; no oil indicators. 7390 Conglomeratic sand = light gray to translucent; medium to very coarse grained with scattered pebbles; poorly to moderately sorted; angular to subrounded; moderate sphericity; estimated 70% quartz, 20% chert, 10% various carbonaceous, lithic fragments; impacted abrasion; no oil indicators. 7450 Tuffaceous claystone = very light gray to light gray some with light brownish gray hue; moderately soluble; slightly to moderately hydrophilic; silty to smooth texture; slight carbonaceous material in matrix; non - calcareous. 7470 Conglomeratic sand = light gray to translucent; medium to very coarse grained with scattered pebbles; poorly to moderately sorted; angular to subrounded; moderate sphericity; estimated 70% quartz, 20% chert, 10% various carbonaceous, lithic fragments; impacted abrasion; no oil indicators. 7520 Sand = transparent or translucent white or gray, occasionally green, red, and black; upper fine to lower medium sized grains; moderately well sorted; subangular to subround; 80% quartz 10% chert 10% assorted lithics; no oil indicators. 7570 Coal = black to brownish black; tough to brittle; irregular to blocky fracture; scaly to wedgelike cuttings habit; waxy to resinous luster; smooth texture. 7615 Sand = transparent or translucent white or gray, lower fine to upper medium with traces of lower coarse sized grains; moderately well sorted; subangular to subround; 80% quartz 10% chert 10% assorted lithics; no oil indicators. 7600 Tuffaceous claystone = very Tight gray to light gray; moderately soluble to very soluble; slightly to moderately hydrophilic; silty to smooth texture; slight carbonaceous material in matrix; non - calcareous. 7670 Coal = black to brownish black; tough to brittle; occasionally crumbly; irregular to blocky fracture; scaly to wedgelike cuttings habit; waxy to resinous luster; smooth texture. Ell EPOCH 21 UNOCAL M -12 7710 Sand = transparent or translucent white or gray, lower fine to upper medium with traces of lower coarse sized grains; moderately well sorted; subangular to subround; 80% quartz 10% chert 10% assorted lithics; no oil indicators. 7730 Coal = black to brownish black; tough to brittle; irregular to blocky fracture; tabular to wedgelike cuttings habit; waxy to resinous luster; smooth texture. 7760 Tuffaceous claystone = very light gray to light gray; moderately soluble to very soluble; slightly to moderately hydrophilic; silty to smooth texture; slight carbonaceous material in matrix; non - calcareous. 7815 Coal = black to brownish black; tough to brittle; irregular to blocky fracture; tabular to wedgelike cuttings habit; waxy to resinous luster; smooth to gritty texture; no visible gas bleeding. 7840 Tuffaceous claystone = light gray to medium light gray with light brown secondary hues; slightly soluble to soluble and moderately hydrophilic; clayey to silty texture, occasionally smooth; occasional loose grains disseminated throughout, including angular sands and silt, probably cavings 7890 Coal = black to brownish black; tough to brittle; irregular to blocky fracture; tabular to wedgelike cuttings habit; waxy to resinous luster; smooth to gritty texture; occasional visible gas bleeding. 7925 Sand = transparent or translucent white or gray, lower fine to upper medium with traces of lower coarse sized grains; moderately well sorted; subangular to subround; 80% quartz 10% chert 10% assorted lithics; no oil indicators. 7965 Ash fall tuff = white to very light to light brownish gray; soft to slightly firm; soluble to moderately soluble; slightly hydrophilic rehydrated; some slightly carbonaceous to grading carbonaceous shale with possible interbedded coal; mostly silty to grittytexture; grading tuffaceous claystone and siltstone and grading to and interbedded with silty to fine grained sandstone; non calcareous. 8025 Tuffaceous claystone = very Tight gray to light gray; moderately soluble to very soluble; slightly to moderately hydrophilic; silty to smooth texture; slight carbonaceous material in matrix; non - calcareous. 8060 Coal = black to brownish black; tough to brittle; irregular to blocky fracture; tabular to wedgelike cuttings habit; waxy to resinous luster; smooth to gritty texture; occasional visible gas bleeding. Li EPOCH 22 UNOCAL M -12 8095 Sand = light gray to medium gray overall, dominantly transluscent white to clear grains, subangular to angular; moderate sphericity; slight to moderate ashy /clay matrix; poorly to moderately sorted; 80% quartz, 20% green, gray, and black lithics; no oil indicators 8135 Coal = black to brownish black; tough to brittle; irregular to blocky fracture; tabular to wedgelike cuttings habit; waxy to resinous luster; smooth to gritty texture; no visible gas bleeding. 8205 Tuffaceous claystone = gray, to some white to light brown; slightly firm; slightly soluble; subplaty; some slightly to moderately organic grading carbonaceous shale; slightly calcareous; interbedded with conglomeratic sand and possibly conglomerate. 8205 Sand /conglomeratic sand = very light gray to light gray; very fine to medium to slight coarse and trace pebble; subangular to angular; moderately sorted in estimated overall slight clay matrix; 80% quartz, and 20% black to dark brown to trace green; no oil indicators. 8245 Tuffaceous claystone = gray, to some light gray to brown; slightly firm; slightly soluble; subplaty; some moderately organic grading to carbonaceous shale; moderately calc; interbedded with conglomeratic sand. 8280 Sand /conglomeratic sand = very light gray to light gray; very fine to medium to slight coarse and trace pebble; subangular to angular; moderately sorted in estimated overall slight clay matrix; 80% quartz, and 20% black to dark brown to trace green lithics and carbonaceous material; no oil indicators. 8325 Tuffaceous siltstone = light gray to medium gray with occasionally brownish gray; pulverulent to sectile; irregular to blocky fracture; equant to nodular cuttings habit; dull to sparkling luster; silty to gritty texture; intercolated with conglomeratic sand and tuffaceous claystone. 8370 Tuffaceous claystone = gray, to some dark brown to medium brown; slightly firm; slightly soluble; subplaty; some graded to carbonaceous shale; blocky fracture; tabular to wedgelike cuttings habit; dull earthy luster; clayey to smooth texture; thinly bedded with carbonaceous and sand stringers. 8415 Coal = black to brownish black; tough to brittle; irregular to blocky fracture; tabular to wedgelike cuttings habit; waxy to resinous luster; smooth to gritty texture; no visible gas bleeding. 8445 Tuffaceous siltstone = light gray to very light gray; very fine to upper medium grains; subangular to subrounded; moderate sphericity; very poorly to poorly sorted in tuffaceous and slightly organic clay matrix; matrix supported grading claystone; mostly quartz, some carbonaceous matter; estimate very poor porosity and permeability; no oil indicated. L4 EPOCH 23 UNOCAL. M -12 8495 Coal = black to brownish black; tough to brittle; irregular to blocky fracture; tabular to wedgelike cuttings habit; waxy to resinous luster; smooth texture; massive bedding with occasional thin laminated brown carbonaceous shale. 8530 Coal = black to brownish black; tough to brittle; irregular to blocky fracture; tabular to wedgelike cuttings habit; waxy to vitreous luster; smooth texture. 8555 Sand = very light gray to translucent and transparent; very fine to medium grains; subangular to subrounded; moderate sphericity; poorly to moderately sorted; 80% quartz, 20% black carbonaceous lithics, no oil indicators. 8590 Sand /conglomeratic sand = very light gray to transparent and translucent; fine to medium to coarse grain; poorly sorted; subangular to angular to subrounded; moderate sphericity; impact surface abrasion; 80% quartz, 20% chert; no visible hydrocarbons. 8630 Tuffaceous claystone = gray, to some to light gray and white; soft to firm; soluble; subplaty; low to no fracture; tabular to nodular cuttings habit; dull earthy luster; clayey to silty texture; thinly bedded with sand and conglomerates. 8670 Coal = black to brownish black; tough to brittle; irregular to blocky fracture; tabular to wedgelike cuttings habit; lignite to subbituminous; no visible gas bleeds. 8715 Tuffaceous claystone = light gray to medium Tight gray with secondary light brownish gray hues; lumpy to clumpy; soft to firm amorphous cuttings; dull to earthy luster; clayey to silty texture; slight very fine disseminated cabonaceous matter and fine flakes of mica; noncalcareous. 8760 Sand = light gray to medium Tight gray; dominantly fine to medium grains, occasionally very fine and coarse grains and bit impacted granules; fair to moderately sorted; subangular to angular; moderate sphericity; probable clay matrix with some grain supported; 70% quartz, 20% chert, 10% undifferentiated meta lithics and volcanics; no oil indicators. 8810 Tuffaceous claystone = light gray to medium light gray with secondary light brownish gray hues; lumpy to clumpy; soft to firm amorphous cuttings; dull to earthy luster; clayey to silty texture; slight very fine disseminated cabonaceous matter and fine flakes of mica; noncalcareous. 8855 Carbonaceous shale = brownish gray to reddish gray to medium gray; moderately firm to soft; sub - brittle to soft and crumbly; irregular to blocky fracture; smooth to clayey with thin silty €I EPOCH 24 UNOCAL M -12 strings well defined laminations of carbonaceous material; interbedded with siltstone and claystone. 8900 Coal = black to brownish black; brittle to tough; irregular to conchoidal to splintery fracture; tabular to wedgelike cuttings; sub - vitreous to greasy luster; smooth texture; no visible gas bleeding. 9835 Tuffaceous claystone = light gray to medium light gray with light brown secondary hues; slightly soluble to soluble and moderately hydrophilic; clayey to silty texture, occasionally smooth; occasional loose grains disseminated throughout; noncalcareous. 8980 Coal = black to brownish black, occasionally dark reddish brown; firm to moderately hard; brittle to tough; irregular to conchoidal fracture; wedgelike to tabular cuttings habit; sub - vitreous luster; smooth to matte texture; subbituminous; no visible gas bleeds. 9020 Tuffaceous claystone = light gray to medium gray to light brownish gray; slightly soluble to firm; silty to clayey texture; some loose grains trapped in matrix, mostly fine sand, silt and carbonaceous material; non to slightly calcareous. 9075 Coal = black to brownish black, occasionally dark reddish brown; firm to moderately hard; brittle to tough; irregular to conchoidal fracture; wedgelike to tabular cuttings habit; sub - vitreous luster; smooth to matte texture; subbituminous; no visible gas bleeds. 9115 Tuffaceous claystone = light gray to medium gray to Tight brownish gray; slightly soluble to firm; silty to clayey texture; some loose grains trapped in matrix, mostly fine sand, silt and carbonaceous material; non to slightly calcareous. 9155 Sand = light gray to medium gray, very fine to lower coarse to some slightly scattered bit impacted coarse to pebble sized grains; overall dominantly fine to medium grains; subangular to angular; moderate to low sphericity; moderately to poorly sorted; probable ashy /clay matrix; dominantly unconsolidated, rare consolidated cuttings; 75% quartz, 15% chert, 10% undifferentiated lithic grains; estimate poor porosity and permeability; no oil indicators. 9220 Coal = black to brownish black, occasionally dark reddish brown; firm to moderately hard; brittle to tough; irregular to conchoidal fracture; wedgelike to tabular cuttings habit; sub - vitreous luster; smooth to matte texture; subbituminous; commonly grades into and is interbedded with carbonaceous shale; no visible gas bleeds. 9285 Tuffaceous claystone = light gray to medium gray to light brownish gray; hydrophilic; soluble; pasty consistency, sectile tenacity; equant cuttings habit; clayey to silty texture; intercalated silt and sand and overall thinly bedded; non - calcareous. El EPOCH 25 UNOCAL M -12 9325 Sand /conglomeratic sand = very light gray to transparent and translucent; fine to medium to coarse grain; poorly sorted; subangular to subround to subangular; moderate sphericity; impact surface abrasion; 80% quartz, 20% chert; traces of consolidated fine grained sandstone by tuffaceous clay matrix; no visible hydrocarbons. 9375 Coal = black to brownish black; firm to moderately hard; brittle to tough; irregular to scaly and conchoidal fracture; wedgelike to tabular cuttings habit; sub - vitreous luster; smooth to matte texture; subbituminous; commonly graded to carbonaceous shale; no visible gas bleeds. 9425 Sand /conglomeratic sand = very light gray to transparent and translucent; fine to medium to coarse grain; poorly sorted; subangular to subround to subangular; moderate sphericity; impact surface abrasion; 80% quartz, 15% chert 5% undifferenciated lithics and sandstone with tight non - calcareous clay matrix; no visible hydrocarbons. 9475 Coal = black to brownish black; firm to moderately hard; brittle to tough; irregular to scaly and conchoidal fracture; wedgelike to tabular cuttings habit; vitreous luster; smooth to matte texture; possible gas bleeding. 9515 Tuffaceous claystone = light gray to medium gray to light brownish gray; hydrophilic; soluble; pasty consistency, sectile tenacity; equant cuttings habit; clayey to silty texture; intercalated carbonaceous shale occurring locally; non - calcareous. 9555 Tuffaceous claystone = light gray to medium gray to Tight brownish gray; hydrophilic; soluble; pasty consistency, sectile tenacity; equant cuttings habit; clayey to silty texture; intercalated carbonaceous shale occurring locally; non - calcareous. 9595 Sand /conglomeratic sand = white to gray to transparent and translucent; fine to medium to coarse grain; poorly sorted; subangular to angular to subangular; moderate sphericity; impact surface abrasion; 70% quartz, 25% chert, 5% assorted lithics and coal fragments; no visible hydrocarbons. 9640 Coal = black to brownish black; firm to moderately hard; brittle to tough; irregular to scaly and conchoidal fracture; wedgelike to tabular cuttings habit; vitreous luster; smooth to matte texture; some visible gas bleeding from surface. 9680 Tuffaceous claystone = light gray to medium Tight gray, occasionally to light brownish gray; soft to firm, occasionally very firm; dull to earthy luster; clayey to gritty texture, slight disseminated carbonaceous matter; occasionally interbedded with carbonaceous shale and carbonaceous material; non to slightly calcareous. E1 EPOCH 26 UNOCAL M -12 9730 Sand /conglomeratic sand = white to gray to transparent and translucent; fine to medium to coarse grain; poorly sorted; subangular to angular to subangular; moderate sphericity; impact surface abrasion; 70% quartz, 25% chert, 5% assorted lithics and coal fragments; no visible hydrocarbons. 