The URL can be used to link to this page

Home My WebLink About203-130Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/8/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221108 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# IRU 241-01 502832018400 221076 8/14/2022 AK E-Line GPT/Plug/Perf IRU 241-01 502832018400 221076 8/31/2022 AK E-Line GPT/Plug/Perf IRU 41-01 502832008800 192109 9/9/2022 AK E-Line GR/Perf IRU 241-01 502832018400 221076 8/25/2022 AK E-Line Perf IRU 241-01 502832018400 221076 8/22/2022 AK E-Line Plug/GR MPU S-34 500292317100 203130 9/4/2022 AK E-Line Cut Tubing NCI A-09A 508832002901 222024 8/20/2022 AK E-Line Perf NCI A-10B 508832003002 222025 8/23/2022 AK E-Line Perf Please include current contact information if different from above. T37244 T37244 T37245 T37244 T37244 T37246 T37247 T37248 MPU S-34 500292317100 203130 9/4/2022 AK E-Line Cut Tubing Kayla Junke Digitally signed by Kayla Junke Date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y Anne Prysunka at 3:44 pm, Nov 07, 2022 'LJLWDOO\VLJQHGE\'DYLG +DDNLQVRQ '1FQ 'DYLG+DDNLQVRQ RX 8VHUV 'DWH 'DYLG+DDNLQVRQ DSR-11/7/22 RBDMS JSB 110922 MGR12NOV2022 BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϭϬͬϳͬϮϬϮϮ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh^Ͳϯϰ >ĂƐƚŽŵƉůĞƚĞĚ͗ϵͬϮϵͬϮϬϮϮ Wd͗ϮϬϯͲϭϯϬ ϲϵũƚƐͲϰͲϭͬϮ͟^ůŽƚƚĞĚ>ŝŶĞƌ ϭϬ͕ϮϮϰ͛ƚŽϭϯ͕Ϭϰϳ͛ ϲϭũƚƐͲϰͲϭͬϮ͟^ůŽƚƚĞĚ>ŝŶĞƌ ϭϬ͕ϱϬϰ͛ƚŽϭϯ͕ϭϰϳ͛ ϯϲϯ͛ZĂƚ,ŽůĞ Ϭ͛ZĂƚ,ŽůĞ dсϭϭ͕ϭϱϵ͛;DͿͬ dсϰ͕ϯϮϯ͛;dsͿ ϮϬ´ KƌŝŐ͘&ůĞǀсϳϮ͛ͬKƌŝŐdďŐ͘,ŐƌůĞǀ͘сϮϵ͘ϳ͛ŽǇŽŶϭϰ ϳͲϱͬϴ͟ ϭϬͲϯͬϰ͟ EKd͗DŝŶ/Λ ϭϬ͕Ϭϯϰ͛ʹϮ͘ϳϱϬ͟ dƵďŝŶŐƵƚΛϵ͕ϵϱϳ͛ ϵͬϰͬϮϬϮϮ ³1(´/DWHUDO ³2$´/DWHUDO EKd͗/ϯ͘ϳϮϱ Λ ϵ͕ϵϯϰ͛ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ W& ϮϬΗ ŽŶĚƵĐƚŽƌ ϮϭϱͬͲϱϯͬtĞůĚĞĚ ϭϳ͘ϵϯϴ ^ƵƌĨĂĐĞ ϭϭϮΖ Eͬ ϭϬͲϯͬϰ͟ ^ƵƌĨĂĐĞ ϰϱ͘ϱͬ>ͲϴϬͬƚƌĐ͘ ϵ͘ϵϱϬ ^ƵƌĨĂĐĞ ϱ͕ϱϭϴ͛ Ϭ͘ϬϵϲϮ ϳͲϱͬϴΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϵ͘ϳͬ>ͲϴϬͬ/dͲD ϲ͘ϴϳϱ ^ƵƌĨĂĐĞ ϭϭ͕ϭϱϵΖ Ϭ͘Ϭϰϱϵ >/EZd/> ϰͲϭͬϮ͟ E^ŽůŝĚ>ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϭϬ͕ϭϮϳ͛ϭϯ͕Ϭϵϭ͛ EͬϰͲϭͬϮ͟ E^ůŽƚƚĞĚ>Ŷƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϭϬ͕ϮϮϰ͛ ϰͲϭͬϮ͟ K^ŽůŝĚ>ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϭϬ͕Ϯϳϯ͛ϭϯ͕ϮϯϮ͛ EͬϰͲϭͬϮ͟ K^ůŽƚƚĞĚ>Ŷƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϭϬ͕ϱϬϰ͛ dh/E'd/> ϰͲϭͬϮ͟ dƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ^ƵƌĨĂĐĞ ϵ͕ϵϲϮ͛ Ϭ͘ϬϭϱϮ ϯͲϭͬϮΗ dƵďŝŶŐ ϵ͘Ϯͬ>ͲϴϬͬdͲ// Ϯ͘ϵϵϮ ϵ͕ϵϲϮ͛ ϭϬ͕ϬϰϬ͛ Ϭ͘ϬϬϴϳ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ ϵ͕ϳϴϵ͛ ,^hZ^ůŝĚŝŶŐ^ůĞĞǀĞ͕ϰ͘ϱ͟;ϯWŽƌƚƐWůƵŐŐĞĚͿʹ/сϯ͘ϴϭϯ͟ Ϯ ϵ͕ϴϯϬ͛ E/d,,WͲϲ'ĂƵŐĞϰ͘ϱ͟ʹ/сϯ͘ϵϯϬ͟ ϯ ϵ͕ϴϲϴ ϳͲϱͬϴΖΖǆϰ͘ϱΖΖϮϲͲϯϮηdƌŝƉŽŝŶƚWĂĐŬĞƌ͗/сϯ͘ϴϳϱ͟ ϰ ϵ͘ϵϯϰ͛ ϰ͘ϱΖΖΗyEΗEŝƉƉůĞǁŝƚŚZ,WůƵŐ/ŶƐƚĂůůĞĚ͗/сϯ͘ϳϮϱ͟ ϱ ϵ͕ϵϲϭ͛ E^WƌŽĚ͘KǀĞƌƐŚŽƚ'ƵŝĚĞ;ϰ͘ϱϬΖΖƌŝĨƚͿʹŽƚƚŽŵΛϵ͕ϵϲϮ͛ ϲ ϵ͕ϵϴϯ͛ ϯ͘ϱ͟ǆϰ͘ϱ͟yͲKǀĞƌ ϳ ϵ͕ϵϴϰ͛ ϳͲϱͬϴ͟ǆϰ͘ϱ͟ĂŬĞƌWƌĞŵŝĞƌWĂĐŬĞƌ͗/сϯ͘ϴϳϱ͟ ϴ ϵ͕ϵϵϭ͛ ϰ͘ϱ͟ǆϯ͘ϱ͟yͲKǀĞƌ ϵ ϭϬ͕Ϭϯϰ͛ ϯ͘ϱ͟,^yEͲEŝƉƉůĞ͗/сϮ͘ϳϱϬ͟EŽ'Ž ϭϬ ϭϬ͕Ϭϯϵ͛ t>'ʹ ŽƚƚŽŵΛϭϬ͕ϬϰϬ͛ ϭϭ ϭϬ͕ϭϯϳ͛ ĂŬĞƌϲ͛dŝĞͲďĂĐŬ^ůĞĞǀĞ ϭϮ ϭϬ͕ϭϰϲ͛ ,ŽŽŬtĂůů,ĂŶŐĞƌ/ŶƐŝĚĞϳͲϱͬϴ͟ĂƐŝŶŐ ϭϯ ϭϬ͕ϭϳϭ͛ ,ŽŽŬtĂůů,ĂŶŐĞƌKƵƚƐŝĚĞ;,ŽŽŬWŽŝŶƚͿ ϭϰ ϭϬ͕Ϯϳϯ͛ ĂŬĞƌϳ͛dŝĞͲďĂĐŬ^ůĞĞǀĞ ϭϱ ϭϬ͕ϮϴϬ͛ ĂŬĞƌyW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϭϲ ϭϬ͕Ϯϴϲ͛ ĂŬĞƌϳͲϱͬϴ͟ǆϱͲϭͬϮ͟,D>ŝŶĞƌ,ĂŶŐĞƌ KWE,K>ͬDEdd/> ϮϬΗ ϮϲϬƐǆŽĨƌĐƚŝĐƐĞƚŝŶϰϮ͟,ŽůĞ ϭϬͲϰͬϰΗ ϵϯϱƐǆW&͛>͕͛ϯϳϭƐǆůĂƐƐ͞'͕͟dŽƉ:ŽďϱϰƐǆW&͚>͛ŝŶϭϯͲϭͬϮ͟,ŽůĞ ϳ͟ ϳϮϱƐǆůĂƐƐ͞'͟ŝŶϵͲϳͬϴ͟,ŽůĞ t>>/E>/Ed/KEd/> <KWΛϮϴϬ͛D ,ŽůĞŶŐůĞWĂƐƐĞƐϱϬĞŐ͘ΛϮ͕ϭϱϬ͛ DĂǆŶŐůĞŝŶdƵďŝŶŐсϳϴĞŐ͘ ϳϱĞŐ͘ĂƚƐůŝĚŝŶŐƐůĞĞǀĞ dZͬt>>, dƌĞĞ ϰͲϭͬϲ͟ϱD&D tĞůůŚĞĂĚ ϭϭ͟ǆϰͲϭͬϮ͟ϱD'ĞŶϲǁϰ͘ϱ͟dͲ//dΘdƵďŝŶŐ ,ĂŶŐĞƌ/t͞,͟WsƉƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϯϭϳϭͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇŽǇŽŶϭϰͲϵͬϮͬϮϬϬϯ ŽŝůůĞĂŶͲŽƵƚĂŶĚ:ĞƚWƵŵƉZĞŵŽǀĂůϭϭͬϮϭͬϮϬϭϱ :ĞƚWƵŵƉŽŵƉůĞƚŝŽŶďǇ^ZʹϵͬϮϵͬϮϬϮϮ E>dZ>t/EKtd/> tŝŶĚŽǁŝŶϳͲϱͬϴ͟ĂƐŝŶŐΛϭϬ͕ϭϱϵ͛ƚŽϭϬ͕ϭϳϭ͛;DͿͬϰ͕ϭϭϱ͛ƚŽϰ͕ϭϭϳ͛;dsͿ tĞůůŶŐůĞΛǁŝŶĚŽǁсϳϴĞŐ͘ K>dZ>t/EKtd/> tŝŶĚŽǁŝŶϳͲϱͬϴ͟ĂƐŝŶŐΛϭϬ͕ϱϭϲ͛ƚŽϭϬ͕ϱϮϴ͛;DͿͬϰ͕ϭϵϵ͛ƚŽϰ͕ϮϬϭ͛;dsͿ tĞůůŶŐůĞΛǁŝŶĚŽǁсϳϳĞŐ͘ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW^Ͳϯϰ ^Zηϭ ϱϬͲϬϮϵͲϮϯϭϳϭͲϬϬͲϬϬ ϮϬϯͲϭϯϬ ϳͬϭͬϮϬϮϮ ϭϬͬϭϬͬϮϬϮϮ ϳͬϭͬϮϬϮϮͲ&ƌŝĚĂǇ ZDKĨƌŽŵͲϯϱ͘EͬhƐƚĂĐŬŽŶ^Ͳϯϰ͘^ƉŽƚŵƵĚďŽĂƚŽŶ^Ͳϯϰ͘ZŝŐĚŽǁŶĂƚǁĂůŬĂŶĚƉŝƉĞƌĂĐŬƐ͘^ƚĂƌƚůŽĂĚŝŶŐdƌƵĐŬƐ͘WƵůůZĂĐŬ ƉŝŶƐ͕<ŶŝĨĞŽǀĞƌŵĂƐƚ͘>ĂǇDĂƐƚŽŶƚŽŚĞĂĚĂĐŚĞƌĂĐŬ͘DĞĐŚĂŶŝĐĂĚũƵƐƚĐŽƵŶƚĞƌďĂůĂŶĐĞǀĂůǀĞƐŽŶ<ŶŝĨĞĐǇůŝŶĚĞƌƐ͘^ƚĂŶĚŵĂƐƚƵƉ ĂŶĚŬŶŝĨĞŽƵƚƚŽĐŚĞĐŬĂĚũƵƐƚŵĞŶƚƐ͘<ŶŝĨĞĚŽǁŶĂŶĚůĂǇŵĂƐƚďĂĐŬĚŽǁŶ͘ŽŶƚŝŶƵĞƚŽZŝŐĚŽǁŶ͘dĂŬĞƌŝŐŽĨĨ:ĂĐŬƐ͘WƵůůƌŝŐŽĨĨ ŵƵĚďŽĂƚĂŶĚƚĂŬĞƚŽƚĞŶƚĨŽƌƐĐŚĞĚƵůĞĚŵĂŝŶƚĞŶĂŶĐĞ͘^ƉŽƚƌĂŶĞĂŶĚƉƌĞƉƚŽŵĂŬĞƉŝĐŬƐ͘ƌĂŶĞŽĨĨĨůŽǁƐƉŽŽůĂŶĚƌŝƐĞƌ ƐƉŽŽůĨƌŽŵƌŝŐĨůŽŽƌ͘ƌĂŶĞŽĨĨƌŝŐĨůŽŽƌĂŶĚƉůĂĐĞŽŶZΘWƚƌƵĐŬ͘ƌĂŶĞƵƐĞĚƚŽůŽǁĞƌǁĞůůŚƵƚƐƚĂŝƌƐ͘hƐĞĐƌĂŶĞƚŽƉŝĐŬŬŽŽŵĞǇ ŚŽƐĞƐĂŶĚƉůĂĐĞŝŶďŝŶ͕ƌĂŶĞŽĨĨǁĞůůŚƵƚ͘EͬKWĂŶĚƉůĂĐĞŽŶĐƌĂĚůĞ͘EͬhƚƌĞĞĂŶĚƚĞƐƚ͘ ϲͬϮϵͬϮϬϮϮͲtĞĚŶĞƐĚĂǇ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϲͬϯϬͬϮϬϮϮͲdŚƵƌƐĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ŽŶƚŝŶƵĞƚŽZDKĨƌŽŵͲϯϱ͘dƌƵĐŬƐŵŽǀĞŽƵƚƉŝƚƐ͕ƚƌĂŝůĞƌĨŽƌƚŚĞǁĞůůŚŽƵƐĞĂŶĚĨůŽŽƌ͕ĂŶĚĂůůŽƚŚĞƌƌŝŐƐƵƉƉŽƌƚĞƋƵŝƉŵĞŶƚ͘ ^ƉŽƚWŝƚƐ͘ƌĂŶĞŽŶǁĞůůŚŽƵƐĞĂŶĚƵƐĞĐƌĂŶĞƚŽƉŝĐŬƐƚĂŝƌƐ͘ƌĂŶĞŽŶĨůŽŽƌ͘ƌĂŶĞƵƉƐƉŽŽůƐŽŶƚŽƌŝŐĨůŽŽƌ͘ƌĂŶĞƉŝĐŬŬŽŽŵĞǇ ůŝŶĞƐĂŶĚƐĞƚŝŶƉůĂĐĞ͘^ƉŽƚZŝŐŽŶƚŽŵƵĚďŽƵƚ͘>ĞǀĞůŽƵƚƌŝŐ͘W:^DĨŽƌƐƚĂŶĚŝŶŐƌŝŐƵƉ͘^ƚĂŶĚŵĂƐƚƵƉ͘<ŶŝĨĞŵĂƐƚƵƉ͘^ƚĂƌƚ ŚŽŽŬŝŶŐƵƉĨůƵŝĚůŝŶĞƐ͘ŽŶŶĞĐƚŬŽŽŵĞǇůŝŶĞƐƚŽƐƚĂĐŬĂŶĚƚŽŬŽŽŵĞǇ͘^ƉŽƚŝŶt^DŽĨĨŝĐĞĂŶĚĐƌĞǁĐŚĂŶŐĞŚŽƵƐĞĂŶĚĐŽŶŶĞĐƚ ƉŽǁĞƌ͘ƌĞǁĐŚĂŶŐĞ͘ŽŶƚŝŶƵĞƐƉŽƚƚŝŶŐŝŶĞƋƵŝƉŵĞŶƚ͘^ƉŽƚĐĂƚǁĂůŬĂŶĚƉŝƉĞƌĂĐŬǁŝƚŚĐŽŶƚĂŝŶŵĞŶƚƵŶĚĞƌĂůů͘ZŝŐƵƉĨůŽǁ ƐƉŽŽůĂŶĚƐƉĂĐĞƌƐƉŽŽůƐ͘dĂŬĞŽŶƚĞƐƚĨůƵŝĚŝŶƚŽƉŝƚϰ͘&ƵŶĐƚŝŽŶƚĞƐƚKW͘ZŝŐƵƉďŝƌĚďĂƚŚ͘dĂŬĞŽŶϴ͘ϱη<>ŝŶƚŽƉŝƚƐ͘^ĞƚƵƉ ƐĞĐŽŶĚĂƌǇĐŽŶƚĂŝŶŵĞŶƚĨŽƌƉŝƉĞďĞŝŶŐƉƵůůĞĚ͘ŚĂŶŐĞĞůĞǀĂƚŽƌƐĨŽƌƉŝƉĞďĞŝŶŐƉƵůůĞĚ͘ZŝŐƵƉƚĞƐƚĞƋƵŝƉŵĞŶƚ͘W:^DĨŽƌƚĞƐƚŝŶŐ KW͘^ƚĂƌƚĨŝůůŝŶŐƐƚĂĐŬ͘WŝĐŬƵƉƚĞƐƚŵĂŶĚƌĞůĨŽƌƐŚĞůůƚĞƐƚ͘ZŝŐĂĐĐĞƉƚĞĚĂƚϬϬ͗ϬϬ͘ŚĞĐŬ/͘/ŽŶĂǀĂĐ͘WƵƌŐĞĂŝƌĨƌŽŵƐǇƐƚĞŵ͘ WƌĞĨŽƌŵƐŚĞůůƚĞƐƚ͘>ĞĂŬŽŶŐƌĞĂƐĞǌĞƌƚĨŽƌǀĂůǀĞ͘ĐŚĂŶŐĞŐƌĞĂƐĞǌĞƌƚ͘'ŽŽĚƐŚĞůůƚĞƐƚ͘^ƚĂƌƚƚĞƐƚŝŶŐKWǁŝƚŚϯͲϭͬϮĂŶĚϰͲϭͬϮ ƚĞƐƚũŽŝŶƚƐ͘^ƚĂƚĞǁŝƚŶĞƐƐǁĂŝǀĞĚďǇZŽďĞƌƚEŽďůĞ͘&ŽƵŶĚůĞĂŬŽŶƚĞƐƚĞƋƵŝƉŵĞŶƚŶĞĞĚůĞǀĂůǀĞ͘ZĞƉůĂĐĞĚŶĞĞĚůĞǀĂůǀĞ͘ ŽŶƚŝŶƵĞƚĞƐƚŝŶŐ͘ ϳͬϮͬϮϬϮϮͲ^ĂƚƵƌĚĂǇ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW^Ͳϯϰ ^Zηϭ ϱϬͲϬϮϵͲϮϯϭϳϭͲϬϬͲϬϬ ϮϬϯͲϭϯϬ ϳͬϭͬϮϬϮϮ ϭϬͬϭϬͬϮϬϮϮ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ ƌĞǁĐŚĂŶŐĞ͘ƐĞƌǀŝĐĞƌŝŐ͘>ƵďƌŝĐĂƚĞĂŶĚŝŶƐƉĞĐƚĂůůĞƋƵŝƉŵĞŶƚ͘WƌĞĨŽƌŵĚĞƌƌŝĐŬŝŶƐƉĞĐƚŝŽŶ͘ŽŶƚŝŶƵĞǁŽƌŬŝŶŐƐƚƵĐŬƉŝƉĞ͘DĂǆ ƉƵůůϭϳϬ<ǁŝƚŚĐĂƐŝŶŐũĂĐŬƐ͘WƵŵƉŝŶŐϮͲϯ>ƐͬŚƌƚŽŬĞĞƉŚŽůĞĨƵůů͘ZŝŐƵƉůŽǁĞƌƐĞƚŽĨƚƵďŝŶŐƐůŝƉƐŽŶďŽƚƚŽŵĚĞĐŬŽĨĐĂƐŝŶŐ ũĂĐŬƐ͘DĂŬĞƵƉͲůŝŶĞƐƚŽŽůƐŽŶĐĂƚǁĂůŬ͘sĞƌŝĨǇKΖƐŽĨͲůŝŶĞƚŽŽůƐďĞŝŶŐƌĂŶ͘>ĂŶĚŚĂŶŐĞƌĂŶĚƐƚĂƌƚƌŝŐŐŝŶŐƵƉͲůŝŶĞ͘,ĂŶŐͲ ůŝŶĞƐŚĞĂǀĞ͕ŵĂŬĞƵƉyKΖƐƚŽůĂŶĚŝŶŐũŽŝŶƚĨŽƌƉƵŵƉŝŶƐƵď͘DĂŬĞƵƉƉƵŵƉŝŶƐƵďƚŽůĂŶĚŝŶŐũŽŝŶƚ͘W:^DǁŝƚŚͲůŝŶĞĂŶĚƌŝŐ ŚĂŶĚƐ͘WŝĐŬƵƉĂŶĚŵĂŬĞƵƉͲůŝŶĞdƌĂĐƚŽƌ͕ŐĂŵŵĂƌĂǇͬ>͕ĂŶĚ'ĂƵŐĞƌŝŶŐ͘ͲůŝŶĞƐƚĂƌƚƌƵŶŶŝŶŐŝŶƚŚĞŚŽůĞ͘ͲůŝŶĞZ/,ƚŽнͬͲ ϴϳϬϬΖĂŶĚĐŽƵůĚŶŽƚŐŽĚŽǁŶĂŶǇĨƵƌƚŚĞƌ͘>ŝŶĞĚƵƉƚŽƉƵŵƉͲůŝŶĞĚŽǁŶĂƚϮ>ƐͬŵŝŶĂƚϯϬϬƉƐŝ͘hŶƐƵĐĐĞƐƐĨƵůĂƚƉƵŵƉŝŶŐ ƚŚĞŵĚŽǁŶ͘ͲůŝŶĞĂƚƚĞŵƉƚĞĚƚŽƚƌĂĐƚŽƌĚŽǁŶ͘ͲůŝŶĞŵĂĚĞŝƚƚŽнͬͲϭϬΖϬϯϲΖ͘ͲůŝŶĞĐĂŵĞƵƉƚŽнͬͲϵϵϵϭΖĂŶĚŐŽƚŚƵŶŐƵƉ͘Ͳ ůŝŶĞĂƚƚĞŵƉƚĞĚƚŽWKK,ĂŶĚǁĂƐƵŶƐƵĐĐĞƐƐĨƵů͘ŽƵůĚŶŽƚŐŽƵƉŽƌĚŽǁŶ͘>ŝŶĞƵƉƚŽƉƵŵƉƌĞǀĞƌƐĞĐŝƌĐƵůĂƚĞƚŽƚƌǇĂŶĚĨƌĞĞͲ ůŝŶĞ͘hŶƐƵĐĐĞƐƐĨƵů͘ŽŶƚŝŶƵĞĚƚƌǇŝŶŐƚŽĨƌĞĞͲůŝŶĞďǇƉƵŵƉŝŶŐĚŽǁŶƚƵďŝŶŐ͘hŶƐƵĐĐĞƐƐĨƵů͘ƚƚĞŵƉƚƉƵŵƉŝŶŐďŽƚŚǁĂǇƐƐĞǀĞƌĂů ƚŝŵĞƐ͘hŶƐƵĐĐĞƐƐĨƵů͘ƌĞǁĐŚĂŶŐĞ͘>ŝŶĞƵƉƚŽƵůůŚĞĂĚƚŽƚƌǇĂŶĚĨƌĞĞͲůŝŶĞƚŽŽůƐƉƵŵƉŝŶŐĂƚϯ>ƐͬŵŝŶĂƚϭϯϬϬƉƐŝ͘ĂƚƚĞŵƉƚ ƵŶƐƵĐĐĞƐƐĨƵů͘ĞĐŝƐŝŽŶǁĂƐŵĂĚĞƚŽƉƵůůŽƵƚŽĨƌŽƉĞƐŽĐŬĞƚĂŶĚƉƵůůŽƵƚŽĨŚŽůĞǁŝƚŚ>ŝŶĞŽŶůǇ͘WŽŽŚǁŝƚŚŽŶůǇůŝŶĞ͘>ĂǇůŝŶĞŽŶ ĐĂƚǁĂůŬĂŶĚŝŶƐƚĂůůŶĞǁƌŽƉĞƐŽĐŬĞƚ͘>ĂŶĚŚĂŶŐĞƌ͘^ĞĐƵƌĞǁĞůůĂŶĚŵŽŶŝƚŽƌ͘ĐůĞĂŶĐůĞĂƌƌŝŐĨůŽŽƌ͘ͲůŝŶĞŵĂŬĞƵƉĨƌĞĞƉŽŝŶƚƚŽŽů ŽŶĐĂƚǁĂůŬ͘tŚŝůĞͲůŝŶĞŵĂŬŝŶŐƵƉƚŽŽůƐĨŽƵŶĚƚŚĞŝƌͲůŝŶĞƚƌƵĐŬǁĂƐŵĂůĨƵŶĐƚŝŽŶŝŶŐ͘ͲůŝŶĞƐĞŶƚŚĂŶĚƐƚŽƌĞƚƌŝĞǀĞĂŶŽƚŚĞƌ ƚƌƵĐŬĨƌŽŵĞĂĚŚŽƌƐĞ͘ƌĞǁĐŽŶƚŝŶƵĞĚƉƌĞĨŽƌŵŵŽŶƚŚůǇĞƋƵŝƉŵĞŶƚŝŶƐƉĞĐƚŝŽŶ͕ĐůĞĂŶĂŶĚŽƌŐĂŶŝǌĞůŽĐĂƚŝŽŶĂŶĚƉƌĞƉĨŽƌ ZDK͘ͲůŝŶĞƐƉŽƚŝŶŶĞǁƵŶŝƚ͘ZƵŶŶĞǁǁŝƌĞƚŚƌŽƵŐŚƉĂĐŬŽĨĨͬŝŶƐƚĂůůŶĞǁƌŽƉĞƐŽĐŬĞƚ͘WƵƚƚŽŐĞƚŚĞƌĨƌĞĞƉŽŝŶƚƚŽŽůƐĂŶĚƚĞƐƚ͘ ^ƚĂƌƚZ/,ǁŝƚŚ&ƌĞĞƉŽŝŶƚƚŽŽů͘ͲůŝŶĞŵĂĚĞŝƚƚŽнͬͲϮϬϬϬΖƚĞƐƚĞĚĨƵŶĐƚŝŽŶŽĨƚŽŽů͘ĂƌŵƐǁŽƵůĚŶŽƚĞǆƚĞŶĚ͘WKK,ĂŶĚŝŶƐƚĂůů ĐĞŶƚƌĂůŝǌĞƌŶĞĂƌĂƌŵƐƚŽŬĞĞƉĐĞŶƚĞƌĞĚ͘ͲůŝŶĞZ/,ǁŝƚŚĨƌĞĞƉŽŝŶƚƚŽŽů͘Z/,ƚŽнͬͲϭϮϬϬΖƚĞƐƚƚŽŽůǁŚŝůĞƉŝĐŬŝŶŐƵƉƚŽϭϲϱ<ǁŝƚŚ ĐĂƐŝŶŐũĂĐŬƐ͘ ϳͬϯͬϮϬϮϮͲ^ƵŶĚĂǇ &ŝŶŝƐŚƚĞƐƚŝŶŐKWǁŝƚŚϯͲϭͬϮĂŶĚϰͲϭͬϮƚĞƐƚũŽŝŶƚ͘WƌĞĨŽƌŵŬŽŽŵĞǇĚƌĂǁĚŽǁŶ͘ŶŶƵůĂƌĐůŽƐŝŶŐƚŝŵĞϮϳƐĞĐ͕ZŝŐĚŽǁŶƚĞƐƚ ĞƋƵŝƉŵĞŶƚ͘ůŽǁĚŽǁŶĨůƵŝĚůŝŶĞƐ͘,ĂŶŐƐŚĞĂǀĞ͘WŝĐŬƵƉdďĂƌ͘WƵůůd^ƉůƵŐ͘ŚĞĐŬĨŽƌƉƌĞƐƐƵƌĞƵŶĚĞƌWs͘ŚĞĐŬĨŽƌƉƌĞƐƐƵƌĞ ŽŶ/͘ŶŽƉƌĞƐƐƵƌĞ͘WƵůůWs͘DĂŬĞƵƉĐƌŽƐƐŽǀĞƌƐƚŽůĂŶĚŝŶŐũŽŝŶƚ͘DĂŬĞƵƉůĂŶĚŝŶŐũŽŝŶƚ͘K>^͘hŶůĂŶĚŚĂŶŐĞƌ͘ŚĂŶŐĞƌ ƵŶƐĞĂƚĂƚϱϯŬƵƉ͘WƵůůƚƵďŝŶŐƚŽϭϰϱ͘tŽƌŬƚƵďŝŶŐďĞƚǁĞĞŶϲϬŬƵƉƚŽϭϰϱŬƵƉ͘ƵƚŶŽŐŽŽĚ͘>ĂǇĚŽǁŶůĂŶĚŝŶŐũŽŝŶƚ͘ZŝŐĚŽǁŶ ƐƉĂĐĞƌƐƉŽŽůƐĂŶĚĨůŽǁĐƌŽƐƐ͘^ƉŽƚĐƌĂŶĞ͘WƵůůƐƉŽŽůƐŽĨĨƌŝŐĨůŽŽƌ͘hƐĞĐƌĂŶĞƚŽŝŶƐƚĂůůĂƐŝŶŐũĂĐŬƉůĂƚĞŽŶƚŽƉŽĨĂŶŶƵůĂƌ͘hƐĞ ĐƌĂŶĞƚŽƉůĂĐĞĐĂƐŝŶŐũĂĐŬƐŽŶƉůĂĐĞ͘,ŽŽŬƵƉĐĂƐŝŶŐũĂĐŬƐĂŶĚĨƵŶĐƚŝŽŶƚĞƐƚ͘DĂŬĞĂƚƚĞŵƉƚƚŽƉƵůůƚƵďŝŶŐĨƌĞĞǁŝƚŚĂƉƉƌŽǀĞĚ ƵƉǁĞŝŐŚƚŽĨϭϲϱ<͘DŝǆϱϬ>ƐƉŝůůŽĨƐĂĨĞͲůƵďĞ͘WƵŵƉϮϱ>ƐŽĨƐĂĨĞͲůƵďĞƉŝůůĚŽǁŶ/ĂŶĚĂůůŽǁƚŽĚƌŽƉ͘ŽŶƚŝŶƵĞƚŽǁŽƌŬ ƚƵďŝŶŐĨƌŽŵϲϬ<ƵƉƚŽϭϱϱ<ƵƉ͘ZŝŐƵƉƚŽƉƵŵƉĚŽǁŶďĂĐŬƐŝĚĞ͘WŝĐŬƵƉƚŽϲϱ<ƵƉǁŝƚŚƚŚĞƌŝŐƚŽŽĨĨƐĞĂƚŚĂŶŐĞƌ͘ůŽƐĞĂŶŶƵůĂƌ͘ WƵŵƉĚŽǁŶ/ǁŝƚŚƚŚĞĂĚĚŝƚŝŽŶĂůϮϱ>ƐŽĨƚŚĞƐĂĨĞͲůƵďĞƉŝůů͕ƚĂŬŝŶŐƌĞƚƵƌŶƐƵƉƚƵďŝŶŐ͘WƵŵƉŝŶŐϮ͘ϱ>ƐͬŵŝŶƉƌĞƐƐƵƌĞĂƚ ϯϬϬƉƐŝ͘ĨƚĞƌϮϱ>ƐĂǁĂǇƚŚĞŚĂŶŐŝŶŐǁĞŝŐŚƚŝŶƚŚĞĞůĞǀĂƚŽƌƐƌŽƐĞƚŽϭϳϲ<ĂŶĚƚŚĞƉƌĞƐƐƵƌĞƐƉŝŬĞĚƚŽϮϬϬϬƉƐŝ͘KƉĞƌĂƚŽƌ ƐŚƵƚƉƵŵƉŽĨĨĂŶĚƐůĂĐŬĞĚŽĨĨŝŶƚŽƚŚĞƐůŝƉƐ͘ůĞĚƉƌĞƐƐƵƌĞŽĨĨƚŚĞ/͘ĂŶĚŵŽŶŝƚŽƌĞĚǁĞůů͘EŽƉƌĞƐƐƵƌĞ͘WƌĞĨŽƌŵĞƌƌŝĐŬͬƌŝŐ ŝŶƐƉĞĐƚŝŽŶ͘KƉĞŶĂŶŶƵůĂƌ͘tŽƌŬƉŝƉĞĨƌŽŵůĂŶĚĞĚƚŽϭϮϬ<ŽŶƚŚĞƌŝŐĂŶĚŵŽǀĞŽǀĞƌƚŽũĂĐŬƐĂŶĚĐŽŵĞƵƉƚŽϭϲϱ<͘EŽ ƉƌŽŐƌĞƐƐŵĂĚĞ͘ZŝŐƵƉƚŽƉƵŵƉƚŽƐƉŽƚƐĂĨĞͲůƵďĞƉŝůůĂƌŽƵŶĚĐƵƚĂƚϵϵϳϱΖ͘ůŽƐĞĂŶŶƵůĂƌ͘ůŝŶĞƵƉƚŽƉƵŵƉĚŽǁŶ/ĂŶĚƚĂŬĞ ƌĞƚƵƌŶƐƵƉƚƵďŝŶŐ͘WƵŵƉϮϭϬ>ƐŽĨϴ͘ϰϱη<>ƚŽƐƉŽƚƐĂĨĞͲůƵďĞƉŝůůĂĐƌŽƐƐĂŶŶƵůĂƌĚĞƉƚŚƐŽĨϵϵϳϱΖƚŽϴϬϲϳΖ͘ďůŽǁĚŽǁŶĂůů ĨůƵŝĚůŝŶĞƐ͘ŚĞĐŬĨŽƌƉƌĞƐƐƵƌĞƵŶĚĞƌĂŶŶƵůĂƌ͘EŽƉƌĞƐƐƵƌĞ͘KƉĞŶĂŶŶƵůĂƌ͘^ƚĂƌƚǁŽƌŬŝŶŐƉŝƉĞŝŶŝŶĐƌĞŵĞŶƚƐϭϬϬ<͕ϭϮϬ<͕ϭϰϬ<͕ ϭϲϬ<͘ŶǇƚŚŝŶŐŽǀĞƌϭϰϬ<ƵƐŝŶŐĐĂƐŝŶŐũĂĐŬƐ͘DĂǆƵƉǁĞŝŐŚƚĂƚƚĞŵƉƚĞĚϭϳϱ<ŽŶĐĂƐŝŶŐũĂĐŬƐ͘ŽŶƚŝŶƵĞƚŽǁŽƌŬWŝƉĞŝŶ ŝŶĐƌĞŵĞŶƚƐ͘ ϳͬϰͬϮϬϮϮͲDŽŶĚĂǇ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW^Ͳϯϰ ^Zηϭ ϱϬͲϬϮϵͲϮϯϭϳϭͲϬϬͲϬϬ ϮϬϯͲϭϯϬ ϳͬϭͬϮϬϮϮ ϭϬͬϭϬͬϮϬϮϮ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ ŽŶƚŝŶƵĞƚŽZ/,ǁŝƚŚŵŽƚŽƌŝǌĞĚĨƌĞĞƉŽŝŶƚƚŽŽůĂŶĚĐŽůůĂƌůŽĐĂƚĞƌ͘WƌĞĨŽƌŵŵƵůƚŝƉůĞĨƌĞĞƉŽŝŶƚƐƚĂƚŝŽŶƐƚŽƉƐďĞƚǁĞĞŶнͬͲϳϬϬϬΖ ĂŶĚнͬͲϴϳϭϯΖ͘ǁŚŝůĞƉƵůůŝŶŐƵƉǁŝƚŚĐĂƐŝŶŐũĂĐŬƐƚŽŐŝǀĞĂƚůĞĂƐƚϯϬ<ŽǀĞƌŚĂŶŐŝŶŐǁĞŝŐŚƚ͘WŽŽŚǁŝƚŚͲůŝŶĞ͘ZŝŐĚŽǁŶͲůŝŶĞ͘ ƌĞĂŬĂůůyKΖƐ͘>ĂŶĚŚĂŶŐĞƌ͘Z/>^͘WŝĐŬƵƉdďĂƌĂŶĚŝŶƐƚĂůůWs͘ĞŐŝŶZŝŐĚŽǁŶƉƌŽĐĞƐƐ͘ZŝŐƌĞůĞĂƐĞĚĂƚϭϴ͗ϬϬ͘ ϳͬϱͬϮϬϮϮͲdƵĞƐĚĂǇ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW^Ͳϯϰ ^>ΘŽŝů ϱϬͲϬϮϵͲϮϯϭϳϭͲϬϬͲϬϬ ϮϬϯͲϭϯϬ ϳͬϭͬϮϬϮϮ ϭϬͬϭϬͬϮϬϮϮ Z/'ͲhW͘ϭϮϱZKEt/Z͘d^сϭ͘ϳϱΗZ^͕ϭϬΖǆϭͲϳͬϴΗZK>>Z^dD;Ϯ͘ϮϬΗǁŚůƐͿ͕<:dϱΖǆϭͲϳͬϴΗ;Ϯ͘ϮϬΗǁŚůƐͿ͕K:͕<:d>^^͘ ^d<WEd<KEdZK>K&t/Z͘Wh>>dZWE^dKEdKt>>,͘WdWϮϱϬ>ͬϮϱϬϬ,;'ŽŽĚͿ͘ZE >^tKZD'EddK&/^,dϭϬ͕ϬϬϵΖ^>D;EŽƌĞĐŽǀĞƌǇͿ͘W>EdϯͲϭͬϮΗ/d^h͕Ϯ͘ϲϬΗ>>'h/͕ϭͲϯͬϴΗ:KE &/^,dϭϬ͕ϬϬϰΖ^>D͘:Z&KZϭ,KhZEDKs&/^,dKd>K&ϭϰΖhW,K>͘ZKsZ/d^h^^D>z;ůĞǁŽƵƚũĚ ƐŬŝƌƚĂŶĚĚŽŐƐͿ͘>zKtEKDW>d͕t>>^hZ͘ Z/'ͲhW͘ϭϮϱZKEt/Z͘d^сϭ͘ϳϱΗZ^͕ϭϬΖǆϭͲϳͬϴΗZK>>Z^dD;Ϯ͘ϲϬΗǁŚůƐͿ͕<:dϱΖǆϭͲϳͬϴΗZK>>Z^dD;Ϯ͘ϲϬΗǁŚůƐ͕ K:͕<:d>^^͘^d<WEd<KEdZK>K&t/Z͘Wh>>dZWE^dKEdKt>>,͘WdWϮϱϬ>ͬϮϱϬϬ, ;'ŽŽĚͿ͘ZEϰͲϭͬϮΗϰϮKdKyͲ^^dϵ͕ϵϯϰΖD;ƉƉĞĂƌƐĐůŽƐĞĚͿ͕d'WKE/y'h'dϵ͕ϵϰϮΖ^>Dͬϵ͕ϵϱϳΖD͘ZE Ϯ͘ϯϬΗ>/dKϵ͕ϵϲϱΖ^>Dͬϵ͕ϵϴϬΖD;ŶŽŝŵƉƌĞƐƐŝŽŶͿ͘ZEϮ͘ϳϱΗ>/dKϵ͕ϵϲϱΖ^>Dͬϵ͕ϵϴϬΖD;ŝŵƉƌĞƐƐŝŽŶŽĨƉŽƐƐŝďůĞƉĂƌƚŝĂů ĨŝƐŚŶĞĐŬͿ͘>zͲKtEKDW>d͕t>>^hZ͘ ϳͬϵͬϮϬϮϮͲ^ĂƚƵƌĚĂǇ ZEKE>Kd/KE͕KWZdKZdKydE:/͘Z/'ͲhW͘ϭϮϱZKEt/Z͘d^сϭ͘ϳϱΗZ^͕ϭϬǆϭͲϳͬϴΗZK>>Z^dD;Ϯ͘ϲϬΗ ǁŚůƐͿ͕<:dϱΖǆϭͲϳͬϴΗZK>>Z^dD;Ϯ͘ϲϬΗǁŚůƐͿ͕K:͕<:d>^^͘^d<WEd<KEdZK>K&t/Z͘Wh>>dZWE ^dKEdKt>>,͕WdWϮϱϬ>ͬϮϱϬϬ,;'ŽŽĚͿ͘ddDWddKWh>>Ͳ>/EdKK>^dZ/E';ƌŽůůĞƌƐƚĞŵǁŚĞĞůƐŚƵŶŐƵƉĂƚ ƚďŐĐƵƚͿdϵ͕ϵϲϱΖ^>D͘D/^^/E'ϯǆϮ͘ϲϬΗt,>^͘ZE^^KZdD'Ed^͕ZKsZϮǆϮ͘ϲϬΗt,>^͘>zͲKtE KDW>d͕t>>^hZ͘ ϳͬϭϮͬϮϬϮϮͲdƵĞƐĚĂǇ ϳͬϭϬͬϮϬϮϮͲ^ƵŶĚĂǇ ZEKE>Kd/KE͘Z/'ͲhW͘ϭϮϱZKEt/Z͘d^сϭ͘ϳϱΗZ^͕ϭϬΖǆϭͲϳͬϴΗZK>>Z^dD;Ϯ͘ϲϬΗǁŚůƐͿ͕<:dϱΖǆϭͲϳͬϴΗ ZK>>Z^dD;Ϯ͘ϲϬΗǁŚůƐͿ͕K:͕<:d>^^͘^d<WEd<KEdZK>K&t/Z͘Wh>>dZWE^dKEdKt>>,͘ WdWϮϱϬ>ͬϮϱϬϬ,;'ŽŽĚͿ͘D<ϰZhE^dKWh>>Ͳ>/EdKK>^dZ/E'dϵ͕ϵϲϱΖ^>D͘Z/'ͲKtEKDW>d͕t>> ^hZ͘ ϳͬϭϭͬϮϬϮϮͲDŽŶĚĂǇ ϳͬϴͬϮϬϮϮͲ&ƌŝĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϳͬϲͬϮϬϮϮͲtĞĚŶĞƐĚĂǇ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϳͬϳͬϮϬϮϮͲdŚƵƌƐĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW^Ͳϯϰ ^>ΘŽŝů ϱϬͲϬϮϵͲϮϯϭϳϭͲϬϬͲϬϬ ϮϬϯͲϭϯϬ ϳͬϭͬϮϬϮϮ ϭϬͬϭϬͬϮϬϮϮ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϳͬϭϲͬϮϬϮϮͲ^ĂƚƵƌĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϳͬϭϵͬϮϬϮϮͲdƵĞƐĚĂǇ ϳͬϭϳͬϮϬϮϮͲ^ƵŶĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϳͬϭϴͬϮϬϮϮͲDŽŶĚĂǇ ϳͬϭϱͬϮϬϮϮͲ&ƌŝĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϳͬϭϯͬϮϬϮϮͲtĞĚŶĞƐĚĂǇ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ Z/'ͲhW͘ϭϮϱZKEt/Z͘d^сϭ͘ϳϱΗZ^͕ϭϬΖǆϭͲϳͬϴΗZK>>Z^dD;Ϯ͘ϮϬΗǁŚůƐͿ͕<:dϱΖǆϭͲϳͬϴΗ;Ϯ͘ϮϬΗǁŚůƐͿ͕K:͕<:d>^^͘ ^d<WEd<KEdZK>K&t/Z͘Wh>>dZWE^dKEdKt>>,͘WdWϮϱϬ>ͬϮϱϬϬ,;'ŽŽĚͿ͘D< Dhd/W>ddDWd^dKWh>>Ͳ>/EdKK>^dZ/E'&ZKDϵ͕ϵϵϳΖ^>D͕ŶŽƐƵĐĐĞƐƐ͕WKK,͘KK,tͬ^,Z'Z͘Z/,tͬϯͲϭͬϮΗ '^͘^ͬΛϵ͕ϵϵϳΖ^>DE>d,/d^h͙WKK,͘KK,tͬ/d^h͕KsZ^,Kd;WŝŶƐŚĞĂƌĞĚͿ>&E͘/^h^^W>E &KZtZ͘>zKtEKDW>d͕t>>^hZ͘ ϳͬϭϰͬϮϬϮϮͲdŚƵƌƐĚĂǇ Z/'ͲhW͘ϭϮϱZKEt/Z͘d^сϭ͘ϳϱΗZ^͕ϭϬΖǆϭͲϳͬϴΗZK>>Z^dD;Ϯ͘ϮϬΗǁŚůƐͿ͕<:dϱΖǆϭͲϳͬϴΗZK>>Z^dD;Ϯ͘ϮϬΗǁŚůƐͿ͕ K:͕<:d>^^͘^d<WEd<KEdZK>K&t/Z͘Wh>>dZWE^dKEdKt>>,͘WdWϮϱϬ>ͬϮϱϬϬ, ;'ŽŽĚͿ͘Wh>>ΘhdϭϬϬΖt/Z͕,<>>ZK>>W/E^͕d/',dE>>KEE͘ǁͬtZE,^͘ZEϮ͘ϲϬΖΖ͘EdZ>/Z͕Θ Ϯ͘ϲϰΖΖ>/͕d'ΛϵϵϵϳΖ^>D͘,/DWZ^^/KEK&ZKW^K<dKE,/',^/;ϭϯ͗ϬϬͿ'Kdǁͬt^>͘'/E>&E͕^hZ t>>͕dZWWdΖĚ͕EKd/&z^K͕>K^WZD/d͘ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW^Ͳϯϰ ^>ΘŽŝů ϱϬͲϬϮϵͲϮϯϭϳϭͲϬϬͲϬϬ ϮϬϯͲϭϯϬ ϳͬϭͬϮϬϮϮ ϭϬͬϭϬͬϮϬϮϮ dhηϲǁͬϭϱ͘Ηd͘:ŽďKďũĞĐƚŝǀĞ͗&ŝƐŚͲůŝŶĞdƌĂĐƚŽƌ͘tĞĞŬůǇKWƚĞƐƚͲWdWϮϱϬͬϯϱϬϬƉƐŝͲŐŽŽĚ͘DhKWƚŽǁĞůů͘,ĂǀĞ ƐĐĂĨĨŽůĚĞƌƐƌĞͲŝŶƐƚĂůůƐĐĂĨĨŽůĚ͘ƵƚϭϰϬΖŽĨƉŝƉĞĨŽƌƉŝƉĞŵĂŶĂŐĞŵĞŶƚ͕Dhz:K&^&ŝƐŚŝŶŐ,͘Z/,ĂŶĚƚĂŐŐĞĚĨŝƐŚĂƚϵϵϳϴΖ͕ ƐƚĂƌƚĞĚũĂƌƌŝŶŐŽŶĨŝƐŚĂŶĚŐŽƚϭϰΖŽĨŵŽǀĞŵĞŶƚŽŶƐĞĐŽŶĚŚŝƚ͕ĂŶĚĐĂŵĞĨƌĞĞŽŶϯƌĚŚŝƚ͘WƵůůĞĚƚŽƐƵƌĨĂĐĞĂŶĚĚŝĚŶΖƚŚĂǀĞĨŝƐŚ͘ DhŶĞǁũĂƌƐĂŶĚƌƵŶŝŶŚŽůĞƚŽƌĞƐƵŵĞĨŝƐŚŝŶŐ͘Z/,ĂŶĚƚĂŐĨŝƐŚĂƚϵϵϰϮΖ͕ũĂƌŽŶĨŝƐŚĂŶĚŽŶϲƚŚŚŝƚƐŽŵĞƚŚŝŶŐĐĂŵĞĨƌĞĞ͘Z/, ĂŶĚƚĂŐŐĞĚƵƉϯƚŝŵĞƐĂƚĚŝĨĨĞƌĞŶƚĚĞƉƚŚƐ͘WKK,ĂŶĚĚĞƚĞƌŵŝŶĞƚŚĂƚĨŝƐŚƌĞƚƌŝĞǀĞĚ͘ZĞĐŽǀĞƌĞĚĨŝƐŚĨƌŽŵǁĞůů͘WƵŵƉĨƌĞĞǌĞ ƉƌŽƚĞĐƚŝŶǁĞůů͘ZDKdh͘:ŽďŽŵƉůĞƚĞ͘ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϳͬϯϬͬϮϬϮϮͲ^ĂƚƵƌĚĂǇ dhηϲǁͬϭ͘ϱΗd͘:ŽďKďũĞĐƚŝǀĞ͗&ŝƐŚͲůŝŶĞdƌĂĐƚŽƌ͘D/Zhdh͕Dhz:K&^ĨŝƐŚŝŶŐ,͘Z/,ĂŶĚůĂƚĐŚĨŝƐŚĂƚϵ͕ϵϳϳΖdD͕ ĂƚƚĞŵƉƚƚŽũĂƌŽŶĨŝƐŚ͕ďƵƚŝƚĂƉƉĞĂƌĞĚũĂƌƐǁĞƌĞĨŝƌŝŶŐĞĂƌůǇ͘WƵŵƉ<>ƚŽŐĞƚƌĂƚĞƚŚƌŽƵŐŚƐƉĞĂƌƚŽƌĞůĞĂƐĞŽĨĨŝƐŚ͘KĨĨĨŝƐŚ͕ WKK,͘ƚƐƵƌĨĂĐĞ͕ďƌĞĂŬŽĨĨƚŽŽůƐ͘^ĐĂĨĨŽůĚŝƐƐƵĞ͕ǁĂŝƚŽŶƐĐĂĨĨŽůĚĞƌƐƚŽĨŝǆƚŚĞŶƌĞŵŽǀĞƚŽƐƚĂƌƚǁĞĞŬůǇKWƚĞƐƚ͘^ƚĂƌƚǁĞĞŬůǇ KWƚĞƐƚ͘ ϴͬϮͬϮϬϮϮͲdƵĞƐĚĂǇ ϳͬϯϭͬϮϬϮϮͲ^ƵŶĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϴͬϭͬϮϬϮϮͲDŽŶĚĂǇ ϳͬϮϵͬϮϬϮϮͲ&ƌŝĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϳͬϮϳͬϮϬϮϮͲtĞĚŶĞƐĚĂǇ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ t>>^ͬ/KEZZ/s>͘KEd/Eh&ZKDϳͲϮϲͲϮϮt^Z͘ZEϯΖyϭͲϳͬϴΖΖ^dD͕ϯ͘ϮϱΖΖ'h'd'ΛϵϴϲΖ^>D͘ZEϰΖyϯΖΖ />Z;ĨůĂƉƉĞƌͿd'ΛϵϴϲΖ^>D͕/>Z&h>>K&/͘>Z^WhDWϭϬ>^EdDd,d,EϮϴ>^ϲϬͬϰϬtZD͘ZEϯΖyϭͲ ϳͬϴΖΖ^dD͕ϯ͘ϮϱΖΖ'h'͕d'WhDW'h'^E^KZΛϵϵϰϮΖ^>DͬϵϵϱϳΖ^>D͘ϯΖyϭͲϳͬϴΖΖ^dD͕Ϯ͘ϳϯΖΖ>/ΖΖd'&/^,Λ ϵϵϵϳΖ^>D͕,/DWZ^^/KEK&ZKW^K<d͘ϯΖΖ'Z;ƐƚĞĞůͿ͕ϯͲϭͬϮ'Ͳ/d^h͕Ϯ͘ϳϮΖΖEd͕͘KsZ^,Kdǁͬϭ͘ϰϯϳ'ZWW>͕ Ϯ͘ϰϮΖΖ>>'h/͕>d,&/^,ΛϵϵϵϳΖ^>D͘;>/,ϯͲϭͬϮ'Ͳ/d^h͕Ϯ͘ϳϮΖΖEd͕͘KsZ^,Kd;Ϯ͘ϯϭΖΖKͿ͕ǁͬϭ͘ϰϯϳ'ZWW>͕ Ϯ͘ϰϮΖΖ>>'h/͕K>ϲϵΖΖͿ͘ZEϯΖΖ'Z;ƐƚĞĞůͿ>d,'Ͳ/d^hΛϵϵϵϱΖ^>D KEd/Eht^ZϳϬϮϴϬϮϮͿ͘t>>^ͬ/KEWZdhZ͘&ƌĞĞǌĞWƌŽƚĞĐƚ͘WƌĞƐƐƵƌĞƚĞƐƚĞƋƵŝƉŵĞŶƚƚŽϮϱϬͬϮϱϬϬƉƐŝ͘WƵŵƉϭϬďďůƐ EĞĞƚĂŶĚϮϴďďůƐϲϬͬϰϬĚŽǁŶdďŐ;/ĐĞ&ƌĞĞͿ͘ ϳͬϮϴͬϮϬϮϮͲdŚƵƌƐĚĂǇ Z/'ͲhW͘ϭϮϱZKEt/Z͘d^сϭ͘ϳϱΗZ^͕ϭϬΖǆϭͲϳͬϴΗZK>>Z^dD;Ϯ͘ϲϬΗǁŚůƐͿ͕<:dϱΖǆϭͲϳͬϴΗZK>>Z^dD;Ϯ͘ϲϬΗǁŚůƐͿ͕ K:͕<:d>^^͘^d<WEd<KEdZK>K&t/Z͘Wh>>dZWE^dKEdKt>>,͘Z/,tͬϯͲϭͬϮΗ'^;ƌĂƐƐͿ͘ ^ͬΛϵ͕ϵϵϱΖ^>DE>d,&/^,͕:Z&KZϯϱD/Ehd^E^,Z'^;EŽŵŽǀĞŵĞŶƚͿWKK,͘KK,tͬ^,Z'^͘ ,<dKK>^dZ/E'͕hdϭϬϬΖK&t/ZEZͲd/ZKW^K<d͘>>&ZKDt^>dKZ/'ͲKtE͘Z/'ͲKtEKDW>d͕ t>>^hZ͘t>>^,hdͲ/EKEWZdhZ͕WKWEKd/&/͘ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW^Ͳϯϰ ^>ΘWƵŵƉ ϱϬͲϬϮϵͲϮϯϭϳϭͲϬϬͲϬϬ ϮϬϯͲϭϯϬ ϳͬϭͬϮϬϮϮ ϭϬͬϭϬͬϮϬϮϮ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϴͬϲͬϮϬϮϮͲ^ĂƚƵƌĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϴͬϵͬϮϬϮϮͲdƵĞƐĚĂǇ ϴͬϳͬϮϬϮϮͲ^ƵŶĚĂǇ t>>^,hdͲ/EKEZZ/s>͕WdWϮϱϬ>ͬϮϱϬϬ,͘DϮZhE^tͬϮ͘ϯϱΗD'EddKϭϬ͕ϬϱϮΖ^>D;ZĞĐŽǀĞƌĞĚƐŵĂůůĐŚƵŶŬ ŽĨŵĞƚĂůͿ͘t>>^,hdͲ/EKEWZdhZ͕EKd/&/WKW͘ ϴͬϴͬϮϬϮϮͲDŽŶĚĂǇ ϴͬϱͬϮϬϮϮͲ&ƌŝĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϴͬϯͬϮϬϮϮͲtĞĚŶĞƐĚĂǇ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϴͬϰͬϮϬϮϮͲdŚƵƌƐĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW^Ͳϯϰ ^>ΘWƵŵƉ ϱϬͲϬϮϵͲϮϯϭϳϭͲϬϬͲϬϬ ϮϬϯͲϭϯϬ ϳͬϭͬϮϬϮϮ ϭϬͬϭϬͬϮϬϮϮ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ t>>^,hdͲ/EKEZZ/s>͕WdWϯϬϬ>ͬϯϱϬϬ,͘ZEϰϬZD>/WZ&ZKDϭϬ͕ϬϱϬΖ^>DdKϳ͕ϬϬϬΖ^>D͘t>>^,hdͲ/EKE WZdhZ͕EKd/&/WKW͘ ϵͬϯͬϮϬϮϮͲ^ĂƚƵƌĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϵͬϲͬϮϬϮϮͲdƵĞƐĚĂǇ ϵͬϰͬϮϬϮϮͲ^ƵŶĚĂǇ >Z^>Kt>>t/d,ϭϱϬ>^K&^&>h͘WdWϮϱϬ>WͲϮϱϬϬ,W͘hddh/E't/d,t>>dϮϯϴtdϵϵϳϱΖD;> ^сϵϵϱϲ͘ϵΖ͕>dK>^сϭϴ͘ϭΖͿ͘dKK>^&>>&Z>zdKΕϰϲϬϬΖE^>Kt>zdKϵϵϴϮΖD͘ϭ^d>>Khd/E/d/d/E' hddZ͕hdKEd/EKh^>z&KZϴD/E^͘^ZKEhZZEd/E/d͘KDW>dhd͘K>>Z^^,/&dhWϭ͘ϱΖ͘Dy hddZyd͘сϯ͘ϲϳΗ͘ƐƐŝƐƚͲ>ŝŶĞ;ZtKͿ;WƌĞƐƐƵƌĞdĞƐƚĞƋƵŝƉŵĞŶƚƚŽϮϱϬͬϮϱϬϬƉƐŝͿWƵŵƉĞĚϭϱϬďďůƐŽĨϭϭϬΎϭй<>ǁͬ ƐĂĨĞůƵďĞƚŽůŽĂĚd'͘WƵŵƉĞĚϭϱďďůƐŽĨϭй<>ǁͬƐĂĨĞůƵďĞĚŽǁŶd'ƚŽĂƐƐŝƐƚͲ>ŝŶĞĚŽǁŶŚŽůĞ͘&ƌĞĞǌĞWƌŽƚĞĐƚĞĚd'ǁŝƚŚ ϰϬďďůƐϲϬͬϰϬ͘ ϵͬϱͬϮϬϮϮͲDŽŶĚĂǇ ϵͬϮͬϮϬϮϮͲ&ƌŝĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϴͬϯϭͬϮϬϮϮͲtĞĚŶĞƐĚĂǇ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϵͬϭͬϮϬϮϮͲdŚƵƌƐĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW^Ͳϯϰ ^Zηϭ ϱϬͲϬϮϵͲϮϯϭϳϭͲϬϬͲϬϬ ϮϬϯͲϭϯϬ ϳͬϭͬϮϬϮϮ ϭϬͬϭϬͬϮϬϮϮ ϵͬϭϲͬϮϬϮϮͲ&ƌŝĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϵͬϭϰͬϮϬϮϮͲtĞĚŶĞƐĚĂǇ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϵͬϭϱͬϮϬϮϮͲdŚƵƌƐĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ tĞůů<ŝůůĞĚƐĞƚϰΗd^Ws͘EdƌĞĞͬĂĚĂƉƚĞƌ͘ŚĞĐŬůŝĨƚƚŚƌĞĂĚƐĂŶĚŝŶƐƚĂůůd^ƉůƵŐ͘EhĂŶĚƚĞƐƚKW͘WƌĞƐƐƵƌĞƚĞƐƚ ĞƋƵŝƉŵĞŶƚƚŽϮϱϬͬϮϱϬϬƉƐŝ͘WƵŵƉϰϱϯďďůƐϭϯϬΎWƌŽĚƵĐĞĚǁĂƚĞƌĚŽǁŶdďŐƵƉ/ƚŽƚĂŶŬ͘ϭ͗ϭŽŶĐĞǁĞůůǁĂƐĨůƵŝĚƉĂĐŬĞĚ͕ &ůƵƐŚ,W,ŽƐĞǁͬϱďďůƐϲϬͬϰϬ͘Ws^Ğƚ͘ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϵͬϭϳͬϮϬϮϮͲ^ĂƚƵƌĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϵͬϮϬͬϮϬϮϮͲdƵĞƐĚĂǇ ϵͬϭϴͬϮϬϮϮͲ^ƵŶĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϵͬϭϵͬϮϬϮϮͲDŽŶĚĂǇ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW^Ͳϯϰ ^Zηϭ ϱϬͲϬϮϵͲϮϯϭϳϭͲϬϬͲϬϬ ϮϬϯͲϭϯϬ ϳͬϭͬϮϬϮϮ ϭϬͬϭϬͬϮϬϮϮ ŽŶƚŝŶƵĞƚŽZ/,ǁŝƚŚϳͲϱͬϴΗ^ĐƌĂƉĞƌ&ͬϮϬϬϬΖƚŽϱϬϬϬΖD͘hƉƵŵƉŝŶŐϯ͘ϳďƉŵĂƚϲϱϬƉƐŝ͘ŽŶƚŝŶƵĞƚŽZ/,&ͬϱϬϬϬdͬϵϴϬϬ͘ hŶĂďůĞƚŽƚƌŝƉŝŶŚŽůĞŽŶĞůĞǀĂƚŽƌƐǁŝƚŚ;ϬͿĚŽǁŶǁĞŝŐŚƚ͘^ǁŝǀĞůƵƉĂŶĚZͬhŝƌĐƵůĂƚŝŶŐĞƋƵŝƉŵĞŶƚ͘tĂƐŚĚŽǁŶ&ͬϵϴϬϬdŽƚĂŐ ĂƚϵϵϲϱΖ͘WƵŵƉŝŶŐĂƚϯ͘ϱďƉŵĂƚϵϬϬϬƉƐŝ͘Whtсϳϴ<͕^KtсϬͲϭϬ<͘ZŽƚĂƚĞĚŽǁŶƐůŽǁƚŽƐĂŵĞĚĞƉƚŚŽĨϵϵϲϱΖD͘^ƚŽƉƉĞĚ ƌŽƚĂƚŝŽŶŝŵŵĞĚŝĂƚĞůǇ͘ZKdtdϯϵ<dŽƌƋƵĞсϰϯϬϬĨƚͬůďƐ͘hƉƵŵƉŝŶŐϯ͘ϱďƉŵĂƚϴϬϬƉƐŝ͘^ŵĂůůĂŵŽƵŶƚŽĨƐĂŶĚĂŶĚĐƌƵĚĞŽŶ ƌĞƚƵƌŶƐ͘ůŽǁĚŽǁŶĚŽǁŶůŝŶĞƐ͘&ůŽǁĐŚĞĐŬǁĞůůƐƚĂƚŝĐ͘WKK,ǁŝƚŚǁŽƌŬƐƚƌŝŶŐ&ͬϵϵϲϱΖdͬϲϯϵϱΖD͘^ƚŽƉƉĞĚƚŽƚƌŽƵďůĞƐŚŽŽƚ ƚƌĂŶƐŵŝƐƐŝŽŶ͘^ĞĐƵƌĞǁĞůů͘dƌĂŶƐŵŝƐƐŝŽŶŽǀĞƌŚĞĂƚĞĚĂŶĚĚĞǀĞůŽƉĞĚĂŶĂďŶŽƌŵĂůŶŽŝƐĞ͘ĞĐŝƐŝŽŶŵĂĚĞƚŽƐƚŽƉŚĞƌĞĂŶĚ ĐŚĂŶŐĞŽƵƚƚƌĂŶƐŵŝƐƐŝŽŶ͘ ϵͬϮϰͬϮϬϮϮͲ^ĂƚƵƌĚĂǇ ŽŶƚŝŶƵĞƚŽƚĞƐƚůůŝƐŽŶdƌĂŶƐŵŝƐƐŝŽŶƚŽŽďƚĂŝŶĂůůŽƉĞƌĂƚŝŶŐƉĂƌĂŵĞƚĞƌƐ͘ůƐŽĐŚĂŶŐĞĚŽƵƚůĞĂŬŝŶŐ'ůǇĐŽůŚŽƐĞƚŽƚŚĞ dƌĂŶƐŵŝƐƐŝŽŶ͘ŽŶƚŝŶƵĞƚŽWKK,&ͬϲϯϵϱdͬϮϯϭΖ͘>ͬ,^ĐƌĂƉĞƌͬDŝůůƐƐĞŵďůǇĂŶĚϲĞĂĐŚϰͲϯͬϰΗƌŝůůŽůůĂƌƐ͘&ŽƵŶĚdƌĞĞ WŝĞĐĞƐŽĨƚŚĞDŝƐƐŝŶŐĂŶŶŽŶůĂŵƉŽŽƌ,ŝŶŐĞƐ͕>ŽĚŐĞĚĂŶĚ^ƚƵĐŬŝŶƚŚĞŵŽƵƚŚŽĨƚŚĞDŝůů^ŚŽĞ͘ĂůůĞĚKĂŶĚĚĞĐŝƐŝŽŶǁĂƐ ŵĂĚĞƚŽŵĂŬĞĂŶŽƚŚĞƌůĞĂŶŽƵƚƌƵŶƚŽĞŶƐƵƌĞƚŚĞƐŚŽĞŐŽĞƐŽǀĞƌƚŚĞƚƵďŝŶŐƐƚƵďĂƚϵϵϲϱΖĂŶĚEŽͲ'ŽŽƵƚĂƚƚŚĞŶĞǆƚƚƵďŝŶŐ ĐŽůůĂƌĂƚϵϵϲϵΖD͘DĂŬĞƵƉƚŚĞƐĂŵĞϳͲϱͬϴΗ^ĐƌĂƉĞƌͬDŝůůƐƐĞŵďůǇdͬϰϳΖ͘Z/,ǁŝƚŚϯ͘ϱΗtŽƌŬ^ƚƌŝŶŐ&ͬϰϳΖdͬϵϯϬϬΖĂƚ ƌĞƉŽƌƚƚŝŵĞ͘ ϵͬϮϱͬϮϬϮϮͲ^ƵŶĚĂǇ ŽŶƚŝŶƵĞƚƌĂŶƐŵŝƐƐŝŽŶĐŚĂŶŐĞͲŽƵƚ͘ŚĂŶŐĞĚZĂŵƐŝŶƚŚĞ^ĞĐŽŶĚĂƌǇKW^ƚĂĐŬĨƌŽŵϱ͘ϱΗ^ŽůŝĚŽĚǇƚŽϮͲϳͬϴΗyϱΗsZ ϵͬϮϲͬϮϬϮϮͲDŽŶĚĂǇ ϵͬϮϯͬϮϬϮϮͲ&ƌŝĚĂǇ ŝƌĐƵůĂƚĞĂŶĚŽŶĚŝƚŝŽŶ͕WƵŵƉŝŶŐϭϭďďůƐ͘ĚŽǁŶƚŚĞĂĐŬƐŝĚĞĂŶĚϭϬďďůƐ͘ĚŽǁŶƚŚĞƚƵďŝŶŐ͘ůŽǁĚŽǁŶĂůůĐŝƌĐƵůĂƚŝŶŐůŝŶĞƐ͘ &ůŽǁŚĞĐŬǁĞůůƐƚĂƚŝĐ͘ŽŶƚŝŶƵĞƚŽWKK,>ĂǇŝŶŐĚŽǁŶϰ͘ϱΗϭϮ͘ϲη͕>ͲϴϬ͕/ddƵďŝŶŐƚŽ^ƵƌĨĂĐĞ͘ ZĞĐŽǀĞƌĞĚϮϯϳũƚƐ͘ϰ͘ϱΗdƵďŝŶŐ͘ϭĞĂ͘ϰ͘ϱΗ'>D͕ϭĞĂ͘ŝƐĐŚĂƌŐĞ'ĂƵŐĞ͕ϭĞĂ͘WƵŵƉ'ĂƵŐĞ͕ϭĞĂ͘ϯ͘ϱΗyͲEŝƉƉůĞ͕ϭƵƚ:ŽŝŶƚс ϯ͘ϭϴΖ͘dŽƚĂůĂŶŶŽŶůĂŵƉŽƵŶƚсϭϮϲĞĂ͘DŝƐƐŝŶŐϰWŝĞĐĞƐŽĨƚŚĞůĂŵƉĚŽŽƌ,ŝŶŐĞƐƚŚĂƚĐŽƌƌŽĚĞĚŽĨĨϮĂŶŶŽŶůĂŵƉƐ͘ ůĞĂŶĂŶĚĐůĞĂƌƚŚĞƌŝŐĨůŽŽƌ͘ZĂĐŬĂŶĚdĂůůǇƚŚĞϳͲϱͬϴΗĂƐŝŶŐ^ĐƌĂƉĞƌƐƐĞŵďůǇĂŶĚϯ͘ϱΗǁŽƌŬƐƚƌŝŶŐ͘DͬhϳͲϱͬϴ^ĐƌĂƉĞƌ, ƐƐĞŵďůǇƚͬϮϯϭΖ͘Z/,ƉŝĐŬŝŶŐƵƉϯͲϭͬϮΗǁŽƌŬƐƚƌŝŶŐƚŽϮϬϯϯΖ͘hϯ͘ϱWDĂƚϯϱϬƉƐŝ͘ZĞĐŝƉƌŽĐĂƚĞƉŝƉĞǁŚŝůĞĐŝƌĐƵůĂƚŝŶŐ͘ ϵͬϮϭͬϮϬϮϮͲtĞĚŶĞƐĚĂǇ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϵͬϮϮͬϮϬϮϮͲdŚƵƌƐĚĂǇ dĞƐƚKWĂƐƉĞƌ^ƚĂƚĞĂƉƉƌŽǀĞĚƐƵŶĚƌǇ͘ůůƚĞƐƚƐƚŽϮϱϬƉƐŝůŽǁͬϮϱϬϬƉƐŝŚŝŐŚ͘,ĞůĚĞĂĐŚƚĞƐƚĨŽƌϱĐŚĂƌƚĞĚŵŝŶ͘ tŝƚŶĞƐƐŽĨƚŚĞƚĞƐƚǁĂƐǁĂŝǀĞĚďǇK'ƌĞƉ͘ŽďEŽďůĞ͘ZͬƚĞƐƚŝŶŐĞƋƵŝƉŵĞŶƚ͘ŚĂŶŐĞŽǀĞƌƉŝƉĞŚĂŶĚůŝŶŐĞƋƵŝƉŵĞŶƚƚŽ ϰ͘ϱΗ͘EŝƉƉůĞƵƉĨůŽǁůŝŶĞƐƉŽŽůƐĂŶĚϲΗĨůŽǁůŝŶĞ͘ZͬhŝƌĚďĂƚŚƵŶĚĞƌƌŝŐĨůŽŽƌ͘Dͬhϰ͘ϱΗ>ĂŶĚŝŶŐũŽŝŶƚ͘ZͬhĐŽŶƚƌŽůůŝŶĞƐŚĞĂǀĞ͘ ŚĞĐŬĨŽƌWƌĞƐƐƵƌĞŽŶƚŚĞ/͘K>^͘WƵůů,ĂŶŐĞƌƚŽƚŚĞĨůŽŽƌ͘,ĂŶŐĞƌƵŶƐĞĂƚĞĚĂƚϱϱ<͘WhtŝƐϵϴ<͘WƵŵƉϮϯďďů͘ƚŽĨŝůůŚŽůĞ͘ >ͬ>ĂŶĚŝŶŐũŽŝŶƚĂŶĚ,ĂŶŐĞƌ͘WKK,ůĂǇŝŶŐĚŽǁŶϰ͘ϱΗϭϮ͘ϲη͕>ͲϴϬ͕/dZͲϯdƵďŝŶŐ&ͬϵϵϳϱΖdͬϲϬϬϬΖĂƚƌĞƉŽƌƚƚŝŵĞ͘/ŶƐƉĞĐƚ ƚƵďƵůĂƌƐĨŽƌƌĞƌƵŶ͘ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW^Ͳϯϰ ^Zηϭ ϱϬͲϬϮϵͲϮϯϭϳϭͲϬϬͲϬϬ ϮϬϯͲϭϯϬ ϳͬϭͬϮϬϮϮ ϭϬͬϭϬͬϮϬϮϮ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ ŽŶƚŝŶƵĞƚŽZ/,ǁŝƚŚ^ĐƌĂƉĞƌĂŶĚDŝůůĂƐƐĞŵďůǇŽŶtŽƌŬ^ƚƌŝŶŐƚŽϵϲϬϬ͘^ǁŝǀĞůƵƉ͕ZͬhŝƌĐƵůĂƚŝŶŐ,ŽƐĞ͘tĂƐŚŽǁŶ&ͬϵϵϲϬ ƚŽdĂŐdƵďŝŶŐ^ƚƵďĂƚϵϵϲϲΖD͘WƵŵƉŝŶŐϯďƉŵĂƚϲϱϬƉƐŝ͘hŶĂďůĞƚŽǁĂƐŚŽǀĞƌ^ƚƵďǁŝƚŚŽƵƚƌŽƚĂƚŝŽŶ͘Whtсϴϯ<^Ktсϭϯ<͘ ZŽƚĂƚĞĂŶĚǁĂƐŚŽǀĞƌdƵďŝŶŐ^ƚƵď&ͬϵϵϲϲΖƚŽϵϵϳϬΖZŽƚĂƚĞϮϬZWDĂƚϯϱϬϬĨƚͬůďƐdŽƌƋƵĞ͘ZKdtdсϯϲ<͘sĞƌŝĨǇǁĂƐŚŝŶŐŽǀĞƌ ǁŝƚŚŽƵƚƌŽƚĂƚŝŽŶǁŝƚŚŶŽƌĞƐƚƌŝĐƚŝŽŶ͘&ůŽǁŚĞĐŬǁĞůůƐƚĂƚŝĐ͘ůŽǁŽǁŶŝƌĐƵůĂƚŝŶŐ>ŝŶĞƐ͘ZͬŝƌĐƵůĂƚŝŶŐ>ŝŶĞ͘WKK,ǁŝƚŚ ǁŽƌŬƐƚƌŝŶŐ&ͬϵϵϳϬdͬϰϱΖ,͘>ͬ,͕^ĐƌĂƉĞƌĂŶĚDŝůůƐƐĞŵďůǇ͘DͬhzĞůůŽǁ:ĂĐŬĞƚϳͲϱͬϴΗdĞƐƚWĂĐŬĞƌƐƐĞŵďůǇ͘Z/,ǁŝƚŚ dĞƐƚWĂĐŬĞƌŽŶϯ͘ϱΗtŽƌŬ^ƚƌŝŶŐƚŽϴϰϬϬΖDĂƚƌĞƉŽƌƚƚŝŵĞ͘ ϵͬϮϳͬϮϬϮϮͲdƵĞƐĚĂǇ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW^Ͳϯϰ ^Zηϭ ϱϬͲϬϮϵͲϮϯϭϳϭͲϬϬͲϬϬ ϮϬϯͲϭϯϬ ϳͬϭͬϮϬϮϮ ϭϬͬϭϬͬϮϬϮϮ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ t>>^,hdͲ/EKEZZ/s>͕WdWϯϬϬ>ͬϯϱϬϬ,͘dDWddK^,/&dyͲ^^dϵ͕ϳϴϵΖD;^ƉĞĞĚƐƐůŽǁƚŽďĞůŽǁϰϬĨƉŵͿ͘ D<ϮddDWd^dKWh>>>>ΘZKdϵ͕ϵϱϮΖ^>D;ďĞůůŐƵŝĚĞƐĨƵůůŽĨƐĂŶĚͿ͘ZEϱΖǆϯ͘ϬΗΗZ/sKtE/>Z&ZKD ϵ͕ϵϱϮΖ^>DdKϵ͕ϵϱϱΖ^>D;ZĞĐŽǀĞƌĞĚϭŐĂůůŽŶŽĨĐŚĂƌĐŽĂůůŝŬĞƐĂŶĚͿ͘ddDWddKWh>>>>ΘZKtͬϯ͘ϮϱΗEd͕Ϯ͘ϬΗ:h^ &ZKDϵ͕ϵϱϯΖ^>D;EŽƌĞĐŽǀĞƌǇͿ͘ ϭϬͬϭͬϮϬϮϮͲ^ĂƚƵƌĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϭϬͬϰͬϮϬϮϮͲdƵĞƐĚĂǇ ϭϬͬϮͬϮϬϮϮͲ^ƵŶĚĂǇ ;WŽƐƚZtKͿ;WƌĞƐƐƵƌĞdĞƐƚĞƋƵŝƉŵĞŶƚƚŽϮϱϬͬϮϱϬϬƉƐŝͿWƵŵƉĞĚϲϬďďůƐĐƌŝĞƐĞůĚŽǁŶd'͘ ϭϬͬϯͬϮϬϮϮͲDŽŶĚĂǇ ϵͬϯϬͬϮϬϮϮͲ&ƌŝĚĂǇ ŝƌĐƵůĂƚĞďĂůůĂŶĚƌŽĚĚŽǁŶƚŽƐĞĂƚ͘ƉƵŵƉŝŶŐĂƚϮWDϯϮϱƉƐŝ͘ŽŶĐĞďĂůůŽŶƐĞĂƚƉƌĞƐƐƵƌĞĚƵƉƚŽϭϬϬϬƉƐŝ͘ďůĞĚŽĨĨĂŶĚ ƉƌĞƐƐƵƌĞĚƵƉƚŽϰϮϬϬƉƐŝƚŽƐĞƚƉĂĐŬĞƌ͘ƐŚƵƚƉ΀ƵŵƉĚŽǁŶĂƚϰϮϬϬƉƐŝĂŶĚƉƌĞƐƐƵƌĞďůĞĚŽĨĨŝŵŵĞĚŝĂƚĞůǇ͘ƚƵƌŶĞĚƉƵŵƉďĂĐŬŽŶ ĂŶĚƚƌŝĞĚƚŽŵĂŝŶƚĂŝŶϰϬϬϬƉƐŝďƵƚǁŽƵůĚŶŽƚŐŽŽǀĞƌϮϱϬϬƉƐŝƉƵŵƉŝŶŐĂƚϮ͘ϱWD͘ƐŚƵƚĚŽǁŶƉƵŵƉĂŶĚƉƌĞƐƐƵƌĞďůĞĚƚŽϴϬϬ ƉƐŝ͘^ƉŽŬĞǁŝƚŚK͘ĚĞĐŝƐŝŽŶǁĂƐŵĂĚĞƚŽƚĞƐƚďĂĐŬƐŝĚĞĨŽƌD/d/͘ƉƌĞƐƐƵƌĞĚƵƉƚŽϯϳϱϬƉƐŝǁŚŝůĞůĞĂǀŝŶŐϱϬϬƉƐŝŽŶƚƵďŝŶŐ͘ ŐŽŽĚƚĞƐƚ͘/ŶƐƚĂůůďĂĐŬƉƌĞƐƐƵƌĞǀĂůǀĞĂŶĚďĞŐŝŶƌŝŐĚŽǁŶƉƌŽĐĞƐƐ͘ƌŝŐĚŽǁŶƚŽŶŐƐ͘ƌŝŐĚŽǁŶďŝƌĚďĂƚŚ͘ƉƵůůƌĂĐŬƉŝŶƐ͘ƌŝŐĚŽǁŶ ĂŶĚŵŽǀĞĐĂƚǁĂůŬ͖ZͬĂůůŶĐŝůůĂƌǇĞƋƵŝƉŵĞŶƚĂŶĚ>ŝŶĞƐ͘>ŽǁĞƌDĂƐƚĂŶĚƐĞĐƵƌĞƚŽƚŚĞĂƌƌŝĞƌĨŽƌƚƌĂŶƐƉŽƌƚ͘DŽǀĞĂƌƌŝĞƌƚŽ ͲWĂĚĨŽƌƌŽƵƚŝŶĞŵĂŝŶƚĞŶĂŶĐĞ͘dƌĂŶƐĨĞƌǁŽƌŬŽǀĞƌĨůƵŝĚĨƌŽŵƚŚĞƉŝƚƐ͘ZĞŵŽǀĞĨůŽǁƐƉŽŽůƐ͘tŝƚŚƌĂŶĞƐƵƉƉŽƌƚ͕>ŽĂĚŽƵƚZŝŐ &ůŽŽƌĂŶĚtĞůů,ŽƵƐĞŽŶƚŽƚƌĂŶƐƉŽƌƚƚƌĂŝůĞƌ͘^ƚĂŐĞƚƌĂŝůĞƌƚŽƚŚĞƐŝĚĞŽĨƚŚĞƉĂĚ͘EͬKWΖƐĂŶĚůŽĂĚŽƵƚĨŽƌƚƌĂŶƐƉŽƌƚ͖Eͬh dƌĞĞĂŶĚĂĚĂƉƚĞƌĨůĂŶŐĞ͘dĞƐƚsŽŝĚƚŽϱϬϬͬϱϬϬϬĨŽƌϭϬŵŝŶ͘dĞƐƚdĞĐŚtŝƌĞ'ŽŽĚ͘ƚĞƐƚĞĚĚĂƉƚĞƌ&ůĂŶŐĞĂŶĚƚƌĞĞƚŽϱϬϬͬ ϱϬϬϬĨŽƌϱŵŝŶ͘^ĞĐƵƌĞǁĞůů͕ůĞĂŶŽƵƚƚŚĞWŝƚDŽĚƵůĞ͘WŝĐŬƵƉƚŚĞZŝŐDĂƚƐĂŶĚƐƚĂŐĞŽŶĞĚŐĞŽĨƉĂĚĨŽƌůŽĂĚŽƵƚ͘ZĞďƵŝůƚ sĂůǀĞ<ͲϳŽŶƚŚĞŬŝůůŵĂŶŝĨŽůĚ͘^ĞƌǀŝĐĞĂůůĐŚŽĐŬĂŶĚŬŝůůǀĂůǀĞƐ͘t>>,͗EKW͕ĐůĞĂŶǀŽŝĚ͕ŝŶƐƚĂůůd^ƉůƵŐ͕ŶĞǁZyϱϰ ŐĂƐŬĞƚ͘WhĂĚĂƉƚĞƌĂŶĚƌƵŶƚĞĐŚǁŝƌĞƚŚƌŽƵŐŚƚĞƌŵƉŽƌƚĂŶĚůĂŶĚ͘DhϰϭͬϲΗƚƌĞĞĂŶĚůĂŶĚƚŽƌƋƵĞďŽƚŚĐŽŶŶĞĐƚŝŽŶƐƚŽƐƉĞĐ ĂŶĚƚĞƐƚƚďŐŚŐƌǀŽŝĚϱϬϬͬϱϬϬϬ;W^^Ϳ͘tĞůůƐƐƵƉƉŽƌƚĂƌƌŝǀĞĚǁŝƚŚƚƌŝƉůĞǆ͘dĞƐƚƚƌĞĞ;W^^Ϳ͕ƉƵůůd^ƉůƵŐĂŶĚƉƵůůƉǀǁͬdďĂƌ͘ ůůǀĂůǀĞƐŝŶĐŽƌƌĞĐƚƉŽƐŝƚŝŽŶ͘EŽƚŝĨŝĞĚŽZĞƉĂŶĚůĞĨƚůŽĐĂƚŝŽŶ͘ũŽďĐŽŵƉůĞƚĞ͘ ϵͬϮϴͬϮϬϮϮͲtĞĚŶĞƐĚĂǇ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ ŽŶƚŝŶƵĞZ/,ǁͬǁŽƌŬƐƚƌŝŶŐĂŶĚϳͲϱͬϴƚĞƐƚƉĂĐŬĞƌĨƌŽŵϴϰϬϬΖƚŽϴϲϬϬΖĐŚĂŶŐĞŽƵƚƐůŝƉƐĨŽƌĐŽůůĂƌƐ͖WͬhϭϮ͕ϰͲϭͬϰĚƌŝůůĐŽůůĂƌƐ ĂŶĚϲ͕ϰͲϯͬϰĚƌŝůůĐŽůůĂƌƐ͘Z/,ƚŽϵϵϮϲΖƐǁŝǀĞůƵƉƚŽƐĞƚƉĂĐŬĞƌ͘ƵƉǁƚϵϬ<ĚŽǁŶǁƚϭϱ<͘^ĞƚƚĞƐƚƉĂĐŬĞƌ͘ƉĂĐŬĞƌĞůĞŵĞŶƚƐĂƚ ϵϵϮϭΖůŝŶĞƵƉƚŽƚĞƐƚĐĂƐŝŶŐƚŽϯϲϱϬƉƐŝ͖ƚĞƐƚĐĂƐŝŶŐƚŽϯϲϱϬƉƐŝĨŽƌϯϬŵŝŶŽŶĐŚĂƌƚ͘ďůĞĞĚŽĨĨƉƌĞƐƐƵƌĞĂŶĚƌĞůĞĂƐĞƉĂĐŬĞƌ͘&ůŽǁ ĐŚĞĐŬǁĞůůƐƚĂƚŝĐ͘WKK,ůĂǇŝŶŐĚŽǁŶϯ͘ϱΗtŽƌŬƐƚƌŝŶŐĂŶĚzĞůůŽǁ:ĂĐŬĞƚϳͲϱͬϴΗdĞƐƚWĂĐŬĞƌ͘>ͬzĞůůŽǁ:ĂĐŬĞƚϳͲϱͬϴΗdĞƐƚ WĂĐŬĞƌ͕ůĞĂŶĂŶĚůĞĂƌƌŝŐĨůŽŽƌ͘ŚĂŶŐĞWŝƉĞ,ĂŶĚůŝŶŐĞƋƵŝƉŵĞŶƚƚŽϰ͘ϱΗ͘,ĂŶŐŽŶƚƌŽůůŝŶĞƐŚĞĂǀĞŝŶƚŚĞĚĞƌƌŝĐŬ͘ZĂĐŬΘ dĂůůǇϰ͘ϱΗŽŵƉůĞƚŝŽŶ͘^ƚĂƌƚZƵŶŶŝŶŐϰ͘ϱΗϭϮ͘ϲη>ͲϴϬdyWŽŵƉůĞƚŝŽŶĂƐƉĞƌƉƌŽŐƌĂŵĚĞƚĂŝů͘ ϵͬϮϵͬϮϬϮϮͲdŚƵƌƐĚĂǇ ŽŶƚŝŶƵĞƚŽZ/,ǁŝƚŚϰ͘ϱΗϭϮ͘ϲη>ͲϴϬdyWŽŵƉůĞƚŝŽŶƚŽϵϵϱϬΖD͘KďƚĂŝŶ^ƚƌŝŶŐtĞŝŐŚƚƐ͘WhtсϵϬ<͕^KtсϭϬ<͖dĂŐdƵďŝŶŐ ^ƚƵďĂƚϵϵϲϮΖD͘^ĞƚĚŽǁŶϲ<ƚŽƐŚĞĂƌƉŝŶƐŽŶŽǀĞƌƐŚŽƚ͘^ůĂĐŬŽĨĨĂŶĚdĂŐEŽͲ'ŽĂƚϵϵϲϳΖD͖^ƉĂĐĞŽƵƚ͘DͬhƚƵďŝŶŐ ,ĂŶŐĞƌ͘dĞƌŵŝŶĂƚĞĂƉ/ͲtŝƌĞƚŽƚŚĞ,ĂŶŐĞƌ͘dŚĞĂƉ/ͲtŝƌĞďƌŽŬĞďĞůŽǁƚŚĞ,ĂŶŐĞƌĂŶĚŚĂĚƚŽďĞƐƉůŝĐĞĚͬZĞƉĂŝƌĞĚ͘dĞƐƚ ĂƉ/ͲtŝƌĞ͘>ĂŶĚdƵďŝŶŐ,ĂŶŐĞƌ͘Z/>^͘ƌŽƉĂůůΘZŽĚ͘dĞƐƚĂƉ/ͲtŝƌĞ͘ ǁŽƌŬƐƚƌŝŶŐĂŶĚϳͲϱͬϴƚĞƐƚƉĂĐŬĞƌĨƌŽŵϴϰϬϬΖƚŽϴϲϬϬΖĐŚĂŶŐĞŽƵƚƐůŝƉƐĨŽƌĐŽůůĂƌƐ͖WͬhϭϮ͕ϰͲϭͬϰĚƌŝůůĐŽůůĂƌƐ ĂŶĚϲ͕ϰͲϯͬϰĚƌŝůůĐŽůůĂƌƐ͘Z/,ƚŽϵϵϮϲΖƐǁŝǀĞůƵƉƚŽƐĞƚƉĂĐŬĞƌ͘ƵƉǁƚϵϬ<ĚŽǁŶǁƚϭϱ<͘^ĞƚƚĞƐƚƉĂĐŬĞƌ͘ƉĂĐŬĞƌĞůĞŵĞŶƚƐĂƚ ϵϵϮϭΖůŝŶĞƵƉƚŽƚĞƐƚĐĂƐŝŶŐƚŽϯϲϱϬƉƐŝ͖ƚĞƐƚĐĂƐŝŶŐƚŽϯϲϱϬƉƐŝĨŽƌϯϬŵŝŶŽŶĐŚĂƌƚ͘ďůĞĞĚŽĨĨƉƌĞƐƐƵƌĞĂŶĚƌĞůĞĂƐĞƉĂĐŬĞƌ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW^Ͳϯϰ ^ůŝĐŬůŝŶĞ ϱϬͲϬϮϵͲϮϯϭϳϭͲϬϬͲϬϬ ϮϬϯͲϭϯϬ ϳͬϮϭϮϬϮϮ ϭϬͬϭϬͬϮϬϮϮ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϭϬͬϴͬϮϬϮϮͲ^ĂƚƵƌĚĂǇ dͬ/ͬKсϱϴͬϬͬϬƐƐŝƐƚ^ůŝĐŬůŝŶĞ;ŝƐƉůĂĐĞdďŐͿWƵŵƉϵϬďďůƐϭϮϬΎWƌŽĚƵĐĞĚǁĂƚĞƌĂŶĚϭϬďďůƐϲϬͬϰϬĚŽǁŶdďŐ͘ &t,WсϴϴϯͬϮϮϴͬϲϱϬ͘WdсϮϱϬ>ͬϯϱϬϬ,͘Wh>>>>ΘZKΛϵϵϱϱΖ^>D͘ZEϮ͘ϳϯΖΖEd͕͘ϭϬΖyϮͲϭͬϮΖΖ/>Z;ďĂůůͿd'Λ ϵϵϲϮΖ^>D͕;ƌĞĐŽǀĞƌϮĐƵƉƐƐĂŶĚǇƚŚŝĐŬĨůƵŝĚͿ͘>Z^WhDWϭϬϬďďůƐWZKh&>h/͘KWE^>sΛϵϴϮϬΖ^>DͬϵϳϴϵΖD͘ Wh>>Z,ΛϵϵϲϮΖ^>DͬϵϵϯϰΖD͘^dϯΖΖ:dWhDW;ƐĞƌη,ͲϬϬϬϭϱ͕ƌĂƚŝŽ͗ϭϬ͕ƐĞĐ͘ůŽĐ͕͘ƐĐƌĞĞŶ͕ϲϵΖΖK>Ϳ^d/Ey^Ͳ^^Λ ϵϴϮϬΖ^>DͬϵϳϴϵΖD͘t>>^ͬ/KEWZdhZ͘ ϭϬͬϭϭͬϮϬϮϮͲdƵĞƐĚĂǇ ϭϬͬϵͬϮϬϮϮͲ^ƵŶĚĂǇ t>>^ͬ/KEZZ/s>͘ZEϮ͘ϳϯΖΖEd͕͘ϭϬΖyϮͲϭͬϮΖΖ/>Z;ďĂůůͿd'ΛϵϵϱϰΖ^>D;ƌĞĐŽǀĞƌϮĐƵƉƐƐĂŶĚǇƚŚŝĐŬĨůƵŝĚͿ t>>^ͬ/KEWZdhZ͘ ϭϬͬϭϬͬϮϬϮϮͲDŽŶĚĂǇ ϭϬͬϳͬϮϬϮϮͲ&ƌŝĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϭϬͬϱͬϮϬϮϮͲtĞĚŶĞƐĚĂǇ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϭϬͬϲͬϮϬϮϮͲdŚƵƌƐĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ 5HJJ-DPHV%2*& )URP%URRNV3KRHEH/2*& 6HQW)ULGD\2FWREHU30 7R$ODVND16$65:HOO6LWH0DQDJHUV &F5HJJ-DPHV%2*& 6XEMHFW5(%23(7HVW6 $WWDFKPHQWV+LOFRUS$65[OV[ ƚƚĂĐŚĞĚŝƐĂƌĞǀŝƐĞĚƌĞƉŽƌƚŵŽǀŝŶŐƚŚĞďŽƚƚůĞƉƌĞĐŚĂƌŐĞƚŽƚŚĞƌĞŵĂƌŬƐ;ƚŚŝƐŝƐĂWͬ&ĨŝĞůĚͿĂŶĚƌĞŵŽǀĞĚƚŚĞ͘ĨƌŽŵƚŚĞ ĐůŽƐƵƌĞƚŝŵĞƐ͘WůĞĂƐĞƵƉĚĂƚĞǇŽƵƌĐŽƉǇ͘ dŚĂŶŬǇŽƵ͕ WŚŽĞďĞ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůǇƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗ůĂƐŬĂE^Ͳ^ZͲtĞůů^ŝƚĞDĂŶĂŐĞƌƐфůĂƐŬĂE^Ͳ^ZtĞůů^ŝƚĞDĂŶĂŐĞƌƐΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗dŚƵƌƐĚĂǇ͕^ĞƉƚĞŵďĞƌϮϮ͕ϮϬϮϮϲ͗ϰϰWD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖KK'WƌƵĚŚŽĞĂǇфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂǇΛĂůĂƐŬĂ͘ŐŽǀх͖ ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх Đ͗ůĂƐŬĂE^Ͳ^ZͲtĞůů^ŝƚĞDĂŶĂŐĞƌƐфůĂƐŬĂE^Ͳ^ZtĞůů^ŝƚĞDĂŶĂŐĞƌƐΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗KWdĞƐƚ͕^Ͳϯϰ͕ϵͬϮϮͬϮϬϮϮ WůĞĂƐĞĨŝŶĚĂƚƚĂĐŚĞĚKWƚĞƐƚĨŽƌ^Ͳϯϰ ZĞŐĂƌĚƐ͕ ^Z^D͛Ɛ ,ŝůĐŽƌƉ^D͗ϵϬϳͲϲϴϱͲϭϮϲϲ ,ŝůĐŽƌƉůĂƐŬĂ͕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ƌĞǀŝƐĞĚƌĞƉŽƌƚ :KLOHDOOUHDVRQDEOHFDUHKDVEHHQWDNHQWRDYRLGWKHWUDQVPLVVLRQRIYLUXVHVLWLVWKHUHVSRQVLELOLW\RIWKHUHFLSLHQWWRHQVXUHWKDWWKHRQZDUGWUDQVPLVVLRQ RSHQLQJRUXVHRIWKLVPHVVDJHDQGDQ\DWWDFKPHQWVZLOOQRWDGYHUVHO\DIIHFWLWVV\VWHPVRUGDWD1RUHVSRQVLELOLW\LVDFFHSWHGE\WKHFRPSDQ\LQWKLVUHJDUGDQG WKHUHFLSLHQWVKRXOGFDUU\RXWVXFKYLUXVDQGRWKHUFKHFNVDVLWFRQVLGHUVDSSURSULDWH STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bm it t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:ASR 1 DATE: 9/22/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2031300 Sundry #322-242 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:953 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators PP #1 Rams 1 2 7/8" x 5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 2 1/16"P Time/Pressure Test Result HCR Valves 1 2 1/16"P System Pressure (psi)3000 P Kill Line Valves 2 2 1/16"P Pressure After Closure (psi)1925 P Check Valve 0NA200 psi Attained (sec)15 P BOP Misc 0NAFull Pressure Attained (sec)53 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4 / 2240 PSI P No. Valves 16 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 26 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 4 P Inside Reel valves 0NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:5.5 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 9/21/2022 04:20 Waived By Test Start Date/Time:9/22/2022 11:00 (date) (time)Witness Test Finish Date/Time:9/22/2022 16:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Bob Noble Hilcorp Tested with both 3-1/2" and 4-1/2" test joints. Bottle Precharge - 1000 psi. C. Pace / C. Greub Hilcorp Alaska LLC S. Heim / C. Huntington MPU S-34 Test Pressure (psi): askans-asr-toolpushers@hilcorp.c ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022) 2022-0922_BOP_Hilcorp_ASR1_MPU_S-34 9 9 9 9999 9 9 9 9 9 9 -5HJJ David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/3/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221003 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 501332053001 214070 8/10/2022 Halliburton CH PPROF BRU 222-34 502832018600 222039 9/15/2022 Halliburton CH RBT BRU 244-27 502832018500 222038 9/13/2022 Halliburton CH RBT END 1-45 500292199100 189124 8/11/2022 Halliburton CH PERF KBU 22-06Y 501332065000 215044 8/22/2022 Halliburton CH PPROF KBU 43-07Y 501332062500 214019 9/7/2022 Halliburton CH PPROF MPU C-24A 500292302001 209134 8/3/2022 Halliburton CH COILFLAG MPU L-46 500292355100 215118 9/10/2022 Halliburton CH MFC24 MPU S-34 500292317100 203130 9/3/2022 Halliburton CH MFC24 NS-10 500292298500 200182 8/18/2022 Halliburton CH WFL- TMD3D NS-32 500292317900 203158 8/17/2022 Halliburton CH WFL- TMD3D PBU 04-30 500292134500 185089 9/17/2022 Halliburton CH RMT3D PBU 05-24A 500292220401 204218 9/12/2022 Halliburton CH CAST PBU 11-16 500292158100 186078 9/10/2022 Halliburton CH PPROF PBU 11-27A 500292163801 222036 8/20/2022 Halliburton CH RBT PBU C-24B 500292081602 212063 8/16/2022 Halliburton CH PPROF PBU E-100A 500292281901 218157 9/20/2022 Halliburton CH LDL PBU S-106 500292299900 201012 9/12/2022 Halliburton CH RBT Please include current contact information if different from above. T37103 T37104 T37105 T37106 T37107 T37108 T37109 T37110 T37111 T37112 T37113 T37114 T37115 T37116 T37117 T37118 T37119 T37120 MPU S-34 500292317100 203130 9/3/2022 Halliburton CH MFC24 Kayla Junke Digitally signed by Kayla Junke Date: 2022.10.05 11:39:32 -08'00' David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/28/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20220928 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 07A 501332028401 214060 7/12/2022 AK E-Line CIBP GPT BCU 18RD 501332058401 222033 7/13/2022 AK E-Line Perf BCU 18RD 501332058401 222033 7/16/2022 AK E-Line GPT Perf BCU 18RD 501332058401 222033 7/23/2022 AK E-Line GPT CIBP Perf BRU 212-24 502832003700 172015 6/27/2022 AK E-Line CBL BRU 212-24 502832003700 172015 7/5/2022 AK E-Line CIBP CBL TBG END 1-45 500292199100 189124 7/23/2022 AK E-Line Perf END 4-02 500292178900 188022 7/21/2022 AK E-Line Perf HVB B-16 502312004000 212133 6/23/2022 AK E-Line Drift, Plug, Cement IRU 241-01 502832018400 221076 8/5/2022 AK E-Line CBL IRU 241-01 502832018400 221076 8/9/2022 AK E-Line Perf Kalotsa 6 501332068500 219114 7/16/2022 AK E-Line Perf KTU 24-06H 501332049000 199073 7/15/2022 AK E-Line GPT Perf MPU S-34 500292317100 203130 7/5/2022 AK E-Line Drift PBU F-26C 500292198703 213045 8/4/2022 AK E-Line Patch/LDL SRU 213-15 501332065200 215100 8/3/2022 AK E-Line GPT Perf Please include current contact information if different from above. T37068 T37069 T37069 T37069 T37070 T37070 T37071 T37072 T37073 T37081 T37081 T37074 T37075 T37076 T37077 T37078 MPU S-34 500292317100 203130 7/5/2022 AK E-Line Drift Kayla Junke Digitally signed by Kayla Junke Date: 2022.09.30 12:44:16 -08'00' 5HJJ-DPHV%2*& )URP5HJJ-DPHV%2*& 6HQW:HGQHVGD\-XO\30 7R$ODVND16$65:HOO6LWH0DQDJHUV &F%URRNV3KRHEH/2*& 6XEMHFW5(,QLWLDO%23(WHVW6 ŚĂŶŐĞĚŽƵƌĐŽƉǇƚŽƌĞĨůĞĐƚKWDŝƐĐĂƐ&W͕ƋƵĂŶƚŝƚǇϮƚŽŵĂƚĐŚǁŝƚŚƌĞŵĂƌŬƐ :ŝŵZĞŐŐ ^ƵƉĞƌǀŝƐŽƌ͕/ŶƐƉĞĐƚŝŽŶƐ K' ϯϯϯt͘ϳƚŚǀĞ͕^ƵŝƚĞϭϬϬ ŶĐŚŽƌĂŐĞ͕<ϵϵϱϬϭ ϵϬϳͲϳϵϯͲϭϮϯϲ &ƌŽŵ͗ůĂƐŬĂE^Ͳ^ZͲtĞůů^ŝƚĞDĂŶĂŐĞƌƐфůĂƐŬĂE^Ͳ^ZtĞůů^ŝƚĞDĂŶĂŐĞƌƐΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗DŽŶĚĂǇ͕:ƵůǇϰ͕ϮϬϮϮϯ͗ϯϮD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖KK'WƌƵĚŚŽĞĂǇфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂǇΛĂůĂƐŬĂ͘ŐŽǀх͖ ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗/ŶŝƚŝĂůKWƚĞƐƚ^Ͳϯϰ ,ĞůůŽ͕ŚĞƌĞŝƐƚŚĞKWƚĞƐƚĨŽƌŵĨŽƌƚŚĞ^ZϭŽŶ^Ͳϯϰ dŚĂŶŬǇŽƵ Ž͘ŵĞŶ^Zϭ ϵϬϳͲϲϴϱͲϭϮϲϲ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h^Ͳϯϰ WdϮϬϯϭϯϬϬ ŚĂŶŐĞĚŽƵƌĐŽƉǇƚŽƌĞĨůĞĐƚKWDŝƐĐĂƐ&W͕ƋƵĂŶƚŝƚǇϮƚ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:ASR 1 DATE: 7/3/22 Rig Rep.: Rig Phone: 685-1266 Operator: Op. Phone:685-1266 Rep.: E-Mail Well Name: PTD #2203-130 Sundry #322-242 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:953 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1P Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators PP #1 Rams 1 2 7/8" x 5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 2 1/16"P Inside Reel valves 0NA HCR Valves 1 2 1/16"P Kill Line Valves 2 2 1/16"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 2 se remarks FP Time/Pressure Test Result System Pressure (psi)3050 P CHOKE MANIFOLD:Pressure After Closure (psi)1900 P Quantity Test Result 200 psi Attained (sec)14 P No. Valves 16 P Full Pressure Attained (sec)49 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 4x2212 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:2 Test Time:6.0 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 7/1/22 22:00 Waived By Test Start Date/Time:7/3/2022 1:00 (date) (time)Witness Test Finish Date/Time:7/3/2022 7:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Bob Noble Hilcorp Test #1 grease fitting on manual valve on kill leaking. replaced grease fitting. tested good. Test #4 leak on needle valve stem leaking. replaced needle valve. good test. Tested w/ both 3.5" & 4.5" test joints. Annular closing time = 27 sec C. Pace/ C. Greub Hilcorp Alaska S. Hiem/ A. Haberthur MPU S-34 Test Pressure (psi): skaNS-ASR-Well Site Managers@hilcorp.c Form 10-424 (Revised 02/2022) 2022-0703_BOP_Hilcorp_ASR1_MPU S-34 9 9 9 9 9999 9 9 9 9 9 9 -5HJJ 2 se remarks FP 2 Test #1 grease fitting on manual valve on kill leaking. Test #4 leak on needle valve stem leaking. Annular closing time = 27 sec Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 05/17/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU S-34 (PTD 203-130) MFC 05/05/2022 Please include current contact information if different from above. PTD:203-130 T36630 Kayla Junke Digitally signed by Kayla Junke Date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ϬϯϴϬϭϬϵ &HQWHUSRLQW'U6XLWH$QFKRUDJH$. +LOFRUS$ODVND//& D/>EWdhE/d^Ͳϯϰ 0,/1(32,176&+5$'(5%/8))2,/ &2 /HQJWK 6L]H /7&,, 79' %XUVW SVL 0' 1$ SVL SVL SVL 3HUIRUDWLRQ'HSWK0'IW 6HH6FKHPDWLF 6HH6FKHPDWLF [3UHPLHUDQG1$ 0'79'DQG1$ U\ 6WDWX )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Samantha Carlisle at 7:18 am, Apr 28, 2022 'LJLWDOO\VLJQHGE\'DYLG +DDNLQVRQ '1FQ 'DYLG+DDNLQVRQ RX 8VHUV 'DWH 'DYLG+DDNLQVRQ 0*5$35'65'/% ; %23(WHVWWRSVL GWV -/& Jeremy M. Price Digitally signed by Jeremy M. Price Date: 2022.05.02 11:44:50 -08'00' RBDMS SJC 050422 tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗DWh^Ͳϯϰ ĂƚĞ͗ϰͬϮϳͬϮϬϮϮ tĞůůEĂŵĞ͗DWh^Ͳϯϰ W/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϯϭϳϭͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗^/KŝůtĞůů΀:ĞƚWƵŵƉ΁ WĂĚ͗^ͲWĂĚ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗:ƵŶĞϭϰ͕ϮϬϮϮ ZŝŐ͗^Z ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍zĞƐ ĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗dŽŵ&ŽƵƚƐ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϬϯͲϭϯϬ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗dĞĚ<ƌĂŵĞƌ ;ϵϬϳͿϳϳϳͲϴϰϮϬ;KͿ ;ϵϴϱͿϴϲϳͲϬϲϲϱ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗ƌŝĂŶ'ůĂƐŚĞĞŶ ;ϵϬϳͿϱϲϰͲϱϮϳϳ;KͿ ;ϵϬϳͿϱϰϱͲϭϭϰϰ;DͿ &EƵŵďĞƌ͗ &XUUHQW%RWWRP+ROH3UHVVXUHSVL#¶79' /DVW%+3PHDVXUHGSSJ (0: 0D[LPXP([SHFWHG%+3SVL#¶79' 1RQHZSHUIVEHLQJDGGHG 0363SVL %DVHGRQSVLIWJDVJUDGLHQW ƌŝĞĨtĞůů^ƵŵŵĂƌǇ͗ dŚĞDŝůŶĞWŽŝŶƚ^ͲϯϰǁĞůůǁĂƐĚƌŝůůĞĚŝŶϮϬϬϯƵƐŝŶŐŽǇŽŶϭϰĂŶĚĐŽŵƉůĞƚĞĚĂƐĂĚƵĂůůĂƚĞƌĂůŝŶƚŚĞ^ĐŚƌĂĚĞƌ ůƵĨĨEĂŶĚKƐĂŶĚƐǁŝƚŚĂ:ĞƚWƵŵƉ͘ /ŶĞĐĞŵďĞƌϮϬϭϮ͕^>ďĂŝůĞĚΕϮϬŐĂůŽĨƐĂŶĚĨƌŽŵŽŶƚŽƉŽĨƚŚĞũĞƚƉƵŵƉĂŶĚĐŽŶƚŝŶƵĞĚƚŽďĂŝůĂŶŽƚŚĞƌϭϬŐĂů ĂĨƚĞƌƉƵůůŝŶŐƚŚĞũĞƚƉƵŵƉ͘dhĨŝůůĐůĞĂŶŽƵƚŽĨƚŚĞƚƵďŝŶŐ ƚĂŝůĂŶĚŝŶƚŽŽŶĞŽĨƚŚĞůĂƚĞƌĂůƐǁĂƐĐŽŵƉůĞƚĞĚŝŶ &ĞďƌƵĂƌǇϮϬϭϯ͕ĂŶĚĂŶϴũĞƚƉƵŵƉǁĂƐƐĞƚŝŶDĂƌĐŚϮϬϭϯ͘ dŚĞũĞƚƉƵŵƉǁĂƐƉƵůůĞĚŽƵƚŽĨDW^ͲϯϰŽŶDĂƌĐŚϮϮ͕ϮϬϭϯ͘ŶĞǁϴũĞƚƉƵŵƉǁĂƐƐĞƚŽŶϰͬϯϬͬϭϯ͕ďƵƚ ĂƉƉĞĂƌƐƚŽũƵƐƚďĞĐŝƌĐƵůĂƚŝŶŐƉŽǁĞƌĨůƵŝĚ͘ ^ůŝĐŬůŝŶĞĂƚƚĞŵƉƚĞĚƚŽƐĞƚĂϵũĞƚƉƵŵƉŝŶ:ƵůǇϮϬϭϯ͘KƌŝŐŝŶĂůůǇƚĂŐŐŝŶŐĂƚϴ͕ϰϱϬ͛^>D͕^>ďĂŝůĞĚĚŽǁŶƚŽϵ͕ϲϴϳ͛ ^>D͘^>ǁĂƐƵŶĂďůĞƚŽďĂŝůĂŶǇĚĞĞƉĞƌƚŚĂŶϵ͕ϲϴϳ͛^>DĂŶĚŝƚǁĂƐƌĞĐŽŵŵĞŶĚĞĚƚŚĂƚdhďĞƵƐĞĚƚŽƌĞƚƌŝĞǀĞ ƚŚĞ:WĂŶĚ&KƚŚĞǁĞůů͘ ŽŝůdƵďŝŶŐƉƵůůĞĚƚŚĞ:WĂŶĚƉĞƌĨŽƌŵĞĚĂ&KŽŶƚŚĞůĂƚĞƌĂůƚŽ ϭϭ͕ϱϯϬ͛dDŝŶEŽǀĞŵďĞƌϮϬϭϱ͘ ŽŝůdƵďŝŶŐƚŚĞŶĐƵƚƚŚĞƚƵďŝŶŐΛϵ͕ϵϳϱ͛dDŝŶĞĐĞŵďĞƌŽĨϮϬϭϱ͘ dŚĞǁĞůůŚĂƐďĞĞŶƐŚƵƚŝŶƐŝŶĐĞƚŚĂƚƚŝŵĞĂŶĚƌĞŵĂŝŶƐŝŶƚŚŝƐĐ ŽŶĨŝŐƵƌĂƚŝŽŶ͘ EŽƚĞƐZĞŐĂƌĚŝŶŐtĞůůďŽƌĞŽŶĚŝƚŝŽŶ x ĞǀŝĂƚŝŽŶĚŽǁŶƚŽƉƵŵƉƐĞĐƚŝŽŶ;ŵĂǆĂŶŐůĞϳϳ͘ϮΣΛϰ͕ϴϴϲ͛Ϳ͘ĞǀŝĂƚŝŽŶĂƚƉƵŵƉŝƐϳϲΣ͘ x dƵďŝŶŐƵƚĂƚƚĞŵƉƚĞĚϭϮͬϮϯͬϮϬϭϱtͬd͘ KďũĞĐƚŝǀĞ͗ WƵůůĞǆŝƐƚŝŶŐĐŽŵƉůĞƚŝŽŶĂŶĚƌƵŶĂŶĞǁ:ĞƚWƵŵƉĐŽŵƉůĞƚŝŽŶ͘dŚĞŶĞǁĐŽŵƉůĞƚŝŽŶĐŽƵůĚďĞŽŶĞŽĨƚǁŽŽƉƚŝŽŶƐ ĚĞƉĞŶĚŝŶŐŽŶǁŚĂƚŝƐĨŽƵŶĚǁŚĞŶƚŚĞƌŝŐƉŝĐŬƐƵƉŽŶƚŚĞƚƵďŝŶŐ͘/ĨƚŚĞƚƵďŝŶŐǁĂƐƐƵĐĐĞƐƐĨƵůůǇĐƵƚĂŶĚĨƌĞĞŝŶ ĞĐĞŵďĞƌŽĨϮϬϭϱ;KƉƚŝŽŶηϭͿŽƌŝĨƚŚĞƚƵďŝŶŐǁĂƐŶŽƚĨƵůůǇĐƵƚ;KƉƚŝŽŶηϮͿ͘ ƌŝĞĨWƌŽĐĞĚƵƌĞ͗ WƌĞͲƌŝŐƉƌĞƉ͗ '/% tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗DWh^Ͳϯϰ ĂƚĞ͗ϰͬϮϳͬϮϬϮϮ ^ůŝĐŬůŝŶĞ ϭ͘ Zh^>͘ƌŝĨƚƚƵďŝŶŐ͘tŝƚŚϮ͘ϳϴ͟'ZĂƚƚĞŵƉƚƚŽŐĞƚƚŚƌŽƵŐŚĐƵƚĂƚϵ͕ϵϳϱ͛ƚŽyEEŝƉƉůĞΛϭϬ͕Ϭϯϰ͛͘ EŽƚĞ͗,ŽůĞŶŐůĞŝƐϳϱ͘ϱĚĞŐ͘ƚƚƵďŝŶŐĐƵƚ͘/ĨĐƵƚǁĂƐƐƵĐĐĞƐƐĨƵů͕dƵďŝŶŐƐŚŽƵůĚŚĂǀĞĚƌŽƉƉĞĚƚŽ ůŽǁƐŝĚĞŽĨǁĞůů͘ Ϯ͘ WKK,͘WhWƌĞƐƐƵƌĞ'ĂƵŐĞ͕Z/,ƚŽϵ͕ϵϳϬ͛͘^ĞƚƚŚĞƌĞĨŽƌϭϬŵŝŶ͘WKK,͘ ϯ͘ WhĂůŝƉĞƌůŽŐ͕Z/,ƚŽϵ͕ϵϲϬ͕>ŽŐǁĞůůĨƌŽŵϵ͕ϵϲϬ͛ƚŽƐƵƌĨĂĐĞ͘ ϰ͘ ZDK^>͘ tKZŝŐWƌŽĐĞĚƵƌĞ͗ ϭ͘ D/Zh^ZtŽƌŬŽǀĞƌZŝŐ͘ Ϯ͘ ŝƌĐƵůĂƚĞǁĞůůǁŝƚŚϴ͘ϰƉƉŐŬŝůůǁĞŝŐŚƚĨůƵŝĚĂŶĚŝŶƐƵƌĞǁĞůů ŝƐĚĞĂĚ͘ ϯ͘ ^ĞƚWsƉŽƌƚŝŽŶŽĨd^ƉůƵŐ͘EdƌĞĞ͘ ϰ͘ ^ĞƚƚŽƉWŽƌƚŝŽŶŽĨd^ƉůƵŐ͕Ehϭϭ͟KW͘ ϱ͘ dĞƐƚKWƚŽϮϱϬƉƐŝůŽǁͬϮ͕ϱϬϬƉƐŝŚŝŐŚ͕ĂŶŶƵůĂƌƚŽϮϱϬƉƐŝůŽǁͬϮ͕ϱϬϬƉƐŝŚŝŐŚ;ŚŽůĚĞĂĐŚ ƌĂŵͬǀĂůǀĞĂŶĚƚĞƐƚĨŽƌϱͲŵŝŶͿ͘ZĞĐŽƌĚĂĐĐƵŵƵůĂƚŽƌƉƌĞͲĐŚĂƌŐĞƉƌĞƐƐƵƌĞƐĂŶĚĐŚĂƌƚƚĞƐƚƐ͘ Ă͘ WĞƌĨŽƌŵdĞƐƚƉĞƌKWdĞƐƚWƌŽĐĞĚƵƌĞĂŶĚĂŶǇĐŽŶĚŝƚŝŽŶƐŽĨĂƉƉƌŽǀĂůǁƌŝƚƚĞŶŝŶƚŽƉƌŽĐĞĚƵƌĞ͘ ď͘ EŽƚŝĨǇK'ϮϰŚƌƐŝŶĂĚǀĂŶĐĞŽĨKWƚĞƐƚƚŽĂůůŽǁƚŚĞŽƉƉŽƌ ƚƵŶŝƚǇƚŽǁŝƚŶĞƐƐ͘ Đ͘ ^ƵďŵŝƚĐŽŵƉůĞƚĞĚKWƚĞƐƚƌĞƐƵůƚƐǁŝƚŚŝŶϱĚĂǇƐƚŽK'͕ĂŶĚdŽŵ&ŽƵƚƐ;DŝůŶĞWŽŝŶƚZĞŐ dĞĐŚͿ͘ Ě͘ dĞƐƚsZƌĂŵƐĂŶĚĂŶŶƵůĂƌǁŝƚŚϯͲϭͬϮ͟ĂŶĚϰͲϭͬϮ͟ƚĞƐƚũŽŝŶƚƐ͘ ϲ͘ŽŶƚŝŶŐĞŶĐǇ͗;/ĨƚŚĞƚƵďŝŶŐŚĂŶŐĞƌǁŽŶ͛ƚƉƌĞƐƐƵƌĞƚĞƐƚĚƵĞƚŽĞƌŽĚĞĚĂŶĚͬŽƌĐŽƌƌŽĚĞĚWsƉƌŽĨŝůĞ ĂŶĚWsĐĂŶŶŽƚďĞƐĞƚǁŝƚŚƚƌĞĞŽŶ͘Ϳ Ă͘ EŽƚŝĨǇKƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌ;,ŝůĐŽƌƉͿ͕Dƌ͘DĞůZŝǆĞ;K'ͿĂŶĚDƌ͘:ŝŵZĞŐŐ;K'ͿǀŝĂ ĞŵĂŝůĞǆƉůĂŝŶŝŶŐƚŚĞǁĞůůŚĞĂĚƐŝƚƵĂƚŝŽŶƉƌŝŽƌƚŽƉĞƌĨŽƌŵŝŶŐĂƌŽůůŝŶŐKWƚĞƐƚ͘K'ŵĂǇ ĞůĞĐƚƚŽƐĞŶĚĂŶŝŶƐƉĞĐƚŽƌƚŽǁŝƚŶĞƐƐ͘ ď͘ tŝƚŚƐƚĂĐŬŽƵƚŽĨƚŚĞƚĞƐƚƉĂƚŚ͕ƚĞƐƚĐŚŽŬĞŵĂŶŝĨŽůĚƉĞƌƐƚĂŶĚĂƌĚƉƌŽĐĞĚƵƌĞ Đ͘ ŽŶĚƵĐƚĂƌŽůůŝŶŐƚĞƐƚ͗dĞƐƚƚŚĞƌĂŵƐĂŶĚĂŶŶƵůĂƌǁŝƚŚƚŚĞƉ ƵŵƉĐŽŶƚŝŶƵŝŶŐƚŽƉƵŵƉ͕;ŵŽŶŝƚŽƌ ƚŚĞƐƵƌĨĂĐĞĞƋƵŝƉŵĞŶƚĨŽƌůĞĂŬƐƚŽĞŶƐƵƌĞƚŚĂƚƚŚĞĨůƵŝĚŝƐŐŽŝŶŐĚŽǁŶͲŚŽůĞĂŶĚŶŽƚůĞĂŬŝŶŐ ĂŶǇǁŚĞƌĞĂƚƐƵƌĨĂĐĞ͘Ϳ Ě͘ ,ŽůĚĂĐŽŶƐƚĂŶƚƉƌĞƐƐƵƌĞŽŶƚŚĞĞƋƵŝƉŵĞŶƚĂŶĚŵŽŶŝƚŽƌƚŚĞĨůƵŝĚͬƉƵŵƉƌĂƚĞŝŶƚŽƚŚĞ ǁĞůů͘ZĞĐŽƌĚƚŚĞƉƵŵƉŝŶŐƌĂƚĞĂŶĚƉƌĞƐƐƵƌĞ͘ Ğ͘ KŶĐĞƚŚĞKWƌĂŵĂŶĚĂŶŶƵůĂƌƚĞƐƚƐĂƌĞĐŽŵƉůĞƚĞĚ͕ƚĞƐƚƚŚĞƌĞŵĂŝŶĚĞƌŽĨƚŚĞƐǇƐƚĞŵĨŽůůŽǁŝŶŐ ƚŚĞŶŽƌŵĂůƚĞƐƚƉƌŽĐĞĚƵƌĞ;ĨůŽŽƌǀĂůǀĞƐ͕ŐĂƐĚĞƚĞĐƚŝŽŶ͕ĞƚĐ͘Ϳ Ĩ͘ ZĞĐŽƌĚĂŶĚƌĞƉŽƌƚƚŚŝƐƚĞƐƚǁŝƚŚŶŽƚĞƐŝŶƚŚĞƌĞŵĂƌŬƐĐŽůƵŵŶƚŚĂƚƚŚĞƚƵďŝŶŐŚĂŶŐĞƌͬWs ƉƌŽĨŝůĞͬƉĞŶĞƚƌĂƚŽƌǁŽƵůĚŶ͛ƚŚŽůĚƉƌĞƐƐƵƌĞĂŶĚƌŽůůŝŶŐƚĞƐƚǁĂƐƉĞƌĨŽƌŵĞĚŽŶKWƋƵŝƉŵĞŶƚ ĂŶĚůŝƐƚŝƚĞŵƐ͕ƉƌĞƐƐƵƌĞƐĂŶĚƌĂƚĞƐ͘ ϳ͘ WƵůůd^ƉůƵŐ͘ůĞĞĚĂŶǇƉƌĞƐƐƵƌĞŽĨĨƚƵďŝŶŐĂŶĚĐĂƐŝŶŐƚŽϱϬ ϬďďůƌĞƚƵƌŶƐƚĂŶŬ͘<ŝůůǁĞůůǁͬϴ͘ϰƉƉŐ ŬŝůůǁĞŝŐŚƚĨůƵŝĚĂƐŶĞĞĚĞĚ͘ ϴ͘ DhůĂŶĚŝŶŐũŽŝŶƚŽƌƐƉĞĂƌĂŶĚƌĞĐŽǀĞƌƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͘ ϵ͘ŽŶƚŝŶŐĞŶĐǇ;/ĨĂƌŽůůŝŶŐƚĞƐƚǁĂƐĐŽŶĚƵĐƚĞĚͿ͗DhŶĞǁŚĂŶŐĞƌŽƌƚĞƐƚƉůƵŐƚŽƚŚĞĐŽŵƉůĞƚŝŽŶ ƚƵďŝŶŐ͘ZĞͲůĂŶĚŚĂŶŐĞƌ;ŽƌƚĞƐƚƉůƵŐͿŝŶƚƵďŝŶŐŚĞĂĚ͘dĞƐƚKWƉĞƌƐƚĂŶĚĂƌĚƉƌŽĐĞĚƵƌĞ͘ 5LVNDVVHVVSRVVLELOLW\RISUHVVXUHXQGHU&76SOXJIRUSRVVLELOLW\RIQHHGWROXEULFDWHRXW tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗DWh^Ͳϯϰ ĂƚĞ͗ϰͬϮϳͬϮϬϮϮ EŽƚĞ͗ŽŶƚŝŶŐĞŶĐǇ Ͳ ,ĂǀĞͲůŝŶĞ͕dƌĂĐƚŽƌ͕ĂŶĚƉŝƉĞĐƵƚƚŝŶŐƚŽŽůƐŽŶ^ƚĂŶĚďǇŝŶĐĂƐĞƚƵďŝŶŐŝƐŶŽƚĨƵůůǇĐƵƚ͘/Ĩ ƚƵďŝŶŐŝƐĨƵůůǇĐƵƚ͕ŐŽƚŽKƉƚŝŽŶηϭ;^ƚĞƉηϵͿ͘/ĨdƵďŝŶŐŝƐŶ ŽƚĨƵůůǇĐƵƚ͕'ŽƚŽKƉƚŝŽŶηϮ;^ƚĞƉϭϴͿ͘ KƉƚŝŽŶηϭʹdƵďŝŶŐŝƐ&ƵůůǇƵƚ ϭϬ͘ WhŽŶdƵďŝŶŐĂŶĚĐŽŶĨŝƌŵƚƵďŝŶŐŝƐĨƌĞĞ͘ ϭϭ͘ WKK,tͬϰͲϭͬϮ͟dƵďŝŶŐĂŶĚ/ǁŝƌĞƚŽϯͲϭͬϮ͟ĐƌŽƐƐŽǀĞƌ͘ ϭϮ͘ ŚĂŶŐĞƚŽŶŐƐƚŽϯͲϭͬϮ͟WŝƉĞ͘>ĂǇĚŽǁŶĐŽŵƉůĞƚŝŽŶƚŽƚƵďŝŶŐĐƵƚ͘ ϭϯ͘ WhϳͲϱͬϴ͟ĐĂƐŝŶŐƐĐƌĂƉĞƌǁŝƚŚĂϲ͟ƐŽůŝĚďŽƚƚŽŵĐŽŶĐĂǀĞŵŝůůŽŶďŽƚƚŽŵ͘ ϭϰ͘ Z/,tͬĂƐŝŶŐ^ĐƌĂƉĞƌƐƚŽƉƉŝŶŐĞǀĞƌǇϱ͕ϬϬϬ͛ĂŶĚh;ůŽŶŐǁĂǇͿƚŽĐůĞĂŶƐŽůŝĚƐŽĨĨƚŚĞƚŽƉŽĨƚŚĞ ŵŝůů͘ ϭϱ͘ dĂŐƵƉŽŶƚƵďŝŶŐƐƚƵď͘^ĞƚƉĂƌĂŵĞƚĞƌƐĂŶĚĚƌĞƐƐŽĨĨƚŽƉŽĨƚƵďŝŶŐ͘WKK,tͬĂƐŝŶŐ^ĐƌĂƉĞƌĂŶĚ Dŝůů͘ ϭϲ͘ WhŽŵƉůĞƚŝŽŶĐŽŶƐŝƐƚŝŶŐŽĨ͗ Ă͘ ϯͲϭͬϮ͟ŶŽŶƐĞĂůŝŶŐŽǀĞƌƐŚŽƚ ď͘ ϯͲϭͬϮ͟yϰͲϭͬϮ͟ĐƌŽƐƐŽǀĞƌ Đ͘ ϰͲϭͬϮ͟yEEŝƉƉůĞůŽĂĚĞĚǁŝƚŚZ,ƉůƵŐ Ě͘ ϰͲϭͬϮ͟yϳͲϱͬϴ͟,ǇĚƌĂƵůŝĐ^ĞƚWĂĐŬĞƌ Ğ͘ /ŶƚĂŬĞWƌĞƐƐƵƌĞ'ĂƵŐĞĂŶĚ/ͲǁŝƌĞ Ĩ͘ ϰͲϭͬϮ͟,^^ůŝĚŝŶŐ^ůĞĞǀĞ Ő͘ ϰͲϭͬϮ͟ƚƵďŝŶŐ ϭϳ͘ Z/,ĂŶĚĞŶŐĂŐĞƚƵďŝŶŐƐƚƵďǁŝƚŚƚŚĞŽǀĞƌƐŚŽƚ͘ ϭϴ͘ 'ŽƚŽƐƚĞƉϮϵ͘ KƉƚŝŽŶηϮʹdƵďŝŶŐŝƐŶŽƚĐƵƚ ϭϵ͘ WhŽŶƚƵďŝŶŐƚŽϭϰϲ͕ϬϬϬůďƐ;^ƚƌŝŶŐǁĞŝŐŚƚŝƐϭϮϱ͕ϲϯϭůďƐ͘ŝŶĂŝƌͿ͘/ĨƚƵďŝŶŐǁŝůůŶŽƚŵŽǀĞ͕ĂƐƐƵŵĞ ĐƵƚŝƐŶŽƚĐŽŵƉůĞƚĞ͘ ϮϬ͘ ZhͲůŝŶĞtͬƚƌĂĐƚŽƌĂŶĚZ/,tͬŐĂŵŵĂƌĂǇ͕>͕ĂŶĚϮ͘ϳϴ͟'ĂƵŐĞZŝŶŐ͘ Ϯϭ͘ Z/,ĂŶĚĂƚƚĞŵƉƚƚŽŐĞƚƚŚƌŽƵŐŚƚŚĞĐƵƚĂƚϵ͕ϵϳϱ͛ĚŽǁŶƚŽyEEŝƉƉůĞΛϭϬ͕Ϭϯϰ͛͘ ϮϮ͘ dƵƌŶƵƉŐĂŝŶŽŶ'ĂŵŵĂZĂǇͬ>ĂŶĚůŽŐƵƉƚŚƌŽƵŐŚWĂĐŬĞƌŶŽƚŝŶŐůŽĐĂƚŝŽŶͬĚĞƉƚŚŽĨƵƚ^ůĞĞǀĞ͘ Ϯϯ͘ ŽŶƚŝŶƵĞůŽŐŐŝŶŐƵƉƚŽϵ͕ϵϮϬ͛ŶŽƚŝŶŐĚĞƉƚŚŽĨĐƵƚĂƚƚĞŵƉƚ͘WKK,͘ Ϯϰ͘ Wh:ĞƚĐƵƚƚĞƌĂŶĚZ/,ŽŶdƌĂĐƚŽƌĂŶĚͲůŝŶĞƚŽĚĞƉƚŚĐŽƌƌĞƐƉŽŶĚŝŶŐǁŝƚŚĐƵƚƐůĞĞǀĞ͘>ŽŐŽŶĚĞƉƚŚ ĐĞŶƚĞƌĐƵƚƚĞƌŝŶĐƵƚƐůĞĞǀĞ͘ Ϯϱ͘ WhŽŶdƵďŝŶŐƚŽƉůĂĐĞŝŶƚĞŶƐŝŽŶ͕ĂŶĚĨŝƌĞĐƵƚƚĞƌ͘EŽƚĞǁĞŝŐŚƚĚĞĐƌĞĂƐĞ͘WKK,tŝƚŚƚƌĂĐƚŽƌ͘ EŽƚĞ͗/ĨĐƵƚƐůĞĞǀĞĐĂŶŶŽƚďĞůŽĐĂƚĞĚ͕WhƚŽũƵƐƚďĞůŽǁĐŽŝůĐƵƚĂƚƚĞŵƉƚ;Εϵ͕ϵϳϴ͛Ϳ͘WhŽŶƚƵďŝŶŐ͕ƵƚƚƵďŝŶŐ͘/Ĩ ƚƵďŝŶŐǁĂƐĐƵƚ͕ŐŽƚŽƐƚĞƉϭϬ͘KƚŚĞƌǁŝƐĞŐŽƚŽƐƚĞƉϮϱ͘ Ϯϲ͘ WhŽŶdƵďŝŶŐĂŶĚĐŽŶĨŝƌŵĨƌĞĞ͘WKK,ǁŝƚŚdƵďŝŶŐĂŶĚƉĂĐŬĞƌůĂǇŝŶŐĚŽǁŶƚŚĞĐŽŵƉůĞƚŝŽŶ͘ Ϯϳ͘ WhϳͲϱͬϴ͟ĂƐŝŶŐƐĐƌĂƉĞƌ͘Z/,tͬƐĂŵĞƚŽϵ͕ϵϵϱ͛͘WKK,tͬĐĂƐŝŶŐƐĐƌĂƉĞƌ͘ Ϯϴ͘ WhŶĞǁĐŽŵƉůĞƚŝŽŶĐŽŶƐŝƐƚŝŶŐŽĨ͗ Ă͘ ϰͲϭͬϮ͟t>' ď͘ ϰͲϭͬϮ͟yEEŝƉƉůĞůŽĂĚĞĚǁŝƚŚZ,ƉůƵŐ Đ͘ ϰͲϭͬϮ͟yϳͲϱͬϴ͟,ǇĚƌĂƵůŝĐ^ĞƚWĂĐŬĞƌ Ě͘ /ŶƚĂŬĞWƌĞƐƐƵƌĞ'ĂƵŐĞĂŶĚ/ͲǁŝƌĞ Ğ͘ ϰͲϭͬϮ͟,^^ůŝĚŝŶŐ^ůĞĞǀĞ Ĩ͘ ϰͲϭͬϮ͟ƚƵďŝŶŐ Ϯϵ͘ Z/,ĂŶĚƐƉĂĐĞƉĂĐŬĞƌĞůĞŵĞŶƚƐΛϵ͕ϵϳϬ͛;нͬͲͿ tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗DWh^Ͳϯϰ ĂƚĞ͗ϰͬϮϳͬϮϬϮϮ ϯϬ͘ ƌŽƉďĂůůĂŶĚZŽĚ͕WƵŵƉŝŶƚŽyEŶŝƉƉůĞ͕ĂŶĚƉƌĞƐƐƵƌĞƵƉĂƐƉĞƌWĂĐŬĞƌŵĂŶƵĨĂĐƚƵƌĞ͛ƐƐĞƚƚŝŶŐ ƉƌŽĐĞĚƵƌĞ͘ ϯϭ͘ ZĞůĞĂƐĞƉƌĞƐƐƵƌĞ͘WĞƌĨŽƌŵD/d/ƚŚĞƚŽϯ͕ϲϱϬƉƐŝ͘ŽŶĐŚĂƌƚĨŽƌϯϬŵŝŶƵƚĞƐ͘ ϯϮ͘ ,ĂŶŐŽĨĨƚƵďŝŶŐŝŶŚĂŶŐĞƌ͘ ϯϯ͘ /ŶƐƚĂůůd^ƉůƵŐ͘ ϯϰ͘ ZKWƐ͕EhtĞůůŚĞĂĚĂŶĚƚƌĞĞ͘WƌĞƐƐƵƌĞƚĞƐƚƐĂŵĞƚŽϱ͕ϬϬϬƉƐŝ͘ ϯϱ͘ ZDK^Z͘ ϯϲ͘ dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ͘ WŽƐƚZŝŐtŽƌŬ ϯϳ͘ Zh^>ĂŶĚƚĞƐƚWƚŽϭ͕ϱϬϬƉƐŝ͘ ϯϴ͘ Z/,ĂŶĚZĞƚƌŝĞǀĞĂůůĂŶĚZŽĚĂŶĚZ,WůƵŐ͘ ϯϵ͘ Z/,tͬ:ĞƚWƵŵƉĂŶĚƐĞƚ͘ ϰϬ͘ Z^>hŶŝƚ͘ EŽƚĞ͗ŽŝůŵĂǇďĞƌĞƋƵŝƌĞĚĚƵĞƚŽŚŽůĞĂŶŐůĞ͘ ϰϭ͘ dƵƌŶtĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐƐ;KƉƚŝŽŶƐϭΘϮͿ ϯ͘ KW^ĐŚĞŵĂƚŝĐ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϭͬϮϬͬϮϬϭϲ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh^Ͳϯϰ >ĂƐƚŽŵƉůĞƚĞĚ͗ϵͬϮͬϮϬϬϯ Wd͗ϮϬϯͲϭϯϬ ϲϵũƚƐͲϰͲϭͬϮ͟^ůŽƚƚĞĚ>ŝŶĞƌ ϭϬ͕ϮϮϰ͛ƚŽϭϯ͕Ϭϰϳ͛ ϲϭũƚƐͲϰͲϭͬϮ͟^ůŽƚƚĞĚ>ŝŶĞƌ ϭϬ͕ϱϬϰ͛ƚŽϭϯ͕ϭϰϳ͛ ϯϲϯ͛ZĂƚ,ŽůĞ Ϭ͛ZĂƚ,ŽůĞ dсϭϭ͕ϭϱϵ͛;DͿͬdсϰ͕ϯϮϯ͛;dsͿ ϮϬ´ KƌŝŐ͘&ůĞǀсϳϮ͛ͬKƌŝŐdďŐ͘,ŐƌůĞǀ͘сϮϵ͘ϳ͛ŽǇŽŶϭϰ ϳͲϱͬϴ͟ ϭϬͲϯͬϰ͟ EKd͗DŝŶ/Λ ϭϬ͕Ϭϯϰ͛ʹϮ͘ϳϱϬ͟ dƵďŝŶŐƵƚΛϵ͕ϵϳϱ͛ ³1(´/DWHUDO ³2$´/DWHUDO ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ W& ϮϬΗ ŽŶĚƵĐƚŽƌ ϮϭϱͬͲϱϯͬtĞůĚĞĚ ϭϳ͘ϵϯϴ ^ƵƌĨ ϭϭϮΖ Eͬ ϭϬͲϯͬϰ͟ ^ƵƌĨĂĐĞ ϰϱ͘ϱͬ>ͲϴϬͬƚƌĐ͘ ϵ͘ϵϱϬ ^ƵƌĨ ϱ͕ϱϭϴ͛ Ϭ͘ϬϵϲϮ ϳͲϱͬϴΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϵ͘ϳͬ>ͲϴϬͬ/dͲD ϲ͘ϴϳϱ ^ƵƌĨĂĐĞ ϭϭ͕ϭϱϵΖ Ϭ͘Ϭϰϱϵ >/EZd/> ϰͲϭͬϮ͟ E^ŽůŝĚ>ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϭϬ͕ϭϮϳ͛ϭϯ͕Ϭϵϭ͛ EͬϰͲϭͬϮ͟ E^ůŽƚƚĞĚ>Ŷƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϭϬ͕ϮϮϰ͛ ϰͲϭͬϮ͟ K^ŽůŝĚ>ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϭϬ͕Ϯϳϯ͛ϭϯ͕ϮϯϮ͛ EͬϰͲϭͬϮ͟ K^ůŽƚƚĞĚ>Ŷƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϭϬ͕ϱϬϰ͛ dh/E'd/> ϰͲϭͬϮ͟ dƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ^ƵƌĨ ϭϬ͕ϬϰϬ͛Ϭ͘ϬϭϱϮ ϯͲϭͬϮΗ dƵďŝŶŐ ϵ͘Ϯͬ>ͲϴϬͬdͲ// Ϯ͘ϵϵϮ ^ƵƌĨ Ϭ͘ϬϬϴϳ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ Ϯ͕ϭϬϭ͛ DKϰ͘ϱ͟ǆϭ͟ǁͬ<>ĂƚĐŚ^ŝĚĞͲƉŽĐŬĞƚ<'ͲϮ'>D Ϯ ϵ͕ϵϮϯ͛ WŚŽĞŶŝǆŝƐĐŚĂƌŐĞ'ĂƵŐĞ͗/сϯ͘ϴϱϬ͟ ϯ ϵ͕ϵϯϰ͛ ϰ͘ϱ͟,^͞y͟ƵƌĂ^ůŝĚŝŶŐ^ůĞĞǀĞ͗/сϯ͘ϴϭϯ͟;ŽƉĞŶƐŽǁŶͿ :ĞƚWƵŵƉZĞŵŽǀĞĚϭϭͬϮϭͬϮϬϭϱ ϰ ϵ͕ϵϱϳ͛ WŚŽĞŶŝǆ:ĞƚWƵŵƉ'ĂƵŐĞ^ĞŶƐŽƌ͗/сϮ͘ϴϰϬ͟;ϰ͕Ϭϲϴ͟dsͿ ϱ ϵ͕ϵϲϮ͛ ϰ͘ϱ͟ǆϯ͘ϱ͟yͲKǀĞƌ ϲ ϵ͕ϵϳϯ͛ ϯ͘ϱ͟,^yͲEŝƉƉůĞ͗/сϮ͘ϴϭϯ͟ ϳ ϵ͕ϵϴϯ͛ ϯ͘ϱ͟ǆϰ͘ϱ͟yͲKǀĞƌ ϴ ϵ͕ϵϴϰ͛ ϳͲϱͬϴ͟ǆϰ͘ϱ͟ĂŬĞƌWƌĞŵŝĞƌWĂĐŬĞƌ͗/сϯ͘ϴϳϱ͟ ϵ ϵ͕ϵϵϭ͛ ϰ͘ϱ͟ǆϯ͘ϱ͟yͲKǀĞƌ ϭϬ ϭϬ͕Ϭϯϰ͛ ϯ͘ϱ͟,^yEͲEŝƉƉůĞ͗/сϮ͘ϳϱϬ͟EŽ'Ž ϭϭ ϭϬ͕Ϭϯϵ͛ t>'ʹ ŽƚƚŽŵΛϭϬ͕ϬϰϬ͛ ϭϮ ϭϬ͕ϭϯϳ͛ ĂŬĞƌϲ͛dŝĞͲďĂĐŬ^ůĞĞǀĞ ϭϯ ϭϬ͕ϭϰϲ͛ ,ŽŽŬtĂůů,ĂŶŐĞƌ/ŶƐŝĚĞϳͲϱͬϴ͟ĂƐŝŶŐ ϭϰ ϭϬ͕ϭϳϭ͛ ,ŽŽŬtĂůů,ĂŶŐĞƌKƵƚƐŝĚĞ;,ŽŽŬWŽŝŶƚͿ ϭϱ ϭϬ͕Ϯϳϯ͛ ĂŬĞƌϳ͛dŝĞͲďĂĐŬ^ůĞĞǀĞ ϭϲ ϭϬ͕ϮϴϬ͛ ĂŬĞƌyW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϭϳ ϭϬ͕Ϯϴϲ͛ ĂŬĞƌϳͲϱͬϴ͟ǆϱͲϭͬϮ͟,D>ŝŶĞƌ,ĂŶŐĞƌ KWE,K>ͬDEdd/> ϮϬΗ ϮϲϬƐǆŽĨƌĐƚŝĐƐĞƚŝŶϰϮ͟,ŽůĞ ϭϬͲϰͬϰΗ ϵϯϱƐǆW&͛>͕͛ϯϳϭƐǆůĂƐƐ͞'͕͟dŽƉ:ŽďϱϰƐǆW&͚>͛ŝŶϭϯͲϭͬϮ͟,ŽůĞ ϳ͟ ϳϮϱƐǆůĂƐƐ͞'͟ŝŶϵͲϳͬϴ͟,ŽůĞ t>>/E>/Ed/KEd/> <KWΛϮϴϬ͛D ,ŽůĞŶŐůĞWĂƐƐĞƐϱϬĞŐ͘ΛϮ͕ϭϱϬ͛ DĂǆŶŐůĞŝŶdƵďŝŶŐсϳϴĞŐ͘ ϳϱĞŐ͘ĂƚƐůŝĚŝŶŐƐůĞĞǀĞ dZͬt>>, dƌĞĞ ϰͲϭͬϲ͟ϱD&D tĞůůŚĞĂĚ ϭϭ͟ǆϰͲϭͬϮ͟ϱD'ĞŶϲǁϰ͘ϱ͟dͲ//dΘdƵďŝŶŐ ,ĂŶŐĞƌ/t͞,͟WsƉƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϯϭϳϭͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇŽǇŽŶϭϰͲϵͬϮͬϮϬϬϯ ŽŝůůĞĂŶͲŽƵƚĂŶĚ:ĞƚWƵŵƉZĞŵŽǀĂůϭϭͬϮϭͬϮϬϭϱ E>dZ>t/EKtd/> tŝŶĚŽǁŝŶϳͲϱͬϴ͟ĂƐŝŶŐΛϭϬ͕ϭϱϵ͛ƚŽϭϬ͕ϭϳϭ͛;DͿͬϰ͕ϭϭϱ͛ƚŽϰ͕ϭϭϳ͛;dsͿ tĞůůŶŐůĞΛǁŝŶĚŽǁсϳϴĞŐ͘ K>dZ>t/EKtd/> tŝŶĚŽǁŝŶϳͲϱͬϴ͟ĂƐŝŶŐΛϭϬ͕ϱϭϲ͛ƚŽϭϬ͕ϱϮϴ͛;DͿͬϰ͕ϭϵϵ͛ƚŽϰ͕ϮϬϭ͛;dsͿ tĞůůŶŐůĞΛǁŝŶĚŽǁсϳϳĞŐ͘ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϰͬϮϲͬϮϬϮϮ WZKWK^ KƉƚŝŽŶ ηϭ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh^Ͳϯϰ >ĂƐƚŽŵƉůĞƚĞĚ͗ϵͬϮͬϮϬϬϯ Wd͗ϮϬϯͲϭϯϬ ϲϵũƚƐͲϰͲϭͬϮ͟^ůŽƚƚĞĚ>ŝŶĞƌ ϭϬ͕ϮϮϰ͛ƚŽϭϯ͕Ϭϰϳ͛ ϲϭũƚƐͲϰͲϭͬϮ͟^ůŽƚƚĞĚ>ŝŶĞƌ ϭϬ͕ϱϬϰ͛ƚŽϭϯ͕ϭϰϳ͛ ϯϲϯ͛ZĂƚ,ŽůĞ Ϭ͛ZĂƚ,ŽůĞ dсϭϭ͕ϭϱϵ͛;DͿͬdсϰ͕ϯϮϯ͛;dsͿ ϮϬ´ KƌŝŐ͘&ůĞǀсϳϮ͛ͬKƌŝŐdďŐ͘,ŐƌůĞǀ͘сϮϵ͘ϳ͛ŽǇŽŶϭϰ ϳͲϱͬϴ͟ ϭϬͲϯͬϰ͟ EKd͗DŝŶ/Λ ϭϬ͕Ϭϯϰ͛ʹϮ͘ϳϱϬ͟ dƵďŝŶŐƵƚΛϵ͕ϵϳϱ͛ ³1(´/DWHUDO ³2$´/DWHUDO ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ W& ϮϬΗ ŽŶĚƵĐƚŽƌ ϮϭϱͬͲϱϯͬtĞůĚĞĚ ϭϳ͘ϵϯϴ ^ƵƌĨ ϭϭϮΖ Eͬ ϭϬͲϯͬϰ͟ ^ƵƌĨĂĐĞ ϰϱ͘ϱͬ>ͲϴϬͬƚƌĐ͘ ϵ͘ϵϱϬ ^ƵƌĨ ϱ͕ϱϭϴ͛ Ϭ͘ϬϵϲϮ ϳͲϱͬϴΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϵ͘ϳͬ>ͲϴϬͬ/dͲD ϲ͘ϴϳϱ ^ƵƌĨĂĐĞ ϭϭ͕ϭϱϵΖ Ϭ͘Ϭϰϱϵ >/EZd/> ϰͲϭͬϮ͟ E^ŽůŝĚ>ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϭϬ͕ϭϮϳ͛ϭϯ͕Ϭϵϭ͛ EͬϰͲϭͬϮ͟ E^ůŽƚƚĞĚ>Ŷƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϭϬ͕ϮϮϰ͛ ϰͲϭͬϮ͟ K^ŽůŝĚ>ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϭϬ͕Ϯϳϯ͛ϭϯ͕ϮϯϮ͛ EͬϰͲϭͬϮ͟ K^ůŽƚƚĞĚ>Ŷƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϭϬ͕ϱϬϰ͛ dh/E'd/> ϰͲϭͬϮ͟ dƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ^ƵƌĨ ϭϬ͕ϬϰϬ͛Ϭ͘ϬϭϱϮ ϯͲϭͬϮΗ dƵďŝŶŐ ϵ͘Ϯͬ>ͲϴϬͬdͲ// Ϯ͘ϵϵϮ ^ƵƌĨ Ϭ͘ϬϬϴϳ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ цϵ͕ϵϰϬ͛ ϰ͘ϱ͟,^͞y͟ƵƌĂ^ůŝĚŝŶŐ^ůĞĞǀĞ͗/сϯ͘ϴϭϯ͟;ŽƉĞŶƐŽǁŶͿ Ϯ цϵ͕ϵϱϬ͛ WŚŽĞŶŝǆ:ĞƚWƵŵƉ'ĂƵŐĞ^ĞŶƐŽƌ͗/сϮ͘ϴϰϬ͟ ϯ цϵ͕ϵϲϬ͛ ϳͲϱͬϴ͟ǆϰ͘ϱ͟ĂŬĞƌWƌĞŵŝĞƌWĂĐŬĞƌ͗/сϯ͘ϴϳϱ͟ ϰ цϵ͕ϵϲϳ͛ ϰ͘ϱ͟,^yEͲEŝƉƉůĞ͗/сϯ͘ϳϮϱ͟EŽͲ'Ž/ ϱ цϵ͕ϵϳϬ͛ ϰ͘ϱ͟ǆϯ͘ϱ͟yͲKǀĞƌ ϲ цϵ͕ϵϳϯ͛ ϯ͘ϱ͟KǀĞƌƐŚŽƚ ϳ ϵ͕ϵϴϯ͛ ϯ͘ϱ͟ǆϰ͘ϱ͟yͲKǀĞƌ ϴ ϵ͕ϵϴϰ͛ ϳͲϱͬϴ͟ǆϰ͘ϱ͟ĂŬĞƌWƌĞŵŝĞƌWĂĐŬĞƌ͗/сϯ͘ϴϳϱ͟ ϵ ϵ͕ϵϵϭ͛ ϰ͘ϱ͟ǆϯ͘ϱ͟yͲKǀĞƌ ϭϬ ϭϬ͕Ϭϯϰ͛ ϯ͘ϱ͟,^yEͲEŝƉƉůĞ͗/сϮ͘ϳϱϬ͟EŽ'Ž ϭϭ ϭϬ͕Ϭϯϵ͛ t>'ʹ ŽƚƚŽŵΛϭϬ͕ϬϰϬ͛ ϭϮ ϭϬ͕ϭϯϳ͛ ĂŬĞƌϲ͛dŝĞͲďĂĐŬ^ůĞĞǀĞ ϭϯ ϭϬ͕ϭϰϲ͛ ,ŽŽŬtĂůů,ĂŶŐĞƌ/ŶƐŝĚĞϳͲϱͬϴ͟ĂƐŝŶŐ ϭϰ ϭϬ͕ϭϳϭ͛ ,ŽŽŬtĂůů,ĂŶŐĞƌKƵƚƐŝĚĞ;,ŽŽŬWŽŝŶƚͿ ϭϱ ϭϬ͕Ϯϳϯ͛ ĂŬĞƌϳ͛dŝĞͲďĂĐŬ^ůĞĞǀĞ ϭϲ ϭϬ͕ϮϴϬ͛ ĂŬĞƌyW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϭϳ ϭϬ͕Ϯϴϲ͛ ĂŬĞƌϳͲϱͬϴ͟ǆϱͲϭͬϮ͟,D>ŝŶĞƌ,ĂŶŐĞƌ KWE,K>ͬDEdd/> ϮϬΗ ϮϲϬƐǆŽĨƌĐƚŝĐƐĞƚŝŶϰϮ͟,ŽůĞ ϭϬͲϰͬϰΗ ϵϯϱƐǆW&͛>͕͛ϯϳϭƐǆůĂƐƐ͞'͕͟dŽƉ:ŽďϱϰƐǆW&͚>͛ŝŶϭϯͲϭͬϮ͟,ŽůĞ ϳ͟ ϳϮϱƐǆůĂƐƐ͞'͟ŝŶϵͲϳͬϴ͟,ŽůĞ t>>/E>/Ed/KEd/> <KWΛϮϴϬ͛D ,ŽůĞŶŐůĞWĂƐƐĞƐϱϬĞŐ͘ΛϮ͕ϭϱϬ͛ DĂǆŶŐůĞŝŶdƵďŝŶŐсϳϴĞŐ͘ ϳϱĞŐ͘ĂƚƐůŝĚŝŶŐƐůĞĞǀĞ dZͬt>>, dƌĞĞ ϰͲϭͬϲ͟ϱD&D tĞůůŚĞĂĚ ϭϭ͟ǆϰͲϭͬϮ͟ϱD'ĞŶϲǁϰ͘ϱ͟dͲ//dΘdƵďŝŶŐ ,ĂŶŐĞƌ/t͞,͟WsƉƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϯϭϳϭͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇŽǇŽŶϭϰͲϵͬϮͬϮϬϬϯ ŽŝůůĞĂŶͲŽƵƚĂŶĚ:ĞƚWƵŵƉZĞŵŽǀĂůϭϭͬϮϭͬϮϬϭϱ E>dZ>t/EKtd/> tŝŶĚŽǁŝŶϳͲϱͬϴ͟ĂƐŝŶŐΛϭϬ͕ϭϱϵ͛ƚŽϭϬ͕ϭϳϭ͛;DͿͬϰ͕ϭϭϱ͛ƚŽϰ͕ϭϭϳ͛;dsͿ tĞůůŶŐůĞΛǁŝŶĚŽǁсϳϴĞŐ͘ K>dZ>t/EKtd/> tŝŶĚŽǁŝŶϳͲϱͬϴ͟ĂƐŝŶŐΛϭϬ͕ϱϭϲ͛ƚŽϭϬ͕ϱϮϴ͛;DͿͬϰ͕ϭϵϵ͛ƚŽϰ͕ϮϬϭ͛;dsͿ tĞůůŶŐůĞΛǁŝŶĚŽǁсϳϳĞŐ͘ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϰͬϮϲͬϮϬϮϮ WZKWK^ KƉƚŝŽŶ ηϮ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh^Ͳϯϰ >ĂƐƚŽŵƉůĞƚĞĚ͗ϵͬϮͬϮϬϬϯ Wd͗ϮϬϯͲϭϯϬ ϲϵũƚƐͲϰͲϭͬϮ͟^ůŽƚƚĞĚ>ŝŶĞƌ ϭϬ͕ϮϮϰ͛ƚŽϭϯ͕Ϭϰϳ͛ ϲϭũƚƐͲϰͲϭͬϮ͟^ůŽƚƚĞĚ>ŝŶĞƌ ϭϬ͕ϱϬϰ͛ƚŽϭϯ͕ϭϰϳ͛ ϯϲϯ͛ZĂƚ,ŽůĞ Ϭ͛ZĂƚ,ŽůĞ dсϭϭ͕ϭϱϵ͛;DͿ ͬ dсϰ͕ϯϮϯ͛;dsͿ ϮϬ´ KƌŝŐ͘&ůĞǀсϳϮ͛ͬKƌŝŐdďŐ͘,ŐƌůĞǀ͘сϮϵ͘ϳ͛ŽǇŽŶϭϰ ϳͲϱͬϴ͟ ϭϬͲϯͬϰ͟ EKd͗DŝŶ/Λ ϭϬ͕Ϭϯϰ͛ʹϮ͘ϳϱϬ͟ dƵďŝŶŐƵƚΛϵ͕ϵϳϱ͛ ³1(´/DWHUDO ³2$´/DWHUDO ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ W& ϮϬΗ ŽŶĚƵĐƚŽƌ ϮϭϱͬͲϱϯͬtĞůĚĞĚ ϭϳ͘ϵϯϴ ^ƵƌĨ ϭϭϮΖ Eͬ ϭϬͲϯͬϰ͟ ^ƵƌĨĂĐĞ ϰϱ͘ϱͬ>ͲϴϬͬƚƌĐ͘ ϵ͘ϵϱϬ ^ƵƌĨ ϱ͕ϱϭϴ͛ Ϭ͘ϬϵϲϮ ϳͲϱͬϴΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϵ͘ϳͬ>ͲϴϬͬ/dͲD ϲ͘ϴϳϱ ^ƵƌĨĂĐĞ ϭϭ͕ϭϱϵΖ Ϭ͘Ϭϰϱϵ >/EZd/> ϰͲϭͬϮ͟ E^ŽůŝĚ>ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϭϬ͕ϭϮϳ͛ϭϯ͕Ϭϵϭ͛ EͬϰͲϭͬϮ͟ E^ůŽƚƚĞĚ>Ŷƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϭϬ͕ϮϮϰ͛ ϰͲϭͬϮ͟ K^ŽůŝĚ>ŝŶĞƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϭϬ͕Ϯϳϯ͛ϭϯ͕ϮϯϮ͛ EͬϰͲϭͬϮ͟ K^ůŽƚƚĞĚ>Ŷƌ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϭϬ͕ϱϬϰ͛ dh/E'd/> ϰͲϭͬϮ͟ dƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ^ƵƌĨ ϭϬ͕ϬϰϬ͛Ϭ͘ϬϭϱϮ ϯͲϭͬϮΗ dƵďŝŶŐ ϵ͘Ϯͬ>ͲϴϬͬdͲ// Ϯ͘ϵϵϮ ^ƵƌĨ Ϭ͘ϬϬϴϳ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ цϵ͕ϵϯϰ͛ ϰ͘ϱ͟,^͞y͟ƵƌĂ^ůŝĚŝŶŐ^ůĞĞǀĞ͗/сϯ͘ϴϭϯ͟;ŽƉĞŶƐŽǁŶͿ Ϯ цϵ͕ϵϱϳ͛ WŚŽĞŶŝǆ:ĞƚWƵŵƉ'ĂƵŐĞ^ĞŶƐŽƌ͗/сϮ͘ϴϰϬ͟ ϯ цϵ͕ϵϳϯ͛ ϰ͘ϱ͟,^yͲEŝƉƉůĞ͗/сϯ͘ϴϭϯ͟ ϰ цϵ͕ϵϴϰ͛ ϳͲϱͬϴ͟ǆϰ͘ϱ͟ĂŬĞƌWƌĞŵŝĞƌWĂĐŬĞƌ͗/сϯ͘ϴϳϱ͟ ϱ цϵ͕ϵϵϭ͛ ϰ͘ϱ͟,^yEͲEŝƉƉůĞ͗/сϯ͘ϳϮϱ͟EŽͲ'Ž/ ϲ цϭϬ͕Ϭϯϵ͛ t>'ʹŽƚƚŽŵΛϭϬ͕ϬϰϬ͛ ϳ ϭϬ͕ϭϯϳ͛ ĂŬĞƌϲ͛dŝĞͲďĂĐŬ^ůĞĞǀĞ ϴ ϭϬ͕ϭϰϲ͛ ,ŽŽŬtĂůů,ĂŶŐĞƌ/ŶƐŝĚĞϳͲϱͬϴ͟ĂƐŝŶŐ ϵ ϭϬ͕ϭϳϭ͛ ,ŽŽŬtĂůů,ĂŶŐĞƌKƵƚƐŝĚĞ;,ŽŽŬWŽŝŶƚͿ ϭϬ ϭϬ͕Ϯϳϯ͛ ĂŬĞƌϳ͛dŝĞͲďĂĐŬ^ůĞĞǀĞ ϭϭ ϭϬ͕ϮϴϬ͛ ĂŬĞƌyW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϭϮ ϭϬ͕Ϯϴϲ͛ ĂŬĞƌϳͲϱͬϴ͟ǆϱͲϭͬϮ͟,D>ŝŶĞƌ,ĂŶŐĞƌ KWE,K>ͬDEdd/> ϮϬΗ ϮϲϬƐǆŽĨƌĐƚŝĐƐĞƚŝŶϰϮ͟,ŽůĞ ϭϬͲϰͬϰΗ ϵϯϱƐǆW&͛>͕͛ϯϳϭƐǆůĂƐƐ͞'͕͟dŽƉ:ŽďϱϰƐǆW&͚>͛ŝŶϭϯͲϭͬϮ͟,ŽůĞ ϳ͟ ϳϮϱƐǆůĂƐƐ͞'͟ŝŶϵͲϳͬϴ͟,ŽůĞ t>>/E>/Ed/KEd/> <KWΛϮϴϬ͛D ,ŽůĞŶŐůĞWĂƐƐĞƐϱϬĞŐ͘ΛϮ͕ϭϱϬ͛ DĂǆŶŐůĞŝŶdƵďŝŶŐсϳϴĞŐ͘ ϳϱĞŐ͘ĂƚƐůŝĚŝŶŐƐůĞĞǀĞ dZͬt>>, dƌĞĞ ϰͲϭͬϲ͟ϱD&D tĞůůŚĞĂĚ ϭϭ͟ǆϰͲϭͬϮ͟ϱD'ĞŶϲǁϰ͘ϱ͟dͲ//dΘdƵďŝŶŐ ,ĂŶŐĞƌ/t͞,͟WsƉƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϯϭϳϭͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇŽǇŽŶϭϰͲϵͬϮͬϮϬϬϯ ŽŝůůĞĂŶͲŽƵƚĂŶĚ:ĞƚWƵŵƉZĞŵŽǀĂůϭϭͬϮϭͬϮϬϭϱ E>dZ>t/EKtd/> tŝŶĚŽǁŝŶϳͲϱͬϴ͟ĂƐŝŶŐΛϭϬ͕ϭϱϵ͛ƚŽϭϬ͕ϭϳϭ͛;DͿͬϰ͕ϭϭϱ͛ƚŽϰ͕ϭϭϳ͛;dsͿ tĞůůŶŐůĞΛǁŝŶĚŽǁсϳϴĞŐ͘ K>dZ>t/EKtd/> tŝŶĚŽǁŝŶϳͲϱͬϴ͟ĂƐŝŶŐΛϭϬ͕ϱϭϲ͛ƚŽϭϬ͕ϱϮϴ͛;DͿͬϰ͕ϭϵϵ͛ƚŽϰ͕ϮϬϭ͛;dsͿ tĞůůŶŐůĞΛǁŝŶĚŽǁсϳϳĞŐ͘ DŝůŶĞWŽŝŶƚ ^ZZŝŐϭKW %23( Εϰ͘ϰϴΖ Εϰ͘ϱϰΖ Ϯ͘ϬϬΖ ϱϬϬϬη ϮͲϳͬϴΗǆϱΗsZ ϱϬϬϬη ůŝŶĚ ^͕ϭϭϱDyϳϭͬϭϲϱD;/ĨEĞĞĚĞĚͿ ϮϭͬϭϲϱD<ŝůů>ŝŶĞsĂůǀĞƐ ϮϭͬϭϲϱDŚŽŬĞ>ŝŶĞsĂůǀĞƐ ,ZDĂŶƵĂůDĂŶƵĂůDĂŶƵĂů ^ƚƌŝƉƉŝŶŐ,ĞĂĚ 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU V-111 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 203-103 50-029-23161-00-00 9850 Conductor Surface Intermediate Production Liner 6694 78 2717 7195 2714 9813 20" 9-5/8" 7" 4-1/2" 6697 30 - 108 29 - 2746 26 - 7221 7101 - 9815 30 - 108 29 - 2741 26 - 6621 6562 - 6696 None 3090 5410 7500 7319 5750 7240 8430 7230 - 9772 3-1/2" 9.2# L80 24 - 7103 6626 - 6699 Structural 4-1/2" Baker S3 Packer 7043, 6534 Stan Golis Sr. Area Operations Manager Brodie Wages David.Wages@hilcorp.com 907.564.5006 PRUDHOE BAY, BOREALIS OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final 13.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028240 No SSSV Installed 24 - 6563 See Attached 305 340 82 66 328 372 997 1385 302 299 321-185 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: 7043 6534 By Samantha Carlisle at 10:00 am, Nov 08, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.11.08 08:55:19 -09'00' Stan Golis (880) CDW 11/9/2021 RBDMS HEW 11/8/2021 SFD 11/9/2021 Fracture Stimulate MGR05FEB2022 DSR-11/8/21 ACTIVITY DATE SUMMARY 5/3/2021 T/I/O=800/800/500 SI Assist SL with Freeze Protect (FRACTURING) Pumped 6 bbls 60/40 down FL. Pumped 2 bbls 60/40 followed by 25 bbls DSL down TBG for SL. Pad Op/WSL notified Tags hung on WV SL incontrol of well upon departure. FWHP=100/800/500 5/3/2021 ***WELL FLOWING ON ARRIVAL*** SET X CATCHER @ 7021' MD. PULLED RK-OGLV FROM STA# 1 (6384' MD). PULLED RK-LGLV's FROM STA's 2 (5717' MD), AND 3 (5108' MD). ***WSR CONTINUED ON 5-4-21*** 5/4/2021 ***WSR CONTINUED FROM 5-3-21*** SET RK-DGLV's IN STA's 6 (2594' MD), 4 (4205' MD), 3 (5108' MD), AND 2 (5717' MD). LRS LOADED IA W/ 2% KCL SET RK-DGLV IN ST# 1 @ 6,384' MD PULLED CATCHER FROM X NIP @ 7,021' MD LRS LOADED TUBING W/ 2% KCL SET 3 1/2" XX PLUG IN X NIP @ 7,089' MD (unable to reach test pressure) PULLED 3 1/2" XX PLUG & RESET IN X NIP @ 7,069' MD. (unable to pressure tbg against plug). RAN 3 1/2" HOEFINDER; DETERMINED PLUG LEAKING, AND ALSO TBG x IA COMM EXISTS IN VICINITY OF STA# 5 (3292' MD). ***leak is one way (TBG > IA) @ low pressure (500 psi). ***WSR CONTINUED ON 5-5-21*** 5/4/2021 T/I/O= 880/870/510 Temp=SI, (FRACTURING) Assist Pollard SL by pumping down IA to load w/ 3 bbls neat methanol spear, 150 bbls 2% KCl and 70 bbls crude. Pumped down Tbg to load w/ 1 bbl neat methanol spear, 105 bbls 2% KCl and 25 bbls crude. Trouble shoot well with hole finder and pumped 125 bbls crude for a total of 220 bbls. FWHP's = 100/56/528 5/5/2021 T/I/O=100/56/528 Temp =SI (FRACTURING) Assit Pollard S/L trouble shooting. MIT- T passed @ 3389 psi (max applied 3500) Pumped 1.4 bbls crude to reach test pressure. 1st 15 minutes TBG lost 85 psi, 2nd 15 minutes TBG lost 35 psi. Bled Tbg to 1800 psi for MIT-IA which passed @ 3321 psi (Max applied 3500). Pumped 3.1 bbls down IA to reach test pressure. 1st 15 minutes IA lost 119 psi, 2nd 15 minutes IA lost 57 psi. Tags hung, S/L in control of well upon LRS departure. FWHP's 195/210/511 5/5/2021 ***WSR CONTINUED FROM 5-4-21*** PULLED 2.81" XX PLUG FROM 7069' MD. BRUSHED & FLUSHED NIPPLE @ 7069' MD. SET 2.81" PX PLUG BODY @ 7069' MD. SET EQ PRONG IN PLUG BODY. PT TBG 1000 PSI (IA TRAKING). SET 3 1/2" WHIDDON CATCHER ON PLUG @ 7,069' MD PULLED ST# 5 & SET NEW RK-DGLV @ 3,292' MD LRS PERFORMED PASSING MIT-T & MIT-IA TO 3,500 PSI PULLED 3 1/2" WHIDDON CATCHER FROM 7,069' MD PULLED 3 1/2" PX PRONG & PLUG BODY FROM X NIP @ 7,069' MD DRIFTED W/ 30' x 2 1/2" DUMMY GUNS (2.78" rings) TO 7,350' SLM (no issues) ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF STATUS*** Daily Report of Well Operations PBU V-111 Daily Report of Well Operations PBU V-111 5/8/2021 T/I/O= 90/1529/504 (INJECTIVITY TEST) Pump into tbg 150 bbls crude for injectivity test. Estabilshed injectivity of 5 bpm @ 925 psi, Followed up w/ 98 bbls KCL and 25 bbls Crude for FP. SW WV SSV, AL= closed MV= open IA/OA= OTG . FWHP's = 210/1659/540 5/9/2021 ***WELL S/I ON ARRIVAL*** PERFORATE 7230'-7260' WITH 2.5" 6SPF 60 DEGREE PHASE HSC W/ 11.1 GRAM MILLENIUM CHARGES SET BAKER 2.5" IBP AT 7278' MID ELEMENT ***JOB COMPLETE, WELL S/I ON DEPARTURE, DSO NOTIFIED*** 5/10/2021 Post Perf Injectivty Test (FRACTURING) Pumped 160 bbls down Tbg for injectivty test. Got 5 bpm @ ~1500 psi for injectivity. Pad Op notified of well status per LRS departure. SV,WV,SSV=C MV=O IA,OA=OTG 6/24/2021 *** SLB FRAC CREW *** Job Scope: Mobilize and rig up SLB frac equipment. 