9775 Coal = black to brownish black; tough to brittle; irregular to blocky fracture; tabular to wedgelike cuttings habit; waxy to resinous luster; smooth to gritty texture; no visible gas bleeding. 9805 Carbonaceous shale = brownish gray to reddish gray to medium gray; moderately firm to soft; sub - brittle to soft and crumbly; irregular to blocky fracture; smooth to clayey with thin silty strings well defined laminations of carbonaceous material; interbedded with siltstone and claystone. 9850 Sand = light gray to medium light gray; very fine to medium and occasional coarse grains; subangular to angular, occasional subrounded; moderate sphericity; moderately sorted; 80% quartz, 15% chert; 5% lithics; no oil indicators. 9900 Tuffaceous claystone = light gray to medium gray to light brownish gray; hydrophilic; soluble; pasty consistency; sectile tenacity; equant cuttings habit; clayey to silty texture; intercalated carbonaceous shale occurring locally; non - calcareous. 9940 Sand = light gray to medium Tight gray; very fine to medium and scattered coarse grains; subangular to angular, occasional subrounded; moderate sphericity; moderately sorted with slight overall ashy /clay matrix, with some grain supported; 70% quartz, 15% chert, 15% metas, volcanics, and lithics; no oil indicators. 9990 Coal = black to brownish black; tough to brittle; irregular to blocky fracture; tabular to wedgelike cuttings habit; waxy to resinous luster; smooth to gritty texture; no visible gas bleeding. 10020 Tuffaceous claystone = light gray to medium gray to light brownish gray; hydrophilic; soluble; pasty consistency; sectile tenacity; equant cuttings habit; clayey to silty texture; intercalated carbonaceous shale occurring locally; non - calcareous. 10060 Sand = light gray to medium Tight gray; very fine to medium and scattered coarse grains; subangular to angular, occasional subrounded; moderate sphericity; moderately sorted with slight overall ashy /clay matrix, with some grain supported; 70% quartz, 15% chert, 15% metas, volcanics, and lithics; no oil indicators. 10110 Coal = black to brownish black; tough to brittle; irregular to blocky fracture; tabular to wedgelike cuttings habit; waxy to resinous luster; smooth to gritty texture; no visible gas bleeding. [4 EPOCH 27 UNOCAL M -12 10140 Sand = light gray to medium light gray; very fine to medium and scattered coarse grains; subangular to angular, occasional subrounded; moderate sphericity; moderately sorted with slight overall ashy /clay matrix, with some grain supported; 70% quartz, 15% chert, 15% metas, volcanics, and lithics; no oil indicators. 10190 Sand /conglomeratic sand = white to gray to transparent and translucent; fine to medium to coarse grain; poorly sorted; subangular to angular to subangular; moderate sphericity; impact surface abrasion; 70% quartz, 25% chert, 5% assorted lithics and coal fragments; no visible hydrocarbons. 10235 Coal = black to brownish black; tough to brittle; irregular to blocky fracture; tabular to wedgelike cuttings habit; waxy to resinous to vitreous luster; smooth texture; no visible gas bleeding. 10265 Conglomeratic sand /sand = clear to white and translucent; predominantly unconsolidatedl0% graded to sandstone moderately consolidated by calcareous white ash matrix; fine to coarse grains and medium clasts; poorly sorted; subround to subangular and angular bit breaking on coarse grains; moderate sphericity; impact surface abrasion; dull yellow sample fluorescence with slow streaming bright yellowish gold cut; 1% sample fluorescence; no noted residual ring. 10330 Ash fall tuff = white to very light to Tight brownish gray; soft to slightly firm; soluble to moderately soluble;slightly hydrophilic rehydrated; some slightly carbonaceous; mostly silty texture; grading tuffaceous claystone and siltstone and grading to and interbedded with silty to fine grained sandstone; very calcareous. 10390 Conglomeratic sand /sand = clear to white and translucent; predominately unconsolidated 10% graded to sandstone moderately consolidated by calcareous white ash matrix; fine to coarse grains and medium clasts; poorly sorted; subround to subangular and angular bit breaking on coarse grains; moderate sphericity; impact surface abrasion; dull yellow sample fluorescence with slow streaming bright yellowish gold cut; 1% sample fluorescence; no noted residual ring. 10430 Tuffaceous claystone = light gray to medium gray to Tight brownish gray; hydrophilic; soluble; pasty consistency; sectile tenacity; equant cuttings habit; clayey to silty texture; intercalated carbonaceous shale occurring locally; non - calcareous. 10510 Coal = black to brownish black; tough to brittle; irregular to blocky fracture; tabular to wedgelike cuttings habit; waxy to resinous to vitreous luster; smooth texture; no visible gas bleeding. 10525 El EPOCH 28 UNOCAL M -12 Conglomeratic sand /sand = clear to white and translucent; predominately unconsolidated 10% graded to sandstone moderately consolidated by calcareous white ash matrix; fine to coarse grains and medium clasts; poorly sorted; subround to subangular and angular bit breaking on coarse grains; moderate sphericity; impact surface abrasion; dull fluorescence; no cut. 10555 Coal = black to brownish black; tough to brittle; irregular to blocky fracture; tabular to wedgelike cuttings habit; waxy to resinous to vitreous luster; smooth texture; no visible gas bleeding. 10555 Tuffaceous claystone = light gray to medium gray to light brownish gray; hydrophilic; soluble; pasty consistency; sectile tenacity; equant cuttings habit; clayey to silty texture; intercalated carbonaceous shale occurring locally; non - calcareous. 10665 Coal = black to brownish black; tough to brittle; irregular to blocky fracture; tabular to wedgelike cuttings habit; waxy to resinous to vitreous luster; smooth texture; no visible gas bleeding. TOTAL DEPTH: MD: 10,715'; TVD: 8,701' EE EPOCH 29 UNOCAL. M -12 DAILY CHRONOLOGY 09/14- 17/2001: 470 -500' Epoch arrived on location 12:20 pm on September 14, 2001, and commenced rig up. Epoch logged on September 17, 2001, when rig tagged junk above pile shoe on conductor pipe at approximately 470'. Rig drilled ahead, rotating, from 470' to 500' with clean out assembly. Worked pipe and circulated out, and tripped out of hole. Made up landing joints and hanger, drifted with riser, and laid down landing joints and hangar. Worked on riser. Made up directional BHA #2 with same 17'/z" bit #1 while removing 26" hole opener. Ran in hole, oriented BHA with gyro, and washed from 488' to bottom at 500'. 09/18/2001: 500 -870' Drilled ahead from 500' to 579', and took gyro survey. Drilled from 579' to 772', and power failed. Restored power with back -up generator and circulated at 50 spm. Restored power on main generator and drilled from 772' to 846', picked up single, and drilled from 846' to 870'. Pumped high viscosity sweep. Pulled out of the hole. Picked up BHA #3, ran in the hole with heavy weight drill pipe to 460'. Circulated. Pulled out of the hole. 09/19/2001: 870 -535' Finished pulling out of hole and worked BHA #3. Made up cement head and cement assembly. Ran in hole to bottom and circulated hole clean, maximum 35 units of gas. Pumped 100 barrel cement plug and displaced with 6 barrels of drilling mud, 1 -2 units of gas. Pulled out of hole to 564' and circulated, washing cement from drill pipe; maximum 12 units of gas. Pulled out of hole and rigged down cement assembly and drained stack. Made up landing joints and casing hangar and drifted surface stack. Serviced rig and made up directional BHA #4. Cut and slipped drill line. Reinstalled flow line. Rigged up gyro. Ran in hole to 535', tagged cement. Pulled out of the hole to 494'. 09/20/2001: 535 -763' Washed to bottom 494' to 535', and drilled ahead, sliding, through soft cement from 535 -638', unable to kick off cement. Pulled out of hole to 494', and rigged down side entry sub. Pulled out of hole to 404', and waited on cement. Ran in hole to 581', and rigged up side entry sub. Ran in the hole to 638'. Drilled from 638' to 646', through cement. Worked pipe from 646' to 616' attempting to trench side of hole. Slid from 646' to 656' controlled drilling at 2 feet per hour. Slid from 656' to 710', circulated and ran survey. Pulled out of the hole to 583', and removed side entry sub and tool. Ran to bottom at 710', and drilled ahead, rotating, to 740'. Circulated and surveyed and reinstalled side entry sub at 730'. Drilled ahead, rotating, from 740' to 763'. 09/21/2001: 763 -870' Drilled ahead, sliding, from to 763' to 780', ran survey and rigged down side entry sub. Drilled ahead, rotating, from 780' to 820', circulated bottoms up survey. ran . Drilled ahead Y to 845', circulated, and ran survey. Drilled ahead to 870', casing depth, circulated sweep and pulled out of the hole. Worked BHA #4, and picked up and ran in with hole opener Li EPOCH 30 UNOCAL M -12 assembly, BHA #5. Ran in hole with heavy weight drill pipe to 396', and serviced top drive. Tripped in to below conductor shoe at 500', and began opening 17'/2' hole to 26 ". Opened hole from 500' to 870', maximum 178 units at 768' and averaged 25 units of gas. Circulated sweep around, short tripped to shoe, tagged bottom, no fill. 09122/2001: 870' Pumped sweep and circulated around, and spotted LCM pill on bottom. Pulled out of hole and laid down hole opener assembly. Rigged up and ran in hole with 18 5/8" casing. Landed casing and rigged down GBR. Ran in hole with open ended 5" drill pipe. Rigged up to circulate. Circulated and swept hole clean for cement. Swapped over to tail cement (dowel having problems). Pumping tail 15.8 with dowel. Pulled out of the hole breaking every joint to wash cement. Picked up floor and flushed lines and riser. 09/23/2001: 870' Nipple down diverter lines and short BOP and begin rigging up for BOP stack. Take short riser off, brought it up into the upper well bay. Moved surface hydrill back and secured. Took flange off riser. 09/24/2001: 870' Continue rigging up for BOP stack. 09/25/2001: 870' Continue working on BOP stack. 09/26/2001: 870' Continue working on BOP stack. 09/27/2001: 870' Installed flowline and tightened turnbuckles. Hammered up fill line and bled off line. Hooked up and secured accumulator lines. Installed valve on annulus in well room. Tested BOP's, choke manifold, choke valve, HCR, and kill valves. Stood back HWDP and pulled up wear ring. Tried to put wear ring in place. Nippled down bell nipple. 09/28/2001: 870 -1011' Grind to allow wear ring to pass through bell nipple. Run in hole with wear ring, stand back test joint, and nipple up bell nipple and flowline. Pick up and run in hole with BHA #6 with new 14 3 /4" bit #4 and 17 °/2" under reamer. Run in hole with heavy weight drill pipe to 810', and test casing. Drill cement, float and shoe down to 870', maximum 162 units of gas bottoms up after begin circulating. Drill formation from 870' to 882' and test, 12.2 EMW. Trip out of hole, work BHA #6, and pick up and run in hole with steerable BHA #7 E4 EPOCH 31 UNOCAL. M -12 and new 12.25" bit #5. Test MWD and run in hole with heavy weight drill pipe. Ran in the hole. Slid from 882' to 1004'. Rigged up to run gyro. 09/29/2001: 1011 -1530' Drilled ahead from 1011 to 1157', taking MWD surveys and running gyros at connection. Lost returns at 1157', pumped LCM and monitored well from trip tank. Drilled ahead from 1157' to 1530', taking MWD surveys and running gyros at connections, discontinuing MWD surveys after 1283'. Pumped sweep and circulated out and pulled out of the hole. Spotted LCM at 1150. Continued pulling out of the hole (wet). Laid down BHA #7. Pick up BHA #8. Ran in the hole. Reamed 12.25 to 17.5 with under reamer from 863' to 1170'. 09/30/2001: 1530' Opened hole from 1170' to 1530', averaging 82 feet per hour and 45 units of gas, maximum 189 units. (Note: averaged 100 feet per hour from 863' to 1530'). Pumped sweep and circulated out. Pulled out of hole to shoe, and washed and reamed from 863' to 1530', averaging 1213 feet per hour and 25 units of gas, maximum 61 units. Pumped sweep and circulated out. Pumped pill and pulled out of the hole. Rigged up to run 13 3/8 casing. Pull up landing joint and made a test run. Laid down landing joint and fill stack. Ran guide shoe joint. Took off centralizers. Run in the hole with 13 3/8 casing to 788.2 (19 joints). 10/01/2001: 1530' Casing hung up due to BOP malfunction. Worked on BOP and loosened casing. Laid down two joints of casing. Continued to run in with casing to bottom, 2 to 8 units of gas from mud displaced over shakers while running in. Landed casing at 1519.08. Rigged up cementers, began cementing, dropped plug at 23:15. 10/02/2001: 1530' Flushed dowel) unit and cement lines to rig. Cleaned shakers and tanks. Set up pump and hoses to pump out landing joint. Opened valve on cement head. Monitored casing for flow. Split stack between mud x and double gate. Sucked out risers down to hanger. Pulled mud x, single gate and both risers with blocks. Took off drilling adapter, put on drilling head. 10/03/2001: 1530' Built volume in the mud pits. Nippled up spool, DSF, riser and single gate. Nippled up double gates and hydril to mud x. Set BOP and tightened bolts. Bell nipple, would not fit; had to cut 12" out of it. Hooked up and tightened kill line, choke line, and koomy lines. Tightened valves on tubing spool. Took off bottom o -ring. Hole not Tined up, had to skid the rig away from the flares. C� EPOCH 32 UNOCAL M -12 10/04/2001: 1530' Skid rig over well. Set test plug and test rams. Lay down drill collars. Nipple up pitcher nipple and test BOPs. Pulled up BHA #9. Took bell nipple off and broke apart hydril. 10/05/2001: 1530' -1620' Repaired hydrill and finished testing BOPE. Picked up steerable BHA #9 with new PDC bit #6. Tested MWD and ran in hole to 1390', tagged cement, pulled off bottom, filled pipe, and tested casing. Drilled cement from 1390' to 1530', gas maximum of 360u at 1450', then formation from 1530' to 1542'. Tested casing. Drilled ahead from 1542' to 1620'. 10/06/2001: 1620' -2544' Drilled ahead, rotating and sliding, from 1620' to 1980'. Pulled out of hole to shoe and repaired saver sub on top drive. Tripped in to bottom washing down last stand, and drilled ahead, rotating and sliding from 1980' to 2544'. 10/07/2001: 2544' -4473' Drilled ahead, rotating and sliding, from 2544' to 3495'. Changed shaker screens. Continued rotating and sliding to 4473'. 10/08/2001: 4473' -5530' Drilled ahead, rotating and sliding, from 4473' to 5530'. 10/09/2001: 5530' Circulated bottoms up. Monitored well. 8 -10 bbl per hour loss. Pumped LCM pill 20 lbs. per bbls, 20 bbls, placed pill. Pulled out of the hole wet from 5553' to 2280'. Worked through tight spots. Circulated bottoms up. Pumped 28 bbl LCM pill. Back reamed 2280 - 2150'. Worked on top drive. Continued to back ream 2150 - 1520'. Pulled out of the hole from 1520 to surface. Downloaded MWD tool. Made up BHA #10. 