6/25/2021 T/I/O= SSV/1600/500. Assist SLB with FRAC (FRACTURING) Pumped 2 bbls DSL down IA to hold IAP while SLB performed Frac. SLB in control of well upon departure. CVs OTG FWHP=500/1500/70 6/25/2021 *** SLB FRAC CREW *** P/T IA line to 300 psi low and 3,600 psi high.Test PRVs (3,100 psi and 3,150 psi). P/T treating lines to 300 psi low and 5,200 psi high. Perform injectivity test at 17 BPM @ 4,500 psi with fresh water. Pump 40 bbl Pad with 28# crosslinked gel at 15 BPM @ 3000 psi, 18 BPM @ 3600 psi, 20 BPM @ 3,700 psi. Pump scour stage with 0.5 ppa (600-lbs) in 28# croslinked gel. Tubing pressure increases to 4,750 psi when crosslinked gel hits perfs. Reduce rate but tubing pressure still increasing. Cut crosslink gel and switch to linear gel. Shut down and evaluate. Pump linear gel at 1 BPM @ 4,200 psi. Injectivity improves as linear gel displaces crosslinked gel. 2 BPM at 4,200 psi. Final injectivity of 20 BPM at 3,900 psi with linear gel. Scour stage with all proppant has been pumped through perfs.Decision made to shut down and wait for acid. SDFN. 6/26/2021 T/I/O=SSV/1420/510 Assist Frac w/ holding IA pressure. Pumped 2 BBL's of diesel down the IA to pressure up to 2500 psi. Maintain 2500 psi while SLB pumps acid treatment followed by an injection test. ***JOB COMPLETE ON 26-JUN-2021*** 6/26/2021 *** SLB FRAC CREW *** PJSM. P/T lines to 300 psi low and 5,000 psi high. Pump 20 bbls of 15% HCL into formation. Allow acid to soak in 4x 5 bbl increments across perfs. Displace acid with 85 bbls of fresh water with clay stabilizer and perform injectivity test at5 BPM @ 900 psi, 10 BPM @ 2,250 psi, 15 BPM @ 4,100 psi, 15.7 BPM @ 4,500 psi. RDMO. 7/7/2021 ***WELL SI ON ARRIVAL*** BAIL 2 GAL OF FRAC SAND W/ 10' x 2.5" PUMP BAILER FROM 7,242' SLM TO 7,251' SLM ***CONT WSR ON 7/8/2021*** 7/8/2021 ***CONT WSR FROM 7/7/2021*** BAIL 1.75 GAL OF FRAC SAND FROM TOP OF IBP @ 7,278' MD PULL 2-1/2" BKR IBP FROM 7,278' MD (all elements recovered on IBP) ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS*** 7/18/2021 CTU #9 - 1.75" Coil Job Objective: FCO, Caliper, Balance Cement Plug. MIRU CTU. Perform Weekly BOP test. ***Continued on 07/19/21*** PERFORATE 7230'-7260' Daily Report of Well Operations PBU V-111 7/19/2021 CTU #9 - 1.75" Coil Job Objective: FCO, Caliper, Balance Cement Plug. Make up and RIH with 2.25 JSN drift bha. Tag at 9538'. Clean out down to TD tag of 9790' CTMD. Pick up and paint TD flag 40' off bottom. Chase gel sweep OOH. Make up 1.69" 24 arm extended length caliper and RIH. Log from TD flag to 6800', painting a red tie-in flag at 7000'. POOH. Download data (+4' correction) Correlate to SLB SBHP Survey dated 02-Nov-2003. MU 2.30" BDJSN and RIH. Turn coil over to diesel. Bullhead 60 bbls of diesel down backside of CT. At flag corect depth, run down and park at 7585'. Lay in 12 bbls of 15.8 ppg Class G cement up to 7210'. (Cement top found 7319, plug spanning 7319' to 7585') Close choke and pump pipe displacement while pooh. Wait on 500 psi compressive strength. ***Continued on 07/20/21*** 7/20/2021 CTU #9 - 1.75" Coil Job Objective: FCO, Caliper, Balance Cement Plug. Wait on 500 psi compressive strength. Make up 2.75" DJN and RIH. PT cement to 1200 psi WHP (500 psi over static) and stabilized leak off of ~30 psi/min. Tie-in at the flag and encounter potentially contaminated cement ~ 7210', and a hard tag at 7319'. Jet across perf interval and pump gel sweep to surface. POOH and FP well with diesel. RDMO, blowing down coil for pipe retirement. ***Job Complete*** 8/6/2021 **WELL S/I ON ARRIVAL** DRIFTED w/ 33'x2.5" DUMMY GUNS(2.78") TO 6751'SLM (unable to work deeper) BRUSHED TBG w/ 3 1/2 BLB & 2.79" GAUGE RING. TAGGED TD @ 7278'SLM (worked area from 6000' to wleg @ 7103', tight spot @ 6794'slm) DRIFTED w/ 33'x2.5" DUMMY GUNS(2.78") TO 6808'SLM **WSR CONT ON 8/7/21** 8/7/2021 **WSR CONT'D FROM 8/6/21** BRUSH & FLUSHED w/ FULLBORE BLB @ 2.50" GAUGE RING TO WLEG @ 7103'MD (.4 bpm @ 3000psi) DRIFTED w/ 33'x2.5" DMY GUNS(2.78") TO 6731'SLM (unable to work deeper) DRIFTED w/ 33'x2.5" DMY GUNS(2.66") TO TAG TD @ 7270'MD (jarred through tight spots from 6739' to 6818'slm) DRIFTED w/ 22'x2.5" DMY GUNS(2.78") TO 6719'SLM (unable to work deeper) BROACHED w/ 2.70"x10' DMY WHIPSTOCK & 2.79" BROACH FROM 6718' TO 6820'SLM, DRIFTED FREELY TO WLEG RAN 2.5"x10' PUMP BLR TO WLEG @ 7103'MD (drifted freely) DRIFTED w/ 11'x2.5" DMY GUNS(2.78") TO TAG TD @ 7268'SLM (bobbles @ 6710' & 6800'slm, did not sd) DRIFTED w/ 21'x2.5" DMY GUNS(2.66") TO 6733'SLM (able to work deeper w/ aggresive jarring) **WELL S/I ON DEPARTURE** 8/7/2021 T/I/O= 200/600/550. LRS unit 72 Assist Slickline Brush & Flush (FRACTURING). Pumped 33 bblsof 180* F crude into the TBG. Pumped 22 bbls of crude into the TBG to help tools get down. Final T/I/O= 1040/640/550. 8/12/2021 ***WELL SHUT IN ON ARRIVAL*** MIRU HES EL UNIT. MADE 4 RUNS WITH 2.5" 6 SPF 60 DEG HSC LOADED 11.1 GR MILLENIUM CHARGES. PERFORATED INTERVAL 7235' - 7259'. ALL SHOTS FIRED. RIG DOWN. ***WELL LEFT S/I / JOB COMPLETE*** PERFORATED INTERVAL 7235' - 7259'. Daily Report of Well Operations PBU V-111 8/16/2021 T/I/O=550/681/665 LRS Unit #46 Injectivity Test (FRACTURING) Pumped a total of 200 BBL's of 80* crude down the tubing to establish an injectivity rate of 5 BPM @ ~ 3600 psi. Performed hard shut down and monitored TBG pressure fall off for 30 min. TBG lost ~2200 psi (SEE LOG FOR DETAILS) Pad-Op notified of well status upon LRS departure. WV/SV/SSV=C MV=O IA/OA=OTG FWHP's=1400/639/590. 9/5/2021 **WELL S/I ON ARRIVAL** DRIFT w/ 5'x2" BLR, TAG TD @ 7282'SLM MEASURE SBHP @ 6939', 7140' & 7243'MD. *good data* **WELL S/I ON DEPARTURE** 10/1/2021 T/I/O = SSV/620/640. Temp = SI. Hold BP on IA for Injectivity Test (Assist HPT). ALP = 1600 psi, SI @ CV. IA FL @ near surface. OA FL @ 120'. Bled OAP to BT from 640 psi to 200 psi in 30 min (Gas to FTS). Assisted w/ test by pumping Diesel into IA (2 bbls total) and holding IAP as directed. Bled IAP to 520 psi (2 bbls). Final WHPs = SSV/520/400. Haliburton in control of well upon departure. 18:00 10/1/2021 *** SLB Frac Crew*** Job Scope injectivity test pre-frac. Using SLB Super pump 2200 HP w/ Universal Isolation Tool ( Tree Saver) RU pressure test to 9000 psi Open well and preform injectivty test Pre-Frac. Preform injectivity test max rate; limited by 2" iron, 8.1 bpm @ 3761 psi. TBG volume to perforations 63 bbls + 50 bbls injectivity through target frac zone. Hard Shut Down, wait 15 min. Sent data to OE Brodie Wages. Preformed step rate test in 1 bbl steps to 8 bpm preform Hard Shut Down. Send data to OE. Freeze protect well with 20 bbls of diesel. ***Job Completed*** Note: SLB Charges will be applied on the frac day ticket. 10/7/2021 LRS unit 70 assist frac crew (FRACTURING) Heated 56 bbls of Diesel to 90* onto SLB transport. 10/8/2021 T/I/O= 500/320/540 Assist SLB (FRACTURING) Pumped 5 bbls diesel down IA to hold back side pressure. FWHP's= 3000/500/500 SLB Frac in control of well upon LRS departure. 10/8/2021 SLB FRAC: Continue to rig up frac lines. Spot Frac Cat. Load LRS with 50 bbls diesel. LRS connect upstream of PRV skid. Change PRVs from 3,300 psi to 4,200 psi. P/T line to IA with LRS to 250 psi low and 5,000 psi high. Test PRVs. Pump Fresh Water at 5 BPM at 2,850 psi. Bring IA pressure up to 3,500 psi and hold. Pump fresh water at 10 BPM at 3,800 psi. Pump fresh water at 15 BPM at 4,950 psi. Pump fresh water at 20 BPM at 6,530 psi. PumpPad at 20 BPM 4,750 psi with xlink throughout Tubing. Increase rate to 25 BPM at 4,950 psi. (125 bbl Pad.) Pump 0.5 PPA scour with 16/20 Carbo Lite at 25 BPM and 4, 830 psi. (50 bbl scour stage). Pump 125 bbls Pad at 25 BPM and 4,660 psi. (Total Pad = 300 bbls). Pump 1 PPA of 16/20 CarboBond Lite at 25 BPM and 4,480 psi. Pump 2 PPA of 16/20 CarboBond Lite at 24.5 BPM and 4,270 psi. Pump 3 PPA of 16/20 CarboBond Lite at 24.4 BPM and 4,069 psi. Pump 4 PPA of 16/20 CarboBond Lite at 25 BPM and 3,995 psi. Pump 5 PPA of 16/20 CarboBond Lite at 24.2 BPM and 3,913 psi. Pump 6 PPA of 16/20 CarboBond Lite at 24.2 BPM and 3,880 psi. Pump 7 PPA of 16/20 CarboBond Lite at 24.2 BPM and 3,860 psi. Pump 8 PPA of 16/20 CarboBond Lite at 24.2 BPM and 3,932 psi. Pump 9 PPA of 16/20 CarboBond Lite w/ S123 at 24.2 BPM and 4,050 psi. Pump 10 PPA of 16/20 CarboBond Lite w/ S123 at 24.1 BPM and 4,300 psi. Pop off goes. Screened out instantly. Check ground lines. 67,872- lbs. of proppant away. 87,835- lbs. of proppant total pumped. Attempted to flush Tubing but Tubing pressures up to over 5,000 psi instantly. Eventually work 2.2 bbls of diesel into Tree. RD SLB Frac. Daily Report of Well Operations PBU V-111 10/11/2021 CTU #9 - 1.75" Coil, 0.156" wt Job Objective: Post Frac FCO MIRU CTU. Make up Reverse nozzle and RIH. Tagged at 956' ctmd, Start reversing. ...Job in Progress... 10/12/2021 CTU #9 - 1.75" Coil, 0.156" wt Job Objective: Post Frac FCO Continue reverse FCO. Set down at 3443 ctmd. Could not reverse past. Jetted through the hard top and down to 3663 ctmd. Swapped back to reverse FCO and was able to make headway. Reverse down to 7280' and begin taking ~30% losses. Stop reverse circulating and switch to a conventional cleanout, pumping a ball to increase jetting ability. Continue cleaning out to to a tag at 7286' CTMD and unable to go any deeper jetting at max rate. Pump Gel sweep off bottom and chase OOH, jetting all jewelry on the way OOH. Circulate in FP with Diesel. Pump drift ball at surface. RDMO CTU. ***Job Complete*** 10/18/2021 ***WELL S/I UPON ARRIVAL*** (fracturing) SET 3 1/2" X-CATCHER IN X-NIPPLE @ 7,021' MD PULLED RK-DGLV'S FROM STA #1, STA #2, STA #3, STA #4, STA #6 SET RK-LGLV'S IN STA #6, STA #4, STA #3, STA #2 SET RK-S/O IN STA #1 @ 6,384' MD ***CONT WSR ON 10/19/21*** 10/19/2021 ***CONT WSR FROM 10/18/21*** (fracturing) PULLED EMPTY 3 1/2" X-CATCHER FROM 7,021' MD TAGGED HARD TD W/ 2.20" CENT, 1.75" SAMPLE BAILER @ 7,295' SLM (metal marks, no sample) RAN 2.50" CENT, 2.30" LIB TO 7,293' SLM (marks on edge of lib) ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** 10/21/2021 LRS Test Unit 6, Post Frac Flowback - SLBU. Begin WSR on 10/21/21 Unit Move, Begin RU, PT, POP, Flow & Stabilize well. Continue WSR on 10/22/21 10/22/2021 LRS Test Unit 6, Post Frac Flowback - SLBU. Cont from WSR 10/21/21. Flow & Stabilize well, Continue Slow Bean Up. Continue WSR on 10/23/21 10/23/2021 LRS Test Unit 6, Post Frac Flowback - SLBU. Cont from WSR 10/22/21. Flow & Stabilize well, Continue Slow Bean Up. Continue WSR on 10/24/21 10/24/2021 LRS Test Unit 6, Post Frac Flowback - SLBU. Cont from WSR 10/23/21. Flow & Stabilize well, Continue Slow Bean Up. FOC, IL Bypassed, Purge WPS, Begin 12 Hr PB Well Test, RDMO. Client : Hilcorp Well : V-111 District : Prudhoe Bay Country : United States Schlumberger-Private FracCAT Treatment Report Well : V-111 Field : Aurora Formation : Kuparuk A Well Location : Greater Prudhoe Bay County : North Slope Borough State : Alaska Prepared for Client : Hilcorp Client Rep : David Wages : Nick Frazier Date Prepared : 10-08-2021 Prepared by Name : Zaid Al-Saadawi Phone : 907 943 1753 Pressures Initial Wellhead Pressure (psi) 350 Maximum Treating Pressure (psi) 8000 Final Surface ISIP (psi) N/A Surface Shut in Pressure(psi) 2000 Calibration ISIP 1776 Treatment Totals Total Slurry Pumped (bbl) 927.9 Total Proppant in Formation (lbs.) 69367 Total YF130ST (bbl) 773.4 Total Proppant Pumped (lbs.); From Load Tickets 87835 Total Water (bbl) 57.7 Total Carbo Bond 16/20 (lbs) 144,000 Total WF130 (bbl) 110 Total Chemical Additives Invoiced Past WH Invoiced Past WH F103 (gal) 35 J580 (lb) 1192 L065 (gal) 33 J532 (gal) 82 L071 (gal) 70 S123 (gal) 15 J475 (lb) 165 Freeze Protect(bbl) 60 M275 (lb) 30 J134 (Ib) 5 Disclaimer Notice This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Client : Hilcorp Well : V-111 District : Prudhoe Bay Country : United States Schlumberger-Private Freedom from infringement of patents of Schlumberger or others is not to be inferred. Client : Hilcorp Well : V-111 District : Prudhoe Bay Country : United States Schlumberger-Private Section 1: Stage 1, Propped Frac: As Measured Pump Schedule As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 Displace FP 58.1 16.0 4.4 Water and Liq Ads 2425 0.0 0.0 0 2 Shutdow n 0.0 16.0 0.0 Water and Liq Ads 0 0.0 0.0 0 3 Crosslin k Ch 19.5 14.6 1.7 YF130ST 805 0.0 0.0 0 4 Pad 125.0 22.2 5.7 YF130ST 5246 0.0 0.0 0 5 0.5 PPA 50.1 24.9 2.0 YF130ST 2065 16/20 CBL 0.6 0.4 1000 6 Pad 125.0 25.0 5.0 YF130ST 5245 7 1.0 PPA 100.0 24.7 4.0 YF130ST 4032 16/20 CBL 1.0 0.9 3749 8 2.0 PPA 50.0 24.5 2.0 YF130ST 1932 16/20 CBL 2.1 1.9 3683 9 3.0 PPA 50.0 24.4 2.1 YF130ST 1858 16/20 CBL 3.1 2.9 5360 10 4.0 PPA 50.0 24.5 2.0 YF130ST 1786 16/20 CBL 4.1 3.9 6975 11 5.0 PPA 50.2 24.4 2.1 YF130ST 1727 16/20 CBL 5.2 4.9 8423 12 6.0 PPA 50.1 24.6 2.0 YF130ST 1661 16/20 CBL 6.3 5.9 9786 13 7.0 PPA 50.1 24.2 2.1 YF130ST 1605 16/20 CBL 7.2 6.9 11083 14 8.0 PPA 50.0 24.1 2.1 YF130ST 1549 16/20 CBL 8.3 7.9 12255 15 9.0 PPA 50.0 24.2 2.1 YF130ST 1499 16/20 CBL 9.2 8.9 13358 16 10.0 PPA 44.9 22.6 18.3 YF130ST 1360 16/20 CBL 10.2 8.9 12161 17 Pre Flush 2.7 0.9 5.5 YF130ST 111 0.0 0.0 0 18 Freeze prote 2.2 0.8 3.0 Diesel 93 0.0 0.0 0 Stage Pressures & Rates Step # Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 Displace FP 16.0 20.0 5424 6579 50 2 Shutdown 16.0 0.0 5424 664 557 3 Crosslink Ch 14.6 19.9 4882 6122 557 4 Pad 22.2 25.2 5024 5957 4428 5 0.5 PPA 24.9 25.1 4862 4913 4832 6 Pad 25.0 25.2 4645 4863 4496 7 1.0 PPA 24.7 25.1 4425 4507 4303 8 2.0 PPA 24.5 24.7 4212 4302 4101 9 3.0 PPA 24.4 24.7 4066 4100 4039 10 4.0 PPA 24.5 24.9 3983 4035 3930 11 5.0 PPA 24.4 24.7 3908 3929 3888 12 6.0 PPA 24.6 24.7 3880 3902 3856 13 7.0 PPA 24.2 24.5 3882 3897 3866 14 8.0 PPA 24.1 24.2 3942 3987 3889 15 9.0 PPA 24.2 24.4 4134 4282 3983 16 10.0 PPA 22.6 24.5 4079 5134 48 17 Pre Flush 0.9 1.8 3312 5812 15 Client : Hilcorp Well : V-111 District : Prudhoe Bay Country : United States Schlumberger-Private Stage Pressures & Rates Step # Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 18 Freeze prote 0.8 1.0 4184 5823 1140 As Measured Totals Slurry (bbl) Pump Time (min) Clean Fluid (gal) Proppant (lb) 927.9 66.0 34999 87835 Average Treating Pressure: 4426 psi Maximum Treating Pressure: 6579 psi Minimum Treating Pressure: 15 psi Average Injection Rate: 23.3 bbl/min Maximum Injection Rate: 25.2 bbl/min Average Horsepower: 2528.6 hhp Maximum Horsepower: 3203.2 hhp Maximum Prop Concentration: 10.2 PPA Section 2: Stage 1, Propped Frac: Job Messages Message Log # Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 Reset Executed Steps 0 0 0.0 0.0 0.0 2 Reset Executed Steps 0 0 0.0 0.0 0.0 3 Reset Executed Steps 0 0 0.0 0.0 0.0 4 Reset Executed Steps 0 0 0.0 0.0 0.0 5 Reset Executed Steps 0 0 0.0 0.0 0.0 6 Reset Executed Steps 0 0 0.0 0.0 0.0 7 13:10:57 GKO Tripped @ 4000 4280 331 0.0 0.0 0.0 8 13:12:55 Good Check valve test 4028 332 0.0 0.0 0.0 9 13:21:36 Start PT 8939 332 0.0 0.0 0.0 10 13:24:42 Good PT 8831 332 0.0 0.0 0.0 11 13:52:41 Start Displace FP Automatically 51 2175 0.0 0.0 0.0 12 13:52:41 Start Propped Frac Automatically 51 2175 0.0 0.0 0.0 13 13:52:41 Start Frac Stage Y Automatically 51 2175 0.0 0.0 0.0 14 13:52:47 Started Pumping 51 2238 0.0 0.0 0.0 15 14:28:53 Start Shutdown Manually 664 3680 58.1 0.0 0.0 16 14:41:57 Start Crosslink Ch Manually 557 3647 58.1 0.0 0.0 17 14:43:32 Stage at Perfs: Displace FP 5980 3778 74.9 19.9 0.0 18 14:43:40 Start Pad Manually 5918 3891 77.6 19.8 0.0 19 14:46:26 Stage at Perfs: Crosslink Ch 4437 4045 132.6 20.0 0.0 20 14:47:20 Stage at Perfs: Pad 4970 4098 152.0 25.1 0.0 21 14:49:22 Start 0.5 PPA Automatically 4918 4061 203.0 25.0 0.0 22 14:49:22 Started Pumping Prop 4918 4061 203.0 25.0 0.0 23 14:51:22 Start Pad Automatically 4863 4072 252.7 24.9 0.5 24 14:51:44 Stopped Pumping Prop 4797 4063 261.8 24.8 0.1 25 14:52:21 Stage at Perfs: 0.5 PPA 4767 4053 277.2 25.1 0.0 26 14:54:21 Stage at Perfs: Pad 4559 4083 327.3 25.1 0.0 27 14:56:22 Start 1.0 PPA Automatically 4506 4043 377.9 25.0 0.0 28 14:56:25 Started Pumping Prop 4488 4041 379.2 24.9 0.0 29 14:59:23 Stage at Perfs: 1.0 PPA 4376 4070 452.5 24.7 1.0 30 15:00:25 Start 2.0 PPA Automatically 4302 4068 478.0 24.6 0.9 31 15:02:27 Start 3.0 PPA Automatically 4100 4069 527.9 24.6 1.9 Client : Hilcorp Well : V-111 District : Prudhoe Bay Country : United States Schlumberger-Private Message Log # Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 32 15:03:27 Stage at Perfs: 2.0 PPA 4074 4066 552.4 24.3 3.1 33 15:04:30 Start 4.0 PPA Automatically 4028 4062 577.9 24.2 2.9 34 15:05:30 Stage at Perfs: 3.0 PPA 3967 4057 602.4 24.9 3.9 35 15:06:32 Start 5.0 PPA Automatically 3902 4055 627.8 24.3 4.0 36 15:07:33 Stage at Perfs: 4.0 PPA 3910 4049 652.4 24.5 5.0 37 15:08:36 Start 6.0 PPA Automatically 3909 4039 678.2 24.4 5.0 38 15:09:35 Stage at Perfs: 5.0 PPA 3868 4031 702.4 24.5 6.1 39 15:10:38 Start 7.0 PPA Automatically 3865 4024 728.2 24.3 6.0 40 15:11:38 Stage at Perfs: 6.0 PPA 3881 4011 752.5 24.1 6.9 41 15:12:42 Start 8.0 PPA Automatically 3880 4004 778.2 24.1 7.0 42 15:13:43 Stage at Perfs: 7.0 PPA 3929 3992 802.7 24.0 8.1 43 15:14:47 Start 9.0 PPA Automatically 3988 3979 828.4 24.3 8.0 44 15:15:47 Stage at Perfs: 8.0 PPA 4132 3966 852.7 24.1 9.1 45 15:16:51 Start 10.0 PPA Automatically 4276 4027 878.4 24.0 9.1 46 15:17:52 Stage at Perfs: 9.0 PPA 4420 4009 902.7 24.1 10.0 47 15:25:36 Stopped Pumping Prop 157 2032 922.3 0.0 0.2 48 15:52:08 Started Pumping 47 3400 923.0 0.0 0.0 49 15:52:15 Start Pre Flush Manually 48 3399 923.0 0.0 0.0 50 16:10:45 Started Pumping 55 3331 923.5 0.0 0.0 51 16:35:30 Started Pumping 1763 3310 925.7 0.0 0.0 52 16:36:29 Start Freeze prote Manually 1318 3308 925.7 0.0 0.0 Client : Hilcorp Well : V-111 District : Prudhoe Bay Country : United States Schlumberger-Private 13:05:11 13:11:01 13:16:51 13:22:41 13:28:31 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 Tr. Press - psi0 5 10 15 20 25 30 Slurry Rate - bbl/min-2 0 2 4 6 8 10 12 Prop Con - PPATr. Press BHP Annulus Press Slurry Rate Prop Con BH Prop Con Pressure Test © Schlumberger 1994-2017 Hilcorp North Slope LLC V-111 10-08-2021 13:56:32 14:06:57 14:17:22 14:27:47 14:38:12 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 Tr. Press - psi0 5 10 15 20 25 30 Slurry Rate - bbl/min-2 0 2 4 6 8 10 12 Prop Con - PPATr. Press BHP Annulus Press Slurry Rate Prop Con BH Prop Con Calibration Test © Schlumberger 1994-2017 Hilcorp North Slope LLC V-111 10-08-2021 Client : Hilcorp Well : V-111 District : Prudhoe Bay Country : United States Schlumberger-Private 14:37:48 14:54:28 15:11:08 15:27:48 15:44:28 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 Tr. Press - psi0 5 10 15 20 25 30 Slurry Rate - bbl/min0 2 4 6 8 10 12 Prop Con - PPATr. Press BHP Annulus Press Slurry Rate Prop Con BH Prop Con Main Treatment © Schlumberger 1994-2017 Hilcorp North Slope LLC V-111 10-08-2021 Hydraulic Fracturing Fluid Product Component Information DisclosureHydraulic Fracturing Fluid Composition:Job Start Date:10/8/2021Job End Date:10/8/2021State:AlaskaCounty:Beechey PointAPI Number:50-029-23161-00-00Operator Name:Hilcorp Alaska, LLCWell Name and Number:V-111Latitude:70.32784600Longitude:-149.26756800Datum:NAD27Federal Well:NOIndian Well:NOTrue Vertical Depth:6,534Total Base Water Volume (gal):36,742Total Base Non Water Volume:0Trade NameSupplierPurposeIngredientsChemicalAbstractServiceNumber(CAS #)MaximumIngredientConcentrationin Additive (% by mass)**MaximumIngredientConcentrationin HF Fluid (% by mass)**CommentsFluidSchlumbergerN/AWater (Including Mix Water Supplied by Client)*7732-18-577.08547J604SchlumbergerCrosslinker J604Listed Below D206SchlumbergerAntifoam AgentListed BelowL065SchlumbergerScale InhibitorListed BelowJ475SchlumbergerBreaker J475Listed BelowF103SchlumbergerSurfactantListed BelowL071SchlumbergerClay Control AgentListed BelowS123SchlumbergerActivatorListed BelowS526-1620SchlumbergerPropping AgentListed BelowM002SchlumbergerAdditiveListed BelowM275SchlumbergerBactericide Listed BelowJ580SchlumbergerGel J580Listed BelowCeramic materials and wares, chemicals66402-68-496.3646422.08151Guar gum9000-30-01.436900.329262-hydroxy-N,N,N-trimethylethanaminiumchloride67-48-10.558960.12808Ulexite1319-33-10.449510.10300Ethylene Glycol107-21-10.355960.08157Diammoniumperoxodisulphate7727-54-00.171780.03936Propan-2-ol67-63-00.152720.034992-Propenoic acid, polymer with sodium phosphinate129898-01-70.089530.02052Alcohols, c11-15-secondary, ethoxylated68131-40-80.076910.017622-butoxyethanol111-76-20.075810.01737Ethoxylated C11 Alcohol34398-01-10.069630.01596Sodium Tetraborate Decahydrate1303-96-40.049680.01138Ethoxylated Alcohol68131-39-50.037790.00866Vinylidenechloride/methylacrylatecopolymer25038-72-60.037240.00853Sodium hydroxide (impurity)1310-73-20.019130.00438Sodium chloride7647-14-50.018080.00414Diatomaceous earth, calcined91053-39-30.016460.00377but-2-enedioic acid110-17-80.011830.00271Items above are Trade Names with the exception of Base Water . Items below are the individual ingredients. Calcium Chloride10043-52-40.009140.00209Dimethyl siloxanes and silicones63148-62-90.007190.00165Undecanol112-42-50.006060.00139Siloxanes and silicones, dimethyl, reaction products with silica67762-90-70.004580.00105Non-crystalline silica (impurity)7631-86-90.003600.00083Magnesium nitrate10377-60-30.003290.000755-chloro-2-methyl-4-isothiazolin-3-one and 2-methyl-4-isothiazolin-3-one55965-84-90.001970.00045Magnesium chloride7786-30-30.001650.00038Magnesium silicate hydrate (talc)14807-96-60.001140.000262,2''-oxydiethanol(impurity)111-46-60.000970.00022Sorbitan stearate1338-41-60.000870.00020Diutan595585-15-20.000590.00014Diutan gum125005-87-00.000590.00014poly(tetrafluoroethylene)9002-84-00.000480.000112-Propenoic acid, 2-ethylhexyl ester, polymer with 2-hydroxyethyl 2-propenoate36089-45-90.000460.00010Siloxanes and Silicones, di-Me, 3-hydroxypropyl Me, ethoxylated propoxylated68937-55-30.000460.00010Fatty acids, C18-unsatd., dimers, ethoxylated propoxylated68308-89-40.000460.00010Cristobalite14464-46-10.000330.00008Quartz, Crystalline silica14808-60-70.000330.00008Potassium chloride (impurity)7447-40-70.000290.00007 * Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water ** Information is based on the maximum potential for concentration and thus the total may be over 100%*** If you are calculating a percentage of total ingredients do not add the water volume below the green line to the water volume above the green lineNote: For Field Development Products (products that begin with FDP), MSDS level only information has been provided.Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets (MSDS)Acetic acid, potassium salt127-08-20.000230.00005Sodiumcarboxymethylcellulose9004-32-40.000110.00003Xanthan Gum11138-66-20.000110.00003Sorbitan monooleate, ethoxylated9005-65-60.000140.00003Sodium nitrite7632-00-00.000090.00002Tetrahydro-3,5-dimethyl-1,3,5-thiadiazine-2-thione533-74-40.000090.000021,2-benzisothiazolin-3-one2634-33-50.000050.00001Acetic acid (impurity)64-19-70.000040.00001 Py OF TSF • • 4,i I�..e • tV THE STATE Alaska Oil and Gas - , o � fLAS <:A Conservation Commission ___- A tt'trx 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS$P Fax: 907.276.7542 www.aogcc.alaska.gov Bo YorkAA Operations Managert `30 Hilcorp Alaska, LLC 0 3 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB S-34 Sundry Number: 315-741 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P ,w, 1 Cathy . Foerster Chair 444— DATED this ID of December, 2015 Encl. • p*C ixle)D i • i:-i I�f E STATE OF ALASKA DEC 11 Z015 . ALASKA OIL AND GAS CONSERVATION COMMISSION P73 iat sI 1,5 APPLICATION FOR SUNDRY APPROVAL.S AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0- Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑✓ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Re-complete Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: JET o`tA41° Hilcorp Alaska LLC • Exploratory ❑ Development ❑✓ 203-130 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-23171-00-00 . 7. If perforating: 8.Wel, Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05- Will planned perforations require a spacing exception? Yes ❑ No ❑., MILNE PT UNIT SB S-34 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL0380109 MILNE POINT/SCHR.ADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,159' • 4,323' . 10,516' . 4,199' - 1,010 NIA N/A Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 110' 110' N/A N/A Intermediate 5,518' 10-3/4" 5,518' 2,894' 3,580psi 2,090psi Production 11,159' 7-5/8" 11,159' 4,246' 6,890psi 4,790psi NE Liner 2,964' 4-1/2" 13,091' 4,225' 8,430psi 7,500psi OA Liner 2,959' 4-1/2" 13,232' 4,234' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 3-1/2" 9.2#/L-80 'SCT 10,040 See Attached Schematic See Attached Schematic 4-1/2" 12.6#/L-801 IBT-M Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7-5/8"x 4.5"Premier and N/A • 9,984'(MD)/4,074(TVD)and N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 2 Exploratory ❑ Stratigraphic [] Development 0. Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 12/28/2015 OIL ❑✓ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Paul Chan Email pchan(aihilcorp.com Printed Name Bo York Title Operations Manager Signatur c., 1,119] ne 777-8345 Date 12'11/2015 COMMISSION USE ONLY Conditions pproval: Notify Commission so that a representative may witness Sundry Number 1 Plug Integrity ❑ BOP Test Mechanical1111 Other: Integrity Test ❑ Location Clearance Other: .k 3 5O0 'sem O I nif- ?F CQ.-Si. . -it S(" l4f 3500si. # ZSOOpst. A.)A, sf J tt Post Initial Injection MIT Req'd? Yes 0 No ❑ U 04,% tSpacing Exception Required? Yes ❑ No Subsequent Form Required: /Q— 1 611 � tl S iik APPROVED BY Approved by:Cti.--6.2 �ry COMMISSIONER THE COMMISSIONDate: Z '�S-�S3e �Z./ �sv &IRteI1BIf/IfQ �lI( ( 7614-----Form 10-403 Rev1Vi Aa Efor 12 months from the date of approval. Attachments in Duplicate • Well Prognosis • Well: MPU S-34 Ilikor,i la.s a.LLI Date: 12/11/2015 Well Name: MPU S-34 API Number: 50-029-23171-00 Current Status: SI Oil Well [Jet Pump] Pad: S-Pad Estimated Start Date: December 28th, 2015 Rig: Nordic#3 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 203-130 First Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Current Bottom Hole Pressure: 1,410 psi @ 4,000' TVD (Last BHP measured 3/23/2015 /6.8 ppg EMW) Maximum Expected BHP: 1,410 psi @ 4,000' TVD (No new perfs being added) MPSP: 1,010 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: The Milne Point S-34 well was drilled in 2003 using Doyon 14 and completed as a dual lateral in the Schrader Bluff NE and OA sands with a Jet Pump. In December 2012, SL bailed ^20 gal of sand from on top of the jet pump and continued to bail another 10 gal after pulling the jet pump. A CTU fill clean out of the tubing tail and into one of the laterals was completed in February 2013, and an 8C jet pump was set in March 2013. The jet pump was pulled out of MPS-34 on March 22, 2013. A tubing caliper confirmed that there is an ID restriction at 9937.5' MD. A new 8C jet pump was set on 4/30/13, but appears to just be circulating power fluid. Slickline attempted to set a 9A jet pump in July 2013. Originally tagging at 8450' SLM, SL bailed down to 9687' SLM recovering 5-10 gal of schmoo/sand mix in the process. SL was unable to bail any deeper than 9687' SLM and it was recommended that CTU be used to retrieve the JP and FCO the well. CT pulled the JP and performed a FCO on the lateral to 11,530' CTM in November 2015. Notes Regarding Wellbore Condition • Deviation down to pump section (max angle 77.2° @ 4,886'). Deviation at pump is 76°. • Casing last tested to 250/3,500 psi for 30 min down to 9,546' on 8/21/2003. • Poor jet pump performance. Objective: Replace existing 4-1/2" x 3-1/2"jet pump completion with a 4-1/2"jet pump completion.. Brief Procedure: Pre-rig prep: Slickline 1. RU SL. Drift 4-1/2" tubing. • • Well Prognosis Well: MPU S-34 Hilcorp Alaska,LLI Date: 12/11/2015 2. Drift 3-1/2" tubing with 2.75" drift for tubing cut. 3. Ensure SS is open. ca-S .rt cs 4. Set standing valve and pressure test casing to 3500 psi for 30 minutes. 5. RDMO SL (C itk IT / / E-Line 6. RU e-line. PT wireline BOPE and lubricator to 1500 psi. 7. RIH with tubing cutter and cut tubing_at±9968' MD (in the middle of the 10.13' pup joint above the w^.(� Pc,w p 'Fero L S 3-1/2" X @ 9973.79' MD). Note: Hole angle is 75.5° at cut depth. �P" .) . a. Contingency: Use wire line tractor if necessary to convey tubing cutter on depth. 8. POOH and RD e-line. 9. Circulate well bore clean and freeze protect. 10. Check each LDS for free movement. Back out and check each LDS for breakage. 11. Set BPV. WO Rig Procedure: 1. MIRU Nordic#3 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 2. Pull BPV. Circulate well clean with 8.5 ppg sea water. 3. Set BPV. ND Tree. NU 11" BOPE. Pull BPV and set TWC. S� >• 4. Test BOPE to 250 psi low/3;00`0 pT high, annular to 250 psi low/2,500 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. �p� a. Perform Test per Nordic 3 BOP Test Procedure. rv,5 b. Notify AOGCC 24 hrs in advance of BOP test. c. Submit completed 10-424 BOPE test results within 5 days of completed test. d. Confirm test pressures per the Sundry Conditions of approval. e. Test VBR rams and annular with 2-7/8" and 4-1/2" test joints. 5. Contingency: (If the tubing hanger won't pressure test due to eroded and/or corroded BPV profile and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via \ email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to� witness. 'Cc'‘1' b. With stack out of the test path, test choke manifold per standard procedure A,,5 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 G6 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.) 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. • • Well Prognosis Well: MPU S-34 lcorp Alaska,LL) Date: 12/11/2015 6. Pull TWC. Bleed any pressure off tubing and casing to 500 bbl returns tank. Kill well w/8.5 ppg seawater as needed. 7. MU landing joint or spear and recover the tubing hanger. Take care when laying down tubing hanger with blast rings (hanger/blast rings will be re-used). Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Contingency: If the tubing is not free: a. RU e-line. PT wireline BOPE and lubricator to 1500 psi b. RIH with tubing cutter and cut tubing at±9968' MD (in the middle of the 10.13' pup joint above the 3-1/2" X @ 9973.79' MD). Note: Hole angle is 75.5° at cut depth. Contingency: Use wire line tractor if necessary to convey tubing cutter on depth. c. POOH and RD e-line. 8. RU i-wire spooler. POOH and laydown the 4-1/2" x 3-1/2" tubing to the cut. Inspect and re-use tubing. RD i-wire spooler. 9. Mill and recover packer on 3-1/2" drillpipe. Establish parameters and mill Baker Premier packer at 9984' MD. Circulate well clean at maximum rate. Watch for gas under packer. Pump hi vis sweeps and reverse circulate if necessary to clean wellbore. POOH. 10. RIH with bit/scraper. Space out scraper to cover packer setting area. Make two short trips through • packer setting area. Pump hi vis sweeps and reverse circulate if necessary to clean wellbore. POOH. 11. RU i-wire spooler. Run 4-1/2" completion as follows: a. °6" OD WLEG (for tie back receptacle) @ "10,140' MD b. 4-1/2" XN with RHC ball catcher @ —9,940' MD c. Packer @ —9900' MD - d. Gauge @ "9860' MD 0 Q e. Halliburton XD slidin sleeve @ —9820' MD(j6' `3"4t0M y f. Discharge gauge @ °9,830' MD �� g. 4-1/2" L-80 Tubing h. 4-1/2" GLM @ ^'2,100' MD w/ DC shear valve i. 4-1/2" L-80 Tubing j. 4-1/2" L-80 Space out pups k. 1 joint 4-1/2" L-80 Tubing • Bit s F d--fs(, I. Tubing hanger. 12. While rolling the pumps, sting 4-1/2" WLEG into tie back receptacle at 10,137' MD and watch for pressure increase. Space out WLEG inside tie back receptacle. MU tubing hanger and landing joint. 13. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off)weights on tally. 14. Drop the ball & rod and set the packer. Increase the pressure and test the tubing to 3500 psi for 30 minutes. Bleed off the tubing pressure to 1500—1700 psi. Test the IA to 3500 As�for 30 minutes. Bleed off the tubing pressure and shear the DC valve. Record and notate all pressure tests on chart 15. Set TWC. ND BOPE. /44 ( r fk ! ! Well Prognosis Well: MPU S-34 Ilileorp Alaska,LU Date: 12/11/2015 16. NU 4" 5,000#tree. Terminate i-wire. Test tubing hanger void to 500 psi low/5,000 psi high. Pull TWC. 17. RU hot oil and freeze protect well to 2100' MD if needed. Install BPV. 18. RD Nordic#3 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 19. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Choke Schematic 5. Existing Tree/Wellhead 6. Nordic#3 Flow Diagram 7. Blank RWO Changes Form • * Milne Point Unit . 11 Well: MPU S-34 • SCHEMATIC Last Completed: 9/2/2003 Hiker!Alaska,LLC PTD: 203-130 TREE/WELLHEAD Tree 4-1/6"5M FMC 11"x 4-1/2"SM Gen 6 w 4.5"TC-IIT&6 Tubing Orig.DF Elev=72'/OrigTbg.Hgr Elev.=29.7 Doyon 14 Wellhead Hanger CIW"H"BPV profile j r F ' OPEN HOLE/CEMENT DETAIL 20'x : is 20" 260 sx of Arcticset in 42"Hole 10-4/4" 935 sx PF'1!,371 sx Class"G",Top Job 54sx PF'L' in 13-1/2"Hole 7" 725 sx Class"G"in 9-7/8"Hole 1 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" _ Conductor 215/A-53/Welded 17.938 Surf 112' N/A 10-3/4" _ Surface 45.5/L-80/Btrc. 9.950 Surf 5,518' 0.0962 7-5/8" Intermediate 29.7/L-80/IBT-M 6.875 Surface 11,159' 0.0459 10-3/4"'y • LINER DETAIL 4-1/2" NE Solid Liner 12.6/L-80/IBT 3.958 10,127' 13,091' N/A 4-1/2" NE Slotted Lnr 12.6/L-80/IBT 3.958 10,224' 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.958 10,273' 13,232' N/A 4-1/2" OA Slotted Lnr 12.6/L-80/113T 3.958 10,504' TUBING DETAIL 4-1/2" Tubing 12.6/L-80/IBT 3.958 Surf 0.0152 10,040' 3-1/2" Tubing 9.2/L-80/TC-II 2.992 Surf 0.0087 WELL INCLINATION DETAIL KOP @ 280'MD Hole Angle Passes 50 Deg.@ 2,150' 1 Max Angle in Tubing=78 Deg. 1 75 Deg.at sliding sleeve JEWELRY DETAIL No Depth Item 1 2,101' CAMCO 4.5"x 1"w/BK Latch Side-pocket KGB-2 GLM 2 9,923' Phoenix Discharge Gauge:ID=3.850" 3 9,934' 4.5"HES"XD"Dura Sliding Sleeve:ID=3.813"(opens Down)Jet Pump Removed 11/21/2015 4 9,957' Phoenix Jet Pump Gauge Sensor:ID=2.840"(4,068"ND) 2 j 5 9,962' 4.5"x 3.5"X-Over I ` 6 9,973' 3.5"HES X-Nipple:ID=2.813" i U 3 9 Ga,, 7 9,983' 3.5"x 4.5"X-Over /L 8 9,984' 7-5/8"x 4.5"Baker Premier Packer:ID=3.875" 5 ,,,,...,/f 9 9,991' 4.5"x 3.5"X-Over 8 6 10 10,034' 3.5"HES XN-Nipple:ID=2.750"No Go 11 10,039' WLEG—Bottom @ 10,040' 7 4 12 10,137' Baker 6'Tie-back Sleeve 9 ,l 8 13 10,146' Hook Wall Hanger Inside 7-5/8"Casing 14 10,171' Hook Wall Hanger Outside(Hook Point) 15 10,273' Baker 7'Tie-back Sleeve NOTE:Mn ID@ 10 tu 16 10,280' Baker ZXP Liner Top Packer 10,034'-2.750 ' 17 10,286' Baker 7-5/8"x 5-1/2"HMC Liner Hanger tu 11 OA LATERAL WINDOW DETAIL Window in 7-5/8"Casing @ 10,516'to 10,528'(MD)/4,199'to 4,201'(TVD) t� Well Angle @ window=77 Deg. 12 69jts-44/r Slotted Liner ✓ NE LATERAL WINDOW DETAIL '13 10,224'to 13,047' iiiii -s. 14 Window in 7-5/8"Casing @ 10,159'to 10,171'(MD)/4,115'to 4,117'(TVD) Well Angle @ window=78 Deg. NE,Lateral 363'Rat Hole 15 GENERAL WELL INFO 1 16 17 API:50-029-23171-00-00 Drilled and Cased by Doyon 14 -9/2/2003 • 4 Coil Clean-out and Jet Pump / /Removal 11 21 2015 "ON'Lateral 0 Rat Hole l . 7-5/8 \61jts-4-1/2"Slotted Liner TD=11,159'(MD)/TD=4,323'(1VD) 10,504'to 13,147' Revised By:TDF 12/2/2015(V) • • Milne Point Unit II Well: MPU S-34 PROPOSED Last Completed:9/2/2003 Hilcorp Alaska.LLC PTD: 203-130 TREE/WELLHEAD Tree 4-1/6"5M FMC Wellhead 11"x 4-1/2"5M Gen 6 w 4.5"TC-II T&B Tubing F El Orig.DF /OrigTbg Hgr Elev.297 14 4 . 'Doyon Hanger CIW"H"BPV profile --0 rel a4 OPEN HOLE/CEMENT DETAIL 20' I' « 20" 260 sx of Arcticset in 42"Hole 10-4/4" 935 sx PF'L',371 sx Class"G",Top Job 54sx PF'L' in 13-1/2"Hole 14, y 7" 725 sx Class"G"in 9-7/8"Hole g 1 1 #i: , CASING DETAIL ;; " Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 215/A-53/Welded 17.938 Surf 112' N/A 10-3/4" Surface 45.5/L-80/Btrc. 9.950 Surf 5,518' 0.0962 7-5/8" Intermediate 29.7/L-80/IBT-M 6.875 Surface 11,159' 0.0459 10-3/4".j LINER DETAIL 4-1/2" NE Solid Liner 12.6/L-80/IBT 3.958 10,127' 13,091' N/A 4-1/2" NE Slotted Lnr 12.6/L-80/IBT 3.958 10,224' 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.958 10,273' 13,232' N/A 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.958 10,504' TUBING DETAIL 4-1/2" Tubing 12.6/L-80/IBT 3.958 Surf ±10,137' 0.0152 WELL INCLINATION DETAIL €. KOP @ 280'MD Hole Angle Passes 50 Deg.@ 2,150' Max Angle in Tubing=78 Deg. 75 Deg.at sliding sleeve JEWELRY DETAIL No Depth Item 1 ±2,101' CAMCO GLM 2 ±9,833' Phoenix Discharge Gauge 3 ±9,844' 4.5"HES"XD"Dura Sliding Sleeve:ID=3.813"(opens Down) 4 ±9,867' Phoenix Jet Pump Gauge Sensor(4,068"TVD) 6 P 5 ±9,883' 4.5"HES X-Nipple:ID=3.813" 2 Pw 6 ±9,900' 7-5/8"x4.5"Production Packer:ID=3.875" 7 ±9,940' 4.5"HES XN-Nipple:ID=3.725"No Go 13 8 ±10,136' WLEG—Bottom @±10,137' 9 10,137' Baker 6'Tie-back Sleeve 4 t,, 10 10,146' Hook Wall Hanger Inside 7-5/8"Casing 11 10,171' Hook Wall Hanger Outside(Hook Point) x , 8 tt 12 10,273' Baker 7'Tie-back Sleeve ' 13 10,280' Baker ZXP Liner Top Packer j 6 14 10,286' Baker 7-5/8"x 5-1/2"HMC Liner Hanger ll '* OA LATERAL WINDOW DETAIL NOTE Mn ID@ 1 "? Window in7-5/8"Casing @10,516'to10,528'(MD)/4,199'to4,201'(TVD) 10,034'-2.750 7 Well Angle @ window=77 Deg. NE LATERAL WINDOW DETAIL , Window in 7-5/8"Casing @ 10,159'to 10,1711MD)/4,115'to 4,117'(TVD) w Well Angle @ window=78 Deg. 9 69jts-4-1/2"Slotted Liner GENERAL WELL INFO 8 { 10,224'to 13,047' I. 10 / API:50-029-23171-00-00 ,. , '�� 11 `/ Drilled and Cased by Doyon 14 -9/2/2003 0.1 J "W"Lateral 363'Rat Hole Coil Clean-out and Jet Pump Removal 11/21/2015 c.kr . 12 4444144,13;ITi * 14 �., ,0'Rat Hole Lateral Is 7-5/84 L \61jts-4-1/2"Slotted Liner TD=11,159'(MD)/TD=4,323'(TVD) 10,504'to 13,147' Revised By:PC 12/8/2015(V) • ! Milne Point . fitNordic#3 BOP If rp 814144.i i A: in in in Hydril 11" 5M , au iii 1i1 iii iii ..-- Hyd4: . !".41114. ' 0 �s Pipe or VBR Rams el . .. rt 11'c5M —• Blinds ---\ —7-J 3 3 1/8 5M Kill Valves 1 ® 3 1/8 5M Choke Valves Manual and HCR I Manual and HCR tr., i i -k il 0:411k v , (l Ali �- t— Hydril — i__ 11" 5M j 4 1/2" Pipe Rams — G� 0, - - �A , �rvurt_ _ rt () 'idA W ArA Y � k x h.14WA,31�-i4 Jr i.tlw v v v 4 vl v v w ,. v M v v v 0 V...99'0,-%^9.4 111111 CO :::: ... Alt'. 0 A1*1 ' * *:::: :: : :'A X::::*A * A.0,::::* 0 .:.: v69...",;64.1.°.991^ > z e N, c . o- ♦ 7 ' k I k V4 V , ION& ° tit: '''. 71 11 //,‘"'" . jil _ , _ v v , v , _ , „v.v......„-v„.„ hYy Y .. ,,,, A Int , R - Xi v 0','V'A',',6,a w a . v ,. I • I 4spe, 0 , 0 9 . 9 , 4999i V9 . 4 TA VO . Vk % 1 0 ' '''''' r'.',..'^''''...''''....^ '.'6 .. A ' "'ill l'AV^'''' ' '''''''''''''''''%' ,.,,,,,,,,,,,.. ,,,, =,,...%.,,,,,,,,,, ,, ,,,:0)10 ,„, , „ . „ . „ , , , , . .:.,,,,,.„.,, ti r ,/rot I TNI I 4 ' ICI v�CI ...—. . A a - X : 711.11)4 -: ki4L, �` It . . iik.,... IF ''''" Cf11:10 :::::::::::::' Int/CI 1'1N . I e 9A . w A 9 ef) , , ,f. , . . , . . . f .000 , ,, ., A �» A X ya ei IN Q x$ Ili v'IRI I91'In fin v v — IX[ 1111 191 111 IbI IRI 191 Iql _ T. ry 1.1 v M+ P118 h M&h i! A y.*,i,PQM+I 0 x v . wg.".1.*.'.*.*.'' Y v v v Y x n n A a r �Y�Y Y h h h w> h yhFihYhYbYAYh 'el", n ,u A . w ♦ . A A �♦ a + A A A e m n. C/ - • • MPU S-34 EXISTING TREE/WELLHEAD Wellhead/Tree Eiaeorp Alaska,TLCMilne Point Unit Tree Cap 121 1i1 O„ Tree Valve 4-1/16" 5M ^1 o '6, ODO; IE1 of mmil Tree Cross 4-1/16" 5M ° o oho)o Tree Valve 4-1/16" 5M s S SSV 4-1/16" 5M isit'ILII SAM ....,1101 Mil Tree Valve 4-1/16" 5M 1-‘4,10 0 6 -0 O•tional Control Line O . , p 6 as t`\ Tubing Adapter ...ism. F1 •0110 Tubing Head hsl lel 11" 5M Top x 11" 5M Btm IIc1"•' ":1 ■ [ t� r 1m1®6g .. I®i a III -' - E� Casing Head ,f't' 11" 5M Top x 11" 5M Btm � llit sin �t .l 1 p-i..! 1' x 000, 1 0 m I 15 : ll ¢o 3a �� . rc a�R U _ ¢ N ¢w 41. T1•'" vl_i i N - .. . ::: pin 0E ce Y • 1.w W '' 52. �I . __._. QJ A *@ a W 3 • gN :iismrs 3 3xN� _ ¢9rc0 zaw1 fZUi _ DU=t-*ili 1 m 4 o w 1 Y m 1(x: . a oW U 3V I I Y Y 4Y 11 I. fl — U . A m . • I . f _ Y - Y 01111 l035ng 5¢3 m f 1 E U 1 O E 0— ° E U E U E 2 1 f E U V ' f.* f * f! f .e. U c 3 _ 'o � O_ • a S f� E , E N U r. • N O o t h_ c (5 Y 5Mi F er w c 0 U UO O j J H n L1 o 4 w� , • • � R / > ƒ 2 0 CD Um c 7 / Oo2 .§ 7 0D_ § < <a E - G oc _ 0 a) E > d f 2 I a . .§ a a ±.E m c L- D 2 / / 22 o \ = / / I 0.w � (xi E.) � m § .SL) a) a) 2 \ k k o % 27 k9- CD % 4 — 0 k / eL O k co & Cn L U 214. m k/ / m \ 0 \ "00 o o \ � / 0a E § a a) o ° 0 2 og • •Y § / / a _ U) \ ƒ c a) »7 2 c § 2 •/ 2 . 2 / 0 2 3 CD 2 § \ - r.I \ 0 ~ a. kG ■ CL 2 I.4 C71 L - « 0 ' W 0 ■ / o c - ci co E O w q 2 § \co / I- g ett E CS § / . & / ) w O o CO0 ii Cu a « 0 - GGk TO- = RI - E0 0. > E M 0 k k CO < 2 STATE OF ALASKA • ALItA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Remove Jet Pump El Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: CT Fill Clean-out ❑✓ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development E Exploratory ❑ 203-130 • 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-23171-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380109 ' MILNE PT UNIT SB S-34 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): • N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth measured 11,159 • feet Plugs measured N/A 'itritECMED true vertical 4,323 • feet Junk measured N/A feet DEC 082015 Effective Depth measured 10,516 feet Packer measured 9,984 feet true vertical 4,199 feet true vertical 4,074 feet OGCC Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 110' 110' N/A N/A Intermediate 5,518' 10-3/4" 5,518' 2,894' 3,580psi 2,090psi Production 11,159' 7-5/8" 11,159' 4,246' 6,890psi 4,790psi NE Liner 2,964' 4-1/2" 13,091' 4,225' 8,430psi 7,500psi AO Liner 2,959' 4-1/2" 13,232' 4,234' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 3-1/2" 9.2#/L-80 NSCT 9,964' 4,070' Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80/IBT-M 10,040' 4,088' 9,984'(MD) Packers and SSSV(type,measured and true vertical depth) 7-5/8"x 4.5"Premier N/A 4,074(TVD) N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A y��g �[ } Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1,424 234 Subsequent to operation: 0 0 0 1,402 231 14.Attachments(required per 20 AAC 25.070.,2x071,&25.283) 15.Well Class after work: • Daily Report of Well Operations ❑., Exploratory❑ Development❑✓ Service ❑ Stratigraphic El Copies of Logs and Surveys Run El 16.Well Status after work: Oil U , Gas Li WDSPL U Printed and Electronic Fracture Stimulation Data CI1GSTOR LI WINJ ❑ WAG Li GINJ ❑ SUSP ElSPLUG LI 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: fAy/ e 315-477 Contact ` _ 1o„ Stan Porhola Email sporhola@hilcorp.com Printed Name Bo York Title Operations Engineer Signature-"` Phone 777-8345Date 12/312$1-5 /,�.'/>-/5 RBDMS �eLL 1 1 1015 Form 10-404 Revised 5/2015 /yam _ �6�� Submit Original Only • • Milne Point Unit Well: MPU S-34 II SCHEMATIC Last Completed: 9/2/2003 Hilcorp Alaska,LLC PTD: 203-130 TREE/WELLHEAD Tree 4-1/6"5M FMC Wellhead 11"x 4-1/2"5M Gen 6 w 4.5"TC-IIT&B Tubing DF El Orig. ev=72'/Orig Mg.Hgr Elev.29.7'Doyon 14 Hanger CIW"H"BPV profile 4 :,, .,, ,`i OPEN HOLE/CEMENT DETAIL 3 .s y. r 20" 260 sx of Arcticset in 42"Hole 10-4/4" 935 sx PF l',371 sx Class"G",Top Job 54sx PF'L' in 13-1/2"Hole 1 7" 725 sx Class"G"in 9-7/8"Hole 1 g. . CASING DETAIL )v 4. Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 215/A-53/Welded 17.938 Surf 112' N/A 10-3/4" Surface 45.5/L-80/Btrc. 9.950 Surf 5,518' 0.0962 ` 7-5/8" Intermediate 29.7/L-80/IBT-M 6.875 Surface 11,159' 0.0459 10-3/4" LINER DETAIL 4-1/2" NE Solid Liner 12.6/L-80/IBT 3.958 10,127' 13,091' N/A 4-1/2" NE Slotted Lnr 12.6/L-80/IBT 3.958 10,224' 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.958 10,273' 13,232' N/A 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.958 10,504' TUBING DETAIL 4-1/2" Tubing 12.6/L-80/IBT 3.958 Surf 0.0152 10,040' 3-1/2" Tubing 9.2/L-80/TC-II 2.992 Surf 0.0087 WELL INCLINATION DETAIL KOP@280'MD Hole Angle Passes 50 Deg.@ 2,150' Max Angle in Tubing=78 Deg. 75 Deg.at sliding sleeve JEWELRY DETAIL No Depth Item 1 2,101' CAMCO 4.5"x 1"w/BK Latch Side-pocket KGB-2 GLM 2 9,923' Phoenix Discharge Gauge:ID=3.850" 3 9,934' 4.5"HES"XD"Dura Sliding Sleeve:ID=3.813"(opens Down)Jet Pump Removed 11/21/2015 4 9,957' Phoenix Jet Pump Gauge Sensor:ID=2.840"(4,068"ND) 2 5 9,962' 4.5"x 3.5"X-Over a 6 9,973' 3.5"HES X-Nipple:ID=2.813" .-, 111 3 ;-) 7 9,983' 3.5"x 4.5"X-Over 1, — y) 8 9,984' 7-5/8"x 4.5"Baker Premier Packer:ID=3.875" 4 9 9,991' 4.5"x 3.5"X-Over 6 •) 10 10,034' 3.5"HES XN-Nipple:ID=2.750"No Go rl a 11 10,039' WLEG–Bottom @ 10,040' • an 7 12 10,137' Baker 6'Tie-back Sleeve 8- 13 10,146' Hook Wall Hanger Inside 7-5/8"Casing ME 9 14 10,171' Hook Wall Hanger Outside(Hook Point) 15 10,273' Baker 7'Tie-back Sleeve NOTE:Mn ID@ ;, _,- 10 , 16 10,280' Baker ZXP Liner Top Packer 10,034'-2.750 ,, 17 10,286' Baker 7-5/8"x 5-1/2"HMC Liner Hanger 11 OA LATERAL WINDOW DETAIL "II Window in 7-5/8"Casing @ 10,516'to 10,528'(MD)/4,199'to 4,201'(TVD) Well Angle @ window=77 Deg. Nt2 +13 10,224'to 13,047'69jts4 -4-1/2"Slotted Liner NE LATERAL WINDOW DETAIL ?' Window in 7-5/8"Casing @ 10,159'to 10,171'(MD)/4,115'to 4,117'(ND) ti� 1 14 )'1 4 ' Well Angle @ window=78 Deg. �} eral 363'Rat Hole 15f GENERAL WELL INFO 16 ;., 17 API:50-029-23171-00-00 Drilled and Cased by Doyon 14 -9/2/2003 \.... ,0'Rat Hole Coil Clean-out and Jet Pump Removal 11/21/2015 7-5/8' l \61jts-4-1/2"Slotted Liner TD=13,234'(MD)/TD=4,234'(1VD) 10,504'to 13,147' Revised By:TDF 12/2/2015(V) • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-34 Coil 50-029-2317-00-00 203-130 11/21/15 11/22/15 Daily Operations: 11/18/2015-Wednesday No activity to report. 11/19/2015-Thursday No activity to report. 11/20/2015 - Friday No activity to report. 11/21/2015-Saturday Hold safety meeting. Review SLB JSA. Remove night cap. Stab on well. Start BOPE test.Test all rams and valve to 250psi low/4,500psi high. BOPE test complete. Blow down to OT. Pop off well. MU BHA. 2" Cold Roll connector, 2" DFCV, 2" MBT, 2" MBT, 2.13" x over, 3.5" nozzle. BHA length 10.6'. Stab on well. Pressure test stack 250psi low/4,500psi high. Displace 60/40 with sea water to 50 bbl methanol storage @ 2bbls/min. IA pressure 350 psi. OA pressure 298. Master swab open 23 turns. 200psi whp dropping to 174psi. RIH. Bump pump and min rate occassionaly while RIH to keep reel warm. Weight check 3,000' 12.8k, 6,400' 18.9k, 9,000' 26k. Dry tag top of fishing neck at 9,925'. Pick up 100' 26k clean. Coming online with 80 degree seawater at 2 bbls/min. Start bottoms up at 131 away. Stack 3k down on fishing neck. @ 175, or 45 bbls of bottoms up away POOH. Bottoms up completed. Swapping to 60/40 for freeze protection. @ 250 on counter. 300 bbls pumped. Blow down stack. Pop off well. Cut off coil connector. Make up external slip connector. Pull test 25K. Pressure test to disconnect 250psi low/3,500psi high. Stabbed on well. Lined up for PT down back side. Pt 250psi low/4,500psi high. Line up with seawater down CT. Circulate 60/40 to 50 bbl methanol tank. IA 783psi, OA 308psi. IA warming up from circulating 85 degree water in wellbore. WHP 150psi. Open well 23.5 turns. RIH. Perform weight check at 9,903'. 27k. RIH 2,500 lbs RIH wt stack 2k down at 9,923.5'. 15k overpull. Pick up to 45k. No lick after 10 minutes. RIH to re-cock jars. Pick up to 40k. Waiting for 15k jar lick.Jars hit 15 minutes pick to 46k. RIH stack to 9,924.5. Pick up for 2nd jar lick to 43k. @ 9913'. 11 min .K jars hit. RIH to cock jars-5k. Pick up for 3rd jar lick. 112,000 lb jar. 46k to 9,913.7'. 3rd lick. PUII to 52k. RIH reset jars. 12minutes for jar lick. Picking up to 50k. 9,912.9'jar lick pu 52k. 9,910.7 (12min). RIH reset. Up to 50k wait on lick. Hit. Pick up to 54k. RIH reset. PU for 6th jar lick. 9,911.4' 52k, lick 8 minutes pick up to 55k. Pick up. Pulling heavy at 9,890'. Broke free on 6th jar lick. Picked up to 58k. Ran back in hole and did not stack weight at 9,923'. Ran past profile and WHP and IA went to -30 psi. X lock opened and dogs retracted. 9,938' started POOH. Tagged up at surface. Close master and swab 23.5 turns. Blow down pop off. Pump Recovered. Break down tools. Stack down. Install Night cap. Location secure. ! • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-34 Coil 50-029-2317-00-00 203-130 11/21/15 11/22/15 Daily Operations: 11/22/2015-Sunday Safety meeting. Discuss job procedure and review SLB JSA. Pick injector head. Dress Coil. Make up BHA 2.0" CC, 2.0" Check valves, 2.0" MBT, 2.0" MBT, 2.13" X-over, 2.25"Jet swirl Nozzle.Total BHA length 10.615'. Stab on well. Pressure test stack to 250psi low/4,500psi high. Bleed down. Open well. Well on vac. IA on vac. RIH with choke closed. Start building WHP at 5,800'. IA Climbing with wellhead. Crack choke. Returns of fluid to surface. Continue in Hole not pumping to dry tag. Dry tagged at 10,451'. Pick up 30k. Come online at 1.8 bbls/min 2,500psi circ pressure. Wash back to tubing tail @ 10,000'. Returns look to be 1:1. RIH to cleanout lateral. RIH wt. 3k @ 10,100'. Light stack at 10,453'. Breaking off or popped in hole. Stack little weight and then breaks back. Cleaning off well. 1.8 bbls/min in 4.5" is giving us a good annular velocity of 158 ft/min. Cleaning out. Stack weight at 10,670'. Pick up clean. 10,745' pu wt 35k. PU at 10,835'. Clean 32k. RIH continue to clean out. 11,530'. Stacking weight. Pick up to tubing tail. RIH, consistent stack at 10,451'. Stacking 10k @ 10,450'. Multiple times. Made it past one time. Stacking again at 10,451'. Clean pick ups to 30k. Clean pick ups but stacking weight at consistenity at 10,451'. 436 bbls pumped for cleanout. Pull into tubing tail and finish bottoms up. Out of fluid.Vac truck on location with 300 bbls of 100 degree seawater filling upright. Rigging up a pump line. Pressure test 250psi low/ 1,500psi high. Open IA. IA wing valve opened. Master swab open, P subs open. Lined up through choke to OT. 2 bbls/min 96psi on annulus. Increase rate to 2.5 bbls/min. 6.4 bbls away returns up tubing to surface. 4.0 bbls/min at 477psi. WHP/tubing pressure 50psi. OA reading 250psi. 4.6 bbls/min @ 609psi.WHP, tubing 85 psi. 5 bbls/min. 665 psi. 92psi tubing. 100 bbls pumped. 756 psi IA pressure and 150psi tubing/wellhead pressure. 165 bbls away. 5 bbls/min. 858psi pump pressure. 293psi WHP. Opened bypass on choke. Pressure droppd to 191psi. 280 bbls pumped. 290 bbls pumped. Swapped to methanol to freeze protect. 20 bbls of 60/40 pumped down IA. 8 bbls of 60/40 pumped down tubing. POOH. Master swab closed. Rigging down CTU 4. Location walk around complete. Location secure. Returns during operation looked to have small traces of sand and top layer of OT tank had 6" of greasy foam. 11/23/2015-Monday No activity to report. 11/24/2015-Tuesday No activity to report. MMMIMMMMIMMMMONMMMMMMMIIMMMMNMIMNMMMMMIMIMMMIMIIIMIIMIIIII OF Tye THE STATE Alaska Oil and Gas 7 o Conservation Commission _ fALASIKi\. = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFALASI1P Fax. 907.276 7542 www aogcc.alaska gov Stan Porhola Operations Engineer o 3- G3 Q Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB S-34 Sundry Number: 315-477 SCANNED Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 1°23tz4V-c_ Cathy . Foerster Chair DATED this day of August, 2015 Encl. RBDMS SEP 0 4 2015 �7 ri STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION L\L' 0 5 /1 APPLICATION FOR SUNDRY APPROVALS crsiS s ( L 3 20 MC 25.280 AUGCC 1.Type of Request. Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing E Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate 0 Alter Casing ❑ Remove&Replace Jet Pump 2 Plug for Redril❑ Perforate New Pool ❑ Repair Well Q Re-enter Susp Well ❑ Other. CT Fill Clean-out Q 2 Operator Name: 4.Current Well Class: 5.Permit to Drill Number: H/corp Alaska,LLC' Exploratory ❑ Development 2- 203-130. 3.AddressStratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23171-00-00 . 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.477.05 Will planned perforations require a spacing exception? Yes ❑ No 0 ✓ MILNE PT UNIT SB S-34 r 9 Property Designation(Lease Number): 10.Field/Pool(s). ADL0380109 , MILNE POINT/SCHRADER BLUFF OIL• 11. PRESENT WELL CONDITION SUMMARY Total Depth j1D�(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft)PA/3 Plugs(measured): Junk(measured): iJ( 11 rod. `14_1254i. N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 110' 110' N/A N/A Intermediate 5,518' 10-3/4" 5,518' 2,894' 3,580psi 2,090psi Production 11,159' 7-5/8" 11,159' 4,246' 6,890psi 4,790psi NE Liner 2,964' 4-1/2" 13,091' 4,225' 8,430psi 7,500psi AO Liner 2,959' 4-1/2" 13,232' 4,234' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size. Tubing Grade. Tubing MD(ft): 3-1/2" 9 2#/L-80 NSCT 10,040 See Attached Schematic/ See Attached Schematic 4-1/2" 12.6#/L-80/IBT-M Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7-5/8"x 4.5"Baker Premier and N/A t 9,984'(MD)/4,074'(TVD)and N/A 12.Attachments: Description Summary of Proposal Q 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. 8/20/2015 ❑ - ❑ WDSPL ❑ Suspended [1Commencing Operations. OIL WINJ 16.Verbal Approval: Date. N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Stan Porhola Email sporhola@hilcorp.com Printed Name Stan orhola Title Operations Engineer • Signature ;,,, " / Phone 777-8412 Date 8/5/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 315 -L177 L {77 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance 0 y Other. 3e,00 / . au ` w/ -s A� CAT1A S,' 0 to- .) Spacing Exception Required? Yes 0 No [ Subsequent Form Required: /O _4/09 RBDMSc SEP 0 4 2015 APPROVED BY Approved by: a..g7? ppt, y + COMMISSIONER THE THE COMMISSION _/ Date: S-� .- �t� o ipp;ov71 r ' A ziy Submit ane Form 10-403 Revised 5/2015 ation is;alkt rt/{t_Jl1e ate of approv Attachments in Duplicate Well Prognosis Well: MPU S-34 IIikoru Alaska,Lb Date:8/04/2015 Well Name: MPU S-34 API Number: 50-029-23171-00 Current Status: SI Oil Well [Jet Pump] Pad: S-Pad Estimated Start Date: August 20th, 2015 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 203-130 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: 1,410 psi @ 4,000' TVD (Last BHP measured 3/23/2015) Maximum Expected BHP: 1,410 psi @ 4,000'TVD (No new perfs being added) Max.Allowable Surf Pressure: 0 psi (Based on SBHP taken 3/23/2015 and water cut of 50% (0.385psi/ft)with an added safety factor of 1,000' TVD of oil cap) Brief Well Summary: MPU S-34 was drilled in 2003 using Doyon 14 and completed as a dual-lateral in the Schrader Bluff NE and OA sands with a Jet Pump. Notes Regarding Wellbore Condition • Deviation down to pump section (max angle 77.2° @ 4,886'). Deviation at pump is 76°. • Casing last tested to 250/3,500 psi for 30 min down to 9,546'on 8/21/2003. • Jet Pump SI, performance impacted by solids on top of pump. Objective: The purpose of this work/sundry is to pull the existing Jet Pump, cleanout the tubing tail and OA lateral with coil tubing, pull the existing completion with the ASR#1 rig, cleanout fill, and run a new Jet Pump completion. Brief Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing, PT BOPE to 4,500 psi Hi 250 Low. 2. RIH w/2.00" coil w/3.5" wash nozzle and cleanout to top of Jet Pump+/-9,934' MD. POOH. a. Min ID is 3.813" thru Sliding Sleeve. 3. RIH w/2.00" coil w/GS pulling tool and pull Jet Pump+/-9,934' MD. POOH. 4. RIH w/2.00" coil w/3.5"wash nozzle to sliding sleeve at+/-9,934' MD. 5. Bullhead filtered 8.4 ppg produced water down annTnklus, lifting sand/solids up the 2.0" coil x 4.5" tubing annulus. POOH. Jf'� 6. RIH w/2.00" coil w/2.5" wash nozzle and cleanout to end of OA lateral at+/- 13,147' MD. POOH. a. Min ID is 2.750"thru XN Nipple. 7. RIH w/2.00" coil w/jet cutter and make cut across packer mandrel at+/-9,984' MD.( 8. PU to+/-9,900' MD. Displace well over to 8.4 ppg produced water. a. Estimated volume (w/o coil in hole) is 150 bbl. 9. POOH w/coil. LD 2.5" wash nozzle. 10. RD Coiled Tubing. Well Prognosis Well: MPU 5-34 Hilcorp Alaska,Lb Date:8/04/2015 11. Turn well over to production. WO Rig Procedure: A S 12. MIRU Hilcorp ASR#1 WO Rig. 13. Circulate well with 8.4 ppg lease water down tubing thru sliding sleeve and fill casing. 14. Set BPV. ND Tree. -11 15. NU 11" BOPE. Test to 250 psi Low/3,000 psi High, annular to 250 psi Low/ 1 psi High (hold each valve and test for 5-min). Record accumulator pre-charge pressures nd chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Test VBR rams on 2-7/8"test joint and 4-1/2" test joint. 