10/10/2001: 5530' -6045' Made up BHA #10. Ran in the hole to shoe. Hung blocks to cut and slip drill line. Ran in the hole below shoe to test MWD tool. Ran in the hole reaming from 5438' to 5530'. Circulated to clean hole. Changed shaker screens. Drilled from 5533' to 6045'. E EPOCH 33 uNOAL M -12 10/11/2001: 6045' -6568' Drilled from 6045' to 6568'. Circulated bottoms up. Pumped a sweep. Epoch put on standby. 10/12/2001: 6568' Epoch on standby to 10/14/2001. 10/15/2001: 6568' -6984' RIH with HWDP to 6350'. Slip new drilling line. Service draw works and TD. Drill out cement to shoe from 6536' to 6568'. Drill from 6568' to 6578'. Conduct F.I.T. test on casing. Drill ahead from 6578' to 6984'. 10/16/2001: 6984' -7306' Drill ahead from 6984' to 7306'. MWD failure. Pulled out of hole. 10/17/2001: 7306' -8055' Pick up new BHA ( #12). Run in hole. Drill ahead from 7306 to 8055'. 10/18/2001: 8055' -8932' Drill ahead, sliding and rotating, from 8055' to 8932'. 10/19/2001: 8932 -9191' Drilled ahead, sliding and rotating, from 8932' to 9091'. Circulated bottoms up. Pulled out of hole to 6500'. Pumped a dry job. Pulled out of hole for new bit #10. Ran in hole with new bit #10. Ran in hole with new bit #10. Drill ahead from 9091' to 9191'. 10/20/2001: 9191 -9803' Drilled ahead from 9191' to 9288'. Saver sub broke out on connection. Torqued back up and it broke out again. Changed out saver sub. Drill ahead, sliding and rotating, from 9288' to 9803'. 10/21/2001: 9803 - 10404' Drilled ahead, sliding and rotating, from 9803 to 10404'. Trip out of hole for new bit #10. 10/22/2001 10404- 10404' €I EPOCH 34 UNOCAL M -12 Trip out of hole for new bit #10. Stuck in hole. Work stuck pipe at 7803'. Able to break lose. Backream from 7803 - 7400'. Circulate bottoms up at 6500', pump dry job. Continue to trip out of hole for new bit. Lay down BHA. Test BOP's. Pick up new BHA. 10/23/2001 10404- 10680' Run in hole with new bit #10. Torque every connection. Ream through tight spots. Drill ahead from 10404 - 10680'. Circulate bottoms up. 10/24/2001 10680 - 10715' TD Drill ahead from 10680' to 10715' (TD). Circulate bottoms up. Pull out of hole for new BHA and LWD tools. Lay down BHA. Pick up new BHA. Load MADD tools. Run in hole with new BHA. 10/25/2001 Run in hole with new BHA to shoe. Run LWD pass from shoe (6568') to TD (10715'). 10/26/2001 Pull out of hole with LWD. Lay down BHA. Start casing /liner run. El EPOCH 35 UNOCAL. M12 MUD RECORD Date Depth TVD MW VIS PV YP Gel FL HTHP Cake Sol 01W Sand MBT pH Pom Cl- Ca+ 9/17/01 500 500 9.1 49 5 31 7/10/13 NC NA 1/ 5 0/95 Tr 14 8.5 0.6 4100 580 9/18/01 870 870 9.2 51 8 29 11/16/18 NC NA 2/ 6 0/94 0.5 15 9.0 0.15 6000 320 9/19/01 870 870 9.25 53 8 22 18/22/24 NC NA 2/ 6 0/94 0.25 15 8.5 0.1 5000 360 9/20/01 764 764 9.2 51 12 18 13/20/25 NC NA 2/ 6 0/94 0.25 16 9.9 0.6 4500 120 9/21/01 870 870 9.4 49 9 27 16/23/26 NC NA 2/ 8 0/92 0.5 20 9.0 0.5 3000 120 9/22/01 870 870 9.4 50 11 21 15/24/30 NC NA 2/ 6 0/94 0.75 18 9.2 0.2 3500 140 9/23/01 870 870 9.4 52 11 21 15/24/30 NC NA 2/ 6 0/94 0.75 18 9.0 0.2 3500 120 9/24/01 870 870 9.4 54 11 21 14/23/29 NC NA 2/ 6 0/94 0.5 18 9.0 0.2 3500 120 9/25/01 870 870 9.4 54 11 21 _ 14/23/29 NC NA 2/ 6 0/94 0.5 18 8.8 0.15 3500 120 9/26/01 870 870 9.4 43 7 21 12/13/14 NC NA NA 6 0/94 0.5 17 8.5 0.1 3000 120 9/27/01 1004 1003 9.2 42 8 11 3/6/11 NC NA NA 4 0/96 0.25 15 10.7 0.7 2500 60 9/28/01 1531 1505 9.35 48 12 15 6/11/14 NC NA NA 6 0/94 0.75 16 9.0 0.4 2000 60 9/29/01 1531 1505 9.4 46 9 8 2/10/11 NC NA NA 6 0/94 0.5 18 8.0 0 1800 80 9/30/01 1531 1505 9.4 46 10 7 2/10/11 NC NA NA 6 0/94 0.5 18 8.0 0 1800 80 10/01/01 1531 1505 9.4 49 9 8 2/10/11 NC NA NA 6 0/99 0.5 18 8.0 0 1800 80 10/02/01 1531 1505 9.4 48 10 7 2/9/10 NC NA NA 6 0/94 0.5 18 8.0 0 1800 80 10/03/01 1531 1505 9.4 47 11 6 2/9/10 NC NA NA 6 0/94 0.5 18 8.0 0 1800 80 10/04/01 1626 1591 9.2 43 9 23 12/15/15 7.8 NA NA 2 0/98 0 NC 9.5 0.5 28000 700 10/05/01 2522 2476 9.3 41 8 27 11/12/14 9.2 NA NA 3 0/97 0.5 NC 9.0 0.35 22000 700 10/06/01 4470 3669 9.55 43 8 24 10/12/13 9.8 NA NA 4 0/96 0.5 NC 9.0 0.3 24000 700 10/07/01 5533 4320 9.4 40 9 23 11/12/14 9.7 NA NA 4 0/96 0.5 NC 9.0 0.35 23000 750 10/08/01 5533 4320 9.4 41 9.4 23 11/12/13 10.0 NA NA 5 0/95 NA NA 9.0 0.30 22000 700 10/09/01 6047 4674 9.3 40 9.0 22 10/11/12/ 10.0 NA 1/ 6 /94 NA 4.5 9 0.30 21000 650 10/10/01 10/11/01 10/12/01 10/13/01 [� EPO('H 37 UNOCALO M12 Date Depth TVD MW VIS PV YP Gel FL HTHP Cake Sol 01W Sand MBT pH Pom Cl- Ca+ 10/14/01 6568 5013 9.2 35 9.0 17 7/10/12 6.8 NA 1/ 4 0/96 TR 2.5 9.0 0.5 21000 650 10/15/01 6983 5335 9.25 37 8.0 17 6/11/12 7.8 NA 1/ 4 0/96 TR 3.5 9.0 0.20 21000 700 10/16/01 7305 5556 9.25 44 9.0 28 8/9/11 8.2 NA 1/ 6 0/94 0.25 8.0 8.5 0.5 16500 1600 10/18/01 8932 6949 9.4 46 13 28 8/10/12 5.2 NA 1/ 7 TR /93 0.25 10.0 9.5 0.25 18500 720 10/19/01 9192 7203 9.4 56 13 28 8/10/12 5.2 NA 1/ 7 TR/93 0.25 10 8.8 0.15 18500 720 10/20/01 9808 9307 9.4 51 11 28 9/12/14 5.2 NA 1/ 6 TR/94 0.25 8.0 8.5 0.1 20000 680 10/21/01 10404 8292 9.45 53 11 29 9/13/15 5.4 NA 1/ 7 TR/93 0.5 8.5 9.0 0.15 21000 960 10/22/01 10404 8292 9.45 53 11 29 9/13/15 5.4 NA 1/ 7 TR/93 0.5 8.5 9.0 0.15 21000 960 10/23/01 10715 8428 9.5 53 13 24 8/11/13 5.0 N/A 1/ 7 TR /93 0.25 9.25 9.2 0.15 21000 920 EPOS T 38 UNocALe M12 SURVEY RECORD MD Ind Azim TVD VSec +NIS- +FJW- Total Displ Course DLS (ft) ( ( (ft) (ft) (ft) (ft) (ft) (ft) ( °/100ft 100.00 0.05 184.68 100.00 -0.04 -0.04 0.00 0.04 100 0.05 200.00 0.01 265.25 200.00 -0.09 -0.09 -0.02 0.09 100 0.05 300.00 0.18 232.11 300.00 -0.22 -0.18 -0.15 0.24 100 0.17 400.00 0.07 338.24 400.00 -0.31 -0.22 -0.3 0.37 100 0.21 454.00 0.16 332.09 454.00 -0.23 -0.13 -.034 0.37 54 0.17 500.00 1.37 340.14 499.99 0.25 0.45 -0.56 0.72 46 2.63 550.00 5.70 347.23 549.89 2.85 3.43 -1.31 3.67 50 8.69 600.00 6.82 344.50 599.59 7.44 8.71 -2.65 9.11 50 2.32 650.00 7.28 337.70 649.21 12.31 14.51 -4.65 15.23 50 1.90 700.00 7.72 318.84 698.79 16.42 19.97 -8.06 21.53 50 4.98 750.00 8.55 301.65 748.29 18.98 24.45 -13.44 27.90 50 5.12 806.00 9.29 293.33 803.62 20.33 28.42 -21.13 35.42 56 2.65 860.00 9.40 292.10 856.90 21.00 31.81 -29.22 43.19 54 0.42 918.00 9.10 296.30 914.15 21.95 35.62 -37.72 51.88 58 1.27 1012.00 8.90 310.50 1007.00 25.73 43.64 -49.92 66.30 94 2.37 1106.00 10.30 345.00 1099.76 35.50 56.49 -57.63 80.69 94 6.20 1199.00 11.90 359.80 1191.04 51.54 74.11 -59.81 95.24 93 3.50 1291.00 15.30 11.60 1280.46 72.60 95.50 -57.40 111.42 92 4.75 1384.00 19.00 21.40 1369.33 99.92 121.63 -49.41 131.28 93 5.04 1472.20 23.07 23.12 1451.63 131.49 150.90 -37.38 155.46 88.2 4.67 1545.82 24.27 27.30 1519.06 160.81 177.61 -24.77 179.33 73.62 2.80 1640.53 29.19 31.14 1603.63 202.59 214.70 -3.89 214.74 94.71 5.50 1735.03 33.34 30.64 1684.39 250.45 256.79 21.27 257.67 94.50 4.40 1826.75 37.82 29.82 1758.97 302.66 302.90 48.12 306.69 91.72 4.91 1924.42 42.46 27.88 1833.62 364.55 358.05 78.44 366.54 97.67 4.92 2012.25 45.10 24.82 1897.03 424.71 412.50 105.37 425.75 87.83 3.85 2107.12 44.51 25.39 1964.35 491.10 473.04 133.73 491.58 94.87 0.75 2196.98 45.04 25.14 2028.13 553.93 530.28 160.75 554.11 89.86 0.62 2292.05 48.67 24.78 2093.14 622.82 593.16 190.01 622.85 95.07 3.83 2383.94 49.03 24.30 2153.60 691.60 656.10 218.74 691.60 91.89 0.56 2476.03 48.10 21.71 2214.55 760.40 719.63 245.73 _ 760.43 92.09 2.34 2569.55 46.19 21.59 2278.16 828.84 783.35 271.02 828.91 93.52 2.04 2663.68 44.81 23.14 2344.13 895.81 845.44 296.56 895.94 94.13 1.88 2758.55 45.01 24.22 2411.32 962.49 906.77 323.46 962.74 94.87 0.83 2854.53 45.31 24.10 2479.00 1030.20 968.87 351.31 1030.60 95.98 0.32 2949.94 45.66 24.08 2542.89 1097.89 1030.98 379.08 1098.46 95.41 0.37 3039.56 45.85 22.61 2608.42 1161.84 1089.92 404.52 1162.57 89.62 1.19 3133.50 46.25 23.37 2673.62 1229.24 1152.18 430.94 1230.13 93.94 0.72 3226.06 46.64 22.74 2737.40 1296.09 1213.90 457.20 1297.15 92.56 0.65 3318.00 47.08 22.86 2800.27 1362.98 1275.75 483.20 1364.19 20.74 0.49 3412.64 46.04 23.39 2865.34 1431.45 1338.94 510.19 1432.85 94.64 1.17 3505.70 45.02 27.04 2930.54 1497.36 1399.01 538.45 1499.05 93.06 3.01 3598.19 45.09 27.63 2995.88 1562.02 1457.16 568.51 1564.14 92.49 0.46 3692.32 45.48 26.45 3062.11 1628.13 1516.13 598.92 1630.71 94.13 0.98 3784.82 45.47 26.43 3127.02 1693.47 1575.83 628.30 1696.47 92.57 0.02 €l EPOCH 39 UNOCAL M12 8376.13 19.34 9.82 6409.31 4838.32 4440.55 1981.26 4862.49 96.21 6.10 8466.66 13.79 359.97 6496.07 4863.41 4466.13 1983.81 4886.91 90.53 6.85 8562.61 11.56 338.87 6589.73 4881.70 4486.55 1980.34 4904.17 95.95 5.32 8655.91 11.17 311.71 6681.26 4892.51 4501.29 1970.22 4913.59 93.30 5.70 8753.51 12.40 278.04 6776.91 4894.40 _ 4509.06 1952.76 4913.74 97.60 7.05 8845.69 12.18 269.87 6866.99 4889.55 4510.42 1933.24 _ 4907.27 92.18 1.90 8940.34 10.87 271.46 6959.73 4883.80 4510.63 1914.33 4900.04 94.65 1.42 9026.04 11.15 266.11 7043.85 4878.32 4510.27 1897.98 4893.35 85.70 1.24 9129.68 12.24 262.75 7145.34 4869.78 4508.20 1877.09 4883.37 103.64 1.24 9226.05 12.51 265.67 7239.47 4861.35 4506.13 1856.54 4873.59 96.37 0.71 9318.05 12.80 270.89 7329.24 4854.46 4505.53 1836.42 4865.41 92.00 1.28 9413.15 12.79 284.11 7422.00 4850.53 _ 4508.26 1815.67 4860.15 95.10 3.07 9512.30 12.29 289.74 7518.79 4849.98 4514.50 1795.09 4858.30 99.15 1.33 9605.25 11.28 292.28 7609.78 4850.85 4521.29 1777.37 4858.10 92.95 1.22 9699.90 10.16 292.45 7702.78 4852.08 4527.99 1761.09 _ 4858.40 94.65 1.18 9792.10 10.23 292.31 7793.52 4853.24 4534.20 1746.00 4858.75 92.20 0.08 9886.13 12.02 291.00 7885.78 4854.27 4540.88 1729.13 4858.96 94.03 1.92 9980.30 11.90 290.83 7977.90 4855.15 4547.85 1710.90 4859.02 94.17 0.13 10074.41 11.20 292.90 8070.11 4856.30 4554.85 1693.41 4859.46 94.11 0.86 10166.02 10.41 294.39 _ 8160.09 4857.89 4561.73 1677.68 4860.45 91.61 0.91 10256.10 10.17 294.71 8248.73 4859.63 4568.42 1663.04 4861.70 90.08 0.27 10340.73 9.64 295.02 8332.13 4860.26 4573.53 1649.62 4861.94 84.63 0.67 10403.00 9.24 295.35 8393.56 4861.48 4577.88 1640.38 4862.90 62.27 0.35 10715.00 9.24 295.35 8701.51 4867.60 4599.32 1595.11 4868.07 312.00 0.00 El EPOCH 41 f UN ®CAL M12 BIT RECORD Bit # Size Vendor Type Serial # Jets In Out Feet Hrs -On Hrs -Off ROP WOB 1 17.5" HUGHES ATX1 R51TF 3X18,16 470 500 30 5.3 1.2 5.7 20 UR 26" SMITH W/ BIT #1 M6980 3X16,3X18 470 500 30 5.3 1.2 5.7 20 1RR -2 17.5" HUGHES ATX1 R51TF 3X18,16 500 870 370 5.1 8.2 72.5 15 -20 1RR -3 17.5" HUGHES ATX1 R51TF 3X18,16 535 870 335 7.4 21.0 45.3 15 -30 HO 26" SMITH W/ BULL NOSE M6980 3X16,3X18 500 870 370 6.0 3.7 61.7 20 4 14.75" HUGHES ATX -1 G78XD OPEN 870 882 12 0.3 3.5 40 8 UR 17.5" SMITH W /BIT #4 2001 2X16 870 882 12 0.3 3.5 40 8 5 12.25 HUGHES CT -C1 F76XK 3X16 882 1531 649 4.3 11.2 150.9 15 -20 HO 17.5" SMITH W/ BULL NOSE 2001 2X18/1X24 863 1531 668 6.7 5.7 99.7 15 6 12.25" SMITH S73HPX JR9178 8X11 1531 6568 5037 63.8 59.5 78.9 15 -20 7 8.5" HYCALOG DSX75HGNW 102086 8x10 6568 7306 738 18.3 11.0 40.3 15 -20 8 8.5" SMITH 15GFDGPS MJ2533 3x16 7306 9091 1785 34.6 10.8 51.6 20 -25 9 8.5" SMITH 15GFDG MJ2522 3x16 9091 10404 1313 32.4 13.3 40.5 20 -25 10 8.5" SMITH ER6026PS MJ1304 3x16 10404 10715 311 6.9 3.9 45.3 20 -25 HI EPOrTi 43 UNOCAL M12 DAILY REPORTS EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: September 18, 2001 DAILY COST: $1740 COST: p I S $ 0 CUM OS $7040 12:01 AM DEPTH: 500' YESTERDAY: 470' 24 HR FTG: 30' ROP (FT /HR): PRESENT: N/A 24 HR AVE: 5.7 CURRENT BIT INFORMATION: NO.: 1 MAKE: HUGHES TYPE: ATX1 DEPTH IN: 470' DEPTH OUT: ' Footage Hours On Bottom Off Bottom Connection TOTAL: 30 6.5 5.3 1.2 0.1 YESTERDAY'S TOTAL: 0 0 0 0 0 PAST 24 HOURS: 30 6.5 5.3 1.2 0.1 GAS SUMMARY BACKGROUND GAS: Max: 11u @493' Average: 5u Current: 9u CONNECTION GAS: Max: OuGa 490' Average: Ou Current: 0u @490' TRIP GAS: 14u©500' WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 25 % SILTSTONE: 0 % SANDSTONE: 15 % CLAYSTONE: 60 % CONGLOMERATE: 0 % TUFF: 0 % COAL INTERVALS: 490 -500'. COAL ANTICIPATED: Type log begins @ 770'. SHOW SUMMARY: NONE REMARKS: Epoch arrived on location 12:20 pm on September 14, 2001, and commenced rig up. Epoch logged on when rig tagged junk above pile shoe on conductor pipe at approximately 470'. Rig drilled ahead, rotating, from 470' to 500' with clean out assembly. Worked pipe and circulated out, and tripped out of hole. Made up landing joints and hanger, drifted with riser, and laid down landing joints and hangar. Worked on riser. Made up directional BHA #2 with same 17'/" bit #1 while removing 26" hole opener. Ran in hole, oriented BHA with gyro, and washed from 488' to bottom at 500'. €l EPOCH 45 UNOCAL. M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: September 19, 2001 DAILY COST: $1740 CUM COST: $8780 12:01 AM DEPTH: 870' YESTERDAY: 500' 24 HR FTG: 370' ROP (FT /HR): PRESENT: 91.2 24 HR AVE: 72.5 CURRENT BIT INFORMATION: NO.: 1 MAKE: HUGHES TYPE: ATX1 DEPTH IN: 470' DEPTH OUT: ' Footage Hours On Bottom Off Bottom Connection TOTAL: 400 19.7 10.4 9.3 2.0 YESTERDAY'S TOTAL: 30 6.5 5.3 1.2 0.1 PAST 24 HOURS: 370 13.2 5.1 8.1 1.9 GAS SUMMARY BACKGROUND GAS: Max: 141u@588' Average: 28u Current: u CONNECTION GAS: Max: Ou @848' Average: Ou Current: Ou @848' TRIP GAS: 14u @500' WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 10 % SILTSTONE: 20 % SANDSTONE: 20 % CLAYSTONE: 50 % CONGLOMERATE: 0 % TUFF: 0 % COAL INTERVALS: 515 -50', 585 -90', 715 -35', 860 -65'. COAL ANTICIPATED: Correlating approximately 10' high to type log. SHOW SUMMARY: NONE REMARKS: Drilled ahead from 500' to 579', and took gyro survey. Drilled from 579' to 772', and power failed. Restored power with back -up generator and circulated at 50 spm. Restored power on main generator and drilled from 772' to 846', picked up single, and drilled from 846' to 870'. Pumped high viscosity sweep. Pulled out of the hole. Picked up BHA #3, ran in the hole with heavy weight drill pipe to 460'. Circulated. Pulled out of the hole. �� EPOCH 46 UNOCAL M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: September 20, 2001 DAILY COST: $1740 CUM COST: $10520 12:01 AM DEPTH: 870' YESTERDAY: 870' 24 HR FTG: 0' ROP (FT /HR): PRESENT: 0 24 HR AVE: 0 CURRENT BIT INFORMATION: NO.: 1 MAKE: HUGHES TYPE: ATX1 DEPTH IN: 470' DEPTH OUT: 870' Footage Hours On Bottom Off Bottom Connection TOTAL: 400 19.7 10.4 9.3 2.0 YESTERDAY'S TOTAL: 400 19.7 10.4 9.3 2.0 PAST 24 HOURS: 0 0 0 0 0 GAS SUMMARY BACKGROUND GAS: Max: 35u Average: 5u Current: NA CONNECTION GAS: Max: NA Average: NA Current: NA TRIP GAS: 35u @870' WIPER TRIP GAS: NA GROSS LITHOLOGY: COAL: 0 % SILTSTONE: 0 % SANDSTONE: 0 % CLAYSTONE: 0 CONGLOMERATE: 0 % TUFF: 0 % COAL INTERVALS: . COAL ANTICIPATED: Correlating approximately 10' high to type log. SHOW SUMMARY: NONE REMARKS: Finished pulling out of hole and worked BHA #3. Made up cement head and cement assembly. Ran in hole to bottom and circulated hole clean, maximum 35 units of gas. Pumped 100 barrel cement plug and displaced with 6 barrels of drilling mud, 1 -2 units of gas. Pulled out of hole to 564' and circulated, washing cement from drill pipe, maximum 12 units of gas. Pulled out of hole and rigged down cement assembly and drained stack. Made up landing joints and casing hangar and drifted surface stack. Serviced rig and made up directional BHA #4. Cut and slipped drill line. Reinstalled flow line. Rigged up gyro. Ran in hole to 535. Pulled out of the hole to 494. 