16. Bleed any pressure off tubing and casing. Pull BPV. 17. MU landing joint and pull 10k tension over string weight on tubing hanger to confirm packer cut. c. ***Contingency*** If landing joint won't make up to tubing hanger(bad threads). d. MU spear and pull 10k tension over string weight on tubing hanger to confirm packer cut. LAfr' i. ***Contingency*** If packer is not fully cut. 54'r1it ii. LD landing joint/spear. lz iii. MIRU E-line. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. t) j/3S iv. BOPE connection is 11" studded top for lubricator on top of annular. /VI t° v. MU 2-1/4"jet cutter. vi. RIH and cut packer at+/-9,984'. ,v vii. POOH. RD E-line. ;1� viii. MU landing joint or spear. Pull tension to confirm packer cut. n ` 18. POOH. Lay 4-1/2" tubing on the pipe rack(send off location for inspection). U 19. LD packer and all jewelry.Spool back `I'wire control line. 20. MU 6-3/4" bit,jars,casing scraper and RIH w/2-7/8"tubing. 21. Clean out casing down to tie-back sleeve at+/- 10,134' MD. a. Min ID is 5.75". 22. POOH. Lay down bit,jars, casing scraper. Lay down 2-7/8"tubing. 23. PU RTTS and RIH w/2-7/8"tubing. 24. Set RTTS at+/- 10,100' MD.Test casing to 3,500 psi for 30 min. 25. Release RTTS. POOH. LD RTTS. Lay down 2-7/8" tubing. z3 /4 ; y,�a • ""� 26. PU 3.75" bit, 2-3/8" PH-6 cleanout string and jars and RIH w/2-7/8"tubing. d adh 4s. 27. Cleanout OA lateral down to+/- 13,147' MD. G7&L tL' ? a. Min ID is 3.88". zAr fc6) 28. Circulate bottoms up x 2 with 8.4 ppg lease water. 29. POOH. Lay down 3.75" bit,2-3/8" cleanout string. Lay down 2-7/8" tubing. 30. PU new 7-5/8" completion packer and jewelry. RIH w/new 4-1/2" IBT L-80 tubing. e. RU to use clamps to secure 'I' wire control line to tubing (ensure adequate clamps). 31. Set WLEG at+/-10,100' (Sliding sleeve around +/- 10,000'). Land tubing hanger. 1;lv 1 _A 32. Lay down landing joint. Set BPV. ND BOPE. NU existing 4-1/16" 5,000#tree. Pull BPV. z 5 p 33. Set TWC.Test tubing hanger to 250/5,000 psi.Test tree to 250/5,000 psi. Pull TWC. G , 34. RD Hilcorp ASR#1 WO Rig. 35. Replace IA x OA pressure gauge if removed (7-5/8" x 10-3/4"). 36. Turn well over to production. Attachments: 1. As-built Schematic 11 Well Prognosis Well: MPU S-34 Hilcora Alaska,Lb Date:8/04/2015 2. Proposed Schematic 3. Coil BOPE Schematic 4. BOPE Schematic 14Milne Point Unit Well: MPU S-34 SCHEMATIC Last Completed: 9/2/2003 Mean)Alaska,LLC PTD: 203 130 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm Orig.DF Elev=72'/Ong Mg.Hgr Elev.=29.7'Doyon 14 20" Conductor 215/A-53/Welded 17.938 Surf 112' 10-3/4" Surface 45.5/L-80/Btrc. 9.950 Surf 5,518' 7-5/8" Intermediate 29.7/L-80/IBT-M 6.875 Surface 11,159' LINER DETAIL 4-1/2" NE Solid Liner 12.6/L-80/IBT 3.958 10,127' 13,091' 4-1/2" NE Slotted Lnr 12.6/L-80/IBT 3.958 10,224' 1 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.958 10,273' 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.958 10,504' 13'232 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/IBT 3.958 Surf 10,040' 3-1/2" Tubing 9.2/L-80/TC-II 2.992 Surf 10-3/4" a JEWELRY DETAIL No Depth Item 1 2,101' CAMCO 4.5"x 1"w/BK Latch Side-pocket KGB-2 GLM 2 9,923' Phoenix Discharge Gauge:ID=3.850" 3 9,934' 4.5"HES"XD"Dura Sliding Sleeve:ID=3.813"(opens Down) 4 9,957' Phoenix Jet Pump Gauge Sensor:ID=2.840"(4,068"TVD) 5 9,962' 4.5"x 3.5"X-Over 6 9,973' 3.5"HES X-Nipple:ID=2.813"_ _ 7- 9,983' 3.5"x 4.5"X-Over 1Jo 9,984' 7-5/8"x 4.5"Baker Premier Packer:ID=3.875" 9 9,991' 4.5"x 3.5"X-Over 10 10,034' 3.5"HES XN-Nipple:ID=2.750"No Go 11 10,039' WLEG—Bottom @ 10,040' 12 10,137' Baker 6'Tie-back Sleeve 13 10,146' Hook Wall Hanger Inside 7-5/8"Casing 14 10,171' Hook Wall Hanger Outside(Hook Point) 15 10,273' Baker 7'Tie-back Sleeve 16 10,280' Baker ZXP Liner Top Packer 17 10,286' Baker 7-5/8"x 5-1/2"HMC Liner Hanger NE LATERAL WINDOW DETAIL Window in 7-5/8"Casing @ 10,159'to 10,171'(MD)/4,115'to 4,117'(TVD) lI 2 Well Angle @ window=78 Deg. OA LATERAL WINDOW DETAIL IO 3 Window in 7-5/8"Casing @ 10,516'to 10,528'(MD)/4,199'to 4,201'(TVD) 4 Well Angle @ window=77 Deg. .1s 5 WELL INCLINATION DETAIL 6 KOP@280'MD air 7 Hole Angle Passes 50 Deg.@ 2,150' 'JIM 9 Max Angle in Tubing=78 Deg. 75 Deg.at sliding sleeve 10 . OPEN HOLE/CEMENT DETAIL 20" 260 sx of Arcticset in 42"Hole 11 10-4/4" 935 sx PF'L',371 sx Class"G",Top Job 54sx PF'L' in 13-1/2"Hole 7" 725 sx Class"G"in 9-7/8"Hole • TREE/WELLHEAD •12 69jts-4-1/2"Slotted Liner Tree 4-1/6"SM FMC 10,224'to 13,047' 13 11"x 4-1/2"5M Gen 6 w 4.5"TC-IIT&B Tubing Wellhead 14 - Hanger CIW"H"BPV profile °rF. eral 363'Rat Hole GENERAL WELL INFO 1s 16 API:50-029-23171-00-00 17 Drilled and Cased by Doyon 14 -9/2/2003 `\ 41— "OA"Lataal rte, 0'Rat Hole 7-5/8'' l It\61jts-4-1/2"Slotted Liner TD=13,234'(MD)/TD=4,234'(TVD) 10,504'to 13,147' Revised By:STP 8/04/2015 Milne Point Unit . II Well: MPU S-34 PROPOSED SCHEMATIC Last Completed: Proposed Hilcorp Alaska,LLC PTD: 203-130 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm Orig.DF Elev=72'/Orig Tbg.Hgr Elev.=29.7'Doyon 14 20" Conductor 215/A-53/Welded 17.938 Surf 112' 10-3/4" Surface 45.5/L-80/Btrc. 9.950 Surf 5,518' 7-5/8" Intermediate 29.7/L-80/IBT-M 6.875 Surface 11,159' 20'j LINER DETAIL 4-1/2" NE Solid Liner 12.6/L-80/IBT 3.958 10,127' 13,091' 4-1/2" NE Slotted Lnr 12.6/L-80/IBT 3.958 10,224' (( I 1 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.958 10,273' 13,232' `VV • 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.958 10,504' TUBING DETAIL 4-1/2" Tubing 12.6/L-80/IBT 3.958 Surf 10,100' 10-3/4" A & JEWELRY DETAIL No Depth Item 1 2,100' CAMCO 4.5"x 1"w/BK Latch Side-pocket KGB-2 GLM 2 9,983' Phoenix Discharge Gauge:ID=3.850" 3 9,994' 4.5"HES"XD"Dura Sliding Sleeve:ID=3.813"(opens Down) 4 10,017' Phoenix Jet Pump Gauge Sensor:ID=2.840"(4,068"TVD) 5 10,022' 4.5"x 4.5"X-Over TC-IIx IBT 6 10,033' 4.5"HES X-Nipple:ID=3.813" 7 10,043' 4.5"x 4.5"X-Over IBT x TC-II 8 10,044' 7-5/8"x 4.5"Baker Premier Packer:ID=3.875" 9 10,051' 4.5"x 4.5"X-Over TC-II x IBT 10 10,094' 4.5"HES XN-Nipple:ID=3.750"No Go 11 10,099' WLEG—Bottom @ 10,100' 12 10,137' Baker 6'Tie-back Sleeve 13 10,146' Hook Wall Hanger Inside 7-5/8"Casing 14 10,171' Hook Wall Hanger Outside(Hook Point) 15 10,273' Baker 7'Tie-back Sleeve 16 10,280' Baker ZXP Liner Top Packer 17 10,286' Baker 7-5/8"x 5-1/2"HMC Liner Hanger NE LATERAL WINDOW DETAIL Window in 7-5/8"Casing @ 10,159'to 10,171'(MD)/4,115'to 4,117'(TVD) 2 Well Angle @ window=78 Deg. OA LATERAL WINDOW DETAIL 3 Window in 7-5/8"Casing @ 10,516'to 10,528'(MD)/4,199'to 4,201'(TVD) q Well Angle @ window=77 Deg. WELL INCLINATION DETAIL } 6 KOP @ 280'MD 7 .ti§ 8 Hole Angle Passes 50 Deg.@ 2,150' 9 Max Angle in Tubing=78 Deg. 75 Deg.at sliding sleeve 10 OPEN HOLE/CEMENT DETAIL 20" 260 sx of Arcticset in 42"Hole 11 10-4/4" 935 sx PF'L',371 sx Class"G",Top Job 54sx PF'L' in 13-1/2"Hole 7" 725 sx Class"G"in 9-7/8"Hole TREE/WELLHEAD 12 69jts-4-1/2"Slotted Liner Tree 4-1/6"SM FMC :, / 10,224'to 13,047' 1311"x 4-1/2"SM Gen 6 w 4.5"TC-IIT&B Tubing Wellhead 14 . Hanger CIW"H"BPV profile iI it „NEa Ldal 363'Rat Hole GENERAL WELL INFO 15 ; API:50-029-23171-00-00 16 17 Ci= Drilled and Cased by Doyon 14 -9/2/2003 ..% r �. �� 0'Rat Hole 7-5/8''4 l '61jts-4-1/2"Slotted Liner TD=13,234'(MD)/TO=4,234'(TVD) 10,504'to 13,147' Revised By:STP 8/04/2015 Milne Point Unit COIL BOPE MPU S-34 irh rp;tim4,,IIIA. 07/28/2015 1 MPU S-34 20 X10% X7%X4% Coil Tubing BOP ILubricator to injection head MI 84,_iti 1.75"Tandem Stripper UM NMI — —; '•',I, Blind/Shear =• 1/16 10 =-Blind/Shear ,I,'•- • yr'•I,I,IBlind/Shear,",..M-.......I • . _ Blind/Shear 11101.4, ....... O , .,... -pit Slip 41111111 AIM M' Slip .i,'.0. IOW 1.I 111 Pipe - In: pipe uiui.1` Mud Cross IIIIIM! 4 1/16 10M X 4 1/16 10M Outlet w/2-2 1/16 10M full opening FMC valves � ane Ball ill III 01 1.0.111( 0 111,, , it HI ® ROI i Manual Manual Manual Manual 2 1/16 10M 2 1/16 10M ii ° 2 1/16 10M 2 1/16 10M Crossover spool a: 4 1/16 10M X 4 1/16 5M IIMI 1., . �,(- Valve,Swab,WKM-M, — �, �� 0FE 4 1/16 5M FE ��— �asle,Q \165 N /li ,irIv., ! I / • Valve,Upper Master,Baker, O 4 1/16 5M FE,w/Hydraulic r aimm• Valve,Lower Master,WKM-M, 1j?Ji � 4 1/16 5M FE 4= Tubing Adapter,4 1/16 5M �+L�\ . fir Milne Point 2015 ASR Rig 1 rrir,,,r, ‘1n.)a.r.u: Knight Oil Tools BOP 11" BOPE ' Stripping Head I" 11111111111 FF---' 3.98' 41/ P 1 Hydril 111 libiGK 11"-5000 iii iii ii; 1111111 H LLU ill � ' ; i , CIS -U '" 4.54' - _) CIA-U ° 2 7/8-5 variables tik ,� - 11' - 5000 ��miti. Blind .14 iia Iii ';,t 11 it 2 1/16 5M Kill Line Valves 1 2 1/16 5M Choke Line Valves >s p0 iQ Ili' ui UI 111 lily; 2.00 .��NJJ / T , ) •,- ; 1 ii 1 10.4 IHOF 'Ilia d1 1!i 111 1!1" - Manual Manual Manual HCR Updated 7/23/15 Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Tuesday, August 11, 2015 2:05 PM To: 'sporhola@hilcorp.com' Subject: MPU S-34L1 Good afternoon Stan: Please submit a separate sundry application for the proposed coil tubing clean-out of the MPU S-34L1 well. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 Image ~ject Well History File ccler Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ D3 - 13 0 Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 D Rescan Needed 1111111111111111111 RES CAN DIGITAL DATA ~skettes, NO.cd- D Other, NolType: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Color Items: D Greyscale Items: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: mP 111111111111111111I Date /~/I d-/ ôC /,/ VtlP á- X 30 - (Pó + {}- = TOTAL PAGES ~?- 1 1 - (Count does not include cover sheet) WI P Date: 18-- I ~I D5 /5/ 1111111111111111111 D Other:: BY: ~ Date: Ia- I.Y ()5 /5/ Project Proofing BY: A Scanning Preparation BY: ~ Production Scanning Stage 1 Page Count from Scanned File: {p 3 (Count does include cover sheet) Page Count Matches Number in Scanning Pr~paration: ~ YES ~ Date/,-/¡a-{DS" Stage 1 If NO in stage 1, page(s) discrepancies were found: NO BY: /5/ rv¡p YES NO BY: Maria Date: /5/ 1I1I11I111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: /5/ Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 5 1 E FEE 1= 4 2 Mr. Tom Maunder 13 O Alaska Oil and Gas Conservation Commission 3,03 333 West 7 Avenue _ 3 Anchorage, Alaska 99501 I v If Subject: Corrosion Inhibitor Treatments of MPS -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPS -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator . 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPS -Pad 10/11/2011 Corrosion Vol of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal MPS-01A 2070340 50029231410100 0.25 NA 0.25 NA 5.1 9/6/2011 MPS-02 2031270 50029231690000 2.5 NA 2.5 NA 23.8 7/30/2011 MPS-03 2021460 50029231050000 Open Flutes - Treated 1 MPS -04 2030520 50029231480000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-05 2021370 50029231000000 Open Flutes - Treated MPS-06 2031090 50029231630000 1.7 NA 1.7 NA 17.0 7/302011 MPS-07 2020720 50029230790000 1 NA 1 NA 13.6 11/3/2009 MPS-08 2031230 50029231680000 1.3 NA 1.3 NA 10.2 7/30/2011 MPS-09 2020200 50029230670000 0.5 NA 0.5 NA 5.1 11/3/2009 MPS -10A 2051250 50029231520100 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -11 2021130 50029230920000 1 NA 1 NA 10.2 7/29/2011 MPS-12 2030230 50029231390000 0.6 NA 0.6 NA 6.8 7/29/2011 MPS -13 2021240 50029230930000 1 NA 1 NA 11.9 11/3/2009 MPS-14 2031040 50029231620000 1.8 NA 1.8 NA 22.1 7/29/2011 MPS-15 2012450 50029230610000 9.6 NA 9.6 NA 88.4 7/31/2011 MPS -16 2030650 50029231510000 1.2 NA 1.2 NA 10.2 7292011 MPS -17 2021730 50029231150000 Open Flutes - Treated MPS-18 2022420 50029231330000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -19A 2022330 50029231210100 1.8 NA 1.8 NA 23.8 7292011 MPS-20 2022410 50029231320000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS-21 2020090 50029230650000 1.8 NA 1.8 NA 22.1 11/3/2009 MPS -22 2031470 50029231760000 9.1 NA 9.1 NA 83.3 7/28/2011 MPS -23 2021320 50029230980000 Open Flutes - Treated MPS -24 2030380 50029231420000 1.3 NA 1.3 NA 10.2 7/28/2011 MPS -25 2021030 50029230890000 Open Flutes - Treated - MPS- 26 2030610 50029231500000 1 NA 1 NA 8.5 7/28/2011 MPS-27 2020850 50029230840000 0.9 NA 0.9 NA 8.5 7/28/2011 MPS-28 2030940 50029231580000 1.1 NA 1.1 NA 11.9 7/28/2011 MPS-29 2021950 50029231190000 - Open Flutes - Treated MPS-30 2022360 50029231310000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS -31 2020140 50029230660000 Open Flutes - Treated MPS-32 2030920 50029231570000 0.8 NA 0.8 NA 6.8 7282011 MPS-33A 2061720 50029231230100 1 NA 1 NA 6.8 7282011 "'--> MPS-34 2031300 50029231710000 6 NA 6 NA 49.3 7/28/2011 MPS -35 2031430 50029231750000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS-37 2070520 50029233550000 13.9 Need top job NA MPS -39 2081830 50029234050000 0.7 NA 0.7 NA 4.3 8/18/2011 MPS -41A 2081610 50029234010100 Sealed NA NA NA NA NA MPS-43 2081760 50029234040000 Dust Cover NA NA NA 6.8 10/11/2011 MPS-90 2051350 50029232760000 0.6 NA 0.6 NA 3.4 9/6/2011 MPSB -04 500299990799 0.6 NA 0.6 NA 3.4 7/30/2011 ) ) WELL LOG TRANSMITTAL :}.Q 3 / (SO To: State of Alaska Alaska Oil and Gas Conservation COlll1U. Attn. : Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 '3:=e~)4- H..E: MWD Forn1ation Evaluation Logs .MPS-34, The technical data listed below is being submitted herewith. Please address any problen1s or concerns to the attention of: Rob l(alish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AI( 99518 907-273-3500 SG&f\NNED MAH 0 9 20DB MPS-34 : LAS Data & Digital Log Images: 50-029-23171-00 1 CD ROln êJ¡¡]yLn 9/ ~ø olJ) ;) ~ ';µy DATA SUBMITTAL COMPLIANCE REPORT 10/6/2005 Permit to Drill 2031300 Well Name/No. MILNE PT UNIT SB S-34 Operator BP EXPLORATION (ALASKA) INC MD 11159/" Completion Date 8/22/2003 TVD 4323/ Completion Status SQZED Current Status SQZED REQUIRED INFORMATION Sf4cL II .4.~~~6) API No. 50-029-23171-00-00 UIC N Mud Log No Samples No Directional Su(ýéy Yes ). DATA INFORMATION Types Electric or Other Logs Run: GRYO, MWD, GR, PWD, ABIIIFRlCASANDRA, RES Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments Log Log Run Scale Media No 4"pt LIS Verification 69 11122 Open 1 0/27/2003 ~D D ~85 Rate of Penetration 69 11122 Open 10/27/2003 ~ D 185 Induction/Resistivity 69 11122 Open 10/27/2003 .éÐ D Pdf Directional Survey 181 11159 9/24/2003 '1fpt Directional Survey 181 11159 9/24/2003 -€ó D Pdf Directional Survey 181 11159 9/24/2003 ~t Directional Survey 0 11159 9/24/2003 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? yG) Chips Received? ~ Daily History Received? ~/N ~N Formation Tops Analysis Received? ~ Comments: . ROP, GR, EWR4 ROP, GR, EWR4 MWD MWD . DATA SUBMITTAL COMPLIANCE REPORT 10/6/2005 Permit to Drill 2031300 Well Name/No. MILNE PT UNIT SB S-34 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23171-00-00 MD 11159 tJ::..tion Date 8/22/2003 Current Status SQZEq ¡j. UIC ~ Date: ,;¿ ) N't-v- lo-&t> TVD 4323 Completion Status SQZED Compliance Reviewed By: . . . . &03--130 WELL LOG TRANSMI'ITAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 October 13, 2003 RE: MWD Formation Evaluation Logs MPS-34, AK-MW-2600988 1 LIS formatted Disc with verification listing. API#: 50-029-23171-00 JB 3-5 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Sign~~e(~LV~~'--~~~~ ~~'bN\.~ _ STATE OF ALASKA . ALAS~ AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil 0 Gas 181 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: GYRO, MWD , GR , PWD , ABI 1 IFR 1 CASANDRA , RES CASING, liNER AND CEMENTING RECORD SeTTINGD¡:¡PTH .HOLE Top BOTTOM SIZE 35' 110' 42" 34' 5518' 13-1/2" o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3252' NSL, 412' WEL, SEC. 12, T12N, R10E, UM Top of Productive Horizon: N/A Total Depth: 2885' NSL, 2550' WEL, SEC. 02, T12N, R10E, UM (OB) 4b. Location of Well (State Base Plane Coordinates): Surface: x- 565599' y- 5999917' Zone- ASP4 TPI: x- N/A y- N/A Zone- N/A Total Depth: x- 558138· Y- 6004769' Zone- ASP4 18. Directional Survey 181 Yes 0 No 22. CASING SIZE 20" 10-3/4" 94# 45.5# H-40 L-80 7-5/8" 29.7# 1-80 32' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD 26. Date First Production: Not on Production Date of Test Hours Tested CEMEN'IiNG RECORD 260 sx Arctic Set (Approx.) 935 sx PF 'L', 371 sx Class 'G' Top Job (54 sx PF 'L') 725 sx Class 'G' Zero Other Well not Completed 5. Date Comp., Susp., or Aband. 8/22/2003 6. Date Spudded 8/11/2003 7. Date T.D. Reached 8/18/2003 8. Elevation in feet (indicate KB, DF, etc.) KBE = 72.30' 9. Plug Back Depth (MD+ TVD) 10516 + 4199 Ft 10. Total Depth (MD+TVD) 11159' + 4323 Ft 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 11159' 9-7/8" 1b. Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-130 13. API Number 50- 029-23171-00-00 14. Well Number MPS-34 15. Field and Pool Milne Point Unit 1 Schrader Bluff 16. Lease Designation and Serial No. ADL 380109 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) 24. TUBING RECORD SIZE DEPTH SET (MD) 4-112"x 3·1/2",12.6# x 9.2#, L-80 10040' TVD 25. DEPTH INTERVAL (MD) 10516' PACKER SET (MD) 9984' AMOUNT & KIND OF MATERIAL USED Set Whipstock Freeze Protected with 95 Bbls of Diesel. PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Oll-Bsl GAs-McF WATER-Bsl PRODUCTION FOR TEST PERIOD .. CALCULATED .-a... 24-HoUR RATE""" Oil -BSl Flow Tubing Casing Pressure Press. 27. GAs-McF WATER-Bsl CHOKE SIZE I GAS-Oil RATIO Oil GRAVITY-API (caRR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state:!'~~_ ; (,:U;V,fiJLET10N i"'"f- None, "'~, t:,~ ¡ ¿. 2..2.'('":2 ¡ VEf1ìFiED I--~. .."'.----..¡ R80MS 8f;L. OCT 2 u2û03 .~ ~ .. OR I GI NAL CONTINUED ON REVERSE SI~ R , GiN A L Form 10-407 Revised 2/2003 GP 28. NAME MD TVD 129. .RMATION TESTS Include and brietly'$ûmmarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". GEOLOGIC MARKER Top of Ugnu Zone C SBF2-NA SBF21 SBF1-NB SBF1-NBR SBF12 SBE4-NC SBE41 SBE2-NE SBE1-NF TSBD-OA TSBC TSBB-OB 7954' 9846' 9868' 9944' 9971' 10020' 10079' 10112' 10159' 10368' 10514' 10786' 10949' 3539' 4038' 4044' 4065' 4072' 4083' 4097' 4104' 4115' 4164' 4198' 4253' 4282' None :'¡ 30. List of Attachments: Summary of Daily Drilling Reports, Surveys and a Leak-Off Test Summary Report. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Technical Assistant Date l 0- OB-O~ MPS-34 Well Number 203-130 Permit No. / Approval No. Prepared By Name/Number: Drilling Engineer: Sandra Stewman, 564-4750 Steve Campbell, 564-4401 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 ~' .. Page 1 of 8 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-34 MPS-34 ORIG DRILLING DOYON DRILLING INC. DOYON 14 Date From - To ¡ Hours Task Code NPT, Phase ------. ..-..... 8/11/2003 00:00 - 00:30 0.50 MOB P PRE 00:30 - 02:30 2.00 MOB P PRE 02:30 - 03:00 0.50 MOB P PRE 03:00 - 03:30 0.50 MOB P PRE 03:30 - 05:30 2.00 MOB P PRE 05:30 - 12:00 6.50 DRILL P SURF 12:00 - 13:30 1.50 DRILL P SURF 13:30 - 14:00 0.50 DRILL P SURF 14:00 - 15:00 1.00 DRILL P SURF 15:00 - 15:30 0.50 DRILL P SURF 15:30 - 16:00 0.50 DRILL P SURF 16:00 - 00:00 8.00 DRILL P SURF 8/12/2003 00:00 - 14:30 14.50 DRILL P SURF 14:30 - 16:30 2.00 DRILL P SURF 16:30 - 18:30 2.00 DRILL P SURF 18:30 - 19:30 1.00 DRILL P SURF 19:30 - 22:00 2.50 DRILL N DPRB SURF 22:00 - 00:00 2.00 DRILL P SURF 8/13/2003 00:00 - 15:00 15.00 DRILL P SURF 15:00 - 19:00 4.00 CASE P SURF 19:00 - 23:00 4.00 CASE P SURF 23:00 - 00:00 1.00 CASE P SURF 8/14/2003 00:00 - 01 :00 1.00 CASE P SURF 01 :00 - 04:00 3.00 CASE P SURF 04:00 - 07:30 3.50 CASE P SURF 07:30 - 09:30 2.00 CASE P SURF Start: 8/10/2003 Rig Release: Rig Number: Spud Date: 8/11/2003 End: Description of Operations Skid rig floor from drlg position to move position Move rig from MPS-02i to MPS-34 Skid rig floor from move position to drlg position Rig up floor Accept rig @ 03:30 Hrs 8/11/2003 - Nipple up divertor Load pipe shed with 4" dp - Pick up 195 Jts of 4" dp - Stand back in derrick Pick up flex dc's - 5" hwdp - stand back in derrick Pick up short bha up beaver slide Make up bit / motor/ mwd - orient same - con't make up bha Function test divertor - Accumulator test - Witness of test waived by Chuck Scheve with AOGCC - Hang sheeve and line for Gyro in derrick Conduct pre spud meeting with all personnel - Fill stack with mud - check for surface leaks - Spud in well S-34 - Directional drill from 112' to 930' - WOB 35K to 40K - RPM 80 - TO on 5K - off 1 K - GPM 423 - PP on 1400 - off 1120 - PU 93K - SO 93K - ROT 93K - Rigged down Gyro survey equipment (two gyro surveys ran) Directional Drill from 930' to 3018' - WOB 40K - GPM 502 - PP 2650 - off 2300 - RPM 80 - TO on 10 k - off 5 k - PU 1 02K - SO 77K - ROT 95K CBU 3X - GPM 502 - PP 2300 - RPM 80 - TO 5K - PU 105K- SO 78K - ROT 95K - Circ from 3018' to 2928' - 30 mins - stand back one stand - Circ from 2928' to 2832' - 30 mins - stand back one stand - Circ from 2832 to 2736' to bottoms up - Pump out from 2736' to 815' to HWDP - no problems - hole in good shape RIH from 815' to 1550' bridge - work through bridge to 1580' - RIH to 1600' bridge - work through bridge to 1638' - Con't RIH to 2826' hit bridge Attempt to work through bridge @ 2826' - Pump at 1/2 drlg rate GPM 250 - Attempt to wash through bridge - Pump at full rate - Orient to high side 10L - Re-drill from 2826' to 3018' Directional drill from 3018' to 3306' - WOB 40K - RPM 80 - TO on 10K - off 6K - GPM 503 - PP on 2700 - off 2400 - PU 1 03K - SO -75K - ROT 91K Directional Drill from 3311' to 5526' - WOB 45K - GPM 503 - PP on 3750 - off 3280K - RPM 80 - TO on 15K - off 7K - PU 125K - SO 70K - Rot 95K CBU 3 X - RPM 100 - TO 7K - GPM 503 - PP 3200 - PU 125K- SO 70K - ROT 95K Pump out from 5526' to 817' - Pump out drlg rate - 445 gpm- tight spot @ 5035' RIH from 815' to 3800' - Tight 1536' RIH - from 3800' to 5526' - Wash last stand to bottom CBU 3 X - GPM 503 - PP 3300 - RPM 100 - TO 7K - PU 125- SO 65K - ROT 94K Pump out from 5526' to 815' HWT - 1st ten stands pumped at 5 bpm laying lubricate pill across bottom 900 feet - (from 5526' to 4626') - Pump out at drlg rate 445 GPM Rack back 5" HWT - Stand back 6.75" Flex dc's - Lay down 8" bha Printed: 912/2003 9:55:32 AM ~ A Page 2 of 8 BP EXPLORATION Operations Summary Report legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-34 MPS-34 ORIG DRilLING DOYON DRilLING INC. DOYON 14 · . · . · . Date From - To ¡ Hours · Task Code NPT Phase -------.- 8/14/2003 09:30 - 10:30 1.00 CASE P SURF 10:30 - 16:00 5.50 CASE P SURF 16:00 - 16:30 0.50 CASE P SURF 16:30 - 20:00 3.50 CASE P SURF 20:00 - 22:30 2.50 CEMT P SURF 8/15/2003 00:00 - 01 :00 1.00 CEMT P SURF 01 :00 - 02:00 1.00 CASE P SURF 02:00 - 03:00 1.00 CASE P SURF 03:00 - 03:30 0.50 CASE N CEMT SURF 03:30 - 05:00 1.50 CASE P SURF 05:00 - 07:00 2.00 CEMT N CEMT SURF 07:00 - 08:00 1.00 CASE P SURF 08:00 - 09:30 1.50 CASE P SURF 09:30 - 10:00 0.50 CASE P SURF 10:00 - 13:00 3.00 CASE P SURF 13:00 - 13:30 0.50 CASE P SURF 13:30 - 14:00 14:00 - 15:30 0.50 CASE 1.50 CASE P SURF SURF Start: 8/10/2003 Rig Release: Rig Number: Spud Date: 8/11/2003 End: Description of Operations .. ...---.- --------- Rig up to run 103/4" - PJSM Run 133 joints 10 3/4" / 45.5# / L-80 / BTC casing - Set down at 1800' - Work pipe down without circulating - Con't run pipe minor problems to 2800' - No problems in tangent section - Land pipe with 30K pipe weight left Rig down Franks fill up tool - Rig up Howco Cementing head - Break circulation Circulate / Condition mud for cement job - Start @ 2.8 bpm 440 psi - staging up to 10 bpm 420 psi Howco pump 10 bbls water - Test lines to 3500 psi - Pump 10 bbls water - Pump 75 bbls Alpha spacer - mixed at 10.2 ppg - (one gallon dye first 5 bbls spacer pumped) - Drop bottom plug on fly of last 5 bbls spacer pumped - Mix and pump 935 sxs 691 bbls Type "L" Yeild 4.15 cf/sx -mixed @ 10.7 ppg - 7 bpm - Mix and pump 375 sxs 76 bbls Class "G" with 2 % Cacl/ Yeild 1.15 cf/sx - mixed @ 15.8 ppg - 5 bpm 500 psi - Drop top plug - Kick out with Howco 30 bbls water 5 bpm 650 psi - Displace with Rig - 5 bpm 900 psi - Lost returns 210 bbls pumped - Regain retruns 230 bbls pumped Con't displacing cement with rig @ 4 bpm 1120 psi - Lost retruns total returns after displacing 290 bbls - Con't displacing 4 bpm @ 1500 psi - Total displacement 522 bbls - Bump plug with 2500 psi - 1000 over - Held pressure for 5 mins - Bled off pressure - floats holding - No Cement to surface - (Did see spacer with dye back) Flush Divertor - Flowline - Break and lay down Howco cementing head - Lay down casing tools - lay down landing joint Nipple down divertor Prepare for top job - Install hoses /lines in cellar for Super sucker / vac truck - 1" pipe in pipe shed - Pick up handling tools for 1" pipe - Change out saver sub on top drive - Top drive service RIH with 1" CS hydrill tubing - Tag up hard at 134' RKB measurements - Pump 50 bbls fresh water to flush conductor pipe - Followed by 54 sxs of Type "L" - Yield 4.15 cf/sx - 224 cf - 40 bbls slurry mixed at 10.5 ppg - 10 bbls of 10.5 ppg cement to surface - Left in hole 30 bbls of slurry - 40 sxs Nipple up 12" FMC Casg head - metal to metal seal - 11" x 11" 5M G5 tubing head - Test to 1000 psi for 10 mins Nipple up BOP's Install test plug - Rig up testing equipment Test BOP's - 250 low 2500 high Annular each test 5 mins - 250 low 3500 high - Top pipe rams - Bottom rams - Blind rams - Choke manifold - Hyd Kill/ Choke valves - Manual Kill/ Choke valves - Upper / Lower IBOP - Floor safety valve - Floor dart valves - Each test 5 mins - John Crisp with AOGCC waived witness of BOP test Pull test plug - Install wear ring - Close annulus valves - Rig down test equipment Pick up short bha up beaver slide Pick up motor 1.22 degree - make up bit - MWD / GR / RES / PWD - orient same - Con't make up BHA Printed: 9/2/2003 9:55:32 AM . . Page 3 of 8 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-34 MPS-34 ORIG DRILLING DOYON DRILLING INC. DOYON 14 i , I Date I From - To Hours . Task ' Code I NPT . Phase i __n..___._..__n. .__________..... _____ _..___m ..__ ..m __.___._. --.--....-.-..... 8/15/2003 15:30 - 16:00 0.50 CASE P SURF 16:00 - 17:30 1.50 CASE P SURF 17:30 - 18:30 1.00 CASE P SURF 18:30 - 19:30 1.00 CASE P SURF 19:30 - 20:30 1.00 DRILL P SURF 20:30 - 22:00 1.50 CASE P SURF 22:00 - 22:30 0.50 CASE P SURF 22:30 - 00:00 1.50 DRILL P INT1 8/16/2003 00:00 - 23:00 23.00 DRILL P INT1 23:00 - 00:00 1.00 DRILL P INT1 8/17/2003 00:00 - 02:30 2.50 DRILL P INT1 02:30 - 05:30 3.00 DRILL P INT1 05:30 - 08:00 2.50 DRILL P INT1 08:00 - 09:00 1.00 DRILL P INT1 09:00 - 10:00 1.00 DRILL P INT1 10:00 - 12:00 2.00 DRILL P INT1 12:00 - 13:00 1.00 DRILL P INT1 13:00 - 00:00 11.00 DRILL P INT1 8/18/2003 00:00 - 14:30 14.50 DRILL P INT1 14:30 - 17:30 3.00 CASE P INT1 17:30 - 20:30 3.00 CASE P INT1 20:30 - 21 :30 1.00 CASE P INT1 21 :30 - 00:00 2.50 CASE P INT1 8/19/2003 00:00 - 02:30 2.50 CASE P INT1 02:30 - 04:30 2.00 CASE P INT1 04:30 - 05:00 0.50 CASE P INT1 05:00 - 06:00 1.00 CASE P INT1 06:00 - 07:00 1.00 CASE P INT1 Start: 8/10/2003 Rig Release: Rig Number: Spud Date: 8/11/2003 End: Description of Operations ...___0--".._----.- RIH HWT - Surface test MWD @ 726' - 400 gpm 1150 psi RIH from 726' to 5332' Break circulation - Test 103/4" casing to 2500 psi for 30 mins- Record on chart Cut drilling line Drill F/equipment - cement - 20" new hole from 5526' to 5546' Circulate conditioning mud for FIT - GPM 400 - PP 2100 psi- 50 RPM - TO 7K Perform FIT - Hole T.D. 5546 MD - Shoe 5518' MD - 2894' TVD - Mud weight 8.9 ppg - Surface pressure 400 = 11.56 ppg EMW - Recorded on chart Spot new mud at bit - Drill from 5546' to 5750' - WOB 30K - RPM 120 - TO on 11 K - off 7K - GPM 400 - PP on 1920' - off 1820' - PU 145K - SO 70K - ROT 98K Directional Drill from 5750' to 8846' - WOB 30K - RPM 120 - TO on 9K - off 7K - GPM 423 - PP on 2980 - off 22790 - PU 133K - SO 82K - ROT 106K CBU 3 X - GPM 440 - PP 2700 - RPM 120 - TO 7.5K - PU 133 - SO 82 - ROT 105 Con't CBU 3 X - GPM 45 - PP 2600 - RPM 120 - TO 8K - PU 134K - SO 83K - ROT 107K Pump out from 8846' to 5427' - @ Drlilling rate 430 gpm - Tight spot 7250' - 7205 to 7070' ratty - 6568 to 6530 ratty Monitor well - Well static - Pump dry job - POH from 5427' to BHA @ 726' Download - Upload MWD Break off bit - reset motor from 1.22 to 1.5 - Make up new bit - Orient MWD - RIH with 6.5" flex dc's - 5" HWT RIH from 726' to 5550' - Test MWD with bit and motor out shoe Con't RIH from 5550' to 8846' - Hole in good shape - No tight spots Directional Drill from 8846' to 9960' - WOB 40K - RPM 80 - TO on 12K - off 9K - GPM 423 - PP on 3320 - off 3150 - PU 150K- SO 80K - ROT 113K - Add two drums E-P Mud lube to slick up casing - Added 3% Lubricants with IDLube and Lubetex Directional Drill from 9960' to 11159' - T.D. 97/8" hole - WOB 40K - RPM 80 - TO on 10K - off 9K - GPM 423 - PP on 3830- off 3510 - PU 150K - SO 83K - ROT 114K CBU 2 X - (20000 strokes) - GPM 423 - PP 3700 - RPM 100- TO 8K - PU 150K - SO 83K - ROT 115K Pump out from 11159' to 8000' - Pump at drilling rate 423 gpm - Hole in good shape - No problems RIH frrom 8000' to 11159' - No problems - Hole in good shape CBU 3 X - (30000 strokes) - GPM 423 - PP 3770 - RPM 100- TO 8K - PU 150K - SO 83K - ROT 114K Con't CBU 3 X - GPM 423 - PP 3680 - RPM 100 - TO 9K - PU 150K - SO 83K - ROT 115K - Lots of thick mud back on bottoms up 10,000 strokes - 12,000 strokes - 16,500 strokes Pump out from 11159' to 8782' - Pump at drlg rate 423 gpm - 3380psi Pull out 8782' to 8302', well not taking proper fill Pump out from 8302' to 7630' - Pump at drlg rate 423 gpm Pull out 7630' to 5427' Monitor well, hole static Printed: 9/2/2003 9:55:32 AM a Page 4 of 8 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/19/2003 8/20/2003 MPS-34 MPS-34 ORIG DRILLING DOYON DRILLING INC. DOYON 14 From - To Hours ! Task Code NPT Phase 07:00 - 08:00 1.00 CASE P INT1 08:00 - 10:00 2.00 CASE P INT1 10:00 - 15:00 5.00 CASE P INT1 15:00 - 20:00 5.00 CASE P INT1 20:00 - 22:30 2.50 CASE P INT1 22:30 - 00:00 1.50 CASE P INT1 00:00 - 04:00 4.00 CASE P INT1 04:00 - 05:00 1.00 CASE N HMAN INT1 05:00 - 06:00 1.00 CASE P INT1 06:00 - 06:30 0.50 CASE P INT1 06:30 - 09:00 2.50 CASE N HMAN INT1 09:00 - 14:30 5.50 CASE P INT1 14:30 - 15:00 0.50 CASE N SFAL INT1 15:00 - 17:30 2.50 CASE P INT1 17:30 - 19:00 1.50 CASE P INT1 19:00 - 00:00 5.00 CASE P INT1 8/21/2003 00:00 - 02:00 2.00 CASE P INT1 02:00 - 03:30 1.50 CASE P INT1 03:30 - 04:00 0.50 CASE P INT1 04:00 - 05:30 1.50 CASE P INT1 05:30 - 07:30 2.00 CEMT P INT1 07:30 - 08:00 0.50 CEMT P INT1 08:00 - 10:30 2.50 CEMT P INT1 10:30-11:00 0.50 CEMT P INT1 11 :00 - 12:00 1.00 CEMT P INT1 12:00 - 14:00 2.00 CEMT P INT1 14:00 -15:30 1.50 CEMT P INT1 15:30 -16:30 1.00 CEMT P INT1 Start: 8/1 0/2003 Rig Release: Rig Number: Spud Date: 8/11/2003 End: Description of Operations .....---.---- Slip and cut drilling line Trip in hole, ream from 11088'/11159' Circ. three bottoms up, with 449 gpm. 3700 psi, 100 rpms, 8k torque, P/U 150k S/O 87k, RTW 116k Flow check, pull out of hole to BHA, No problems, getting P/U and S/O wt. every 10 sds Laying down BHA, clear floor Change top rams to 7 5/8, remove saver sub from top drive to install TESCO CDA tool Installing TESCO CDA tool, as per Tesco tech. install extension sub on top drive, fit anti-rotation device, re-install torque rings on top drive, and Dan Glacken fell backwards off ladder from bottom step and landed on his back, send to medic to be checked Safety stand down, meeting with all hands on regarding fall from ladder Installing CDA tools Test BOP door seals to 1500 psi, rig down test Eqp. and clear floor Shut down for Accident investigation PJSM with Tesco Techs on running csg, Picking up 7 5/8 29.7# L-80 csg. getting pick up and slack off wt.s every 20 jts to 3390', bend one grapple on CDA tool Replace bend grapple Picking up 7 5/829.7# L-80 csg, getting pick up and slack off wt.s every 20 jts to 5518' Circ one full circulation @ shoe with 60 spm 400 psi Picking up 7 5/8 29.7# L-80 csg getting pick up and slack off wt.s every 20 jts, to 9800' Finish Picking up 7 5/8 29.7# L-80 csg getting pick up and slack off wt.s every 20 jts, to 11159', total of 274 jts.11170 ft, set @ 11,159, float @ 11,075, P/U 250K, S/O 90K wash last jt to bottom no fill, no hole problems running csg, CDA tool worked good, Csg was not rotate with CDA tool. Circ. stage up to 6 bbls min. 500 psi full returns, circ one csg volume 5,120 strokes. Didn't Reciprocate csg Rig up cement head Circ. 6 bbls min. 500 psi full returns, circ one csg volume 5,120 strokes. Didn't Reciprocate csg Cement with Halliburton with 5 bbls water, test lings 3500 psi, 15 bbls water, 35 bbls Alpha spacer mixed @ 10.5, drop bottom plug,725 sxs. Class G 156 bbls mixed @ 15.6, drop top plug, displace with Halliburton with 9.5 Flo-Pro mud, @ 8 bbls min, pumped 509 bbls bump plug with 1600 psi, full return tru out job, floats held Rig down cement head Change rams to 2 7/8 X 5", nipple down flow lines, pick up BOPS Set Emergency slips with 150k on slips Make rough cut and final cut as per FMC tect. Nipple up BOPS, rig down Tesco CDA Equip. Install new saver sub, bails and 5" elevators on top drive Install 1 0 3/4 x 7 5/8 packoff and test same to 3350 psi for 10 Printed: 9/212003 9:55:32 AM . . BP EXPLORATION Operations Summary Report Page 5 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-34 MPS-34 ORIG DRILLING DOYON DRILLING INC. DOYON 14 Start: 8/10/2003 Rig Release: Rig Number: Spud Date: 8/11/2003 End: Date From - To Hours : Task Code NPT: Phase Description of Operations ---.-- _____._n______. . -...-----...------.. 8/21/2003 15:30 - 16:30 1.00 CEMT P INT1 min. 16:30 - 21 :00 4.50 CASE P INT1 Rip up test BOPS and Manifold 250 psi low. 3500 psi high for 5 min. per test, Hydril 250 low, 2500 high, 5 min. per test., Install wear ring, The right to witness test was wavier by Jeff Jones AOGCC 21 :00 - 22:00 1.00 CASE P INT1 Test csg to 3500 psi for 30 min. 22:00 - 00:00 2.00 CASE P INT1 Picking up 12-43/4 Dc and 16 jts 3.5 HWP pump tru to insure they are free of rust, stand back in derrick 8/22/2003 00:00 - 02:00 2.00 STWHIP P PROD1 Picking up 17 jts and cut jt. of 3.5 tubing for space out of whipstock 02:00 - 05:00 3.00 STWHIP P PROD1 Pick up Trip anchor, whipstock, mills and MWD, orient same, finish picking up BHA # 4 05:00 - 11 :30 6.50 STWHIP P PROD1 Tripping in with whipstock 11:30-12:00 0.50 STWHIP P PROD1 Orient to 20 degrees to right of high side, set trip anchor, shear whipstock 12:00 - 16:30 4.50 STWHIP P PROD1 Mill window 10,516 to 10,528' Drill to 10,540', top O-A sand 10515' 16:30 - 18:00 1.50 STWHIP P PROD1 Circ and work window, pump sweep 340 gals min 2650 psi 18:00 - 18:30 0.50 STWHIP P PROD1 FIT test with 9.5 MW 340 psi 4198 TVD= 11.0 EMW 18:30 - 21 :00 2.50 STWHIP P PROD1 Slug pipe, pull out to BHA 21 :00 - 22:00 1.00 STWHIP P PROD1 Stand back BHA,Lay down MWD and mills 22:00 - 23:00 1.00 STWHIP P PROD1 Pick up stack washer and flush out BOPS, Function all rams 23:00 - 00:00 1.00 STWHIP P PROD1 Picking up 90 jts 4" drill pipe 8/23/2003 00:00 - 02:00 2.00 STWHIP P PROD1 Finish picking up 90 jts 4" pipe, Circ. tru pipe to clear out rust 02:00 - 03:00 1.00 STWHIP P PROD1 Stand 30 stands in derrick 03:00 - 05:00 2.00 STWHIP P PROD1 Clear floor, P/U BHA #5 05:00 - 06:30 1.50 STWHIP P PROD1 Tripping in hole To 5,957, Iron roughneck broke 06:30 - 07:00 0.50 STWHIP N RREP PROD1 Rig up spinner hawk, PJSM 07:00 - 08:30 1.50 STWHIP P PROD1 Tripping in to 10,369 08:30 - 09:30 1.00 STWHIP P PROD1 Slip and cut drilling line 09:30 - 10:00 0.50 STWHIP P PROD1 Trip in to 10465, Orient to high side, slide tru window 10:00 - 00:00 14.00 DRILL P PROD1 Directional drill from 10540 to 11,392 with 80 rpms, 250 gals min. 2450 psi 8/24/2003 00:00 - 00:00 24.00 DRILL P PROD1 Directional drill from 11,392 to 13,030 with 80 rpms, 250 gals min. 2550 psi, having lots of trouble sliding,Motor acting weak stalls to easy, ABI working part time, Lube up to 4%, AST 6.09, ART 10.25, TO 6500 8/25/2003 00:00 - 04:30 4.50 DRILL P PROD1 Directional drill from 13,030' to 13,232' TD with 80 rpms, 250 gals min. 2550 psi, (went out of O-A 13,160) 04:30 - 08:00 3.50 CASE P LNR1 Circ, three bottoms up with 100 rpms, 280 gals min 2800 psi 08:00 - 10:30 2.50 P LNR1 Pump out to Csg shoe, pump to 10561, pull tru window @ 10516 with out pumping, no problems pumping out 10:30 - 12:00 1.50 CASE P LNR1 Circ two bottoms up with 280 gals min 100 rpms 2450 psi 12:00 - 15:00 3.00 CASE P LNR1 Slug pipe, trip out to BHA 15:00 - 16:00 1.00 CASE P LNR1 Stand back jars and dc., lay down MWD, motor 16:00 - 16:30 0.50 CASE P LNR1 Rig up to pickup liner, PJSM 16:30 - 18:30 2.00 CASE P LNR1 Picking up 4.5 12.6# L-80 slotted liner, total 61 jts slotted, 10 jts 4.512.6# L-80 solid liner 2931', Baker 75/8 X 5.5 HMC liner hanger, Baker 7 5/8 X 5.5 ZXP liner top packer. 18:30 - 22:00 3.50 CASE P LNR1 Tripping in with liner to 13232', no problems tripping in with liner,drop ball, pickup wt 145,000, S/O 80,000 22:00 - 23:30 1.50 CASE P LNR1 Pump ball to seat with 3 bbls min. 900 psi, set hanger with 2500 psi,set packer with 3300 psi, shear ball with 4,300 psi, Printed: 9/2/2003 9:55:32 AM . . Page 6 of 8 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-34 MPS-34 ORIG DRILLING DOYON DRILLING INC. DOYON 14 Date From - To Hours Task Code NPT I Phase 8/25/2003 1.50 CASE P 22:00 - 23:30 23:30 - 00:00 0.50 CASE P 8/26/2003 00:00 - 03:00 3.00 CASE P 03:00 - 03:30 0.50 CASE P 03:30 - 04:00 0.50 STWHIP P 04:00 - 06:30 2.50 STWHIP P 06:30 - 10:30 4.00 STWHIP P 10:30 - 11 :00 0.50 STWHIP P 11 :00 - 14:00 3.00 STWHIP P 14:00 - 15:30 1.50 STWHIP P 15:30 - 18:00 2.50 STWHIP P 18:00 - 19:00 1.00 STWHIP P 19:00 - 20:30 1.50 STWHIP P 20:30 - 00:00 3.50 BOPSURP 8/27/2003 00:00 - 01 :30 1.50 DRILL P 01 :30 - 04:30 3.00 DRILL P 04:30 - 05:30 1.00 DRILL P 05:30 - 06:00 0.50 DRILL P 06:00 - 00:00 18.00 DRILL P 8/28/2003 00:00 - 16:30 16.50 DRILL P 16:30 - 20:30 4.00 CASE P 20:30 - 23:30 3.00 CASE P 23:30 - 00:00 0.50 CASE P 00:00 - 01 :30 1.50 CASE P 01 :30 - 05:00 3.50 CASE P 05:00 - 06:00 1.00 CASE P 06:00 - 07:30 1.50 CASE P 07:30 - 10:30 3.00 CASE P 10:30-11:00 0.50 CASE P 11 :00 - 12:00 1.00 CASE P 12:00 - 15:30 3.50 CASE P 15:30 - 18:00 2.50 CASE P 18:00 - 19:00 1.00 CASE P 19:00 - 21 :00 2.00 CASE P 8/29/2003 21 :00 - 23:30 2.50 CASE P 23:30 - 00:00 0.50 CASE P 8/30/2003 00:00 - 01 :00 1.00 CASE P 01 :00 - 02:30 1.50 CASE N 02:30 - 03:00 0.50 CASE N LNR1 LNR1 LNR1 LNR1 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 DPRB PROD2 DPRB PROD2 Start: 8/10/2003 Rig Release: Rig Number: Spud Date: 8/11/2003 End: Description of Operations test liner top packer with 1000 psi on back side,rotate off liner, pickup wt without liner 126,000, top of tie back sleeve 10274, packer @ 10280' Flow check, Tripping out with running tools Tripping out with running tools Lay down running tools Clear floor, PJSM Pickup 3.5 spacer its, Baker whipstock and mills,MWD Tripping in with whipstock to 10245' Orient 11 degrees to right of high side, set whipstock Mill window, 10159' to 10171' drill to 10184' Circ. Two bottoms up, pumped sweep,worked window Flow check, POH to BHA Stand back DC, lay down MWD,and window mills Pickup Johnny Wacker, Flush BOPS stack, and function rams Pull wear ring, Test BOPS and manifold 250-3,500 psi 5 min. per test, Hydril 250-2,500 psi 5 min. per test, install wear ring. the right to witness test was wavier by Jeff Jones AOGCC. PJSM,Clear floor, Pickup BHA # 7, surface test MWD Tripping in to 10,080' Cut and slip Drilling line Orient, slide tru window without pumping, tag bottom 10184' Directional Drill 1 0, 184' to 11953" with 80 rpms, 245 gpm, 3000 psi AST 4.58, ART 6 Directional Drill 11953' to 13454'TD with 80 rpms, 245 gpm, 3450 psi Circ, four bottoms up with 280GPM, 3800 psi, 100 RPMs Pumping out to window @ 1 0159,with full drilling rate, pull tru window with out pumping Circ, two bottoms up with 280GPM, 2700 psi, 100 RPMs Circ, two bottoms up with 280GPM, 2700 psi, 100 RPMs Tripping out to BHA Laying down BHA Picking up BHA # 8 Whipstock Retrieving tool., surface test MWD Trip in to 10130' Orientate, engage whipstock,pull free Circ bottoms up, 250 gals min. 1800 psi Poh with whipstock Lay down BHA, whipstock, and space out its. Rig up to pickup Iiner,PJSM Picking up Slotted liner 4.5 12.6# L-80 IBT total 71 its 2906' and Baker Hook wall hanger, two centralizers per it. on slotted its Tripping in with liner to 10150' Working trying to Exit window @ 10159' to 10171' Working trying to Exit window @ 10159' to 10171' setting down on lower liner @ 10273, got out window on the 8th try Working liner @ 10260' acts like the centralizer in the middle #3 it is hanging on bottom of window. P/U wt 125,000 S/O wt 90,000 Pulled above window and went back to lower liner top @ Printed: 9/2/2003 9:55:32 AM . . Page 7 of 8 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date MPS-34 MPS-34 ORIG DRILLING DOYON DRILLING INC. DOYON 14 ¡ Ii' From - To : Hours! Task Code i NPT' Phase 8/30/2003 02:30 - 03:00 0.50 CASE N DPRB PROD2 03:00 - 03:30 0.50 CASE N DPRB PROD2 03:30 - 06:30 3.00 CASE N DPRB PROD2 06:30 - 07:00 0.50 CASE N DPRB PROD2 07:00 - 11 :30 4.50 CASE N DPRB PROD2 11 :30 - 12:00 0.50 CASE N DPRB PROD2 12:00 - 15:30 3.50 CASE N DPRB PROD2 15:30 - 18:00 2.50 CASE N DPRB PROD2 18:00 - 21 :30 3.50 CASE N DPRB PROD2 21 :30 - 23:30 2.00 CASE P PROD2 23:30 - 00:00 0.50 CASE P PROD2 8/31/2003 00:00 - 01 :00 1.00 CASE P PROD2 01 :00 - 05:00 4.00 CASE P PROD2 05:00 - 05:30 0.50 CASE P PROD2 05:30 - 08:30 3.00 CASE P PROD2 08:30 - 09:30 1.00 CASE P PROD2 09:30 - 12:00 2.50 CASE P PROD2 12:00 -17:30 5.50 CASE P PROD2 17:30 - 19:00 1.50 CASE P PROD2 19:00 - 00:00 5.00 CASE P PROD2 9/1/2003 00:00 - 05:00 5.00 CASE P PROD2 05:00 - 06:30 1.50 CASE P PROD2 06:30 - 07:30 1.00 BOPSUR.P PROD2 07:30 - 09:00 1.50 WHSUR P PROD2 09:00 - 09:30 0.50 WHSUR P PROD2 09:30 - 10:00 0.50 CASE P PROD2 10:00 - 10:30 0.50 CASE P PROD2 Start: Rig Release: Rig Number: 8/10/2003 Spud Date: 8/11/2003 End: Description of Operations ..-...----... _.. ._n___. .....___.... n._ 10273' Orient and went out window on 3rd try, to 10260' and liner still hanging up @ same spot. POH to liner hanger inspect liner hanger,stand back in derrick PJSM, lay down liner found two centralizers pushed up to collar on jt.#2 Service top drive Picking up Slotted liner 4.512.6# L-80 IBT total 71 jts 2906' and Baker Hook wall hanger, no centralizers on jt. 1 tru 3, one centralizer per jt on jts 4 tru 6, two centralizers per jt on 7 tru 70, no centralizer on jt 71, stop rings welded in middle of jt. Tripping in with liner to 10165' Working pipe to locate window, exit window after 24 attempts Tripping in with liner had to beat centralizers past bottom of window for app. 1300' the rest went with no problems, hole was slick, pickup wt. 134,000 S/O 80,000 Hooking liner hanger, took 6 attempts, top of liner tie back sleeve 10,136' shoe 13,091' Drop ball, pumped down 3 bbls min.,750 psi, pressure up to 4300 psi, shear ball, release from liner hanger, P/U wt 125,000 Slug pipe, Tripping out with running tools, laying down 105 jts of excess drill pipe. Laying down liner running tools Pick up Johnny Wacker tripping in to 10,070' Slip and cut drilling line Displace hole with 9.5 brine with Inhibitor, with 10 bbls min. 120 rpms, 3050psi PJSM, laying down excess drill pipe, stand 40 stands in derrick Pull wear ring, Rig up I-wire spool, rig up tubing tongs, count tubing Picking up, 3.5 tail pipe assem. Baker 7 5/8x 4.5 Premier packer, and Phoenix jet pump sensors and gauge, picking up 4.512.6# L-80 IBT Tubing with I-wire to 4,312' Finish picking up 4.512.6# L-80 IBT Tubing with I-wire to 10,040.05 total of 237 jts, tail pipe 10,040, XN 10034, packer, 9984, x nipple 9973, Phoenix Sensor 9957, Sliding sleeve 9934, Phoenix pressure gauge 9923, GLM 2101' Picking up FMC hanger and land tubing P/U 115K, S/O 83K 123 Clamps. 123 cannon clamps used. Test I-Wire. RILDS and test TWC to 300 psi from below. Clear rig floor. Nipple down BOP stack. Nipple up FMC 11" X 4-1/16" 5000# Tubing Head Adapter. Run control line through adapter and test pack off to 3500 psi. Nipple up 4-1/16" CIW 5000# tree and test tree to 4000 psi. Open annulus valve and pulled TWC with dry rod. Dropped Ball/rod/roller assembly down tubing. Rig up line to tubing for pressure test. Pressure on to tubing to 2500 psi to set packer, continued pressuring up to 3000 psi with rig pump. Switched to test pump and continued pressuring up slowly to 3800 psi and suddenly lost pressure on tubing to 400 psi. No flow on annulus. Printed: 9/212003 9:55:32 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W" - Page 8 of 8 BP EXPLORATION Operations Summary Report MPS-34 MPS-34 ORIG DRILLING DOYON DRILLING INC. DOYON 14 9/1/2003 10:00 - 10:30 From - To Hours Task Code NPT: Phase 0.50 CASE P Date Start: 8/10/2003 Rig Release: Rig Number: Spud Date: 8/11/2003 End: Description of Operations .. .. .-.-.......--..- PROD2 Attempted to pressure up on tubing and pumped 3 bbls and pressure on tubing increased to 800 psi and began pumping into formation. Appeared that the RHC plug sheared (set to shear at 4900 psi). Pressure test casing to 1000 psi for 10 minutes with no bleed off. Freeze protected 10-3/4" X 7-5/8" annulus with 95 bbls of diesel. Installed TWC and tested to 1000 psi from the top. RID circ. hoses and test eguip. secure well Rig Release @ 1500 hrs 9/1/2003 10:30 - 11 :30 1.00 CASE P PROD2 11:30-12:00 0.50 WHSUR P PROD2 12:00 - 15:00 3.00 CASE P PROD2 Printed: 9/212003 9:55:32 AM Page 1 of 1 __....______n Suñace Pressure Leak Off Pressure (BHP) EMW --------._--_.__._._....~ .-.... "'"_'""V __..__.....___.___.._ 400 (psi 1 ,738 (psi) 11.56 (ppg) 340 (psi 2,412 (psi 11.06 (ppg) . . Printed: 9/2/2003 9:55:17 AM BP EXPLORATION Leak-Off Test Summary Test Depth (TMD) -or -"Te~t Depth (rvD) .. _.__.u..._. _ AMW 5,546.0 (ft) 2,893.0 (ft) 8.90 (ppg) 10,515.0 (ft) 4,198.0 (ft) 9.50 (ppg) Legal Name: MPS-34 Common Name: MPS-34 Test Date Test Type ,·....w...........__·... 8/15/2003 FIT 8/22/2003 FIT · e803-J30 16-Sep-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK,99501 Re: Distribution of Survey Data for Well MPS-34 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 11,159.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William 1. Allen Survey Manager AUachment(s) ""'à....,~, " ( ~ ~':D \~'\ ~ Sperry-Sun Drilling Services \.... Milne Point Unit SPXA Milne Po/ntMPS MPS·34 Job No. AKZZOOO2600988, Surveyed: 18 August, 2003 Survey·iReport 16 September, 2003 Your Ref: API 600292317100 Surface Coordinates: 5999917.12 N, 565598.66 E (10° 24' 36.7947" N, 149027' 57.0634" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 999917.12 N, 65598.66 E (Grid) Surface Coordinates relative to Structure: 51.32 S, 746.82 W (True) Kelly Bushing: 72.300 above Mean Sea Level Elevation relative to Project V Reference: 72.30ft Elevation relative to Structure: 72.30ft Bþ!!I""".....1/-......, DAIL..LINGi S&AVtc:SS A Halliburton Company DEFINITIVE· . . Survey Ref: svy1248 Sperry-Sungtl1llllffl'i§frvices Survey Report forMifnf1il'"J,Wr,fI1S- MPS-34 Your Ref: APJ 500292317100 Job No. AKZZ0002600988, Surveyed: 18 August, 2003 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -72.30 0.00 0.00 N O.OOE 5999917.12 N 565598.66 E 0.00 Tolerable Gyro 181.70 0.500 23.000 109.40 181 .70 0.73N 0.31 E 5999917.85 N 565598.96 E 0.275 0.66 278.90 1.000 322.000 206.59 278.89 1.79 N 0.05W 5999918.91 N 565598.60 E 0.900 1.77 AK-6 BP.)FR-AK 301.90 1.360 314.840 229.59 301.89 2.14 N 0.36W 5999919.26 N 565598.28 E 1.688 2.17 395.79 3.180 309.940 323.40 395.70 4.60 N 3.15W 5999921.69 N 565595.47 E 1.948 5.07 "- 485.74 5.380 296.580 413.09 485.39 8.09N 8.84W 5999925.13 N 565589.75 E 2.669 9.50 . 575.70 8.830 303.940 502.35 574.65 13.83 N 18.34 W 5999930.79 N 565580.20 E 3.959 16.80 668.65 12.620 299.750 593.66 665.96 22.85 N 33.08 W 5999939.68 N 565565.38 E 4.160 28.25 759.49 16.190 299.780 681.63 753.93 34.07 N 52.69 W 5999950.73 N 565545.67 E 3.930 42.71 853 90 18.460 301.790 771.75 844.05 48.49 N 76.82 W 5999964.93 N 565521.41 E 2.486 61.09 949.81 21.930 302.120 861.75 934.05 66.01 N 104.91 W 5999982.21 N 565493.18 E 3.620 83.23 1046.01 24.560 302.050 950.14 1022.44 86.18 N 137.07W 6000002.09 N 565460.84 E 2.734 108.67 1141.75 25.720 302.320 1036.81 1109.11 107.84 N 171.49 W 6000023.45 N 565426.22 E 1.218 135.99 1238.04 27.230 302.070 1123.00 1195.30 130.71 N 207.82 W 6000046.00 N 565389.70 E 1.572 164.81 1333.07 29.810 300.160 1206.49 1278.79 154.13 N 246.68 W 6000069.08 N 565350.64 E 2.879 194.62 1424.45 33.240 297.910 1284.37 1356.67 177.27 N 288.46 W 6000091.85 N 565308.65 E 3.968 2?4.67 1520.45 35.960 296.400 1363.39 1435.69 202.12 N 336.97 W 6000116.28 N 565259.93 E 2.971 2'57.57 1620.89 35.910 295.050 1444.71 1517.01 227.71 N 390.07 W 6000141.39 N 565206.61 E 0.790 291.98 1716.84 36.770 294.550 1522.00 1594.30 251.55 N 441.68 W 6000164.79 N 565154.79 E 0.948 324.43 1813.40 38.650 294.350 1598.39 1670.69 276.00 N 495.45 W 6000188.76 N 565100.81 E 1.951 357.84 1909.07 43.140 295.040 1670.69 1742.99 302.17 N 552.33 W 6000214.43 N 565043.70 E 4.717 393.49 2006.04 46.160 292.180 1739.67 1811.97 329.42 N 614.77 W 6000241.12 N 564981.02 E 3.740 431.17 2100.91 48.390 289.590 1804.04 1876.34 354.23 N 679.88 W 6000265.36 N 564f15.70 E 3.090 466.91 . 2197.65 53.490 290.320 1864.98 1937.28 379.87 N 750.46 W 6000290.39 N 564844.90 E 5.304 504.42 2288.39 58.250 291.470 1915.88 1988.18 406.67 N 820.60 W 6000316.57 N 564774.52 E 5.349 542.99 2387.72 62.250 292.340 1965.16 2037.46 438.85 N 900.59 W 6000348.04 N 564694.25 E 4.098 588.57 2484.58 64.740 293.410 2008.39 2080.69 472.55 N 980.44 W 6000381.04 N 564614.11 E 2.754 635.62 2580.59 67.230 294.480 2047.46 2119.76 508.15 N 1060.58 W 6000415.93 N 564533.66 E 2.786 684.60 2676.86 70.800 295.890 2081.93 2154.23 546.40 N 1141.90 W 6000453.47 N 564452.01 E 3.952 736.39 2772.98 71.720 296.370 2112.81 2185.11 586.49 N 1223.62 W 6000492.84 N 564369.94 E 1.068 790.06 2865.61 73.260 296.270 2140.68 2212.98 625.66 N 1302.80 W 6000531.31 N 564290.42 E 1.666 842.38 2962.82 73.470 297.420 2168.51 2240.81 667.72 N 1385.90 W 6000572.64 N 564206.95 E 1.154 898.23 3060.62 74.870 297.420 2195.19 2267.49 711.05 N 1469.42 W 6000615.23 N 564123.05 E 1431 95541 3156.74 75.320 298.800 2219.91 2292.21 754.81 N 1551.34 W 6000658.28 N 564040.75 E 1464 1012.73 3253.94 74.950 295.010 2244.86 2317.16 797.32 N 1635.10W 6000700.04 N 563956.62 E 3.788 1 069 14 ---~-~'---~-~--'--'----'-------'.'--- 16 September, 2003 - 7:01 Page 2 0'6 Drí/lQuest 3.03.02.005 Sperry-SUß'iq ervices surveyReportforMtli, ......... .... .... .S"MPS-34 Your Ref: A~I 500292317100 Job No. AKZZOOO2600988, Surveyed: 18 August, 2003 BP EXPLORA TlON (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 3346.74 75.080 293.640 2268.85 2341.15 834.24 N 1716.79 W 6000736.25 N 563874.61 E 1.433 1119.68 3442.91 73.540 294.250 2294.86 2367.16 871.81 N 1801.40W 6000773.08 N 563789.67 E 1.714 1171.38 3537.89 72.050 293.690 2322.95 2395.25 908.67 N 1884.30 W 6000809.21 N 563706.45 E 1.667 1222.08 3634.02 74.370 292.520 2350.72 2423.02 944.78 N 1968.95 W 6000844.57 N 563621.49 E 2.680 1272.33 3730.04 75.130 292.620 2375.98 2448.28 980.34 N 2054.49 W 6000879.37 N 563535.64 E 0.798 1322.20 3826.55 73.860 292.440 2401.77 2474.07 1015.97 N 2140.39 W 6000914.25 N 563449.43 E 1.328 1372.21 . 3922.67 75.520 294.330 2427.16 2499.46 1052.77 N 2225.47 W 6000950.30 N 563364.03 E 2.565 1423.22 4018.77 75.070 294.840 2451.55 2523.85 1091.44 N 2310.00 W 6000988.23 N 563279.16 E 0.695 1475.99 4115.29 73.800 295.450 2477.45 2549.75 1130.95 N 2394.17 W 6001027.00 N 563194.65 E 1.450 1529.51 4211.87 74.760 295.590 2503.62 2575.92 1171.00 N 2478.06 W 6001066.31 N 563110.41 E 1.004 1583.52 4307.74 75.130 296.310 2528.52 2600.82 1211.51 N 2561.31 W 6001106.09 N 563026.81 E 0.822 1637.87 4404.04 74.690 296.140 2553.59 2625.89 1252.60 N 2644.72 W 6001146.44 N 562943.05 E 0.488 1692.82 4499.90 76.790 296.640 2577.20 2649.50 1293.89 N 2727.93 W 6001187.00 N 562859.47 E 2.248 1747.94 4596.12 77.110 296.690 2598.93 2671.23 1335.96 N 2811.70W 6001228.33 N 562775.33 E 0.336 1803.91 4692.22 76.530 297.480 2620.84 2693.14 1378.56 N 2895.01 W 6001270.20 N 562691.66 E 1.002 1860.33 4788.89 76.910 297.240 2643.04 2715.34 1421.80 N 2978.57 W 6001312.70 N 562607.72 E 0.461 19H,42 4885.92 77.230 298.470 2664.76 2737.06 1465.99 N 3062.18 W 6001356.15 N 562523.73 E 1.279 1975.45 4980.71 76.860 297.800 2686.01 2758.31 1509.55 N 3143.64 W 6001399.00 N 562441.89 E 0.792 2032.50 5075.30 76.660 297.300 2707.67 2779.97 1552.13 N 3225.27 W 6001440.87 N 562359.88 E 0.556 2088.61 5171.69 77.050 298.060 2729.59 2801.89 1595.74 N 3308.39 W 6001483.74 N 562276.38 E 0.868 2145.99 5265.62 74.560 295.830 2752.63 2824.93 1637.00 N 3389.55 W 6001524.29 N 562194.86 E 3.511 2200.72 5359.62 74.560 295.370 2777.65 2849.95 1676.15 N 3471.27 W 6001562.72 N 5621.12.81 E 0.472 2253.47 5466.88 73.730 295.930 2806.96 2879.26 1720.81 N 3564.28 W 6001606.56 N 562019.41 E 0.923 2313.60 . 5550.20 72.960 294.590 2830.84 2903.14 1754.88 N 3636.46 W 6001639.99 N 561946.92 E 1.797 2359.68 5646.60 71.890 294.270 2859.94 2932.24 1792.89 N 3720.14 W 6001677.26 N 561862.92 E 1.154 2411.64 5740.95 73.880 292.760 2887.71 2960.01 1828.85 N 3802.81 W 6001712.50 N 561779.93 E 2.605 2461.42 5836.13 75.330 293.780 2912.98 2985.28 1865.11 N 3887.11 W 6001748.02 N 561695.32 E 1.841 2511.76 5931 .40 74.940 293.390 2937.42 3009.72 1901.95 N 3971.50 W 6001784.12 N 561610.61 E 0.569 2562.70 6028.15 75.650 293.510 2961.98 3034.28 1939.19 N 4057.35 W 6001820.60 N 561524.43 E 0.744 2614.28 6122.48 75.140 293.890 2985.76 3058.06 1975.88 N 4140.93 W 6001856.56 N 561440.53 E 0.667 2664.93 6217.06 75.070 293.830 3010.08 3082.38 2012.85 N 4224.52 W 6001892.79 N 561356.62 E 0.096 2715.86 6313.40 75.480 294.580 3034.56 3106.86 2051.06 N 4309.51 W 6001930.25 N 561271.30 E 0.865 2768.23 6410.05 74.950 293.950 3059.23 3131.53 2089.46 N 4394.70 W 6001967.90 N 561185.78 E 0.835 2820.85 6503.12 75.530 293.350 3082.94 3155.24 2125.56 N 4477.14 W 6002003.28 N 561103.02 E 0.881 2870.72 6599.39 76.110 293.410 3106.52 3178.82 2162.60 N 4562.81 W 6002039.56 N 561017.03 E 0.605 2922.07 16 September, 2003 - 7:01 Page 3 of6 DrillQuest 3.03.02.005 Sperry-Suniq~ll(~I'IEJXServices Survey Report forM;/(ne,,,olnt.6fPS - MPS-34 Your Ref:A.~1.5Ø0292317100 Job No. AKZZ0002600988, Surveyed: 18 August, 2003 BP EXPLORA TlON (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6695.57 76.690 293.720 3129.14 3201.44 2199.98 N 4648.50 W 6002076.18 N 560931.02 E 0.680 2973.76 6792.46 77.060 294.070 3151.14 3223.44 2238.20 N 4734.77 W 6002113.64 N 560844.41 E 0.519 3026.38 6888.50 74.420 297.570 3174.80 3247.10 2278.71 N 4818.54 W 6002153.42 N 560760.29 E 4.475 3080.82 698467 72.700 298.590 3202.02 3274.32 2322.12 N 4899.92 W 6002196.12 N 560678.53 E 2.058 3137.71 7081.26 72.110 299.190 3231.22 3303.52 2366.60 N 4980.53 W 6002239.89 N 560597.53 E 0.851 3195.51 7176.76 72.250 299.450 3260.44 3332.74 2411 .13 N 5059.81 W 6002283.71 N 560517.87 E 0.298 3253.12 . 