11 EPOCH 47 UNOCAL M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, M -12, STEELHEAD PLATFORM DATE: September 21, 2001 DAILY COST: $1740 CUM COST: $12260 12:01 AM DEPTH: 760' YESTERDAY: 535' 24 HR FTG: 225' ROP (FT /HR): PRESENT: 111.9 24 HR AVE: 36.9 CURRENT BIT INFORMATION: NO.: 3(RR #1) MAKE: HUGHES TYPE: ATX1 DEPTH IN: 535' DEPTH OUT: ' Footage Hours On Bottom Off Bottom Connection TOTAL: 225 23.5 6.1 17.4 11.0 YESTERDAY'S TOTAL: 0 0 0 0 0 PAST 24 HOURS: 225 23.5 6.1 17.4 11.0 GAS SUMMARY BACKGROUND GAS: Max: 142u @727' Average: 48u Current: 12u CONNECTION GAS: Max: Ou _ Average: Ou Current: Ou TRIP GAS: NA WIPER TRIP GAS: I 5u @638' GROSS LITHOLOGY: COAL: 40 % SILTSTONE: 0 % SANDSTONE: 20 % CLAYSTONE: 30 % CONGLOMERATE: 10 % TUFF: 0 % COAL INTERVALS: 680 -685', 700 -705', 715 -740'. COAL ANTICIPATED: Correlating approximately 10' high to type log. SHOW SUMMARY: NONE REMARKS: Washed to bottom 494' to 535', and drilled ahead, sliding, through soft cement from 535 -638', unable to kick off cement. Pulled out of hole to 494', and rigged down side entry sub. Pulled out of hole to 404', and waited on cement. Ran in hole to 581', and rigged up side entry sub. Ran in the hole to 638'. Drilled from 638' to 646', through cement. Worked pipe from 646' to 616' attempting to trench side of hole. Slid from 646' to 656' controlled drilling at 2 feet per hour. Slid from 656' to 710', circulated and ran survey. Pulled out of the hole to 583', and removed side entry sub and tool. Ran to bottom at 710', and drilled ahead, rotating, to 740'. Circulated and surveyed and reinstalled side entry sub at 730'. Drilled ahead, rotating, from 740' to 760'. Li EPOCH 48 UNOCAL M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: September 22, 2001 DAILY COST: $1740 CUM COST: $14000 12:01 AM DEPTH: 870' YESTERDAY: 760' 24 HR FTG: 110' ROP (FT /HR): PRESENT: 24 HR AVE: 84.6 CURRENT BIT INFORMATION: NO.: 3(RR #1) MAKE: HUGHES TYPE: ATX1 DEPTH IN: 535' DEPTH OUT: 870' Footage Hours On Bottom Off Bottom Connection TOTAL: 335 28.4 7.4 21.0 12.5 YESTERDAY'S TOTAL: 225 23.5 6.1 17.4 11.0 PAST 24 HOURS: 110 4.9 1.3 3.6 1.5 NO.: HO MAKE: SMITH TYPE: 26" HO DEPTH IN: 500' DEPTH OUT: 870' Footage Hours _ On Bottom Off Bottom Connection TOTAL: 370 9.7 6 3.7 2 YESTERDAY'S TOTAL: 0 0 0 0 0 PAST 24 HOURS: 370 9.7 6 3.7 2 GAS SUMMARY BACKGROUND GAS: Max: 240u@765' Average: 45u Current: u CONNECTION GAS: Max: Ou Average: Ou Current: u TRIP GAS: 55u WIPER TRIP GAS: NA GROSS LITHOLOGY: COAL: 20 % SILTSTONE: 0 % SANDSTONE: 25 % CLAYSTONE: 45 % CONGLOMERATE: 5 % TUFF: 5 % COAL INTERVALS: 760 -70', 810 -15', 855 -65'. COAL ANTICIPATED: Correlating approximately 10' high to type log. SHOW SUMMARY: NONE REMARKS: Drilled ahead, sliding, from to 763' to 780', ran survey and rigged down side entry sub. Drilled ahead, rotating, from 780' to 820', circulated bottoms up and ran survey. Drilled ahead to 845', circulated, and ran survey. Drilled ahead to 870', casing depth, circulated sweep and pulled out of the hole. Worked BHA #4, and picked up and ran in with hole opener assembly, BHA #5. Ran in hole with heavy weight drill pipe to 396', and serviced top drive. Tripped in to below conductor shoe at 500', and began opening 17'/2' hole to 26 ". Opened hole from 500' to 870', maximum 178 units at 768' and averaged 25 units of gas. Circulated sweep around, short tripped to shoe, tagged bottom, no fill. [1 EPOCH 49 UNOCAL. M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: September 23, 2001 DAILY COST: $1740 CUM COST: $15740 12:01 AM DEPTH: 870' YESTERDAY: 870' 24 HR FTG: 0' ROP (FT /HR): PRESENT: 24 HR AVE: CURRENT BIT INFORMATION: NO.: HO MAKE: SMITH TYPE: 26" HO DEPTH IN: 500' DEPTH OUT: 870' Footage Hours On Bottom Off Bottom Connection TOTAL: 370 9.7 6 3.7 2 YESTERDAY'S TOTAL: 370 9.7 6 3.7 2 PAST 24 HOURS: 0 0 0 0 0 GAS SUMMARY BACKGROUND GAS: Max: Average: Current: CONNECTION GAS: Max: Average: Current: TRIP GAS: WIPER TRIP GAS: 1 10u GROSS LITHOLOGY: COAL: 0 % SILTSTONE: 0 % SANDSTONE: 0 % CLAYSTONE: 0 % CONGLOMERATE: 0 % TUFF: 0 % COAL INTERVALS: COAL ANTICIPATED: Correlating approximately 10' high to type log. SHOW SUMMARY: NONE REMARKS: Pumped sweep and circulated around, and spotted LCM pill on bottom. Pulled out of hole and laid down hole opener assembly. Rigged up and P Y 9g p ran in hole with 18 5/8" casing. Landed casing and rigged down GBR. Ran in hole with open ended 5" drill pipe. Rigged up to circulate. Circulated and swept hole clean for cement. Swapped over to tail cement (dowel having problems). Pumping tail 15.8 with dowel. Pulled out of the hole breaking every joint to wash cement. Picked up floor and flushed lines and riser. Pi EPOCH 50 1 UNOCAL M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC M -12, STEELHEAD PLATFORM DATE: September 24, 2001 DAILY COST: $1740 CUM COST: $17480 12:01 AM DEPTH: 870' YESTERDAY: 870' 24 HR FTG: 0' ROP (FT /HR): PRESENT: NA 24 HR AVE: NA CURRENT BIT INFORMATION: NO.: MAKE: TYPE: _ DEPTH IN: 870' DEPTH OUT: ' Footage Hours On Bottom Off Bottom Connection TOTAL: 0 0 0 0 0 YESTERDAY'S TOTAL: 0 0 0 0 0 PAST 24 HOURS: 0 0 0 0 0 GAS SUMMARY BACKGROUND GAS: Max: NA Average: NA Current: NA CONNECTION GAS: Max: NA Average: NA Current: NA TRIP GAS: NA WIPER TRIP GAS: ( NA GROSS LITHOLOGY: COAL: 0 % SILTSTONE: 0 % SANDSTONE: 0 % CLAYSTONE: 0 % CONGLOMERATE: 0 % TUFF: 0 % COAL INTERVALS: . COAL ANTICIPATED: Correlating approximately 10' high to type log. SHOW SUMMARY: NONE REMARKS: Nipple down diverter lines and begin rigging up for BOP stack. Take short riser off, brought it up into the upper well bay. Moved surface hydrill back and secured. Took flange off riser. HI EPOCH 51 UNOCAL M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC M -12, STEELHEAD PLATFORM DATE: September 25, 2001 DAILY COST: $1740 CUM COST: $19220 12:01 AM DEPTH: 870' YESTERDAY: 870' 24 HR FTG: 0' ROP (FT /HR): PRESENT: NA 24 HR AVE: NA CURRENT BIT INFORMATION: NO.: MAKE: TYPE: _ DEPTH IN: 870' DEPTH OUT: ' Footage Hours On Bottom Off Bottom Connection TOTAL: 0 0 0 0 0 YESTERDAY'S TOTAL: 0 0 0 0 0 PAST 24 HOURS: 0 0 0 0 0 GAS SUMMARY BACKGROUND GAS: Max: NA Averase: NA Current: NA CONNECTION GAS: Max: NA Averaee: NA Current: NA TRIP GAS: NA WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 0 % SILTSTONE: 0 % SANDSTONE: 0 % CLAYSTONE: 0 % CONGLOMERATE: 0 % TUFF: 0 COAL INTERVALS: COAL ANTICIPATED: Correlating approximately 10' high to type log. SHOW SUMMARY: NONE REMARKS: Continue rigging up for BOP stack. EI EPOCH 52 UNOCAL. M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: September 26, 2001 DAILY COST: $1740 CUM COST: $20960 12:01 AM DEPTH: 870' YESTERDAY: 870' 24 HR FTG: 0' ROP (FT /HR): PRESENT: NA 24 HR AVE: NA CURRENT BIT INFORMATION: NO.: MAKE: TYPE: _ DEPTH IN: 870' DEPTH OUT: ' Footage Hours On Bottom Off Bottom Connection TOTAL: 0 0 0 0 0 YESTERDAY'S TOTAL: 0 0 0 0 0 PAST 24 HOURS: 0 0 0 0 0 GAS SUMMARY BACKGROUND GAS: Max: NA Average: NA Current: NA CONNECTION GAS: Max: NA Average: NA Current: NA TRIP GAS: NA WIPER TRIP GAS: 1 NA GROSS LITHOLOGY: COAL: 0 % SILTSTONE: 0 % SANDSTONE: 0 % CLAYSTONE: 0 % CONGLOMERATE: 0 % TUFF: 0 % COAL INTERVALS: COAL ANTICIPATED: Correlating approximately 10' high to type log. SHOW SUMMARY: NONE REMARKS: Continue working on BOP stack. Fl EPOCH 53 UNOCAL M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: September 27, 2001 DAILY COST: $1740 CUM COST: $22700 12 :01 AM DEPTH: 870' YESTERDAY: 870' 24 HR FTG: 0' ROP (FT /HR): PRESENT: NA 24 HR AVE: NA CURRENT BIT INFORMATION: NO.: MAKE: TYPE: _ DEPTH IN: 870' DEPTH OUT: ' Footage Hours On Bottom Off Bottom Connection TOTAL: 0 0 0 0 0 YESTERDAY'S TOTAL: 0 0 0 0 0 PAST 24 HOURS: 0 0 0 0 Q GAS SUMMARY BACKGROUND GAS: Max: NA Average: NA Current: NA CONNECTION GAS: Max: NA Average: NA Current: NA TRIP GAS: NA WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 0 % SILTSTONE: 0 % SANDSTONE: 0 % CLAYSTONE: 0 % CONGLOMERATE: 0 % TUFF: 0 % COAL INTERVALS: COAL ANTICIPATED: Correlating approximately 10' high to type log. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Installed flowline and tightened turnbuckles. Hammered up fill line and bled off line. Hooked up and secured accumulator lines. Installed valve on annulus in well room. Tested BOP's, choke manifold, choke valve, HCR, and kill valves. Stood back HWDP and pulled up wear ring. Tried to put wear ring in place. Nippled down bell nipple. E1 EPOC;H 54 UNOCAL M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: September 28, 2001 DAILY COST: $1740 CUM COST: $24440 12:01 AM DEPTH: 1011' YESTERDAY: 870' 24 HR FTG: 141' ROP (FT /HR): PRESENT: NA 24 HR AVE: 201' CURRENT BIT INFORMATION: NO.: 4MAKE: HUGHES TYPE: ATX -1 DEPTH IN: 870' DEPTH OUT: 882' Footage Hours On Bottom Off Bottom Connection TOTAL: 12 3.8 0.3 3.5 0.1 YESTERDAY'S TOTAL: 0 0 0 0 0 PAST 24 HOURS: 12 3.8 0.3 3.5 0.1 NO.: 5MAKE: HUGHES TYPE: CT -C1 DEPTH IN: 882' DEPTH OUT: NA' Footage Hours On Bottom Off Bottom Connection TOTAL: 129 2.1 0.4 1.7 0.1 YESTERDAY'S TOTAL: 0 0 0 0 0 PAST 24 HOURS: 129 2.1 0.4 1.7 0.1 GAS SUMMARY BACKGROUND GAS: , Max: 72u @978' Average: 27u Current: 11u CONNECTION GAS: _ Max: Ou Average: Ou Current: Ou TRIP GAS: 162u @810' WIPER TRIP GAS: _ I NA GROSS LITHOLOGY: COAL: 25 % SILTSTONE: 0 % SANDSTONE: 40 % CLAYSTONE: 10 % CONGLOMERATE: 25 % TUFF: 0 % COAL INTERVALS: . COAL ANTICIPATED: Correlating approximately 10' high to type log. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Grind to allow wear ring to pass through bell nipple. Run in hole with wear ring, stand back test joint, and nipple up bell nipple and flowline. Pick up and run in hole with BHA #6 with new 14 3 /," bit #4 and 17 1 /2" under reamer. Run in hole with heavy weight drill pipe to 810', and test casing. Drill cement, float and shoe down to 870', maximum 162 units of gas bottoms up after begin circulating. Drill formation from 870' to 882' and test, 12.2 EMW. Trip out of hole, work BHA #6, and pick up and run in hole with steerable BHA #7 and new 12.25" bit #5. Test MWD and run in hole with heavy weight drill pipe. Ran in the hole. Slid from 882' to 1004'. Rigged up to run gyro. Ell EPOCH 55 UNOCAL M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: September 29, 2001 DAILY COST: $1740 CUM COST: $26180 12:01 AM DEPTH: 1530' YESTERDAY: 1011' 24 HR FTG: 519' ROP (FT /HR): PRESENT: NA 24 HR AVE: 133 CURRENT BIT INFORMATION: NO.: 5MAKE: HUGHES TYPE: CT -C1 DEPTH IN: 882' DEPTH OUT: 1530' Footage Hours On Bottom Off Bottom Connection TOTAL: 648 15.5 4.3 11.2 2.9 YESTERDAY'S TOTAL: 129 2.1 0.4 1.7 0.1 PAST 24 HOURS: 519 13.4 3.9 9.5 2.8 NO.:HO MAKE: SMITH TYPE: 17.5 HO DEPTH IN: 863' DEPTH OUT: NA' Footage Hours _ On Bottom Off Bottom Connection TOTAL: 307' 3 2.3 .7 .1 YESTERDAY'S TOTAL: NA NA NA NA NA PAST 24 HOURS: 307' 3 2.3 .7 .1 GAS SUMMARY BACKGROUND GAS: Max: 358u @1411' Average: 91u Current: 48u CONNECTION GAS: Max: Ou Average: Ou Current: Ou TRIP GAS: 12u @860' WIPER TRIP GAS: f NA GROSS LITHOLOGY: COAL AND PEAT: 40 % SILTSTONE: 0 SANDSTONE: 30 % CLAYSTONE: 25 % CONGLOMERATE: 5 % TUFF: 0 % COAL INTERVALS: 1020'- 1070', 1210'- 1250', 1360'- 1470'. COAL ANTICIPATED: Correlating approximately 40' high to type log. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Drilled ahead from 1011 to 1157', taking MWD surveys and running gyros at connection. Lost returns at 1157', pumped LCM and monitored well from trip tank. Drilled ahead from 1157' to 1530', taking MWD surveys and running gyros at connections, discontinuing MWD surveys after 1283'. Pumped sweep and circulated out and pulled out of the hole. Spotted LCM at 1150. Continued pulling out of the hole (wet). Laid down BHA #7. Pick up BHA #8. Ran in the hole. Reamed 12.25 to 17.5 with under reamer from 863' to 1170'. El EPOCH 56 umocauLe M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: September 30, 2001 DAILY COST: $1740 CUM COST: $27920 12:01 AM DEPTH: 1530' YESTERDAY: 1530' 24 HR FTG: 0' ROP (FT /HR): PRESENT: NA 24 HR AVE: NA CURRENT BIT INFORMATION: NO.:HO MAKE: SMITH TYPE: 17.5 HO DEPTH IN: 863' DEPTH OUT: 1530' Footage Hours On Bottom Off Bottom Connection TOTAL: 667 9.4 6.7 2.7 0.7 YESTERDAY'S TOTAL: 307 3.0 2.3 0.7 0.2 PAST 24 HOURS: 360 6.4 4.4 2.0 0.5 NO.:HO(2n Run) MAKE: SMITH TYPE: 17.5 HO DEPTH IN: 863' DEPTH OUT: 1530' Footage Hours On Bottom Off Bottom Connection TOTAL: 667 3.0 0.55 2.45 0.5 YESTERDAY'S TOTAL: 0 0 0 0 0 PAST 24 HOURS: 667 3.0 0.55 2.45 0.5 GAS SUMMARY BACKGROUND GAS: Max: 189u @1435' Average: 40u Current: NA CONNECTION GAS: Max: Ou Average: Ou Current: Ou TRIP GAS: 189u @1530' WIPER TRIP GAS: 1 61u @1530' GROSS LITHOLOGY: COAL AND PEAT: 0 % SILTSTONE: 0 % SANDSTONE: 0 % CLAYSTONE: 0 % CONGLOMERATE: 0 % TUFF: 0 % COAL INTERVALS: COAL ANTICIPATED: Correlating approximately 40' high to type log. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Opened hole from 1170' to 1530', averaging 82 feet per hour and 45 units of gas, maximum 189 units. (Note: averaged 100 feet per hour from 863' to 1530'). Pumped sweep and circulated out. Pulled out of hole to shoe, and washed and reamed from 863' to 1530', averaging 1213 feet per hour and 25 units of gas, maximum 61 units. Pumped sweep and circulated out. Pumped pill and pulled out of the hole. Rigged up to run 13 3/8 casing. Pull up landing joint and made a test run. Laid down landing joint and fill stack. Ran guide shoe joint. Took off centralizers. Run in the hole with 13 3/8 casing to 788.2 (19 joints). El EPOCH 57 UNOCAL M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: October 1, 2001 DAILY COST: $1740 CUM COST: $29660 12:01 AM DEPTH: 1530' YESTERDAY: 1530' 24 HR FTG: 0' ROP (FT /HR): PRESENT: NA 24 HR AVE: NA CURRENT BIT INFORMATION: NO.:6 MAKE: TYPE:_ DEPTH IN: ' DEPTH OUT: ' Footage Hours On Bottom Off Bottom Connection TOTAL: YESTERDAY'S TOTAL: PAST 24 HOURS: GAS SUMMARY BACKGROUND GAS: Max: Average: Current: CONNECTION GAS: Max: Average: Current: TRIP GAS: WIPER TRIP GAS: GROSS LITHOLOGY: COAL AND PEAT: 0 % SILTSTONE: 0 % SANDSTONE: 0 % CLAYSTONE: 0 % CONGLOMERATE: 0 % TUFF: 0 % COAL INTERVALS: COAL ANTICIPATED: Correlating approximately 40' high to type log. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Casing hung up due to BOP malfunction. Worked on BOP and loosened casing. Laid down two joints of casing. Continued to run in with casing to bottom, 2 to 8 units of gas from mud displaced over shakers while running in. Landed casing at 1519.08. Rigged up cementers, began cementing, dropped plug at 23:15. PI EPOCH 58 UNOCAL. M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: October 2, 2001 DAILY COST: $1740 CUM COST: $31400 12:01 AM DEPTH: 1530' YESTERDAY: 1530' 24 HR FTG: 0' ROP (FT /HR): PRESENT: NA 24 HR AVE: NA CURRENT BIT INFORMATION: NO.: MAKE: TYPE:_ DEPTH IN: ' DE PTH OUT: ' Footage Hours On Bottom Off Bottom Connection TOTAL: YESTERDAY'S TOTAL: PAST 24 HOURS: GAS SUMMARY BACKGROUND GAS: Max: _ Av ra e: Current: CONNECTION GAS: Max: Avera¢ Current: TRIP GAS: WIPER TRIP GAS: GROSS LITHOLOGY: COAL AND PEAT: 0 % SILTSTONE: 0 % SANDSTONE: 0 % CLAYSTONE: 0 % CONGLOMERATE: 0 % TUFF: 0 COAL INTERVALS: COAL ANTICIPATED: Correlating approximately 40' high to type log. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Flushed dowel) unit and cement lines to rig. Cleaned shakers and tanks. Set up pump and hoses to pump out landing joint. Opened valve on cement head. Monitored casing for flow. Split stack between mud x and double gate. Sucked out risers down to hanger. Pulled mud x, single gate and both risers with blocks. Took off drilling adapter, put on drilling head. €� EPOCH 59 UNOCALe M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: October 3, 2001 DAILY COST: $1740 CUM COST: $33140 12:01 AM DEPTH: 1530' YESTERDAY: 1530' 24 HR FTG: 0' ROP (FT /HR): PRESENT: NA 24 HR AVE: NA CURRENT BIT INFORMATION: NO.: MAKE: TYPE:_ DEPTH IN: ' DEPTH OUT: ' Footage Hours On Bottom Off Bottom Connection TOTAL: YESTERDAY'S TOTAL: PAST 24 HOURS: GAS SUMMARY BACKGROUND GAS: Max: Average: Current: CONNECTION GAS: Max: Average: Current: TRIP GAS: WIPER TRIP GAS: GROSS LITHOLOGY: COAL AND PEAT: 0 % SILTSTONE: 0 % SANDSTONE: 0 % CLAYSTONE: 0 % CONGLOMERATE: 0 % TUFF: 0 % COAL INTERVALS: COAL ANTICIPATED: Correlating approximately 40' high to type log. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Built volume in the mud pits. Nippled up spool, DSF, riser and single gate. Nippled up double gates and hydril to mud x. Set BOP and tightened bolts. Bell nipple, would not fit; had to cut 12" out of it. Hooked up and tightened kill line, choke line, and koomy lines. Tightened valves on tubing spool. Took off bottom o -ring. Hole not lined up, had to skid the rig away from the flares. HI EPOCH 60 UNOCAL M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: October 4, 2001 DAILY COST: $1740 CUM COST: $34880 12:01 AM DEPTH: 1530' YESTERDAY: 1530' 24 HR FTG: 0' ROP (FT /HR): PRESENT: NA 24 HR AVE: NA CURRENT BIT INFORMATION: NO.: MAKE: TYPE:_ DEPTH IN: ' DEPTH OUT: ' Footage Hours On Bottom Off Bottom Connection TOTAL: YESTERDAY'S TOTAL: PAST 24 HOURS: GAS SUMMARY BACKGROUND GAS: Max: Average: Current: CONNECTION GAS: Max: Average: Current: TRIP GAS: WIPER TRIP GAS: I GROSS LITHOLOGY: COAL AND PEAT: 0 % SILTSTONE: 0 % SANDSTONE: 0 % CLAYSTONE: 0 % CONGLOMERATE: 0 % TUFF: 0 % COAL INTERVALS: COAL ANTICIPATED: Correlating approximately 40' high to type log. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Skid rig over well. Set test plug and test rams. Lay down drill collars. Nipple up pitcher nipple and test BOPs. Pulled up BHA #9. Took bell nipple off and broke apart hydril. LI EPOCH 61 UNOCALO M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: October 5, 2001 DAILY COST: $1740 CUM COST: $36620 12:01 AM DEPTH: 1620' YESTERDAY: 1530' 24 HR FTG: 90' ROP (FT /HR): PRESENT: 50 24 HR AVE: 180 CURRENT BIT INFORMATION: NO.:6 MAKE:SMITH TYPE: PDCJR9178 DEPTH IN: 1531' DEPTH OUT: ' Footage Hours On Bottom Off Bottom Connection TOTAL: 89' 2.8 0.5 2.3 0 YESTERDAY'S TOTAL: 0 0 0 0 0 PAST 24 HOURS: 89' 2.8 0.5 2.3 0 GAS SUMMARY BACKGROUND GAS: Max: 207u @1555' Average: 105 Current: 31u CONNECTION GAS: Max: NA Average: NA Current: _ NA TRIP GAS: 33u WIPER TRIP GAS: ) NA GROSS LITHOLOGY: COAL AND PEAT: 0 % SILTSTONE: 0 % SAND: 40 % CLAYSTONE: 60 % CONGLOMERATE: 0 % TUFF: 0 % COAL INTERVALS: COAL ANTICIPATED: Correlating approximately 40' high to type log. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Repaired hydrill and finished testing BOPE. Picked up steerable BHA #9 with new PDC bit #6. Tested MWD and ran in hole to 1390', tagged cement, pulled off bottom, filled pipe, and tested casing. Drilled cement from 1390' to 1530', gas maximum of 360u at 1450', then formation from 1530' to 1542'. Tested casing. Drilled ahead from 1542' to 1620'. I4 EPOCH 62 uNocALe M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: October 6, 2001 DAILY COST: $1740 CUM COST: $38360 12:01 AM DEPTH: 2544' YESTERDAY: 1620' 24 HR FTG: 924' ROP (FT /HR): PRESENT: 130 24 HR AVE: 142 CURRENT BIT INFORMATION: NO.:6 MAKE:SMITH TYPE: PDC JR9178 DEPTH IN: 1531' DEPTH OUT: ' Footage Hours On Bottom Off Bottom Connection TOTAL: 1013 26.8 7.0 19.8 10.2 YESTERDAY'S TOTAL: 89 2.8 0.5 2.3 0.0 PAST 24 HOURS: 924 24 6.5 17.5 10.2 GAS SUMMARY BACKGROUND GAS: Max: 414u @2508' Average: 108u Current: 60u CONNECTION GAS: Max: _ u@ Average: Current: u@ TRIP GAS: NA WIPER TRIP GAS: I 170u @1980' GROSS LITHOLOGY: COAL AND PEAT: 20 % SILTSTONE: 20 SAND: 30 % CLAYSTONE: 30 % CONGLOMERATE: 0 % TUFF: 0 % COAL INTERVALS: COAL ANTICIPATED: Correlating approximately 62' high to type log. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Drilled ahead, rotating and sliding, from 1620' to 1980'. Pulled out of hole to shoe and repaired saver sub on top drive. Tripped in to bottom washing down last stand, and drilled ahead, rotating and sliding from 1980' to 2544'. El EPOCH 63 UNOCAL M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: October 7, 2001 DAILY COST: $1740 CUM COST: $40100 12:01 AM DEPTH: 4473' YESTERDAY: 2544' 24 HR FTG: 1929' ROP (FT /HR): PRESENT: 78 24 HR AVE: 126 CURRENT BIT INFORMATION: NO.:6 MAKE:SMITH TYPE: PDC JR9178 DEPTH IN: 1531' DEPTH OUT: ' Footage Hours On Bottom Off Bottom Connection TOTAL: 2942 50.8 22.3 28.5 10.7 YESTERDAY'S TOTAL: 1013 26.8 7.0 19.8 10.2 PAST 24 HOURS: 1929 24 15.3 8.7 0.5 GAS SUMMARY BACKGROUND GAS: Max: 516u @2753' Averaee: 179u Current: 42u CONNECTION GAS: Max: Ou@ Average: 0 Current: Ou@ TRIP GAS: NA WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL AND PEAT: 20 % SILTSTONE: 10 % SAND: 40 % CLAYSTONE: 30 % CONGLOMERATE: 0 % TUFF: 0 COAL INTERVALS: 2580 -2605, 2660 -2665, 2720 -2780, 2800 -2815, 2845 -2860, 3010 -3045, 3225 -3250, 3570- 3590, 3790 -3835, 3975 -4030, 4290 -4345. COAL ANTICIPATED: Correlating approximately 50' low to type log. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Drilled ahead, rotating and sliding, from 2544' to 3495'. Changed shaker screens. Continued rotating and sliding to 4473'. EPOCH 64 UNOCAL M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: October 8, 2001 DAILY COST: $1740 CUM COST: $41840 12:01 AM DEPTH: 5528' YESTERDAY: 4473' 24 HR FTG: 1055 ROP (FT /HR): PRESENT: 58 24 HR AVE: 70.3 CURRENT BIT INFORMATION: NO.:6 MAKE:SMITH TYPE: PDC JR9178 DEPTH IN: 1531' DEPTH OUT: ' Footage Hours On Bottom Off Bottom Connection TOTAL: 3997 74.1 37.3 37.5 11.2 YESTERDAY'S TOTAL: 2942 50.8 22.3 28.5 10.7 PAST 24 HOURS: 1055 23.3 15.0 9 0.5 GAS SUMMARY BACKGROUND GAS: Max: 354u @4788' Average: 69u Current: 9u CONNECTION GAS: Max: Ou@ Average: 0 Current: Ou@ TRIP GAS: NA WIPER TRIP GAS: 1 NA GROSS LITHOLOGY: COAL AND PEAT: 10 % SILTSTONE: 10 % SAND: 40 % CLAYSTONE: 40 % CONGLOMERATE: 0 % TUFF: 0 % COAL INTERVALS: 4610 -4645, 4780 -4800, 4970 -5005, 5175 -5200, 5295 -5315. COAL ANTICIPATED: Correlating approximately 40' low to type log. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Drilled ahead, rotating and sliding, from 4473' to 5530'. Eli EPOCH 65 UNOCAL M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: October 9, 2001 DAILY COST: $1740 CUM COST: $43580 12:01 AM DEPTH: 5528' YESTERDAY: 5528' 24 HR FTG: 0 ROP (FT /HR): PRESENT: 0 24 HR AVE: 0 CURRENT BIT INFORMATION: NO.:6 MAKE:SMITH TYPE: PDC JR9178 DEPTH IN: 1531' DEPTH OUT: 5528' Footage Hours On Bottom Off Bottom Connection TOTAL: 3997 85.7 37.3 49.1 23.1 YESTERDAY'S TOTAL: 3997 74.1 37.3 37.5 20.1 PAST 24 HOURS: 0 11.6 0 11.6 3.0 GAS SUMMARY BACKGROUND GAS: Max: u @' Average: u Current: u CONNECTION GAS: Max: Ou@ Average: 0 Current: Ou@ TRIP GAS: NA WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL AND PEAT: 10 % SILTSTONE: 10 % SAND: 40 % CLAYSTONE: 40 % CONGLOMERATE: 0 % TUFF: 0 % COAL INTERVALS: COAL ANTICIPATED: Correlating approximately 40' low to type log. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Circulated bottoms up. Monitored well. 8 -10 bbl per hour loss. Pumped LCM pill 20 lbs. per bbls, 20 bbls, placed pill. Pulled out of the hole wet from 5553' to 2280'. Worked through tight spots. Circulated bottoms up. Pumped 28 bbl LCM pill. Back reamed 2280 - 2150'. Worked on top drive. Continued to back ream 2150 - 1520'. Pulled out of the hole from 1520 to surface. Downloaded MWD tool. Made up BHA #10. Li EPOCH 66 UNOCAL. M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: October 10, 2001 DAILY COST: $1740 CUM COST: $45320 12:01 AM DEPTH: 6045' YESTERDAY: 5528' 24 HR FTG: 517 ROP (FT /HR): PRESENT: 34 24 HR AVE: 41 CURRENT BIT INFORMATION: NO.:6 MAKE:SMITH TYPE: PDC JR9178 DEPTH IN: 1531' DEPTH OUT: 5528' Footage Hours On Bottom Off Bottom Connection TOTAL: 3997 85.7 37.3 49.1 23.1 YESTERDAY'S TOTAL: 3997 85.7 37.3 49.1 23.1 PAST 24 HOURS: 0 0 0 0 0 NO.:RR6 MAKE:SMITH TYPE: PDC JR9178 DEPTH IN: 5528' DEPTH OUT: ' Footage Hours On Bottom Off Bottom Connection TOTAL: 517' 16.4 12.4 4 .5 YESTERDAY'S TOTAL: 0 0 0 0 0 PAST 24 HOURS: 517' 16.4 12.4 4 .5 GAS SUMMARY BACKGROUND GAS: Max: _ 173u @5787' Avera2e: 25.1u Current: 84u CONNECTION GAS: Max: Ou@ Avera2e: Ou Current: Ou@ TRIP GAS: 120u @5528' WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL AND PEAT: 10 % SILTSTONE: 10 % SAND: 40 % CLAYSTONE: 40 % CONGLOMERATE: 0 % TUFF: 0 % COAL INTERVALS: 5750 -5860' COAL ANTICIPATED: Correlating approximately 70' to 75' low to type log. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Made up BHA #10. Ran in the hole to shoe. Hung blocks to cut and slip drill line. Ran in the hole below shoe to test MWD tool. Ran in the hole reaming from 5438' to 5530'. Circulated to clean hole. Changed shaker screens. Drilled from 5533' to 6045'. El EPOCH 67 UNOCAL M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: October 11, 2001 DAILY COST: $1740 CUM COST: $47060 12:01 AM DEPTH: 6568' YESTERDAY: 6045' 24 HR FTG: 523 ROP (FT /HR): PRESENT: 28 24 HR AVE: 37.1 CURRENT BIT INFORMATION: NO.:RR6 MAKE:SMITH TYPE: PDC JR9178 DEPTH IN: 5528' DEPTH OUT: 6568' Footage Hours On Bottom Off Bottom Connection TOTAL: 1040' 37 26.5 10.4 1.0 YESTERDAY'S TOTAL: 517' 16.4 12.4 4.0 0.5 PAST 24 HOURS: 523' 20.6 14.1 6.4 0.5 GAS SUMMARY BACKGROUND GAS: Max: ^ 325u @6416' Averaee: 71u Current: u CONNECTION GAS: Max: . Ou@ Average: Ou Current: _ Ou@ TRIP GAS: NA WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 30 % SILTSTONE: 10 % SAND: 10 % CLAYSTONE: 50 % CONGLOMERATE: 0 % TUFF: 0 % COAL INTERVALS: 6030 -50', 6070 - 6105', 6170 - 6185', 6255 - 6285', 6415 -40', 6455 -75', 6520 -35'. COAL ANTICIPATED: Correlating approximately 20-30' low to type log. I SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Drilled from 6045' to 6568'. Circulated bottoms up. Pumped a sweep. Epoch put on standby. U4 EPOCH 68 UNOCALO M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: October 15, 2001 DAILY COST: $1740 CUM COST: $53540 12:01 AM DEPTH: 6984' YESTERDAY: 6568' 24 HR FTG: 416 ROP (FT /HR): PRESENT: 5 24 HR AVE: 66.0 CURRENT BIT INFORMATION: NO.:6 MAKE:HYCALOG TYPE: PDC 102086 DEPTH IN: 6568' DEPTH OUT: NA' Footage Hours On Bottom Off Bottom Connection TOTAL: 416 11.2 6.3 4.9 1.0 YESTERDAY'S TOTAL: 0' 0 _ 0 0 0 PAST 24 HOURS: 416' 11.2 6.3 4.90 1.0 GAS SUMMARY BACKGROUND GAS: Max: 60u @6665' Average: 12.3u Current: 5u CONNECTION GAS: Max: 14u@ Averaae: 11u Current: NA TRIP GAS: 176u WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 20 % SILTSTONE: 10 % SAND: 30 % CLAYSTONE: 30 % CONGLOMERATE: 10 % TUFF: Trace% COAL INTERVALS: 6660 - 6670', 6685- 6695', 6760 - 6770', 6855 - 6865'. COAL ANTICIPATED: Correlating approximately 10-20' low to type log. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: RIH with HWDP to 6350'. Slip new drilling line. Service draw works and TD. Drill out cement to shoe from 6536' to 6568'. Drill from 6568' to 6578'. Conduct F.I.T. test on casing. Drill ahead from 6578' to 6984'. U4 EPOCH 69 UNOCAL M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: October 16, 2001 DAILY COST: $1740 CUM COST: $55280 12:01 AM DEPTH: 7306' YESTERDAY: 6984' 24 HR FTG: 322 ROP (FT /HR): PRESENT: 0 24 HR AVE: 26.8 CURRENT BIT INFORMATION: NO.:6 MAKE:HYCALOG TYPE: PDC 102086 DEPTH IN: 6568' DEPTH OUT: NA' Footage Hours On Bottom Off Bottom Connection TOTAL: 738 _ 29.3 18.3 11.0 2.0 YESTERDAY'S TOTAL: 416 11.2 6.3 4.9 1.0 PAST 24 HOURS: 322 18.1 12.0 6.1 1.0 GAS SUMMARY BACKGROUND GAS: Max: 55u @7086' Average: 9.0u Current: Ou CONNECTION GAS: Max: 16u@ Average: 9.0u Current: NA TRIP GAS: NAu WIPER TRIP GAS: 1 NA GROSS LITHOLOGY: COAL: 10 % SILTSTONE: 10 % SAND: 40 % CLAYSTONE: 20 % CONGLOMERATE: 20 % TUFF: Trace% COAL INTERVALS: 6985' - 6995', 7085 - 7095'. COAL ANTICIPATED: Correlating approximately 5 -15' low to type log. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Drill ahead from 6984' to 7306'. MWD failure. Pulling out of hole. €i EPOCH 70 1 UNOCAL M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: October 17, 2001 DAILY COST: $1740 CUM COST: $57020 12:01 AM DEPTH: 8055' YESTERDAY: 7306' 24 HR FTG: 749' ROP (FT /HR): PRESENT: 54 24 HR AVE: 49.9 CURRENT BIT INFORMATION: NO.:8 MAKE:SMITH TYPE: MJ2533 DEPTH IN: 7306' DEPTH OUT: NA' Footage Hours On Bottom Off Bottom Connection TOTAL: 749' 21.3 15.0 6.3 1.0 YESTERDAY'S TOTAL: 0 0 0 PAST 24 HOURS: 749' 21.3 15.0 6.3 1.0 1 N0.:7 MAKE: HYCALOG TYPE: PDC 102086 DEPTH IN: 6568' DEPTH OUT: 7306' Footage Hours On Bottom Off Bottom Connection TOTAL: 738 29.3 18.3 11.0 2.0 YESTERDAY'S TOTAL: 322 18.1 12.0 6.1 1.0 PAST 24 HOURS: 0 0 0 0 0 GAS SUMMARY BACKGROUND GAS: Max: 185u @7577' Averase: 27.0U Current: 12 CONNECTION GAS: Max: 26u@ Avera2e: 16.0u Current: NA TRIP GAS: NAu WIPER TRIP GAS: ( NA GROSS LITHOLOGY: COAL: 20 % SILTSTONE: 10 % SAND: 30 % CLAYSTONE: 30 % CONGLOMERATE: 10 % TUFF: Trace% COAL INTERVALS: 7310 -20', 7340 -45', 7365 -75', 7570 -90', 7680 -90' 7735 -50', 7825 -40' 7878 -85', . COAL ANTICIPATED: Correlating approximately 20 -30' low to type log. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Pick up new BHA ( #12). Run in hole. Drill ahead from 7306 to 8055'. [1 EPOCH 71 UNOCAL M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: October 18, 2001 DAILY COST: $1740 CUM COST: $58760 12:01 AM DEPTH: 8932' YESTERDAY: 8055 24 HR FTG: 877' ROP (FT /HR): PRESENT: 22 24 HR AVE: 44.7 CURRENT BIT INFORMATION: NO.:8 MAKE:SMITH TYPE: MJ2533 DEPTH IN: 7306' DEPTH OUT: NA' Footage Hours On Bottom Off Bottom Connection TOTAL: 1626' 45.4 34.6 10.8 2.0 YESTERDAY'S TOTAL: 749' 21.3 15.0 6.3 1.0 PAST 24 HOURS: 877' 24.1 19.6 4.5 1.0 GAS SUMMARY BACKGROUND GAS: Max: 266u e8118' Average: 17.9u Current: 15u @8917' CONNECTION GAS: Max: 35u@ Average: 30u Current: NA TRIP GAS: NAu WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 20 % SILTSTONE: 10 % SAND: 30 % CLAYSTONE: 30 % CONGLOMERATE: 10 % TUFF: Trace% COAL INTERVALS: 8110 — 20', 8180 — 90', 8420 — 30', 8495 — 8505', 8535 — 45', 8660 —75', 8870 — 75', 8885 — 95'. COAL ANTICIPATED: Correlating approximately 50 - 70' low to type log. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Drill ahead, sliding and rotating, from 8055' to 8932'. U EPOCH 72 UNOCAL M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: October 19, 2001 DAILY COST: $1740 CUM COST: $60500 12:01 AM DEPTH: 9191' YESTERDAY: 8932' 24 HR FTG: 259 ROP (FT /HR): PRESENT: 80 24 HR AVE: 51.8 CURRENT BIT INFORMATION: NO.:9 MAKE:SMITH TYPE: MJ2522 DEPTH IN: 9091' DEPTH OUT: NA' Footage Hours On Bottom Off Bottom Connection TOTAL: 100 1.0 1.0 0 0 YESTERDAY'S TOTAL: NA NA NA NA NA PAST 24 HOURS: 100 1.0 1.0 0 0 NO.:8 MAKE:SMITH TYPE: MJ2533 DEPTH IN: 7306' DEPTH OUT: 9 Footage Hours On Bottom Off Bottom Connection TOTAL: 1626' 45.4 34.6 10.8 2.0 YESTERDAY'S TOTAL: 877' 24.1 19.6 4.5 1.0 PAST 24 HOURS: 159 5.5 4.0 1.0 0.5 GAS SUMMARY BACKGROUND GAS: Max: 245u @8958' Average: 27.5u Current: 15u @9191' CONNECTION GAS: Max: 26u@ Average: 21u Current: NA TRIP GAS: 401u @9092' WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 20 % SILTSTONE: 10 % SAND: 30 % CLAYSTONE: 30 % CONGLOMERATE: 10 % TUFF: Trace% COAL INTERVALS: 8950 -60', 9000 -05', 9035 -40' 9070 -75'. COAL ANTICIPATED: Correlating approximately 45 — 55' low to type log. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Drilled ahead, sliding and rotating, from 8932' to 9091'. Circulated bottoms up. Pulled out of hole to 6500'. Pumped a dry job. Pulled out of hole for new bit #10. Ran in hole with new bit #10. Ran in hole with new bit #10. Drill ahead from 9091' to 9191'. €l EPOCH 73 UNOCAL M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: October 20, 2001 DAILY COST: $1740 CUM COST: $62240 12:01 AM DEPTH: 9803' YESTERDAY: 9191' 24 HR FTG: 612' ROP (FT /HR): PRESENT: 24 24 HR AVE: 34.4 CURRENT BIT INFORMATION: NO.:9 MAKE:SMITHTYPE: 15GFDG SIN: MJ2522 DEPTH IN: 9091'DEPTH OUT: NA' Footage Hours On Bottom Off Bottom Connection TOTAL: 712 24.8 18.8 10.0 0 YESTERDAY'S TOTAL: 100 1.0 1.0 5.0 0 PAST 24 HOURS: _ 612 23.8 17.8 5.0 1.0 GAS SUMMARY BACKGROUND GAS: Max: 219u @9464' Average: 23.8u Current: 8u @9803' CONNECTION GAS: Max: 26u Average: 21u Current: 20u TRIP GAS: NA WIPER TRIP GAS: 1 NA GROSS LITHOLOGY: COAL: 20 % SILTSTONE: 10 % SAND: 20 % CLAYSTONE: 40 % CONGLOMERATE: 10 % TUFF: Trace% COAL INTERVALS: 9215 -20', 9225 -30', 9235 -40', 9245 -50', 9265 -70', 9275 -80', 9285 -90', 9360 -70', 9390 -95', 9445 -55', 9515 -20', 9540 -45', 9555 -60', 9590 -95', 9630 -50', 9705 -10', 9730 -35'. COAL ANTICIPATED: Correlating approximately 45 - 55' low to type log. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Drilled ahead from 9191' to 9288'. Saver sub broke out on connection. Torqued back up and it broke out again. Changed out saver sub. Drill ahead, sliding and rotating, from 9288' to 9803'. ELI EPOCH 74 !!NOCAL M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: October 21, 2001 DAILY COST: $1740 CUM COST: $63980 12:01 AM DEPTH: 10404' YESTERDAY: 9803' 24 HR FTG: 601' ROP (FT /HR): PRESENT: 0 24 HR AVE: 34.4 CURRENT BIT INFORMATION: NO.:9 MAKE:SMITH TYPE: 15GFDG S /N: MJ2522 DEPTH IN: 9091' DEPTH OUT: NA' Footage Hours On Bottom Off Bottom Connection TOTAL: 1313 42.4 31.4 13.3 1.5 YESTERDAY'S TOTAL: 612 23.8 17.8 5.0 1.0 PAST 24 HOURS: 601 17.4 13.6 3.3 .5 GAS SUMMARY BACKGROUND GAS: Max: 184u @10033' Average: 27.3u Current: NA CONNECTION GAS: Max: 26u Average: 21u Current: NA TRIP GAS: NA WIPER TRIP GAS: _ I NA GROSS LITHOLOGY: COAL: 20 % SILTSTONE: 10 % SAND: 20 % CLAYSTONE: 40 % CONGLOMERATE: 10 % TUFF: Trace% COAL INTERVALS: 9810 -15', 9845 -55', 9925 -40', 9990 - 10000', 10010 -15', 10085 -90', 10125 -30', 10160 -65', 10230 -35' 10260 -65'. COAL ANTICIPATED: Correlating approximately 50 - 60' low to type log. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Drilled ahead, sliding and rotating, from 9803 to 10404'. Trip out of hole for new bit #10. I I , 11 EPOCH 75 UNOCALO M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: October 22, 2001 DAILY COST: $1740 CUM COST: $65720 12:01 AM DEPTH: 10404' YESTERDAY: 10404' 24 HR FTG: 0' ROP (FT /HR): PRESENT: 0 24 HR AVE: 0 CURRENT BIT INFORMATION: NO.:9 MAKE:SMITH TYPE: 15GFDG S /N: MJ2522 DEPTH IN: 9091' DEPTH OUT: 10404' Footage Hours On Bottom Off Bottom Connection TOTAL: 1313 42.4 31.4 13.3 1.5 YESTERDAY'S TOTAL: 601 17.4 13.6 3.3 .5 PAST 24 HOURS: 0 0 0 0 0 GAS SUMMARY BACKGROUND GAS: Max: NA Average: NA Current: NA CONNECTION GAS: Max: NA Average: NA Current: NA TRIP GAS: NA WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 20 % SILTSTONE: 10 % SAND: 20 % CLAYSTONE: 40 % CONGLOMERATE: 10 % TUFF: Trace% COAL INTERVALS: COAL ANTICIPATED: Correlating approximately 50 - 60' low to type log. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Trip out of hole for new bit #10. Stuck in hole. Work stuck pipe at 7803'. Able to break lose. Backream from 7803 - 7400'. Circulate bottoms up at 6500', pump dry job. Continue to trip out of hole for new bit. Lay down BHA. Test BOP's. Pick up new BHA. [1 EPOCH 76 UNOCAL M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: October 23, 2001 DAILY COST: $1740 CUM COST: $67460 12:01 AM DEPTH: 10680' YESTERDAY: 10404' 24 HR FTG: 276' ROP (FT /HR): PRESENT: 0 24 HR AVE: 40 CURRENT BIT INFORMATION: NO.:10 MAKE:SMITH TYPE: ER6026PS S /N: MJ1304 DEPTH IN: 10404' DEPTH OUT: NA' Footage Hours On Bottom Off Bottom Connection TOTAL: 276 11.3 6.9 3.9 .5 YESTERDAY'S TOTAL: NA NA NA NA NA PAST 24 HOURS: 276 11.3 6.9 3.9 .5 GAS SUMMARY BACKGROUND GAS: Max: I 212@10680 Averag I `emu e: I 51.0 Current: CONNECTION GAS: Max: a1 26u Average: 21u Current: TRIP GAS: _ 980 U WIPER TRIP GAS: NA NA GROSS LITHOLOGY: COAL: 20 % SILTSTONE: 10 % SAND: 20 % CLAYSTONE: 30 % CONGLOMERATE: 10 % TUFF: 10 % COAL INTERVALS: 10445 -50', 10505 -10', 10515 -20', 10555 -60', 10565 -70', 10575 -80', 10670 -80'. COAL ANTICIPATED: Correlating approximately 75-80" low to type log. SHOW SUMMARY: NONE Lithotogy Descriptions: REMARKS: Run in hole with new bit #10. Torque every connection. Ream through tight spots. Drill ahead from 10404 - 10680'. Circulate bottoms up. Ell EPOCH 77 UNOCALO M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: October 24, 2001 DAILY COST: $1740 CUM COST: $69200 12:01 AM DEPTH: 10715' YESTERDAY: 10680' 24 HR FTG: 35' ROP (FT /HR): PRESENT: 0 24 HR AVE: 58.3 CURRENT BIT INFORMATION: NO.:10 MAKE:SMITH TYPE: ER6026PS S /N: MJ1304 DEPTH IN: 10� DEPTH OUT: NA' Footage Hours On Bottom Off Bottom Connection TOTAL: 311 13.1 7.5 4.9 YESTERDAY'S TOTAL: 276 11.3 6.9 3.9 .2 .7 5 1 PAST 24 HOURS: 35 1.0 .6 1.0 .2 GAS SUMMARY BACKGROUND GAS: Max: I NA NA Average: NA Current: Ou CONNECTION GAS: Max: TRIP GAS: Average: NA Current: I NA NA WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 20 % SILTSTONE: 10 % SAND: 20 % CLAYSTONE: 30 % CONGLOMERATE: 10 % TUFF: 10 % COAL INTERVALS: COAL ANTICIPATED: Correlating approximately 75-80" low to type log. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Drill ahead from 10680' to 10715' (TD). Circulate bottoms up. Pull out of hole for new BHA and LWD tools. Lay down BHA. Pick up new BHA. Load MADD tools. Run in hole with new BHA. U4 EPOCH 78 UNOCAL M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: October 25, 2001 DAILY COST: $1740 CUM COST: $70940 12:01 AM DEPTH: 10715' YESTERDAY: 10715' 24 HR FTG: NA ROP (FT /HR): PRESENT: 0 24 HR AVE: NA CURRENT BIT INFORMATION: NO.:10 MAKE:SMITH TYPE: ER6026PS S /N: MJ1304 DEPTH IN: 10404' DEPTH OUT: NA' Footage Hours On Bottom Off Bottom Connection TOTAL: 311 13.1 7.5 4.9 .7 YESTERDAY'S TOTAL: 35 1.8 .6 1.0 PAST 24 HOURS: 0 0 0 0 0 p GAS SUMMARY BACKGROUND GAS: Max: I 340u cei 10670' Average: I 30u Current:) Ou CONNECTION GAS: Max: NA Average: NA Current: I NA TRIP GAS: NA WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 20 % SILTSTONE: 10 % SAND: 20 % CLAYSTONE: 30 % CONGLOMERATE: 10 % TUFF: 10 % COAL INTERVALS: NONE. COAL ANTICIPATED: NONE. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Run in hole with new BHA to shoe. Run LWD pass from shoe (6568') to TD (10715'). El EPOCH 79 UNOCAL M12 EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M -12, STEELHEAD PLATFORM DATE: October 26, 2001 DAILY COST: $1740 CUM COST: $72680 12:01 AM DEPTH: 10715' YESTERDAY: 10715' 24 HR FTG: NA ROP (FT /HR): PRESENT: 0 24 HR AVE: NA CURRENT BIT INFORMATION: NO.:10 MAKE:SMITH TYPE: ER6026PS S /N: MJ1304 DEPTH IN: 10404' DEPTH OUT: NA' Footage Hours On Bottom Off Bottom Connection TOTAL: 311 13.1 7.5 4,9 .7 YESTERDAY'S TOTAL: PAST 24 HOURS: 0 0 0 0 0 GAS SUMMARY BACKGROUND GAS: Max: NA Averaee: NA Current: Ou CONNECTION GAS: Max: NA Averaee: NA Current: NA TRIP GAS: NA WIPER TRIP GAS: I NA GROSS LITHOLOGY: COAL: 20 % SILTSTONE: 10 % SAND: 20 % CLAYSTONE: 30 % CONGLOMERATE: 10 % TUFF: 10 % COAL INTERVALS: NONE. COAL ANTICIPATED: NONE. SHOW SUMMARY: NONE Lithology Descriptions: REMARKS: Pull out of hole with LWD. Lay down BHA. Start casing /liner. U EPOCH 80 J; , (' UNoCAL8 McArthur River Field Steelhead Well M-12 General Procedure 8/27/2001 1 Skid rig from M-14RD to M-12 slot 3 2 NU diverter, overboard lines 3 Function test di verter 4 PU directional drilling assy, tag fill in conductor 5 R U gyro survey tool 6 Spud well and drill 24" hole to 850' 10 Short trip and circ thoroughly 11 POOH 12 Run 18-5/8" casing, land hanger 13 Cement 18-5/8" casing at 850' 14 WOC 15 ND diverter, install packoff. 16 NU and test BOPE 17 RIH with 17-1/2" directional drilling assy, 18 Drill out shoe and perform LOT 19 Drill 17-1/2" hole from 850' to 1500' 20 Short trip and circ thoroughly 21 POOH 22 Run 13-3/8" casing to 1500', land hanger 23 Cement 13-3/8" casing at 1500' 24 RIH with 12-1/4" directional drilling Assy, 25 WOC 26 Drill cmt and perform LOT 27 Drill 12-1/4" hole from 1500' to 4867' TVD/6800' MD 28 Circ hole, POOH to run casing 29 Run 9-5/8" casing to 6800'MD 30 Cement 9-5/8" casing 31 PU DP and RIH with 6" directional drilling assy. 32 Drill cmt and perform LOT 33 Drill from 6800' to 10755' MD/8722' TVD 34 Circ and POOH to run liner 35 Run 4155' of 3-1/2" liner to 10755' TD 36 Set hanger, cmt liner, set liner top packer 37 POOH with drill pipe and running tool General Procedure M-12 1 8/27/2001 I ~. (' UNoCAL8 McArthur River Field Steelhead Well M-12 General Procedure 8/27/2001 38 Run 3-112" tbg inel SSSV, chern inj mandrel and GLMs 39 Circ. KCL brine. Stab into 3-112" liner top, test annulus 40 Space out and land hanger, retest annulus 41 ND BOPE, NU tree and test 42 Clean Out well Perf well after rig released General Procedure M-12 2 8/27/2001 ., , . - UNOCALf) Report Date: Client: Reid: Structure I Slot Well: Borehole: UWl/API#: Survey Name / Date: Tort I AHD I DOlI ERD ratio: Grid Coordinate System: Location lat/long: Location Grid NJE YlX: Grid Convergence Angle: Grid Scale Factor. M-12 . . Proposed Well Profile';' Geodetic Report May 3D, 2001 Unocal McArthur River Unit ft I ~~head/M-12(regA1 S~3) . . study "," Y M-12 Feasibility . Schlumberger Survey I DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Minimum Curvature / Lubinski 24.940° N 0.000 ft, E 0.000 ft KB 152.0 ft relative to Mean Sea Level M-12/ May 30, 2001 100.124 ° 15022.95 ft 15.792/ 0.57E NAD27 Alaska State Planes, Zone 4, US Feel N 604954.562, W 151368.737 N 2499463.220 ftUS, E 214075.220 ftUS -1.39931489° 0.99999303 Magnetic Declination: Total Reid Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North.> True North: Local Coordinates Referenced To: 20.755° 55376.066 nT 73.515° September 12, 2001 BGGM 2001 True North +20.755° Well Head ~-'. Grid Coordinates Station ID I MD Northing Easting 'ft flUS ftUS KBE 0.00 2499463.22 214075.22 N 604954.562 W 151 368.737 KOP Bid 3/100 550.00 2499463.22 214075.22 N 604954.562 W 151 368.737 600.00 2499463.81 214075.50 N 60 49 54.568 W 151368.732 700.00 2499468.55 214077.71 N 604954.616 W 151 36 8.689 800.00 2499478.02 214082.14 N 60 49 54.710 W 151 368.605 900.00 10.50 23.68 898.04 31.97 29.29 12.85 3.00 2499492.19 214088.78 N 60 49 54.851 W 151 368.478 1000.00 13.50 23.68 995.85 52.76 48.33 21.20 3.00 2499511.02 214097.59 N 604955.038. W 151 368.309 1100.00 16.50 23.68 1092.43 78.63 72.03 31.59 3.00 2499534.46 214108.56 N 604955.272 W 151368.100 .- 1200.00 19.50 23.68 1187.52 109.52 100.32 44.00 3.00 2499562.44 214121.66 N 604955.550 W 151 367.849 1300.00 22.50 23.68 1280.87 145.34 133.14 58.39 3.00 2499594.89 214136.84 N 604955.874 W 151 367.559 1400.00 25.50 23.68 1372.22 186.00 170.38 74.73 3.00 2499631.72 214154.09 N 604956.240 W 151 367.229 1500.00 28.50 23.68 1461.31 231.39 211.95 92.96 3.00 2499672.84 214173.33 N 60 49 56.650 W 151 366.862 1600.00 31.50 23.68 1547.90 . 281.37 257.74 113.04 3.00 2499718.12 214194.52 N604957.100 W 151 366.457 1700.00 34.50 23.68 1631.76 335.81 307.61 134.92 3.00 2499767.44 214217.61 N 604957.592 W 151 366.015 1800.00 37.50 23.68 1712.65 394.57 361.43 158.52 3.00 2499820.67 214242.52 N 60 49 58.122 W 151 365.539 1900.00 40.50 23.68 1790.35 457.48 419.06 183.80 3.00 2499877.66 214269.20 N 604958.689 W 151 365.029 2000.00 43.50 23.68 1864.66 524.37 480.33 210.67 3.00 . 2499938.26 214297.56 N 604959.292 W 151 364.487 2100.00 46.50 23.68 1935.36 . 595.06 . 545.08 239.07 3.00 2500002.29 214327.53 N 604959.930 W 151 363.914 M-12 (P1) reporlxls Page 1 of 2 5/30/2001-7:37 PM Grid Coordinates Station ID I MD Northing Easting 'It ftUS ftUS End Cry 2369.01 2500190.23 214415.49 N 60501.801 W 151 362.233 Tgt 1/ Cry 5/100 5967.05 2502845.54 215658.28 N 60 5028.-240 W 151 3538.470 6000.00 2502869.59 215669.58 N 60 5028.479 W 151 3538.254 6100.00 2502939.15 215702.75 N 60 5029.172 W 151 3537.619 6200.00 2503003.16 215734.04 N 60 50 29.809 W 151 3537.019 6300.00 37.99 25.72 4421.33 3973.35 3638.07 1599.65 5.00 2503061.11 215763.22 N 60 50 30.387 W 151 3536.458 6400.00 33.02 26.65 4502.72 4031.38 3690.18 1625.24 5.00 2503112.58 215790.08 N 60 5030.900 W 151 3535.942 6500.00 28.05 27.86 4588.82 4082.13 3735,35 1648.41 5.00 2503157.17 215814.40 N 60 50 31.345 W 151 3535.473 6600.00 23.11 29.55 4679.00 4125.20 3773.23 1669.14 5.00 2503194.53 215835.99 N 60 50 31.718 W 151 3535.056 End Cry 6676.21 19.35 31.37 4750.02 4152.66 3797.03 1683.10' 5.00 2503217.98 215850.53 N 60 50 31,952 W 151 3534.774 ---. Tgt 21 Cry 5/100 7817.68 19.35 31.37 5827.00 4528.55 4120.00 1880.00 0.00 2503536.05 216055.25 N 60 50 35.132 W 151 3530.800 7900.00 15.24 30.68 5905.58 4552.88 4140.96 1892.63 5.00 2503556.69 216068.39 N 60 50 35.339 W 151 3530.545 8000.00 10.25 29.11 6003.08 4574.85 4160.05 1903.67 5.00 2503575.50 216079.89 N 60 50 35.526 W 151 3530.322 EndCrv 8019.59 9.28 28.61 6022.39 4578.16 4162.96 1905.27 5.00 2503578.37 216081.56 N 60 50 35.555 W 151 3530.290 Tgt3 10542.20 9.28 28.61 8512.00 4984.01 4520.00 2100.00 0.00 2503930.55 216284.95 N 60 50 39.071 W 151 3526.359 TO 10754.98 9.28 28.61 8722.00 5018.25 4550.12 2116.43 0.00 2503960.26 216302.11 N 60 50 39.367 W 151 3526.027 LeQal Description: Surface: 4240 FSL 4822 FEL S33 T9N R13W 3M Tgt 1/ Crv 5/100: 2379 FSL 3316 FEL S28T9N R13W SM Tgt 21 Crv 5/100: 3079 FSL2935 FEL S~8 T9N R13W SM Tgt 3: 3479 FSL 2714 FEL S28 T9N R13W SM BHL: 3509 FSL 2697 FELS28 T9N R13W SM NorthinQ m mUg) 2499463.22 2502845.54 2503536.04 2503930.55 2503960.26 EastinQ eX) fftUSl 214075.22 215658.28 216055.25 216284.95 216302.11 /.,~~ M-12 (P1) report.xls Page 2 of 2 5/30/2001-7:37 PM ( ( UNOCALf) VERTICAL Client: Well: Field: Structure: SECTION VIEW Unocal Section At: Date: M-12 McArthur River Unit Steelhead 24.94 deg May 30, 2001 Schlumbergep -2000 .