7273.04 73.470 297.600 3288.82 3361.12 2455.05 N 5140.64 W 6002326.93 N 560436.66 E 2.231 3310.42 7368.85 73.790 297.210 3315.82 3388.12 2497.37 N 5222.25 W 6002368.52 N 560354.68 E 0.514 3366.26 7465.94 73.930 297.390 3342.81 3415.11 2540.14 N 5305.12 W 6002410.57 N 560271.43 E 0.~29 3422.77 7560.95 73.110 297.610 3369.76 3442.06 2582.21 N 5385.94 W 6002451.92 N 560190.25 E 0.891 3478.24 7656.81 75.920 295.980 3395.36 3467.66 2623.84 N 5468.39 W 6002492.83 N 560107.44 E 3.358 3533.55 7752.35 76.290 296.330 3418.30 3490.60 2664.72 N 5551.64 W 6002532.98 N 560023.83 E 0.526 3588.27 7849.59 76.280 296.400 3441.35 3513.65 2706.67 N 5636.28 W 6002574.19 N 559938.83 E 0.071 3644.28 7945.89 75.520 294.960 3464.82 3537.12 2747.15 N 5720.45 W 6002613.92 N 559854.31 E 1.651 3698.76 8041.57 75.850 294.130 3488.47 3560.77 2785.66 N 5804.78 W 6002651.69 N 559769.64 E 0.909 3751.33 8137.24 75.960 294.330 3511.77 3584.07 2823.74 N 5889.39 W 6002689.02 N 559684.69 E 0.233 38p3.52 8232.89 75.780 293.980 3535.12 3607.42 2861.70 N 5974.03 W 6002726.24 N 559599.73 E 0.402 3855.60 8328.42 76.470 294.480 3558.03 3630.33 2899.76 N 6058.60 W 6002763.55 N 559514.83 E 0.883 3907.77 8425.20 76.230 294.220 3580.87 3653.17 2938.53 N 6144.28 W 6002801.58 N 559428.81 E 0.360 3960.83 8521.17 76.990 295.080 3603.09 3675.39 2977.47 N 6229.13 W 6002839.77 N 559343.62 E 1.178 4013.92 8617.70 76.440 295.320 3625.28 3697.58 3017.47 N 6314.14 W 6002879.02 N 559258.27 E 0.619 4068.07 8714.04 76.460 294.980 3647.85 3720.15 3057.28 N 6398.92 W 6002918.08 N 559173.14 E 0.344 4121.99 8808.14 74.950 293.620 3671.08 3743.38 3094.80 N 6482.02 W 6002954.87 N 559å89.71 E 2.130 4173.38 . 8903.68 74.500 293.530 3696.25 3768.55 3131.66N 6566.49 W 6002990.99 N 559004.92 E 0.480 4224.35 8999.72 74.250 295.290 3722.12 3794.42 3169.88 N 6650.71 W 6003028.47 N 558920.37 E 1.784 4276.61 9096.88 73.160 297.670 3749.39 3821.69 3211.46 N 6734.18 W 6003069.31 N 558836.54 E 2.605 4332.05 9193.00 73.050 300.020 3777.33 3849.63 3255.82 N 6814.73 W 6003112.96 N 558755.60 E 2.342 4389.73 9289.21 72.080 303.890 3806.16 3878.46 3304.39 N 6892.60 W 6003160.84 N 558677.31 E 3.968 4451.07 9384.53 71.840 306.230 3835.68 3907.98 3356.44 N 6966.78 W 6003212.25 N 558602.67 E 2.348 4515.22 9481.21 72.060 309.550 3865.65 3937.95 3412.89 N 7039.31 W 6003268.05 N 558529.65 E 3.273 4583.40 9576.46 73.610 315.310 3893.78 3966.08 3474.27 N 7106.44 W 6003328.84 N 558461.98 E 6.002 4655.51 9672.14 75.140 319.400 3919.56 3991.86 3542.04 N 7168.83 W 6003396.06 N 558398.99 E 4.416 4733.08 9768.54 74.570 323.120 3944.75 4017.05 3614.60 N 7227.05 W 6003468.11 N 558340.14 E 3.771 4814.65 986535 73.710 328.090 3971.22 4043.52 3691.41 N 7279.65 W 6003544.45 N 558286.87 E 5.017 4899.43 9961.42 75.520 332.040 3996.72 4069.02 3771.67 N 7325.85 W 6003624.30 N 558239.97 E 4.389 4986.49 --.- _.._...._._~-- ..~._- --.....------"-..--.----------- 16 September, 2003 - 7:01 Page 4 0'6 DrillQuest 3.03.02.005 Sperry.SLl"~lilÌi(llin;gServices Survey R.portf6r~/ln.l'olnt MPS - MPS-34 Your Ref: API 500292317100 Job No. AKZZ0002600988, Surveyed: 18 August, 2003 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10057.42 76.670 335.360 4019.80 4092.10 3855.20 N 7367.12W 6003707.46 N 558197.96 E 3.564 5075.92 10153.41 77.760 341.880 4041.06 4113.36 3942.32 N 7401.22 W 6003794.28 N 558163.10 E 6.720 5167.63 10249.18 76.040 347.810 4062.78 4135.08 4032.30 N 7425.60 W 6003884.04 N 558137.93 E 6.292 5260.48 10346.20 75.780 350.330 4086.41 4158.71 4124.68 N 7443.45 W 6003976.27 N 558119.27 E 2.533 5354.56 '- 10440.75 76.480 354.320 4109.08 4181.38 4215.63 N 7455.70 W 6004067.11 N 558106.22 E 4.163 5446.26 10537.26 76.930 357.920 4131.28 4203.58 4309.33 N 7462.05 W 6004160.74 N 558099.05 E 3.660 5539.63 . 10632.49 78.070 1.460 4151.90 4224.20 4402.28 N 7462.55 W 6004253.69 N 558097.74 E 3.821 5631.26 10728.71 79.640 5.020 4170.50 4242.80 4496.51 N 7457.20 W 6004347.96 N 558102.25 E 3.980 5723.13 10824.55 79.690 3.440 4187.70 4260.00 4590.54 N 7450.25 W 6004442.05 N 558108.38 E 1.623 5814.52 10920.32 80.130 6.210 4204.48 4276.78 4684.48 N 7442.32 W 6004536.06 N 558115.49 E 2.884 5905.66 11019.00 78.110 5.970 4223.10 4295.40 4780.84 N 7432.04 W 6004632.50 N 558124.92 E 2.061 5998.77 11086.79 78.750 6.240 4236.70 4309.00 4846.87 N 7424.97 W 6004698.59 N 558131.40 E 1.022 6062.57 11159.00 78.750 6.240 4250.79 4323.09 4917.28 N 7417.28 W 6004769.06 N 558138.48 E 0.000 6130.57 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. ,¡,"' The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 350.000° (True). Magnetic Declination at Surface is 25.412°(11-Aug-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 11159.00ft., The Bottom Hole Displacement is 8899.19ft., in the Direction of 303.542° (True). . -- -.----.---.--"-"--- 16 September, 2003 - 7:01 Page 5 0'6 DrillQllest 3.03.02.005 Sperry-Sunl/ll'j > Services Survey Report for MIl '/fIS- MPS·34 Your Ref: A'þ/~i .. ... ..... '/100 Job No. AKZZOOO2600988, . Surveyed: 18 August, 2003 BP EXPLORA TION (ALASKA) INC. Milne Point Unit Comments Measured Depth (ft) 11159.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 4323.09 Comment 4917.28 N 7417.28 W Projected Survey Survey tool program for MPS-34 From Measured Vertical Depth Depth (ft) (ft) 0.00 278.90 16 September, 2003 - 7:01 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 278.90 278.89 11159.00 278.89 Tolerable Gyro 4323.09 AK-6 BP _IFR-AK ~--,---,._'--'-'-. Page 60f6 BPXA . .> . _.__.__.._,.~- DrillQuest 3.03.02.005 · AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 e Re: Distribution of Survey Data for Well MPS-34 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00 I MD 0.00' MD 11,159.00' MD (if applicable) 903--/30 16-Sep-03 Please call me at 273-3545 if you have any questions or concerns. Regards, William 1. Allen Survey Manager Attachment(s) ~b~{'Y,"~ . Sperry-Sun Drilling Services Milne Point Unit BPXA Milne PointMPS MPS-34 MWD Surveyed: 18 August, 2003 Job No. AKMW0002600988, Survey Report ,~ 2003 16 September, W) Your Ref: API 500292317100 Surface Coordinates: 5999917.12 N, 565698.66 E (70°24' 36.7947" N, 149° 27"57.0634" Grid Coordinate System: NAD21 Alaska State Planes, Zone 4 . Survey Ref: svy1262 Surface Coordinates relative to Project H Reference: 999917.12 N, 65598.66 E (Grid) Surface Coordinates relative to Structure: 51.32 S, 746.82 W (True) Kelly Bushing: 72.30ft above Mean Sea Level Elevation relative to Project V Reference: 72.30ft Elevation relative to Structure: 72.30ft !s~""'''''\i-''I ,., DAILL-ING SGAVIC:G$ A Halliburton Company Sperry-Sun <Dtillltij1if$ørvices Survey Report for Milne Point MPS . MPS-34 MWD Your Ref: API 500292317100 Job No. AKMWOO02600988, Surveyed: 18 August, 2003 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) ('(100ft) 0.00 0.000 0.000 -72.30 0.00 O.OON 0.00 E 5999917.12 N 565598.66 E 0.00 Tolerable Gyro 181.70 0.500 23.000 109.40 181.70 0.73 N 0.31 E 5999917.85 N 565598.96 E 0.275 0.66 278.90 1.000 322.000 206.59 278.89 1.79 N 0.05W 5999918.91 N 565598.60 E 0.900 1.77 MWD Magnetic 301.90 1.360 315.590 229.59 301.89 2.14 N 0.36W 5999919.26 N 565598.28 E 1.665 2.17 395.79 3.180 310.230 323.40 395.70 4.62N 3.13W 5999921.71 N 565595.49 E 1.949 5.09 485.74 5.380 296.980 413.09 485.39 8.14 N 8.79W 5999925.19 N 565589.80 E 2.666 9.55 . 575.70 8.830 304.970 502.35 574.65 14.02 N 18.21 W 5999930.98 N 565580.33 E 3.980 16.97 668.65 12.620 300.970 593.66 665.96 23.33 N 32.77 W 5999940.17 N 565565.69 E 4.153 28.67 759.49 16.190 300.660 681.63 753.93 34.90 N 52.18 W 5999951.56 N 565546.18 E 3.931 43.43 853.90 18.460 301.620 771.75 844.05 49.45 N 76.23 W 5999965.90 N 565522.00 E 2.423 61.94 949.81 21.930 303.020 861.75 934.05 67.18 N 104.19W 5999983.38 N 565493.89 E 3.653 84.25 1046.01 24.560 303.190 950.14 1022.44 87.92 N 135.99 W 6000003.84 N 565461.91 E 2.735 110.20 1141.75 25.720 301.730 1036.81 1109.11 109.74 N 170.31 W 6000025.36 N 565427.39 E 1.374 137.64 1238.04 27.230 301.870 1123.00 1195.30 132.36 N 206.79 W 6000047.65 N 565390.71 E 1.570 166.25 1333.07 29.810 300.930 1206.49 1278.79 155.98 N 245.52 W 6000070.94 N 565351.78 E 2.756 196.25 1424.45 33.240 297.680 1284.38 1356.68 179.30 N 287.20 W 6000093.89 N 565309.90 E 4.188 248.45 1520.45 35.960 295.720 1363.39 1435.69 203.76 N 335.91 W 6000117.92 N 565260.98 E 3.061 258.99 1620.89 35.910 294.840 1444.72 1517.02 228.93 N 389.20 W 6000142.62 N 565207.46 E 0.517 293.04 1716.84 36.770 293.300 1522.01 1594.31 252.11 N 441.12W 6000165.35 N 565155.35 E 1.307 324.88 1813.40 38.650 293.080 1598.39 1670.69 275.36 N 495.41 W 6000188.12 N 565100.85 E 1.952 357.21 1909.07 43.140 293.810 1670.69 1742.99 300.29 N 552.84 W 6000212.55 N 565043.20 E 4.720 391.73 2006.04 46.160 290.700 1739.68 1811.98 326.05 N 615.91 W 6000237.75 N 564979.91 E 3.844 428.05 2100.91 48.390 288.440 1804.05 1876.35 349.37 N 681.58 W 6000260.49 N 564914.04 E 2.930 462.41 .' 2197.65 53.490 291.140 1864.99 1937.29 374.85 N 752.20 W 6000285.34 N 564843.20 E 5.699 499.77 2288.39 58.250 292.520 1915.89 1988.19 402.79 N 821.89 W 6000312.68 N 564773.26 E 5.394 539.39 2387.72 62.250 292.460 1965.17 2037.47 435.77 N 901.56 W 6000344.96 N 564693.31 E 4.027 585.70 2484.58 64.740 294.430 2008.40 2080.70 470.27 N 981.06 W 6000378.75 N 564613.51 E 3.150 633.48 2580.59 67.230 296.670 2047.47 2119.77 508.10 N 1060.16W 6000415.89 N 564534.07 E 3.357 684.48 2676.86 70.800 297.820 2081.94 2154.24 549.25 N 1140.06 W 6000456.34 N 564453.82 E 3.872 738.88 277298 71.720 295.340 2112.83 2185.13 589.97 N 1221.46 W 6000496.34 N 564372.07 E 2.624 793.11 2865.61 73.260 299.370 2140.71 2213.01 630.56 N 1299.89 W 6000536.24 N 564293.28 E 4.470 846.71 2962.82 73.470 299.230 2168.54 2240.84 676.15 N 1381.11 W 6000581.1'1 N 564211.66 E 0.256 905.70 306062 74.870 302.010 2195.22 2267.52 724.07 N 1462.07 W 6000628.32 N 564130.29 E 3.087 966.96 3156.74 75.320 305.250 2219.95 2292.25 775.51 N 1539.40 W 6000679.08 N 564052.51 E 3.291 1031.04 3253.94 74.950 296.670 2244.93 2317.23 823.79 N 1619.87 W 6000726.65 N 563971.62 E 8.540 1092.56 -,_._-~ "r---"'--- ---- 16 September, 2003 - 7:05 Page 20f6 Drif/Qllest 3.03.02.005 > . Sperry-Sun Qr;l/f Services Survey Report for 111'''-:, < < '.MÞS·34 MWD Your Ref: API5(J()292317100 Job No. AKMWOO02600988, Surveyed: 18 August, 2003 BP EXPLORA TlON (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinate. Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 3346.74 75.080 292.170 2268.94 2341.24 860.84 N 1701.47W 6000762.98 N 563889.69 E 4.686 1143.22 3442.91 73.540 295.530 2294.95 2367.25 898.26 N 1786.14 W 6000799.66 N 563804.70 E 3.725 1194.77 3537.89 72.050 293.590 2323.05 2395.35 935.97 N 1868.65 W 6000836.65 N 563721.86 E 2.504 1246.24 3634.02 74.370 292.360 2350.81 2423.11 971.89 N 1953.38 W 6000871.81 N 563636.82 E 2.706 1296.32 3730.04 75.130 291.980 2376.07 2448.37 1006.85 N 2039.17 W 6000906.02 N 563550.73 E 0.879 1345.65 3826.55 73.860 292.010 2401.87 2474.17 1041.67N 2125.39 W 6000940.09 N 563464.20 E 1.316 1394.92 . 3922.67 75.520 296.360 2427.26 2499.56 1079.66 N 2209.93 W 6000977.33 N 563379.33 E 4.694 1447.01 4018.77 75.070 295.920 2451.65 2523.95 1120.61 N 2293.38 W 6001017.54 N 563295.53 E 0.645 1501.83 4115.29 73.800 293.930 2477.55 2549.85 1159.80 N 2377.69 W 6001055.99 N 563210.88 E 2.382 1555.06 4211.87 74.760 287.430 2503.75 2576.05 1192.59 N 2464.62 W 6001088.02 N 563123.66 E 6.554 1602.45 4307.74 75.130 290.590 2528.65 2600.95 1222.75 N 2552.13 W 6001117.41 N 563035.89 E 3.206 1647.35 4404.04 74.690 287.530 2553.73 2626.03 1253.11 N 2640.00 W 6001146.99 N 562947.75 E 3.102 1692.50 4499.90 76.790 286.390 2577.34 2649.64 1280.20 N 2728.86 W 6001173.31 N 562858.66 E 2.475 1734.62 4596.12 77.110 294.610 2599.10 2671.40 1313.00 N 2816.58 W 6001205.34 N 562770.66 E 8.329 1782.15 4692.22 76.530 300.500 2621.03 2693.33 1356.26 N 2899.49 W 6001247.86 N 562687.37 E 5.998 1839.15 4788.89 76.910 294.830 2643.26 2715.56 1399.92 N 2982.79 W 6001290.79 N 562603.69 E 5.722 1806.61 4885.92 77.230 302.190 2665.00 2737.30 1445.03 N 3065.82 W 6001335.17 N 562520.26 E 7.400 1955.45 4980.71 76.860 299.910 2686.25 2758.55 1492.68 N 3144.96 W 6001382.12 N 562440.71 E 2.376 2016.12 5075.30 76.660 295.900 2707.92 2780.22 1535.76 N 3226.31 W 6001424.48 N 562358.99 E 4.132 2072.67 5171.69 77.050 297.730 2729.84 2802.14 1578.10 N 3310.08 W 6001466.09 N 562274.85 E 1.893 2128.92 5265.62 74.560 295.080 2752.88 2825.18 1618.60 N 3391.62 W 6001505.87 N 562192.96 E 3.809 2182.96 5359.62 74.560 294.590 2777.91 2850.21 1656.66 N 3473.85 W 6001543.20 N 562110.40 E 0.502 2234.72 . 5466.88 73.730 295.020 2807.21 2879.51 1699.94 N 3567.50 W 6001585.66 N 562016.36 E 0.865 2293.61 5550.20 72.960 296.190 2831.09 2903.39 1734.44 N 3639.49 W 6001619.53 N 561944.08 E 1.632 2340.08 5646.60 71.890 295.630 2860.20 2932.50 1774.60 N 3722.15 W 6001658.96 N 561861.07 E 1.240 2393.98 5740.95 73.880 293.760 2887.97 2960.27 1812.26 N 3804.07 W 6001695.90 N 561778.82 E 2.835 2445.29 5836.13 75.330 294.070 2913.23 2985.53 1849.46 N 3887.95 W 6001732.36 N 561694.61 E 1.555 2496.50 5931 .40 74.940 291.530 2937.68 3009.98 1885.14 N 3972.83 W 6001767.29 N 561609.42 E 2.609 2546.37 6028.15 75.650 290.730 2962.24 3034.54 1918.87 N 4060.12 W 6001800.26 N 561521.84 E 1.085 2594.75 6122.48 75.140 291.820 2986.02 3058.32 1951.99N 4145.18 W 6001832.63 N 561436.50 E 1.242 2642.14 6217.06 75.070 289.540 3010.34 3082.64 1984.27 N 4230.69 W 6001864.15 N 561350.71 E 2.331 2688.77 6313.40 75.480 294.800 3034.84 3107.14 2019.42 N 4316.94 W 6001898.54 N 561264.15 E 5.298 2738.37 6410.05 74.950 293.360 3059.51 3131.81 2057.55 N 4402.25 W 6001935.92 N 561178.51 E 1.541 2790.73 6503.12 75.530 292.570 3083.22 3155.52 2092.66 N 4485.12 W 6001970.31 N 561095.34 E 1.031 2839.70 6599.39 76.110 295.000 3106.81 3179.11 2130.30 N 4570.52 W 6002007.20 N 561009.61 E 2.520 2891.60 ~~_.____"_."'__"_"~___'_'~'~__"____"____.__"_""__.__w.__ 16 September. 2003 - 7:05 Page 3 of 6 DrillQuest 3.03.02.005 Sperry-Sun ·.Drl/~tl'!l~·Services Survey Report for Milne Point MPS - MPS-34 MWD Your Ref: API 500292317100 Job No. AKMWOO02600988, SUrlleyed: 18 August, 2003 SP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 6695.57 76.690 291.270 3129.43 3201.73 2167.02 N 4656.47 W 6002043.16 N 560923.34 E 3.817 2942.69 6792.46 77.060 281.140 3151.48 3223.78 2193.31 N 4746.95 W 6002068.65 N 560832.63 E 10.188 2984.29 6888.50 74.420 303.810 3175.43 3247.73 2228.53 N 4832.36 W 6002103.12 N 560746.91 E 23.030 3033.80 6984.67 72.700 302.400 3202.65 3274.95 2278.91 N . 4909.62 W 6002152.82 N 560669.21 E 2.275 3096.83 7081.26 72.110 301.690 3231.85 3304.15 2327.76 N 4987.66 W 6002200.98 N 560590.75 E 0.930 3158.49 7176.76 72.250 302.820 3261.08 3333.38 2376.28 N 5064.55 W 6002248.83 N 560513.44 E 1.136 3219.63 . 7273.04 73.470 299.710 3289.46 3361.76 2424.02 N 5143.18 W 6002295.87 N 560434.39 E 3.337 3280.29 . 7368.85 73.790 300.080 3316.46 3388.76 2469.83 N 5222.88 W 6002340.99 N 560354.29 E 0.499 3339.25 7465.94 73.930 298.330 3343.45 3415.75 2515.34 N 5304.28 W 6002385.77 N 560272.49 E 1.737 3398.20 7560.95 73.110 300.420 3370.41 3442.71 2560.02 N 5383.67 W 6002429.76 N 560192.71 E 2.279 3455.99 7656.81 75.920 296.570 3396.00 3468.30 2604.06 N 5464.84 W 6002473.08 N 560111.16 E 4.855 3513.46 7752.35 76.290 296.270 3418.95 3491.25 2645.33 N 5547.90 W 6002513.62 N 560027.74 E 0.493 3568.52 7849.59 76.280 297.920 3442.00 3514.30 2688.35 N 5632.00 W 6002555.90 N 559943.27 E 1.648 3625.50 7945.89 75.520 298.560 3465.46 3537.76 2732.54 N 5714.28 W 6002599.37 N 559860.60 E 1.019 3683.30 8041.57 75.850 294.100 3489.13 3561.43 2773.65 N 5797.35 W 6002639.75 N 559777.18 E 4.530 3738.21 8137.24 75.960 294.370 3512.43 3584.73 2811.74 N 5881.96 W 6002677.09 N 559692.23 E 0.297 3790.41 8232.89 75.780 293.160 3535.78 3608.08 2849.12 N 5966.85 W 6002713.72 N 559607.02 E 1.241 3841.97 8328.42 76.470 296.700 3558.70 3631.00 2888.21 N 6050.93 W 6002752.07 N 559522.60 E 3.669 3895.06 8425.20 76.230 296.910 3581.54 3653.84 2930.62 N 6134.87 W 6002793.74 N 559438.29 E 0.326 3951.40 8521.17 76.990 295.470 3603.76 3676.06 2971.82 N 6218.65 W 6002834.21 N 559354.15 E 1.661 4006.53 8617.70 76.440 296.390 3625.95 3698.25 3012.90 N 6303.13 W 6002874.54 N 559269.31 E 1.089 4061.65 8714.04 76.460 296.930 3648.52 3720.82 3054.92 N 6386.83 W 6002915.83 N 559185.24 E 0.545 4117.57 8808.14 74.950 299.520 3671.75 3744.05 3098.04 N 6467.17W 6002958.24 N 559104.53 E 3.113 4173.98 . 8903.68 74.500 297.140 3696.93 3769.23 3141.77N 6548.29 W 6003001.26 N 559023.03 E 2.449 4231.14 8999.72 74.250 305.100 3722.83 3795.13 3189.53 N 6627.40 W 6003048.31 N 558943.50 E 7.986 4291.90 9096.88 73.160 304.670 3750.10 3822.40 3242.86 N 6703.90 W 6003100.98 N 558866.54 E 1.200 4357.71 9193.00 73.050 306.020 3778.03 3850.33 3296.07 N 6778.91 W 6003153.52 N 558791.06 E 1.349 4423.14 9289.21 72.080 308.490 3806.86 3879.16 3351.62 N 6851.97 W 6003208.43 N 558717.52 E 2.649 4490.53 9384.53 71.840 310.580 3836.38 3908.68 3409.31 N 6921.87 W 6003265.50 N 558647.12 E 2.100 4559.48 9481.21 72.060 310.630 3866.34 3938.64 3469.14 N 6991.65 W 6003324.72 N 558576.81 E 0.233 4630.52 9576.46 73.610 319.190 3894.50 3966.80 3533.34 N 7056.02 W 6003388.35 N 558511.88 E 8.738 4704.92 9672.14 75.140 324.960 3920.29 3992.59 3605.99 N 7112.61 W 6003460.50 N 558454.66 E 6.023 4786.30 9768.54 74.570 329.540 3945.48 4017.78 3684.23 N 7162.93 W 6003538.29 N 558403.64 E 4.624 487209 9865.35 73.710 335.960 3971.97 4044.27 3766.96 N 7205.56 W 6003620.65 N 558360.30 E 6.440 4960.96 9961.42 75.520 333.990 3997.46 4069.76 3850.88 N 7244.74 W 6003704.22 N 558320.37 E 2.731 5050.41 ______.____.__M_ ._ _._..__.",."._..,--_._,...__.-..._._.--~-_._-_._-- 16 September, 2003 - 7:05 Page 40f6 DrillQlJest 3.03.02.005 Sperry-Suntarilf' Survey Report for MII"t."Ffðt Your Ref:Al!þSt1O ., .,,60 Job No. AKMW0002600988, Surveyed: 18 August, 2003 BP EXPLORA TlON (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (·¡100ft) 10057.42 76.670 338.980 4020.54 4092.84 3936.30 N 7281.90 W 6003789.31 N 558282.47 E 5.186 5140.99 10153.41 77.760 342.280 4041.79 4114.09 4024.60 N 7312.94 W 6003877.34 N 558250.66 E 3.540 5233.34 10249.18 76.040 349.580 4063.52 4135.82 4115.00 N 7335.62 W 6003967.54 N 558227.19 E 7.638 5326.30 10346.20 75.780 352.050 4087.14 4159.44 4207.89 N 7350.64 W 6004060.29 N 558211.35 E 2.484 5420.39 10440.75 76.480 355.200 4109.81 4182.11 4299.10 N 7360.82 W 6004151.41 N 558200.36 E 3.318 5511.98 10537.26 76.930 359.350 4132.02 4204.32 4392.90 N 7365.28 W 6004245.16 N 558195.08 E 4.211 5605.13 . 10632.49 78.070 4.780 4152.64 4224.94 4485.77 N 7361.93 W 6004338.06 N 558197.62 E 5.694 5696.01 10728.71 79.640 6.510 4171.24 4243.54 4579.71 N 7352.64 W 6004432.08 N 558206.08 E 2.403 5786.91 10824.55 79.690 2.480 4188.44 4260.74 4673.68 N 7345.25 W 6004526.11 N 558212.65 E 4.137 5878.17 10920.32 80.130 5.260 4205.22 4277.52 4767.75 N 7338.88 W 6004620.23 N 558218.18 E 2.895 5969.70 11019.00 78.110 5.510 4223.85 4296.15 4864.22 N 7329.79 W 6004716.78 N 558226.43 E 2.062 6063.13 11086.79 78.750 5.940 4237.45 4309.75 4930.30 N 7323.17 W 6004782.91 N 558232.47 E 1.130 6127.05 11159.00 78.750 5.940 4251.53 4323.83 5000.74 N 7315.84 W 6004853.42 N 558239.18 E 0.000 6195.15 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 350.000· (True). Magnetic Declination at Surface is 25.412°(11-Aug-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 11159.00ft., The Bottom Hole Displacement is 8861.65ft., in the Direction of 304.355· (True). . _._--_._--,-----~_._--.,~-----_.- 16 September, 2003 - 7:05 Page 50'6 DrillQuest 3.03.02.005 Sperry-Sunprt . ·;Services Survey Report for Milne. S ;'MPS-34 MWD Your Ref: API S()(}Z92317100 Job No. AKMWOO02600988, Surveyed: 18 August, 2003 BP EXPLORA TION (ALASKA) INC. Milne Point Unit Comments Measured Depth (ft) 11159.00 Station Coordinates TVD Northings Eastings ~) ~ ~) 4323.83 Comment 5000.74 N 7315.84 W Projected Survey Survey tool program for MPS-34 MWD From Measured Vertical Depth Depth (ft) (ft) 0.00 278.90 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 278.90 278.89 11159.00 278.89 Tolerable Gyro 4323.83 MWD Magnetic 16 September, 2003 - 7:05 Page 6 0£6 , BPXA . .~ . DrillQllest 3.03.02.005 · ffiJ} !Æ ~!Æ~ ,-- I I ! / / / i I FRANK H. MURKOWSKI, GOVERNOR AI/ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage Alaska 99519 Re: Milne Point Unit MPS-34 BP Exploration (Alaska), Inc. Permit No: 203-130 Surface Location: 3252' NSL, 412' WEL, Sec. 12, TI2N, RI0E, UM Bottomhole Location: 4584' NSL, 1003' WEL, Sec. 02, T12N, RI0E, UM Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincer..e. ly,....(2dJL . ~' I - .' J Sarah Palin Chair BY ORDER 9J THE COMMISSION DATED thisN day of July, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section · STATE OF ALASKA .. ALASI\!IIft)IL AND GAS CONSERVATION COrJllllfSSION PERMIT TO DRILL 20 MC 25.005 1 a. Type of work II Drill 0 Redrill 11 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil ORe-Entry 0 Deepen 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 72' Milne Point Unit / Schrader 3. Address 6. Property Designation Bluff P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 380109 4. Location of well at surface x = 565599: Y = 5999917· 7. Unit or Property Name 3252' NSL, 412' WEL, SEC. 12, T12N, R10E, UM ' Milne Point Unit At top of productive interval x = 558106. Y = 6004303 8. Well Number 2419' NSL, 2586' WEL, SEC. 02, T12N, R10E, UM / MP&-34 At total depth x = 559670, Y = 6006480 9. Approximate spud date 4584' NSL, 1003' WEL, SEC. 02, T12N, R10E, UM 08105103 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025906, 695' MD No Close Approach 2560 /' 13393' MD / 4242' TVD ..- 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} o Kick Off Depth 300' MD Maximum Hole Angle 99 Maximum surface 1545 psig, At total depth (TVD) 4202' / 1966 psig 18. Casing Program S T r Setting Depth Size pecllca Ions Top Bottom Casina Weiaht Grade CouclinÇl Lenath MD TVD MD TVD 20" 92# H-40 Welded 112' Surface Surface 112' 112' 10-3/4" 45.5# L-80 BTC 5491' Surface Surface 5491' 2892' 7-5/8" 29.7# L-80 BTC·L11104' Surface S.u..rface 11104' 4309' 4-1/2" 12.6# L-80 BTC 3140' 10675' r(229' 13393' 4242' R,C. ...~T ç~..< Á (;}-) 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Hole 42" 13-1/2" 9-7/8" 6-1/8" Quantity of Cement (include staae data) 260 sx Arctic Set (Approx.) 853 sx PF 'L', 221 sx Class 'G' 255 sx PF 'E', 434 sx Class 'G' Uncemented Slotted Liner i9. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 3 Perforation depth: measured true vertical II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch III Drilling Program IBI Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report IBI 20 AAC 25.050 Requirements Contact Engineer Name/Number: Steve Campbell, 564-4401 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I ~erebY certify that the fpgOing is true 20rrect to the best of my ~nOWI~~ge . L S,g~~. f'a>"':'" .>;Sa..tl~"'.¢ì~~~;;;~&1Ji¡ Date ;:.;:~y/,:?-~ Permit Numbe203~/30 I ::1 ~~;_ 23// j-DD I AJ?P1C>~~ 1 ~~:~::re;~~~ti~:ments Conditions of Approval: Samples Required 0 Yes &No Mud Log Rlruired 0 Yes I:3No Hydrogen Sulfide Measures 0 Yes -aNo Directional Sùrvey Required ~Yes 0 No Required Working Pressure for BOPE Ó 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Orfg0ther: ~50QÇ>";\ {ßOQ~",>~ Inal Sigi1ed tsy' . by order of :~~~o~;~~~ Rev. 12_01_8¿~rah I'sIlir¡ 0 ttf(jrt~JeÀ L the commission 20. Attachments Date 1 ~~ SUOO1it In ~~Pllate -- Milne. MPS-34 Well Permit I Well Name: I MPS-34 Drill and Complete Plan Summary I Type of Well (service I producer I injector): 1 Multi Lateral Producer "OA" & "OB" Surface Location: 2028' FNL, (3251' FSL),/412' FEL. (4867' FWL), SEC. 12, T12N, R10E /" E=565598.69 N=5999916.85 Target Location: 3268' FNL, (2011' FSL), 2542' FEL, (2736' FWL), SEC. 2, T12N, R10E TOP "OA" E=558153.03 N=6003895.24 Z=4137' TVD Target Location: 695' FNL, (4584' FSL), 1003' FEL, (4276' FWL), SEC. 2, T12N, R10E BHL "OA" Well TD E=559670.0 N=6006480.0 Z=4202' TVD Target Location: ' 2860' FNL, (2419' FSL);"2585' FEL, (2693' FWL), SEC.2, T12N, R10E TOP "OB" E=558106.48 N=6004302.67 Z=4229' TVD Target location: 695' FNL, (4584' FSL);"1003' FEL, (4276' FWL), SEC. 2, T12N, R10E /' BHL "OB" Welt TD E=559670.0 N=6006480.0 Z=4242' TVD ' I AFE Number: 1 TBD I Rig: I Doyon 14 1 I Estimated Start Date: 1 05 AUG 2003 I Operating days to complete: 114 1 I MD: 113,3931 I TVD: 14,242 1 I Max Inc: 199 I I KOP: 1300 I I KBE: 172 I I Well Design (conventional, slim hole, etc.): 1 Conventional Grass Roots ML Producer 1 /' I Objective: I Schrader Bluff OA & OB Sand Mud Program: 13.S-in Surface Hole Mud Properties: Spud - LSND Freshwater Mud Density (ppg) Funnel Vis I yp I HTHP pH I API Filtrate I LG Solids 8.6 - 9.2 75 - 150 25 - 60 N/A 9.0 - 9.5 < 12 < 6.5 9.87S-in Intermediate Hole Mud Properties: LSND Freshwater Mud Density (ppg) PV I YP HTHP pH API Filtrate LG Solids 8.8 - 9.2 10 - 20 25 - 30 10- 11 9.0 - 9.5 < 6 < 15 6.12S-in Production Hole Mud Properties: KCI-CaC03 FloPro Density (ppg) I PV YP I HTHP pH API Filtrate I MBT 9.0 - 9.2 10 - 20 25 - 30 10 - 11 9.0 - 9.5 < 6 < 7 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU lR. 1 It Milne ~t MPS-34 Well Permit Cement Program: Casing 1 0.75-in 40-lb/ft L-80 BTC surface casing Size Basis 175% excess over gauge hole in permafrost interval. 40% excess over gauge hole below permafrost. Top of tail cement 500-ft MD above casing shoe. Total Cement Wash 20-bbl Water Spacer Vol: 527-bbl Spacer 50-bbI10.3-lb/gal un-viscosified Alpha spacer Lead 630-bbl, 853-sx 10.7-lb/gal Permafrost L - 4.15 fe/sx (cement to surface) Tail 45-bbl, 221-sx 15.8-lb/gal Premium G - 1.15 fe/sx of tail at 4991-ft Temp BHST == 55°F from SOR, BHCT 60°F estimated by Halliburton Casing Size Basis 7.625-in 29.7-lb/ft L-80 BTC intermediate casing Top of lead cement 500-ft above top of Ugnu-sand. 0% excess over gauge. Top of tail cement 500-ft MD above top of N-sand. 40% excess over gauge. Total Cement Wash 5-bbl Water Vol: 117-bbl Spacer 30-bbl 10.3-lb/gal un-viscosified Alpha Spacer Lead 98-bbl, 255-sx 12.0-lb/gal Permafrost E - 2.17 fe/sx (top of lead at 7591-ft MD) Tail 89-bbl, 434-sx 15.6-lb/gal Premium G - 1.15 fe/sx of tail at 9438-ft Temp BHST == 80°F from SOR, BHCT 70°F estimated by Halliburton Evaluation Program: 13.5-in Hole Section: Open Hole: MWD/GR, IFRlCASANDRA Cased Hole: N/A 9.875-in Hole Section: Open Hole: MWD/GRlRES, - -., IFRlCASANDRA Cased Hole: N/ A 6.125-in Hole section: Open Hole: MWD/GRlRES, ABI/lFRlCASANDRA Cased Hole: N/A / / 2 e Milne et MPS-34 Well Permit Formation Markers Formation Tops MOrkb TVDrkb Pore Pressure Estimated EMW (ft) (ft) (psi) (Ib/gal)* Base Permafrost 2040 1822 8.35 TUZC 8091 3567 1548 8.35 NA 9938 4057 1761 8.35 NB 10014 4077 1770 8.35 NC 10091 4097 1778 8.35 NE 10131 4107 1783 8.35 NF 10314 4152 1802 8.35 Top OA 10422 4177 1813 8.35 Base OA 10537 4202 1966 9.0 Top OB 10738 4242 1841 8.35 TO 11104 4309 1870 8.35 / * Based on SS depths CasingITubing Program Hole Size Csg/ Wt/Ft Grade Conn Length Top Bottom Tbg O.D. MD / TVDrkb MD / TVDrkb 42-in 20-in* 92# H-40 Welded 80' 0' 112' 1 112' 13.5-in 10.75-in 45.5# L-80 BTC- 5491 0' 5491 '/2892' - 9.875-in 7.625-in 29.7# L-80 BTC- 11104 0' 11104/4309 - 6.125-in 4.5-in 12.6# L-80 8TC' 3140' 10,675/4229 13,393/4242' 08 Slotted 6.125-in 4.5-in 12.6# L-80 BTC 2701' 10,253/4137 13,376/4202' OA Slotted * The 20-in conductors are insulated. ~ i'I'C>~A~ Recommended Bit Program BHA Hole Size Depth (MD) Bit Type 1 13.5-in 0' - 5491' Smith MGXi 2 9.875-in 5491' - 11104' Smith FGXiCPS 3 6.125-in 10253' - TO Security FM2643 4 6.125-in 10625' - TO Security FM2643 Nozzle/Flow rate 3-15 & 1-1 0 3-15 & 1-1 0 3-12 3-12 3 e Milne. MPS-34 Well Permit Well Control: Surface hole will be drilled with a diverter. Intermediate hole: · Maximum anticipated BHP: · Maximum surface pressure: 1,96&psi @ 4,202-ft TVOrkb - Top of "OA" 1 ,545-psi @ surface (Based on BHP and a full column of gas from TO @ 0.1-psi/ft) · Planned BOP test pressure: 3,500-psi. · Integrity test: ~. . . n FIT to 11.5-lb/gal will be made on the 10. 