-.-- --'-.'--.-......'..-.'.---.-......,--..... __._m.__._..---..--..... .....- ---....--.-............----......-..-.- ...-..............-...........-.--.-....----..-....--... -..-.......-........-.. ........-.-..-............. 0 ...."-'.-'-.........'.......--.............................'....."......'.....'.................., ................................................................-'..'....'..."..... ................................... .............'-.'.'..................'.'..... ...................,...-...............,..........,.................... .................................... 2000 .................................... KOP Bid 311 0 550 MD 55 TVD 0.00' 23.68 az Odeplrtu,e End C 2389 D 2106TVD 54.57' 23.88' IZ 803 de Irture - Q) > Q) ~....J Q) ro ~ Q) O(/) 0 c: a ro N Q) II :: c: Q) ,- > "f"8 0 - .c .c ro 'õ..= Q)O O~ -N rolC) , S:2 "f"8 1::- Q)CO >~ Q)'¡"': :J Q) ~ a::: I- > Q) W 4000 T911/ CN 8/100 5987 MD 4192 TVD 54.57' 23.88' IZ 3734 depI,lu,e ............................................................................................................................................,............................,......... ................................................................................................................................................ .. End Cry 88 6 MD 4750TVD ~ 19.35' 31. 7'az 4153depertu,e Hold An Ie 19.35° 6000 ......................,..........................................'............"........'...'...'.'...... '....'..""................,....,........"...................................... ........................................'...'.......'.......'....................'...................".........,............. ......'......."...............'........................................ Hal Angle 9.28° 8000 ........................,.....,.....................................,....................,........................ .........'.'......".'.'....'.'..'...".............'.........,.........,........................................'..."..... ..........................'...'................."............,.............................. ..."'.......'........,......".........,.,...............'.......'..'.'............."...........'.....................".... <î T91 3 10542 MD 8512 TVD . 9.28' 28.81' az 4984 departure 10000 TD 10755 MD 8722TVD 9.28' 28.61' az 5018 depertu,e ,-- .-..,.--.--..--. ...--..-----.---- ..-.--.---.-.....--.---.-.....--...-. '.--.....-...--'.-..'."'.'--.........,-..........., .._........__.c...........................................-....,.- -2000 0 2000 4000 6000 Vertical Section Departure at 24,94 deg from (0,0, 0,0), (1 in = 2000 feet) ( ,(' PLAN VIEW Client: Unocal I UNOCAL@) Well: Field: Structure: Scale: Date: M-12 (Pl) McArthur River Steelhead 1 in = 1000 ft 30-May-2001 Unit SChlUin,ber.uer -1000 0 1000 2000 3000 6000 . ,-..- '-'..... .---- 6000 True North Mag Dec ( E 20.75° ) --.- I I Ao ! -oy- , '" ! 0, I ~ I .~ I ~~ t' .::if' .::,' -" -...----.-..-....--- --".-.7' -- I ('~ TO -""m5n~"-81"žnVO---.'."-'.--_. .'..'..-'..--. 9.28' 28.61' IZ 4550 N 2116 E 5000 5000 ,') ~. Tal3 1054 MO 8S12TVD 9.28' 28.6' IZ 4520 N 2100 End CN 8020 MD 8022 TVD .-'..--"'-ïf2"s-r.'.2ê:6"f' Îz... ïã3N....1iïõ5.~'.._...' 4000 4000 ^ ^ ^ J: I- 0:: 0 Z Tal21 CN 51100781 MD 5827 TVD 19.35' 31.37'u 41 ON 1880E End CN 6676 MD 4750 D 19.35' 31.37' IZ 3797 N 1683 E ./' 2000 .........................1....................................... 0 ~ ~. rv :S .;:j I .~ I .~ , ! .............................................,.......1....................................õ>........,............ . I :¡:.. ..,......... I I Tat 11 CN 811005967 MD 419 TVD 54.57' 23.88' IZ 3420 N ISO E 3000 ...'.'...."....................................'.."........................................................................ .................................................................... ...........................................,.......................,..............................................'.'.'................................. 3000 ..'......'....................'...........................................................................................................,...............,......... ..................:... 2000 :r: I- :::::> 0 en V V V 1000 ...........'......"..'.......'.'.... ................................................,.........."'.........'.................1...'............".................... I ..........................................................................................,...........................,........ 1000 En CN 23 MD 2108 TVD 54. 7' 23,88' IZ 73 N 322 E 0 .........................................,....................................................................................... .......................,...................................................................................................,........................................................................................................................................... 0 ...................................................................... KOP Bid 31100 550 MD 550 TVD 0.00' 23.68' IZ 0 N 0 E -1000 I ¡ ..'.".:..'.........'.'........"'.....11......................................,...........,.......,............................................................... ....,........,.......,.................................. ...............................................................................................................................-..........-........................................'...........'....'............'.............................. -1000 -1000 0 «< WEST 1000 2000 , EAST »> 3000 ,. ( ( McArthur River Field Steel head Platform Well M-12 Anticated Surface Pressure The following calculations estimate the anticipated surface pressures (ASP) expected while drilling the M-12 well. Data from numerous wells in the McArthur River Field indicates that a maximum pore pressure gradient of 0.465 psi/ft can be expected in the Grayling Gas Sands from 4000' to 8722' tvd. Also, data from offset wells indicate fracture gradients of 0.68 psi/ft to 850' tvd and greater then 0.74 psi/ft below 1450' tvd (see attached sheet). Casing Size (in.) 28 Drive Pipe 18-5/8 1 3-3/8 9-5/8 3-1/2" Liner Casing Setting Depth (TVD, ft) Pore Pressure Gradient ( #/gal) Mud Pore Wt. Pressure (#/gal) (psi) Fracture Gradient ( #/gal) ASP (psi) 448 850 1461 4867 8722 8.6 8,8 9,0 9.0 9.2 9.2 9.4 9.4 380 668 2278 4082 99 221 380 1265 13.1 14.2 14,2 Procedure for Calculatina Ant~ace Pressure <A§.f) While Dri!!!!!g ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat (with a gas bubble just below the shoe and the mud gradient above the shoe) or 2) formation pore pressure at the next casing point less gas gradient to the surface as follows: For the 24" Hole Section from 448' TVD to 850' TVD 1) ASP = (FG x 0.052 x D) - (MW x 0,052 x D) = (13.1 x 0,052 x 448) - (9.2 x 0,052 x 448) = 99 psi 2) ASP = FPP - (0,1 gas gradient x D) = 380 - (0,1 x 850) = 295 psi NOTE: This hole section will be drilled utilizing a diverter and is not designed to shut the well in. The values for a fracture gradient at the 28" Drive Pipe shoe have been estimated using the 18-5/8" casing shoe depth data, but without offset well data to support, For the 17-1/2" Hole Section from 850' TVD to 1461' TVD 1) ASP = (FG x 0,052 x D) - (MW x 0,052 x D) = (14,2 x 0.052 x 850) - (9,2 x 0,052 x 850) = 221 psi 2) ASP = FPP - (0,1 gas gradient x D) = 2278 - (0,1 x 8722) = 1405 psi I' ( ( McArthur River Field Steelhead Platform Well #M-12 Anticipated Surface Pressure For the 12-1/4" Hole Section from 1461' TVD to 4867' TVD 1) ASP = (FG x 0.052 x D) - (MW x 0.052 x D) = (14.2 x 0.052 x 1461) - (9.2 x 0.052 x 1461) = 380 psi 2) ASP = FPP - (0.1 gas gradient x D) = 2278 - (0.1 x 4867) = 1791 psi For the 6" Hole Section from 4867' TVD to 8722' TVD 1) ASP = (FG x 0.052 x D) - (MW x 0,052 x D) = (14,2 x 0,052 x 4867) - (9.2 x 0.052 x 4867) = 1265 psi 2) ASP = FPP - (0.1 gas gradient x D) = 4082 - (0,1 x 8722) = 3210 psi CASING DESIGN WELL: STEELHEAD M-12 FIELD: TRADING BAY UNIT DATE: 27-Aug-01 DESIGN BY: Larry Buster Section 1. MUD WT. 9.2 PPG MSP= 99 psi Section 2. MUD WT. 9.2 PPG MSP= 221 psi Section 3. MUD WT. 9.4 PPG MSP= 380 psi Section 4 MUD WT. 9.4 PPG MSP= 1265 psi TENSION MINIMUM COLLAPSE COLLAPSE MAX WEIGHT TOP OF STRENGTH PRESS @ RESIST. SURF MINIMUM INTERVAL DESCRIPTION WIO BF SECTION TENSION BOTTOM wlo TENSION PRESSURE YIELD CASING SIZE BOTTOM TOP LENGTH WT. GRADE THREAD LBS LBS 1000 LBS SF TENSION PSI" PSI SF COLL. PSI" ~ SF BURST 18-5/8" 850 82 768 94.5 X-56 DO E-60 72576 72576 1468 20.23 374 780 2.09 643 2420 3.76 .- TVD 850 82 2 13-3/8" 1500 82 1418 68 K-55 BTC 96424 96424 1069 11.09 643 1950 3.03 2141 3450 1.61 TVD 1461 82 3 9-5/8" 6800 82 6718 47 N-80 BTC 315746 315746 1086 3.44 2141 4760 2.22 3838 6870 1.79 TVD 4867 82 4 3-1/2" 10755 6600 4155 9.2 L-80 BTC 38226 38226 159 4.16 3838 10530 2.74 3838 10160 2.65 TVD 8722 4679 NOTES: See attached for calculation of M.S.P. including assumptions & estimates. . Collapse pressure is calculated; Normal Pressure Fluid Gradient for external stress (.44 psilft) and the casing evacuated for the internal stress (0 psilft) .. Maximum surface pressure is calculated; (BHP @ depth next csg assuming a Normal Fluid Gradient (.44 psi/ft» - .1 ~. I l N í :II ! ~ ~ f ~ .:J , I I I KIN G II -------t------- I I I I I I 22 . UNOCALO McArthur River Field Steel head Platform M.12 Well Proposal ***** 16 15 . TradIng Bay Unit Boundary -------- , ADL-18772 Unocal I I I I 20 ADL-17594 Unocal Marathon 21 ---------. I M-12 I Proposed I I I 27 I 29 28 I I GRAYLING II I ADL-18730 I I Unocal Marathon I I 1--.---.--- ----------------- I STEELHEAD I I I I I I 32 33 34 I I I I , I 0 1,000 2,000 3,000 ~--- I I T9N - R13W SCALE IN FEET ADL-18729 TBN - R13W ADL-17579 U nocal U nocal Marathon ( ( STEELHEAD M-12 Cementing Program 18-5/8" Surface Casina 24" hole @ 850' MOl 850' TVO. Cement Volume for open hole based on open hole volume plus 100%, casing annulus and shoe joints. Class G (Litecrete) with additives at 12.0 ppg. 850' (850'-0') x 0,22257 bbl/ft x 2,0 (100% excess) = 378 bbl 80' float joints = 80' x ,3028 bbl/ft = 24.2 bbl Total cement = 402 bbls or 2257 cu ft 13-3/8" Intermediate Casina 17-1/2" hole @ 1500' MOl 1461' TVO. Cement Volume for open hole based on open hole volume plus 50%, casing annulus and shoe joints, Class G (Litecrete) with additives at 12.0 ppg, 1500' (1500'-0') x ,12372 bbl/ft x 1,5 (50% excess) = 278 bbl 80' float joints = 80' x ,14973 bbl/ft = 12.0 bbl Total cement = 290 bbl or 1625 cuft 9-5/8" Intermediate Casina 12-1/4" hole @ 6800' MOl 4867' TVO. Cement Volume for open hole based on open hole volume plus 20%, casing annulus and shoe joints, Class G (Litecrete) with additives at 12,0 ppg, 5500' (6800 - 1300) x 0.0558 bbl/ft x 1,2 (20% excess) = 368 bbl 80' float joints = 80' x 0,07586 bbl/ft = 6.1 bbl Total cement = 374 bbl or 2096 cuft 3-1/2" Production Liner 6" hole @ 10755' MOl 8722' TVO, Cement Volume for open hole based volume plus 20%, casing annulus and shoe joints, Class G (Gasblok) with additives at 15,8 ppg. 3950' (10750 - 6800') x 0,02308 bbl/ft X 1,2 (20% excess) = 109 bbl 200' Liner Lap = 5,1 bbl 200' above liner = 5.7 bbl 80' float joints = 80' x 0.0087 bbl = ,7 bbl Total cement = 120,5 bbl or 678 cu ft 82.1S' Schematic 20,50' 5.65' Rig Sub Gratìng Floor 23.47' Needed For Nipple UP 21.07' each R.95 2. each Spare Drill 84 1 3/4" x studs 168 23/4'. , I 3/4 Nuts ( each etra 01 above for Flow nipple) Torque wrench. 10r 200 ft Ibs on on Drll-Qulp Quick clam connector Diverter line Nipple up 160eaeh 1 112'. x 10 Studs 320 each 2318'. xl 112.' Nuts 8 each 16"" 600 flange gaskets Hydraulic line Hook up Choke line to Noth Dlverter Va've Kill line to South Diverter Valve Annular (Close) to annular Upper well bay room floor 17.04' Top of grating In well room 4.08' 22.88' Well head room floor Upper well Bay Floor M-12 163/4" BOP Stack up 71.81. 71.8, 36.25' 6.75' 23.47' 60 Top of 16.. 5 M Tog Spool 59.76. v , ";" , f . TO 1 0" CROWN VENT 15.. . ~l:i) GAS BUSTER r<.,C'~:_.'.. : '-.'; "~;"~ 10- TO SHAKER .'. ;:, - .. . '". + ,c. . " ,- - " , ';<, . ¡ 8 t. rci'cHOKE ;":, ;PANEL - . ¡,. .i ., . . ,::, J;\;~'í, ': - r ;, . c~ 11 ',. SWACOI ;.~.~ .::! CHOKE ;~: ,,'. 1 ~, t:.,:;- .' ,. . . ,. 4 ,l > !. .' BLOW DOWN 12 13 , ... .. 't" 1 01 I BlOCK I 111 4 2 BLOCK NOTE: . SWACO CHOKES , EACH. HYDRAUUCALL Y ACTUATED VIA REMOTF .' ;. (~ -I. I: 6 TO BOPE MANUAL 7 - - - r ....' ,~o' '" .: C"'~ ! -' " . ! (;":~ .~,' ,,~- '- -, ~! '. :, :'. L':' I'.' ':: i I I ' " . '" LI.. .. l. ,', . ' '. I . . . . , ~ - " : ~ ',---, ~ SWACO CHOKE . IIIIJIIXr.[.(\I ..... ... ~ .. ....... CH 0 KE MANIFO LD Unocal PLATFORM. RIGS 4~1/lr & 3-- I.,.. 51 MSP '- .......- -. ..... ..' ..:..----.-- .... 'I' \ ( Drilling Fluids Program UNOCAL Steelhead Platform Well M - 12 McArthur River Unit Prepared by: Lee Dewees Reviewed by: Presented to: Larry Buster August 28,2001 M-I Drilling Fluids LLc. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRILLINIj FLUIDS ~1 \ .J , Interval Summary 24" Well M-12 0-850' M D 18 5/8" Casing 24" Hole Drilling Fluid System Gel - Gelex Key Prod u cts M-I Gel / M-I Bar / Soda Ash / Caustic Soda / Gelex / DD / Sapp Solids Control Flow Line Cleaners / Centrifuge / Desander / Desilter Potential Problems Hole Cleaning / Gravel/Gas Kick / Lost Circulation / Bit Balling IptE:) wal DlÄillingiF IUictRroperties (ft) 0-850 Total Drilled- Solids (%) <6 (ppg) 9.2 (cp,) 7-12 (lb./100ft2) 15 - 25 (lb./100ft2) 12 (ml/30min) 12 - 15 . Build spud system with pre-hydrated bentonite and Gelex in fresh water. . Utilize all solids control equipment. . Pump sweeps if required. . Add DD (drilling detergent) and/or Sapp for possible bit balling. . Potential Problems: Running gravel, bit balling, shallow gas, and swelling clay. M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRILLINI:i FLUIDS ,( ( Interval Summary 17.5" Well M-12 1000' - 1500' MD 13 3/8" Casing 17.5" Hole Drilling Fluid System Gel - Gelex Key Products M-I Gel / M-I Bar / Soda Ash / Caustic Soda / Gelex / DD / Sapp Solids Control Flow Line Cleaners / Centrifuge / Desander / Desilter Potential Problems Hole Cleaning / Gravel/Gas Kick / Lost Circulation / Bit Balling Il'1terv~IDr.illing~ f'1 uld . Prc:>perties Depth Mud Plastic Yield Gel API Total Interval Weight Viscosity Point Strength Fluid Loss Drilled- Solids (ft) (ppg) (cp.) (lb.l100ft2) (lb.l100ft2) (ml/30min) (%) 1000 -1500 9.2 7-12 15 - 25 12 12 - 15 <6 . Build spud system with pre-hydrated bentonite and Gelex in fresh water. . Utilize all solids control equipment. . Pump sweeps if required. . Add DD (drilling detergent) and/or Sapp for possible bit balling. . Potential Problems: Running gravel, bit balling, shallow gas, and swelling clay Lower fluid loss to below 10 cc's API by end of interval with Polypac additions. . M-I Drilling Fluids LLC. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRILLING FLUIDS .,' ( 'I' .~ Interval Summary 12.25" Well M-12 1500' - 6800' M D Drilling Fluid System Seawater Bio-polymer Flo-Drill Key Products Flo- Vis I Polypac UL I Asphosol/ MI Bar I Caustic Soda Resinexl Klagaurd/Lubetex/Dual Flo/KCl/Greencide/citric acid Solids Control Swaco Shale Shakers I Mud Cleaner 1518 Centrifuge Potential Problems Hole cleaning I coal sloughing I drill solids buildup I lost circulation! stuck pipe/shallow gas Interval Drilling Fluid Properties ... .' ...... .... ..... ... .... .... ... ...', ... Depth Mud Plastic Yield API 3RPM Drill Interval Weight Viscosity Point Fluid Loss Reading Solids (ft) (ppg) (cp,) (lb/100ft2) (ml/30min) (%) 1500' -6800' 9.2-9.4 12-20 15-20 < 10 cc's 8-12 <5% . Drill cement and shoe with existing spud mud. . Run leak off test to establish fracture gradient at the kick off window. . Build Flo-Pro NT mud system with the following; 11 ppb KCl, 2.0 ppb Flo-Vis, 2 ppb Dual Flo, 2-4 ppb Soltex, 4-6 ppb Klagaurd. Adjust pH to 9.0 - 9.5 w/Caustic Soda. Adjust 3 RPM reading to> 8 w/Flo-Vis. Raise mud weight to 9,2 ppg, Increase mud weight as required, . If coal becomes a problem, increase Soltex (Asphsol) and Resinex concentration to 4 - 8 ppb. . Maintain 3-4 ppb Klagaurd to inhibit clay swelling. . Add Glydrill GP for lubricity. . Keep drill solids to a minimum by use of all solids control equipment and water additions. . Add Lubetex to system for lubricity and to help sliding, (pilot test to confirm sheen test compli- ance) . Monitor ALC 50 values to ensure ability to discharge mud and cuttings. M-I Drilling Fluids LLC. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRilliNG FLUIDS ,1' ~' Interval Summary 12.25" Well M-12 1500' - 6800' M D Drilling Fluid System Seawater Bio-polymer Flo- Drill Key Products Flo- Vis I Polypac UL I Asphosol/ MI Bar I Caustic Soda Resinexl KlagaurdlLubetex/Dual Flo/KCl/Greencide/citric acid Solids Control Swaco Shale Shakers I Mud Cleaner 1518 Centrifuge Potential Problems Hole cleaning I coal sloughing I drill solids buildup I lost circulation! stuck pipe/shallow gas . Increase mud weight as required. Shallow gas can be a problem on the Steelhead Platform, . Consider the use of a Form A Set AK lost circulation pill if significant loss of returns are en- countered . Use MIX II andl or calcium carbonate for losses if the drill string contains a MWD and a mud motor. M-I Drilling Fluids LLC. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRilliNG FLUIDS. ,( { Interval Summary 6" Well M-12 6800'.10750' MD Drilling Fluid System Seawater Bio-polymer Flo-Drill Key Products Flo- Vis 1 Polypac UL 1 AsphosoV MI Bar 1 Caustic Soda Resinexl Klagaurd/ Lubetex/Dual Flo/KCL/NaCL Solids Control Swaco Shale Shakers 1 Mud Cleaner 1518 Centrifuge Potential Problems Hole cleaning 1 drill solids buildup 1 lost circulation/stuck pipel formation damage ,.. ........ ... ... ... .. . ... .. .. . . .... . ..... ... . ... .... ... ..... ..... ....... ..... ..... .......... ... .. ... ,. c,~.._...,.~,._"-",.,."-,.,..~""..."".c,,,..,,._;.,_.,"""....._._,.....c...,.......,_.,..",'."""",;""",....."",.,."."-,.'"",c"";""c,_.'c,,.,,--,,",-,_.,,...c-.-_.,~c...._.~..~".",-,.._..",-,.'--'"",--~,,,.-'.,.,;;,",~~-"._"..~_..,,_c:,.,,~;.,,_:..c...C_---",","-"'.~,",c~~---~,,"'--'--" In tervälDrilllftg Fl....id pro pe rtle s Depth Interval (ft) 6800'-10750' Mud Plastic Yield API 3RPM Weight Viscosity Point Fluid Loss Reading (ppg) (cp.) (lb/100ft2) (mI/30min) 9.2 8-12 12-15 < 5 cc' s 6-8 Drill Solids (%) <4% . Ifpossible utilize mud system from the 12,25" interval. If possible displace 9 5/8" casing with FIW and drill cement, float collar and shoe with FIW, . Condition fluid as required to lower fluid loss to 5cc or less, lower drilled solids to less than 4%, and adjust rheology as required. Maintain KCl at no greater than 30/0, . Drill to 10750' and displace well to liner displacement completion fluid. (3 % KC1) M-I Drilling Fluids LLc. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRilliNG FLUID 5 0 - ŒJ 0 CENTRIFUGE n C~R PIT 100 BBIS CAP. I I I PIT 0. De BBIS /IR I I I 105 B8IS CAP. l03 ÐBIB /IR 0 0 0 SUCTION PIT 12 320 BBlB CAP. 3. œ BBIS /1ft 0 US BBIB CJP. 1 U HIlS /DI 0 ŒJ 0 JdIX P IT 82 BBIS CAP. 0.." BBIS ,tor 0 0 ~ EQUAUZER Q ) ..... .. - AGITATOR PlUD G UN -.-.---.--.---.----..-.- --..-...- ..----- ŒJ ~ERVE PIT 0 0 ~ ŒJ D~ANDER n ,~~ MUD n CENTRIFUGE PIT CLEANER PIT PIT 100 B8IS C-AP. UB DIU CAP. ~ 106 BBLS CAP. I I I 0.00 BBIS/IR 11 1 BIIS /!If L 03 B81S /IX 0 0 1508 BBIB CAP, 4.8'1 IIIIBJDI 0 N ~ 0 SUCTIO N PIT , 1 320 BBUI Cg, 3. œ IIJU /IR PILL PIT ŒJ ŒJ 80 BBLS CJP, 0.75 BBIS/JIf 010 lliRJ@~~ S TEE LHE AD P LA TFO IUl MUD PIT LAYOUT , . '7 -- 0-1 Legals !( /' ,~ Subject: D-l Legals Date: Thu, 6 Sep 2001 10:11:37 -0700 From: "Buster, Larry W -Alaska" <lbuster@unocal.com> To: "'Davies, Steve'" <steve_davies@admin.state.ak.us> Steve, The Legal Description and depths to the top of the 0-1 Sand would be: 2379 FSL 3316 FEL S28 T9N R13W SM 5967 md/4192' tvd RKB RKB - 152' relative to MSL. Regards, Larry Larry W. Buster Drilling Engineer Unocal Alaska (907) 263-7804 (907) 263-7884 (907) 351-6730 - Office - Fax - Mob. ~. ¡--.--. I ~p rt 1 2 Type: applicationlms-tne I ~ a '. Encoding: base64¡ -_._---~_._,~,----_..__._--_._-"..._-----,,---_. , 1 of 1 9/6/2001 9:23 AM M-12 Permit to Drill Corrections :( ( Subject: M-12 Permit to Drill Corrections Date: Wed, 5 Sep 2001 09:55:53 -0700 From: "Buster, Larry W -Alaska" <lbuster@unocal.com> To: "'Davies, Steve'" <steve - davies@admin.state,ak.us> Steve, As per our discussion, I would like to make the following corrections to the Trading Bay Unit, McArthur River Field, Well M-12 Permit to Drill Application Package: 1. On the Cover Letter addressed to Commissioner Heusser, the proposed TO should be 8722' tvd RKB not 8,752' tvd RKB 2. On the Permit to Drill Application, Item #4 should list the location of well at TO as 3509 FSL and 2697 FEL Sec. 28, T9N, R13W, SM 3. On the Permit to Drill Application, Item #15 should list the Proposed TO at 10,755 MD / 8722' tvd RKB. 4. On the letter from Mr. Shannon Martin, the Total Depth Location should read 3509 FSL and 2697 FEL, Sec. 28, T9N, R13W, SW. Please advise if more information is required herein. Sincerely, Larry W. Buster Advising Drilling Unocal Alaska (907) 263-7804 (907) 263-7884 (907) 351-6730 Engineer - Office - Fax - Mob. r----'----------.--.'----------------.'-----'.-- ¡¡.; P 1 2: Type: application ms-lner ¡ ~ art .1 Encoding: base64 1 of] 9/6/2001 8:56 AM It ( Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL8 Dan Williamson Drilling Manager Tuesday, August 28, 2001 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Application for Permit to Drill (Form 10-401) McArthur River Field Steel head Platform, Well M-12 Commissioner Heusser: Enclosed for your review and approval is the Application for Permit to Drill the Steel head Well #M-12. This well will be drilled from an existing empty well slot and is designed to be a directionally drilled Grayling Gas Sand producer with a proposed TD of R '2Fð' TVD RKB, ~ 1):2 ~þ We are planning to drill a 24" hole 850' utilizing a 30" diverter and then run 18-5/8" \ casing. We will then nipple-up the 16-5/8" BOP and directionally drill 17-1/2" hole to 13- 3/8" casing point at 1500' (as mandated in Administrative Approval No. 228.1 Rule 4). Next, we will drill 12-1/4" hole to 9-5/8" casing point at 6800' and then drill 6" hole to the programed TD. The well will be completed utilizing a 3-1/2" liner and a stab-in gas lift mandrel completion string. We are planning to utilize a water base drill fluid, with the cuttings disposal occuring as per Steelhead NPDES Permit # AKG285019. The expected date for work to begin is approximately September 8, 2001, so your timely consideration for approval is appreciated. If there are any questions, please contact Dan Williamson at 263-7677 or Larry Buster at 263-7804. RECErVED AUG 2 9 2001 Alaska Oil & Gas Cons. Commission ,L\nchoraqe ORIGINAL ~. Unocal Alaska (' Union Oil Company of California 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNoCAL8 August 29, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Trading Bay Unit McArthur River Field Permit to Drill, M-12, ADL 18730 Request for Administrative Approval to Conservation Order 228 Dear Commissioners: Union Oil Company of California, as Operator of the Trading Bay Unit requests Administrative Approval to drill the McArthur River Field well M-12, Adl 18730, pursuant to Rule 3, Conservation Order 228 and the spacing requirements set forth therein. The proposed drilling and completion of this well will allow for additional gas recovery from the Middle Kenai Gas Pool. Enclosed with our Permit to Drill (form 10-401) is Unocal check No. 2004703 in the amount of$100.00 as required by 20 AAC 25.005 (c)(l). The specific location, interval and depth are as follows: Surface Location: 4240' FSL and 4822' FEL Sec. 33, T9N, RI3W, SM Top of Productive Interval: 3079' FSL and 2935' FEL Sec, 28, T9N, R13W, SM Total Depth:~' FSL and" 4 FEL Sec, 28, T9N, R13W SM ~'35"cf} ;;::~7' If you should require additional information, please condJ the undersigned at (907) 263-7882 or Mr, Larry Buster, Drilling Department at 263-7804. We appreciate your review and trust the enclosed is satisfactory to complete this request. RECEIVED enclosures AUG 2 9 2001 Alaska Oil & Gas Cons. Commission .A.nchof9ge ..~ ¡i ~l I 1~ I' " .J FOR INQUIRIES CONTACT LOCATION WHERE INVOICES WERE SUBMITTED ..................VENDORNO. DATE CHECK NO. 1031548 27-AUG-0 L 2004703 DATE INVOICEíCREDIT MEMO NO. VOUCHER NO. GROSS DISCOUNT NET ! 27-AUG-OJ DRILLPERMITM12 [)801300l063 100.00 100.00 l~ v(l/ 0 ~ :ORM 4-28181 (REV. 11-95) PRINTED IN U.S.A. I:T9:r~L"" 100.00 100.00 )ETACH STUB BEFORE DEPOSITING CHECK . . ~ITIBANK DELAWARE A Subsidiary of Gitiçorp ONE PENN'8WAY NEW CASTLE; DE 19720 62-20 31T Union Oil Cömpanyof Qalifornia Accounts Payable Fi.eld Disbursing 2004703 Pay U:N.OCAL'G One Hundred Dollars And no Cents******************************* Date 27-AUG--Ol Check Amount *****100.00 ro the )rder )f STATE OF ALASKA ALASKA OIL. & GAS CONSERVATION COMMISSION. 333 WEST lTHAVENUE SUITE 100 ANCHORAGE ,AX 9 9 5.01 United States 111200 t. 70 3111_:0 3 ~ ~OO 20 E1-: Void after six months from.abovedate. ~..~ ~ 3E1 ~. ~8~ 3 7 III CHECK 1 ST ANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION WELL. INJECTION WELL RED RILL ( ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMUTTALLETTER " " WELL NAME ~ vL /t(,. / 2----- (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNUL~gSAL ANNULAR DISPOSAL <-) YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well . Permit No, API No. . Production should continue to be reported as a function. of the original API number stated above. In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal. of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS <-) YES + SPACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. The. permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. ~ \.JJ\e:~L'c ~~~~\t.~ Templates are located m drive\jody\templates ¿f WELL PERMIT CHECKLIST COMPANY Y1 DCA WELL NAME - /Z-PROGRAM: exp - dev ,/ redrtl FIELD & POOL -5--z.b 5~~ INIT CLASS - e v/ / --- 6~5 GEOL AREA c-Cj 2C:;J ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . , . . . . . 4. Well located in a defined pool. .. . . . . . . . . . . . . . . . . N 5. Well located proper distance from drilling unit boundary. , . . "', N \ 6. Welll~ted proper di~tan~ fro~ ~ther ~ells.¥-. . . . . . . . crt .~ - ð ~ '\.$ k; ..5í4. c- '-- ':-) i 7. SuffiCIent aaeage available. In dniling Unit.. . . . . . . . . . . T N....s -1..-LL. U-Fl /i a..-c~ &1., /ð ~: ~=~~~~~~~;=: ~~~~~d~.: : : : : : : : : : : :': : ~At ~ u ~ #f 2)-1) - --V/; 2>F>;:if 1:i2 ~¿~ : ~., ~ c ~ 10. Operator has appropriate bond in force. . . . . . . . . . . . . ¿. . Ä1-IZ-Ie:. . ....:5'^;&Jt:.4k.d x:.../ ¿..() 11. Permit can be issued without conservation order. , . . . . . . N 4 "" -:¡ . C/O APPR DATE. 12, Permit can.be issued without administrative approval. .. . . . , ~w~ Xl) 4.~. c I 13. Can permit be approved before 15-day wait.. . . . . . . . . . ') . '. ENGINEERING ~~: ;~~::~:~;~=~II~Ùs'DWS:..'.'.'... '..,'.'.'. /VA Y ~ Ì2>"'-,..u~ ~/i ~ ~ =~šiæ~~-.4 16. CMT vol adequate to ':Ïrc:ulate on ~uctor & surf csg. . . . . Y N c;.o,:'»",,"""" ~. . . ~""" ~...'. \'" >.e ~.... '" "". 17. CMT vol adequate to .tle-In long string to surf csg. . . . . , . . N '. 18. CMT will cover all known productive horizons. . . . . '. . . . . ~ N 19. Casing. designs adequate for C. T. B & permafrost. . . . . . , , N \. \ (" C' -'>- I "-.l 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N ~'\'S.\"\ "'- '(\~"""'" "- t\ð ~S,(tÑ~ ~~ 21. If a re-drill. has a 10-403 for abandonment been approved, . . ~ .;> 22. Adequate weilbore separation proposed.. . . . . . : . . . . . N '- ~'"' ~. ~\\~ 23. If~Ï':'erter~equired,doesitme~tregul~~io.ns.......... N :Sa" 'o,.)~~ç-'~' \~"\\"",<-~,~\o..~\,:>-\o ~\\\~ \~\{ë>q~\\c+-~\~\-\'n\~\r-b..~ . 24. Dniling .fluld program schematic & equip hst adequate. . ~ . . N 'oq.ç. ~ t:.>. t:(í(m~~ ~ ~~~"~~~ \.... r ~J}TE ~~: :g~~spr:~~~:~,:e:~~~;~~~~~~t~sÙ~ . . '~U' . ~sig: ~ :.:::!b- . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N ~:: r:~:::~:;rH~h;~~ ~~:~:~f: ~~u~d~~n: : : : : : : : : : : ~ ~ . 30. Permit can be issued w/o hydrogen sulfide measures. , . . '. ~ N ~ /t~.. G~ 31. Data presented on potential overpressure zones. . . . . . . ~ ~ 32. Seismic anal~~is of shallo~ gas zones. . . . . . . . . . ..' '. .~. N AJDR DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . ~ Y N '/.j.5-b I. 34. Contact name/phone for weekly progress reports lexplor~ only] Y N ANNULAR DISPOSAL35. With proper cementing records. this plan. (A) will contain waste in a suitable receiving zone; . . . . . . , (B) will not contaminate freshwater; or cause drilling waste. .. to surface; .' (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and . . E will not circumvent 20 AAC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING:.. UIC/Annuiar COMMISSION: ~Þ8~ W~ ~ .8~s ~. ~ ( JM serv wellbore seg _ann. disposal para req - UNIT# I 2-¿) -?Ó ON/OFF SHORE C)ç¡:::- GEOLOGY ~JJ-S-~ ~. /},"~I ~~~~ua- S~í.þ¿~ ~ S if.. APPR Y N Y N DATE Com m e nts/l ns tructi ons: '1/7/61 c:\msoffice\wordian\diana\checklist (rev. 11/01/100) c 0 Z 0 -4 ~ :::u ( - ....' m - Z -I , J: . - en )- ::0 m » (