75-in casing /' ~~oe. Kick tolerance: 89-bbl with 9.2-lb/gal mud. · Planned completion fluid: 9.7-lb/gal brine / 7.0-lb/gal Diesel (1 ,BOO-ft MD). Drilling Hazards & Contingencies: Hydrates · Hydrates have not been seen on S pad, but has been encountered in the surface holes on other pads, especially nearby H-Pad. Hydrates generally occur just below the Permafrost (+/- 1800 ss) but may be present in shallower SV sands and also as deep as 3000 ft. Be alert for the possibility of shallow gas and/or hydrates. Use recommended practices for drilling hydrates. Increase mud wt; Maintain cool mud « 60 deg F); Limit ROP and reduce pump rate while drilling hydrates; Circulate connections thoroughly. See Well Program and Recommended Practices for specific information. · Another item to watch out for is deeper gravels below the Permafrost or gravels that calve off within the permafrost and will tend to drop out when the aerated hydrate gas cut mud is being circulated out. Maintain adequate viscosity. In the past several Milne Pt wells have experienced stuck pipe from this situation. Lost Circulation · We do not expect losses while drilling this well. · Offset wells encountered losses while running and cementing casing and only one well had losses while running a hole opener. Below is a list of the wells and the lost circulating problems associated with them. H-06 (1995): Lost 100 bbls running 9-5/8" casing, good returns during cementing except no returns for last 20 bbls, contaminated cement to surface, cement 12 ft down, no top job. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. Expected Pressures · It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. Reservoir pressure is expected to be (8.35 Ib/gal EMW). In this well, the Schrader Bluff formation will be drilled with 9.1-lb/gal mud. 4 e Milne ~t MPS-34 Well Permit Pad Data Sheet · Please Read the S-Pad Data Sheet thoroughly. Breathing . N/A Hydrocarbons · Hydrocarbons will be encountered in the NA through the Schrader Bluff. Faults · NA Hydrogen Sulfide · MPS Pad is not designated as an H2S Pad. Anti-collision Issues . MPS-34 has no anti-collision issues. 5 e Milne.e.t MPS-34 Well Permit DRILL & COMPLETION PROCEDURE Pre-Rig Operations 1 . The 20-in insulated conductor is installed 2. NU diverter Procedure 1. MI/RU Doyon 14 2. Function test diverter, PU 4.0-in drill pipe 3. Drill 13.5-in surface hole 4. Run and cement 10. 75-in casing 5. ND diverter, install wellhead, NU BOPE and test 6. Drill 9.875-in intermediate hole 7. Run and cement 7.625-in casing 8. Set whipstock and mill window for OB 9. Drill 6.125-in OB horizontal production hole 10. Run 4.5-in slotted liner 11. Run whipstock and mill window for OA lateral 12. Drill 6.125-in OA horizontal production hole 13. Retrieve whipstock 14. Run 4.5-in slotted liner and hang off in 7.625-in casing 15. Displace drilling mud to brine 16. Run 4.5-in jet pump completion 17. ND /NU 18. Freeze protect well 19. RD/MO 6 I Ie I I I MPS-34t33 I r _31i..j I _29i I I _27 I r.. _25 J I _24i I -23 1 _21i 1 I _19i I MPU I~ 1 _17 1 _15i I I _13i I LEGEND r _ 11 ..j -+- AS-BUILT CONDUCTOR ___I _ 9i II. EXISTING CONDUCTOR I . ___ _ 7i L 1i5___ J I .l SE:CT - - - 1- -... MPS-2~ 3 - :::--:.. 12 TI2 II I .... SE:CT 7· . N. RIOE: I MPS-1 TI2N. Rì"ìf- . I r 1 I I 1 ~ r I 1 ~ I ~x:::/:J!~ _'- _ _ _'- _ _ _L _ _ _L j . Æ> / · , NOTES: 1. DATE OF SURVEY: DECEMBER 13 & 15, 2002. 2. REFERENCE FIELD BOOK: MP02-08 PGS. 16-17 & 20-21. 3. COORDINATES ARE ALASKA STATE PLANE, ZONE-4 NAD-27. 4. GEODETIC COORDINATES ARE NAD-27. 5. MPU S-PAD AVERAGE SCALE FACTOR IS: 0.999904923. 6. HORIZONTAL CONTROL IS BASED ON MPU CFP MONUMENT CFP-3 AND MPU H-PAD MONUMENT H-1. 7. ELEVATIONS ARE BPX MEAN SEA LEVEL BASED ON MILNE POINT PIPELINE VERTICAL CONTROL. I -Z~ I PLANT t 15·00'00" GRID S-PAD _2~ 21 28 ~-~AD 35 32 33 T13N T12N 2 11 9 10 Ww 14 13 SO::: 18 17 16 15 "'''' VICINITY MAP N.T.S. SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERL Y REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF DECEMBER 15, 2002. LOCATED WITHIN PROTRACTED SEC. 7, T. 12 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.s.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS MPS-01 Y=6,OOO,044.65 N= 2,236.68 70·24'38.007" 70.4105578· 38.3' 3,375' FSL X= 566,076.93 E= 6,959.07 149·27'43.011" 149.4619475· 4,714' FEL MPS-02 Y=6,OOO,041.30 N= 2,237.19 70·24'37.976" 70.4105489· 38.3' 3,372' FSL X= 566,062.45 E= 6,944.21 149·27'43.437" 149.4620658· 4,729' FEL LOCA TED WITHIN PROTRACTED SEC. WELL A.s.P. PLANT NO. COORDINATES COORDINATES MPS-34 Y= 5,999,917.12 N= 2,237.28 X= 565,598.66 E= 6,464.04 12, T. 12 N., R. 10 E., UMIAT MERIDIAN, ALASKA GEODETIC GEODETIC CELLAR SECTION POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS 70·24'36.795" 70.4102208· 38.0' 3,252' FSL 149·27'57.063" 149.4658508· 412' FEL F. Robert DRA'NN: Obp COTTON bf CHECKED: AWSON DATE: 12/11/02 DRAWING: MILNE POINT UNIT S-PAD SHEET: FRB02 MPS 33-00 ~ ff]~~[JœD JOS NO: AS-BUILT CONDUCTORS ENœ€ERS NC) LAHO SUR'£YORS SCALE: 1 OF 1 JJC RFA WELLS MPS-01, MPS-02 & MPS-34 IID1\IEST FlREWEED LANE 1"= 160' BY CHK ANCHORAGE. I\lASKA ~50.1 o 12/17/02 ISSUEO FOR INFORMATION NO. DATE REVISION TREE: Cameron 4-1/16" 5M WELLHEAD: FMC Gen 5 11 ", 5M Tubing Head: 11" x 4-1/2", FMC Tubing Hanger ~HOI-'O~I:::U COMI-'LI::: I lOr). WI P 5-34 & ~-::¡~J 1. I KB. ELEV =66' I Cellar Box ELEV = 38.5' 112' 20" 92 Ib/tt, H-40 Welded ~ Insulated Diesel Freeze protect to 500' MD 10-314" 45.5#, L-80, BTC-M Casing Drift: 9.875 Casing 10: 9.950 Coupling 00: 11.75" Burst: 5,210 psi Collqpse: ? .480 psi . 9.7 KCL with corrosion inhibitor as packer fluid Jet Pump Installed in Sliding Sleeve Post rig! 7-5/8" 29.7#, L-80, BTC-M Casing Drift: 6.75 Casing 10: 6.875 Coupling 00: 11.75" Burst: 6,890 psi Collapse: 4,790 psi Window in 7-5/8" casing @ 10,253' Well Inclination @ Window = 76 deg ~ Top liner @ 10,575' MD~ ,-~, ~ ?<t."'-^ \ \. Window in 7-5/8" casing @ 10,675' Well Inclination @ Window = 79 deg 7-5/8" ing Shoe @ 11,104' Mn Welllnclina . @ Shù~79 Degree;-- DATE 07/24/03 REV. BY SKC COMMENTS Level 3 Multi-Lateral, 4-1/2" Jet Pump Completion Milne Point Unit WF : 8-34 API NO: .... III . ----- ~ ~L .... 42" Hole 4-1/2" x 1" Gas Lift Mandrel @ 2,267' MD, 2080' TVD, RP shear valve open position, "X" Nipple (2.813" ID) 70' below GLM 4-1/2", 12.6Ib/ft, L-80, IBT-M Coupling 00: 5.2" OriftllD: 3.833" Burst: 8,430, 80% 6,744 psi Collapse: 7,500, 80%=6,000 psi , .. 110-314" @ 5,491'MD; 2,892' TVD BIW 1- Wire Phoenix Pressure Gauge (3.850" ID, W/BIW 1- wire down to lower sensor) Halliburtion Dura Sleeve XD WIX Nipple (3.813" ID) Phoenix Pressure Gauge (2.840" ID) 7-5/8" x 4-1/2" Premier Packer ISet @ 10,200'MD, 4124' TV' 3-1/2" HES 'XN' nipple 2.750" ID No Go W/RHC-M for ball & rod Wireline Entry Guide Multi-Lateral Junction 110,253' I 6-1/8" OA Lateral 2 TD 13,376' \~ ....... """'- - - - - -- OA Horizontal 6-1/8" hole r'- - - - - - - - - 4-1/2" Slotted Liner W/Hookwall hanger ( 9-7/8" Hole ~OBLatp.~93'J 08 Horizontal 6-118" hole - - - - - -- - - - - -- ------ 4-1/2" Slotted Liner W/liner hanger ~ BP bp COMPANY DETAILS DP Amoco Calculation Method: Minimum Curvatun; Error System; ISCWSA Scan Method: Trav Cylinder North E~r Surface: Elliptical i' Casing Wamm~ Method: Rules Bast.'<i 0--:: A REFERENCE INFORMATION Co-ordinate (NÆ) Reference: Well Centre: Plan MPS-34, True North Vertical (TVD) Reference: S-Pad Dev 72.00 Section (VS) Reference: Slot - (O.(}{}N,O.OOE) Measured Depth Referenœ; S-Pad Dev 12.00 Calculation Method: Minimum Curvature l I I ~ I I" '#' '" #, , # ;" Start Dir 3/100' : 300' MD. 300'TVD "/ S· 100 Start Dir 2.751100': 1500' MD, 1422.59'TVD '2 £i o o o :;; 2000 " Ö '" o .€ .;: 2 f-< 3000 4000 5000 o #-/~ '< End Dir : 1966.74' MD. 1772' TVD Start Dir 4/100': 2081.11' MD, 1850'TVD q SURVEY PRCXJRAM Tool Created By: Ken Allen Checked: Plan: MPS-34PBl wpll (plan MPS-341P1an MPS-34PBJ) Date Depth Frn Depth To SurveyIPlan 33.00 700,00 Plarmed: MPS-J4PßI wpll V22 700.00 11104.83 PlaMed: MPS-34PBI wpll V22 Cß-GYRO-SS MWD+IFR+MS Reviewed: WELL DETAILS Date: 7/18/2003 Date N~ +NI-S +E/-W Northing Easting ~titude Longitude Slot PJanMPS-34 -54.52 -746.89 5999916.85 565598.69 70024'36.792N 149°27'57.063W NIA TARGET DETAILS N~ TVD +NI-S +E/·W Northing Easting Shape MPS-34 T1 4242.00 4514.18 -7450.04 6004365.00 558110.00 Circle (Radiu~: 150) SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TF ace VSec Target 1 33.00 0.00 0.00 33.00 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 1500.00 36.00 300.00 1422.59 182.38 -315.88 3.00 300.00 364.15 4 1966.74 47.00 290.00 1772.00 309.87 -596.23 2.75 325.07 668.46 5 2081.11 47.00 290.00 1850.00 338.47 -674.83 0.00 0.00 749.86 6 2789.60 74.95 295.45 2190.54 579.00 -1238.73 4.00 11.13 1353.24 e 7 9046.26 74.95 295.45 3814.92 3175.16 -6694.66 0.00 0.00 7338.73 8 10738.59 79.34 5.00 4242.00 4514.18 -7450.04 4.00 95.55 8705.20 MPS- 34 T1 9 10954.83 79.34 5.00 4282.00 4725.88 -7431.52 0.00 0.00 8805.94 10 11104.83 79.34 5.00 4309.75 4872.73 -7418.67 0.00 0.00 8875.82 FORMATION TOP DETAILS No. TVDPath MDPath Formation 1 2 3 4 5 6 7 8 9 10 11 12 1822.00 3567.00 3832.00 4057.00 4077.00 4097.00 4107.00 4152.00 4177.00 4202.00 4242.00 4282 00 ., Jtf"""~^~"~"~ CASING DETAILS .. ..... ~'- No. TVD MD Name ., - ~ 1 2892.00 5491.44 103/4" ..1. wv, -~ 2 4309.75 11104.82 75/8 m : , "n .,... ~. ]t}E fL.....I..............i......!.·... , . , 10 ~/4 Total Depth 11104 S3' MD. 4309 75' TVD j End DIf 1073859' MD, 4242' TVD . ..'j ... '.mm ., .. j j : .- . j................. . m'm. . j .. ........ ..... . . 1.; .. .. .....mm. ..... SBM-NC j j . SBF I-NB .....¡... SBF2-NA , · . =1[\r,[:1+ "v'"" /, . .. .. .. . + . .......... ... .' ........ m: , Rè E~_ , . 'm ..j 11m ...... ~BEl·NF· 1.'1 lq~Òi' n1-1rt ., , All TVD depths are :m T ,..... ....... SFC ·11.... +1. ..... ssTVD plus 72'for RKBE. I. 'm ....... . .. m ..:.m m. ... SBA5 (OO,e OB . i · i I j , t t 1 ¡ · , . j . . . . . j j . + . '1 j I .' . .. . I L I J I I , , , , I I , , , , , , I I I : I , , , , , , I L I I I I I I I I I I I I , , , I I I I I I , I I I I , , , 10)0 20)0 3C )0 4000 5000 6000 7000 8000 9 Vertical Section at 303.30· [lOOOft/in] 2040.05 8091.35 9111.55 9938.48 10014.46 10091.84 10131.16 10314.78 10422.98 10537.31 10738.59 10954 83 BPRF TUZC TUBL SBF2-NA SBF1-NB SBE4-NC SBE2·NE SBEI-NF TSBD-OA TSBC (base OA) TSBB·OB SBA5 (base OB) Size 10.750 7.625 e MPS-34PBI wpl1 75/8 I ' 000 I I I I I I bp COMPANY DETAILS BP Amoco REFERENCE INFORMATION SURVEY PROGRAM Plan: MPS-34PBI wpll (plan MPS-34/Plan MPS-34PBI) Depth Fm Depth To SUiVeyIPlan 33.00 700.00 Planned: MPS-34PBl wpll V22 100.00 11104.83 Planned: MPS-J4PBI wpll V22 Tool Co-ordinate (NÆ) Reference: Well Centre: Plan MPS-34, True North Vertical (1VD) Reference: S-Pad Dev 72.00 Section (VS) Reference: Slot - (O.OON,O.OOE) Measured Depth Reference: S·Pad Dev 72.00 Calculation Method: Minimum Curvature Date Calculation Method: Minimum CUlVature Error System: ISCWSA Scan Method: Trav Cylinder North Error Surface: Elliptical + Casing Wamin~ Method: Rules Based CASING DETAILS No. TVD Name Size MD 2892.00 5491.44 103/4" 4309.75 I I 104.82 75/8 10.750 7.625 All TVD depths are ssTVD plus 72'for RKBE. 500(}- Total Depth: 11104.83' MD, 4309.75' TVD MPS·34PBI wpll Dir : 10738.59' MD, 4242' TVD 4000 C 3000 :fi o o ~ +' :E 10 ~ :E ~ 2000 '" 1000 o -8000 -7000 ·6000 Created By: Ken Allen Checked: Date: 7/18/2003 CB-GYRO-SS MWD+IFR+MS Date:_ Reviewed: WELL DETAll..S FORMATION TOP DETAILS ""'" +NI·S +E/-W Northing &sting Latitude Longitude Slol No. TVDPath MDPath Fonnation Plan MPS-34 -54.52 -746.89 5999916.85 565598.69 70024'36.792N 149°27'57.063W NiA 1 1822.00 2040.05 BPRF TARGET DETAILS 2 3567.00 8091.35 ruzc +NI-S +EI-W 3 3832.00 9111.55 ruBL N"", TYO Northing Easting Shape 4 4057.00 9938.48 SBF2-NA MPS-34TI 4242.00 4514.18 "7450.04 6004365.00 558110.00 Circle (Radius; 150) 5 4077.00 10014.46 SBFI-NB 6 4097.00 10091.84 SBE4-NC 7 4107.00 10131.16 SBE2-NE SECTION DETAILS 8 4152.00 10314.78 SBEI-NF 9 4177.00 10422.98 TSBD-OA See MD Ine Azi TVD +N/-S +E/-W DLeg TFaee VSee Target 10 4202.00 10537.31 TSBC (base OA) II 4242.00 10738.59 TSBB-OB I 33.00 0.00 0.00 33.00 0.00 0.00 0.00 0.00 0.00 12 4282.00 10954.83 SBA5 (base OB) 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 1500.00 36.00 300.00 1422.59 182.38 -315.88 3.00 300.00 364.15 4 1966.74 47.00 290.00 1772.00 309.87 -596.23 2.75 325.07 668.46 5 2081.11 47.00 290.00 1850.00 338.47 -674.83 0.00 0.00 749.86 6 2789.60 74.95 295.45 2190.54 579.00 -1238.73 4.00 11.13 1353.24 e 7 9046.26 74.95 295.45 3814.92 3175.16 -6694.66 0.00 0.00 7338.73 8 10738.59 79.34 5.00 4242.00 4514.18 -7450.04 4.00 95.55 8705.20 MPS· 34 Tl 9 10954.83 79.34 5.00 4282.00 4725.88 -7431.52 0.00 0.00 8805.94 10 11104.83 79.34 5.00 4309.75 4872.73 -7418.67 0.00 0.00 8875.82 103/4" e ¡lIP ,I I ¡P ;I I" '# #, #, , # l' #'/~ .... pnd Dir : 2789.6' MD, 2190.54' TVD Start Dir 4/100' : 2081.11' MD, 1850'TVD End Dir : 1966.74' MD, 1772' TVD Start Dir 2.75/100' : 1500'MD, 1422.59'TVD Start Dir 3/100' : 300' MD, 300'TVD I I I I I I I I ·5000 o , I ' 1000 I I I I I I I -4000 -3000 West(-)/East(+) [lOOOftlin] -2000 -1000 Company: Field: Site: Well: Wellpath: BP Amoco Milne Point MPtSPad Plan MPS-34 Plan MPS-34PB1 e BP-GDB KW A Planning Report e Oracle I I Date: 7/18/2003 Time: 16:33:48 Page: Co-ordinate(NE) Referenee: Well: Plan MPS-34, True North Vertieal (TVD) Reference: S-Pad Dev 72.0 Section (VS) Reference: Well (O.00N,0.00E,303.30Azi) Survey Calculation Method: Minimum Curvature Db: . --.-.....--...-..----- Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: M pt S Pad Site Position: From: Map Position Uncertainty: Ground Level: Well: Plan MPS-34 Map Zone: Coordinate System: Geomagnetic Model: Northing: Easting: 5999978.00 ft 566345.00 ft Latitude: 70 24 Longitude: 149 27 North Reference: Grid Convergence: 0.00 ft 0.00 ft Slot Name: Well Position: +N/-S -54.52 ft Northing: 5999916.85 ft +E/-W -746.89 ft Easting: 565598.69 ft Position Uncertainty: 0.00 ft Latitude: Longitude: Wellpath: Plan MPS-34PB1 Current Datum: Magnetic Data: Field Strength: Vertical Section: S-Pad Dev 6/29/2001 57481 nT Depth From (TVD) ft 33.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Height 72.00 ft +N/-S ft 0.00 Principal: Yes Plan: MPS-34PB1 wp11 Date Composed: Version: Tied-to: Casing Points MD TVD ft ft 5491.44 2892.00 11104.82 4309.75 Formations MD TVD ft ft ...-.-..--.... 2040.05 1822.00 8091.35 3567.00 9111.55 3832.00 9938.48 4057.00 10014.46 4077.00 10091.84 4097.00 10131.16 4107.00 10314.78 4152.00 10422.98 4177.00 10537.31 4202.00 10738.59 4242.00 10954.83 4282.00 Targets Name MPS-34 T1 -Circle (Radius: 150) -Plan hit target Diameter in 10.750 7.625 Hole Size in 13.500 9.875 Name 103/4" 7 5/8 Formations Lithology BPRF TUZC TUBL SBF2-NA SBF1-NB SBE4-NC SBE2-NE SBE1-NF TSBD-OA TSBC (base OA) TSBB-OB SBA5 (base OB) .. ........--.---.----....-. Alaska, Zone 4 Well Centre bggm2003 37.329 N 35.171 W True 0.51 deg 70 24 36.792 N 149 27 57.063 W Well Ref. Point 33.00 ft Mean Sea Level 26.21 deg 80.79 deg Direction deg 303.30 7/18/2003 22 From Well Ref. Point ......-.---.--.---....... ....,..·._·'.'...__·_...._..'h__.......___.._.........._....·_.... Dip Angle deQ ...... ...............-......-.----..--..-.-----.... 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Dip Direction deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Description Dip. Dlr. -,............--.--...- Map Map <-- Latitude --> <-- Longitude --> TVD +N/-S +E/-W Northing Easting Dcg Min Sec Deg Min See ft ft ft ft ft 4242.00 4514.18 -7450.04 6004365.00 558110.00 70 2521.152 N 149 31 35.558 W e BP-GDB e KW A Planning Report r-.--.-- BP Amoco 7/18/2003 Time: 16:33:48 Page: 2 I Company: Date: I ¡"ield: Milne Point Co-ordinate(NE) Reference: Well: Plan MPS-34, True North I Site: MPtSPad Vcrtical (TVD) Reference: S-Pad Dev 72.0 I Well: Plan MPS-34 Section (VS) Reference:· Well (0.00N,0.ooE,303.30Azi) I Wellpath: Plan MPS-34PB1 Survey Calculation Method: Minimum Curvature Db: Oracle ....................------..-..... ....................-.---.-- Plan Section Information MD IncI Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/10OO deg/100ft deg/100ft deg ----........--.---. ....__.._. __._____.___.._..______ m 33.00 0.00 0.00 33.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 1500.00 36.00 300.00 1422.59 182.38 -315.88 3.00 3.00 0.00 300.00 1966.74 47.00 290.00 1772.00 309.87 -596.23 2.75 2.36 -2.14 325.07 2081.11 47.00 290.00 1850.00 338.47 -674.83 0.00 0.00 0.00 0.00 2789.60 74.95 295.45 2190.54 579.00 -1238.73 4.00 3.95 0.77 11.13 9046.26 74.95 295.45 3814.92 3175.16 -6694.66 0.00 0.00 0.00 0.00 10738.59 79.34 5.00 4242.00 4514.18 -7450.04 4.00 0.26 4.11 95.55 MPS-34 T1 10954.83 79.34 5.00 4282.00 4725.88 -7431.52 0.00 0.00 0.00 0.00 11104.83 79.34 5.00 4309.75 4872.73 -7418.67 0.00 0.00 0.00 0.00 Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Too ft deg deg ft ft ft ft ft deg/10OO deg 33.00 0.00 0.00 33.00 -39.00 5999916.85 565598.69 0.00 0.00 0.00 CB-GYRO-SS 100.00 0.00 0.00 100.00 28.00 5999916.85 565598.69 0.00 0.00 0.00 CB-GYRO-SS 200.00 0.00 0.00 200.00 128.00 5999916.85 565598.69 0.00 0.00 0.00 CB-GYRO-SS 300.00 0.00 0.00 300.00 228.00 5999916.85 565598.69 0.00 0.00 0.00 CB-GYRO-SS 400.00 3.00 300.00 399.95 327.95 5999918.14 565596.41 2.61 3.00 0.00 CB-GYRO-SS 500.00 6.00 300.00 499.63 427.63 5999922.00 565589.58 10.45 3.00 0.00 CB-GYRO-SS 600.00 9.00 300.00 598.77 526.77 5999928.43 565578.23 23.47 3.00 0.00 CB-GYRO-SS 700.00 12.00 300.00 697.08 625.08 5999937.40 565562.37 41.67 3.00 0.00 MWD+~FR+MS 800.00 15.00 300.00 794.31 722.31 5999948.89 565542.05 64.97 3.00 0.00 MWD+IFR+MS 900.00 18.00 300.00 890.18 818.18 5999962.87 565517.34 93.32 3.00 0.00 MWD+IFR+MS 1000.00 21.00 300.00 984.43 912.43 5999979.30 565488.29 126.64 3.00 0.00 MWD+IFR+MS 1100.00 24.00 300.00 1076.81 1004.81 5999998.14 565454.99 164.84 3.00 0.00 MWD+IFR+MS 1200.00 27.00 300.00 1167.06 1095.06 6000019.33 565417.53 207.82 3.00 0.00 MWD+IFR+MS 1300.00 30.00 300.00 1254.93 1182.93 6000042.82 565376.00 255.45 3.00 0.00 MWD+IFR+MS 1400.00 33.00 300.00 1340.18 1268.18 6000068.54 565330.54 307.61 3.00 0.00 MWD+IFR+MS 1500.00 36.00 300.00 1422.59 1350.59 6000096.43 565281.25 364.15 3.00 0.00 MWD+IFR+MS 1600.00 38.28 297.46 1502.30 1430.30 6000124.94 565228.05 424.31 2.75 325.07 MWD+IFR+MS 1700.00 40.61 295.17 1579.53 1507.53 6000152.57 565170.87 487.35 2.75 327.09 MWD+IFR+MS 1800.00 42.98 293.09 1654.08 1582.08 6000179.24 565109.82 553.13 2.75 328.86 MWD+IFR+MS 1900.00 45.38 291.18 1725.80 1653.80 6000204.91 565045.05 621.48 2.75 330.41 MWD+IFR+MS 1966.74 47.00 290.00 1772.00 1700.00 6000221.44 564999.82 668.46 2.75 331.78 MWD+IFR+MS 2000.00 47.00 290.00 1794.69 1722.69 6000229.56 564976.89 692.13 0.00 0.00 MWD+IFR+MS 2040.05 47.00 290.00 1822.00 1750.00 6000239.33 564949.28 720.64 0.00 0.00 BPRF 2081.11 47.00 290.00 1850.00 1778.00 6000249.35 564920.98 749.86 0.00 0.00 MWD+IFR+MS 2100.00 47.74 290.20 1862.80 1790.80 6000254.01 564907.88 763.39 4.00 11.13 MWD+IFR+MS 2200.00 51.67 291.17 1927.45 1855.45 6000280.34 564836.32 837.82 4.00 11.00 MWD+IFR+MS 2300.00 55.61 292.04 1986.73 1914.73 6000309.34 564761.22 916.66 4.00 10.37 MWD+IFR+MS 2400.00 59.55 292.83 2040.33 1968.33 6000340.87 564682.94 999.55 4.00 9.85 MWD+IFR+MS 2500.00 63.50 293.57 2087.99 2015.99 6000374.79 564601.87 1086.08 4.00 9.43 MWD+IFR+MS 2600.00 67.45 294.25 2129.49 2057.49 6000410.93 564518.41 1175.82 4.00 9.08 MWD+IFR+MS 2700.00 71.41 294.89 2164.61 2092.61 6000449.11 564432.95 1268.35 4.00 8.80 MWD+IFR+MS 2789.60 74.95 295.45 2190.54 2118.54 6000484.89 564355.04 1353.24 4.00 8.57 MWD+IFR+MS 2800.00 74.95 295.45 2193.24 2121.24 6000489.13 564345.93 1363.19 0.00 180.00 MWD+IFR+MS 2900.00 74.95 295.45 2219.20 2147.20 6000529.85 564258.37 1458.85 0.00 180.00 MWD+IFR+MS 3000.00 74.95 295.45 2245.16 2173.16 6000570.58 564170.82 1554.52 0.00 180.00 MWD+IFR+MS 3100.00 74.95 295.45 2271.12 2199.12 6000611.30 564083.26 1650.19 0.00 180.00 MWD+~FR+MS 3200.00 74.95 295.45 2297.09 2225.09 6000652.02 563995.71 1745.85 0.00 180.00 MWD+IFR+MS 3300.00 74.95 295.45 2323.05 2251.05 6000692.75 563908.15 1841.52 0.00 180.00 MWD+IFR+MS 3400.00 74.95 295.45 2349.01 2277.01 6000733.47 563820.60 1937.18 0.00 180.00 MWD+IFR+MS 3500.00 74.95 295.45 2374.97 2302.97 6000774.19 563733.04 2032.85 0.00 180.00 MWD+IFR+MS e BP-GDB e KW A Planning Report ...-.-."-. Company: BP Amoco Date: 7/18/2003 Time: 16:33:48 Page: 3 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPS-34, True North Site: M Pt S Pad Vertical (TVD) Reference: S-Pad Dev 72.0 Well: Plan MPS-34 Section (VS) Reference: Well (0.00N,0.00E,303.30Azi) Wellpath: Plan MPS-34PB 1 Survey Calculation Method: Minimum Curvature Db: Oracle n_m_m___._n_._n.__.__._.n. ...............-.----..-.-.. Survey MD lncl Azim TVD Sys TVD MapN MapE VS DLS TFO Too ft deg deg ft ft ft ft ft deg/10OO deg _._.-.-.-_._.~ _.~,..- ----"" ..--_. ..._.~.._---_.._--- 3600.00 74.95 295.45 2400.94 2328.94 6000814.91 563645.49 2128.52 0.00 180.00 MWD+IFR+MS 3700.00 74.95 295.45 2426.90 2354.90 6000855.64 563557.94 2224.18 0.00 180.00 MWD+IFR+MS 3800.00 74.95 295.45 2452.86 2380.86 6000896.36 563470.38 2319.85 0.00 180.00 MWD+IFR+MS 3900.00 74.95 295.45 2478.82 2406.82 6000937.08 563382.83 2415.51 0.00 180.00 MWD+IFR+MS 4000.00 74.95 295.45 2504.79 2432.79 6000977.81 563295.27 2511.18 0.00 180.00 MWD+IFR+MS 4100.00 74.95 295.45 2530.75 2458.75 6001018.53 563207.72 2606.84 0.00 180.00 MWD+IFR+MS 4200.00 74.95 295.45 2556.71 2484.71 6001059.25 563120.16 2702.51 0.00 180.00 MWD+IFR+MS 4300.00 74.95 295.45 2582.67 2510.67 6001099.98 563032.61 2798.18 0.00 180.00 MWD+IFR+MS 4400.00 74.95 295.45 2608.64 2536.64 6001140.70 562945.05 2893.84 0.00 180.00 MWD+IFR+MS 4500.00 74.95 295.45 2634.60 2562.60 6001181.42 562857.50 2989.51 0.00 180.00 MWD+IFR+MS 4600.00 74.95 295.45 2660.56 2588.56 6001222.14 562769.94 3085.17 0.00 180.00 MWD+IFR+MS 4700.00 74.95 295.45 2686.52 2614.52 6001262.87 562682.39 3180.84 0.00 180.00 MWD+IFR+MS 4800.00 74.95 295.45 2712.49 2640.49 6001303.59 562594.83 3276.51 0.00 180.00 MWD+IFR+MS 4900.00 74.95 295.45 2738.45 2666.45 6001344.31 562507.28 3372.17 0.00 180.00 MWD+IFR+MS 5000.00 74.95 295.45 2764.41 2692.41 6001385.04 562419.73 3467.84 0.00 180.00 MWD+IFR+MS 5100.00 74.95 295.45 2790.37 2718.37 6001425.76 562332.17 3563.50 0.00 180.00 MWD+IFR+MS 5200.00 74.95 295.45 2816.33 2744.33 6001466.48 562244.62 3659.17 0.00 180.00 MWD+IFR+MS 5300.00 74.95 295.45 2842.30 2770.30 6001507.21 562157.06 3754.84 0.00 180.00 MWD+IFR+MS 5400.00 74.95 295.45 2868.26 2796.26 6001547.93 562069.51 3850.50 0.00 180.00 MWD+IFR+MS 5500.00 74.95 295.45 2894.22 2822.22 6001588.65 561981.95 3946.17 0.00 180.00 MWD+IFR+MS 5600.00 74.95 295.45 2920.18 2848.18 6001629.37 561894.40 4041.83 0.00 180.00 MWD+IFR+MS 5700.00 74.95 295.45 2946.15 2874.15 6001670.10 ·561806.84 4137.50 0.00 180.00 MWD+IFR+MS 5800.00 74.95 295.45 2972.11 2900.11 6001710.82 561719.29 4233.16 0.00 180.00 MWD+IFR+MS 5900.00 74.95 295.45 2998.07 2926.07 6001751.54 561631.73 4328.83 0.00 180.00 MWD+IFR+MS 6000.00 74.95 295.45 3024.03 2952.03 6001792.27 561544.18 4424.50 0.00 180.00 MWD+IFR+MS 6100.00 74.95 295.45 3050.00 2978.00 6001832.99 561456.62 4520.16 0.00 180.00 MWD+IFR+MS 6200.00 74.95 295.45 3075.96 3003.96 6001873.71 561369.07 4615.83 0.00 180.00 MWD+IFR+MS 6300.00 74.95 295.45 3101.92 3029.92 6001914.44 561281.51 4711.49 0.00 180.00 MWD+IFR+MS 6400.00 74.95 295.45 3127.88 3055.88 6001955.16 561193.96 4807.16 0.00 180.00 MWD+IFR+MS 6500.00 74.95 295.45 3153.85 3081.85 6001995.88 561106.41 4902.83 0.00 180.00 MWD+IFR+MS 6600.00 74.95 295.45 3179.81 3107.81 6002036.60 561018.85 4998.49 0.00 180.00 MWD+IFR+MS 6700.00 74.95 295.45 3205.77 3133.77 6002077.33 560931.30 5094.16 0.00 180.00 MWD+IFR+MS 6800.00 74.95 295.45 3231.73 3159.73 6002118.05 560843.74 5189.82 0.00 180.00 MWD+IFR+MS 6900.00 74.95 295.45 3257.70 3185.70 6002158.77 560756.19 5285.49 0.00 180.00 MWD+IFR+MS 7000.00 74.95 295.45 3283.66 3211.66 6002199.50 560668.63 5381.16 0.00 180.00 MWD+IFR+MS 7100.00 74.95 295.45 3309.62 3237.62 6002240.22 560581.08 5476.82 0.00 180.00 MWD+IFR+MS 7200.00 74.95 295.45 3335.58 3263.58 6002280.94 560493.52 5572.49 0.00 180.00 MWD+IFR+MS 7300.00 74.95 295.45 3361.55 3289.55 6002321.67 560405.97 5668.15 0.00 180.00 MWD+IFR+MS 7400.00 74.95 295.45 3387.51 3315.51 6002362.39 560318.41 5763.82 0.00 180.00 MWD+IFR+MS 7500.00 74.95 295.45 3413.47 3341.47 6002403.11 560230.86 5859.48 0.00 180.00 MWD+IFR+MS 7600.00 74.95 295.45 3439.43 3367.43 6002443.83 560143.30 5955.15 0.00 180.00 MWD+IFR+MS 7700.00 74.95 295.45 3465.39 3393.39 6002484.56 560055.75 6050.82 0.00 180.00 MWD+IFR+MS 7800.00 74.95 295.45 3491.36 3419.36 6002525.28 559968.19 6146.48 0.00 180.00 MWD+IFR+MS 7900.00 74.95 295.45 3517.32 3445.32 6002566.00 559880.64 6242.15 0.00 180.00 MWD+IFR+MS 8000.00 74.95 295.45 3543.28 3471.28 6002606.73 559793.09 6337.81 0.00 180.00 MWD+IFR+MS 8091.35 74.95 295.45 3567.00 3495.00 6002643.93 559713.10 6425.21 0.00 180.00 TUZC 8100.00 74.95 295.45 3569.24 3497.24 6002647.45 559705.53 6433.48 0.00 180.00 MWD+IFR+MS 8200.00 74.95 295.45 3595.21 3523.21 6002688.17 559617.98 6529.15 0.00 180.00 MWD+IFR+MS 8300.00 74.95 295.45 3621.17 3549.17 6002728.90 559530.42 6624.81 0.00 180.00 MWD+IFR+MS 8400.00 74.95 295.45 3647.13 3575.13 6002769.62 559442.87 6720.48 0.00 180.00 MWD+IFR+MS 8500.00 74.95 295.45 3673.09 3601.09 6002810.34 559355.31 6816.14 0.00 180.00 MWD+IFR+MS 8600.00 74.95 295.45 3699.06 3627.06 6002851.06 559267.76 6911.81 0.00 180.00 MWD+IFR+MS 8700.00 74.95 295.45 3725.02 3653.02 6002891.79 559180.20 7007.48 0.00 180.00 MWD+IFR+MS e BP-GDB e KW A Planning Report .' _.__._.n____..__ Company: BP Amoco Date: 7/18/2003 Time: 16:33:48 Page: 4 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPS-34, True North Site: M PI S Pad Vertical (TVD) Reference: S-Pad Dev 72.0 Well: Plan MPS-34 Section (VS) Reference: Well (0.00N,0.00E,303.30Azi) Wellpath: Plan MPS-34PB1 Survey Calculation Method: Minimum Curvature Db: Oracle .--.-.-............--..---.... ..... .....----. Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Too ft deg deg ft ft ft ft ft deg/10OO deg -..-...... H ----._- ......__.__._~....~ 8800.00 74.95 295.45 3750.98 3678.98 6002932.51 559092.65 7103.14 0.00 180.00 MWD+IFR+MS 8900.00 74.95 295.45 3776.94 3704.94 6002973.23 559005.09 7198.81 0.00 180.00 MWD+IFR+MS 9000.00 74.95 295.45 3802.91 3730.91 6003013.96 558917.54 7294.47 0.00 180.00 MWD+IFR+MS 9046.26 74.95 295.45 3814.92 3742.92 6003032.80 558877.04 7338.73 0.00 180.00 MWD+IFR+MS 9100.00 74.76 297.66 3828.96 3756.96 6003055.57 558830.44 7390.24 4.00 95.55 MWD+IFR+MS 9111.55 74.72 298.14 3832.00 3760.00 6003060.70 558820.55 7401.33 4.00 94.97 TUBL 9200.00 74.45 301.80 3855.52 3783.52 6003102.63 558746.34 7486.44 4.00 94.85 MWD+IFR+MS 9300.00 74.22 305.95 3882.54 3810.54 6003155.58 558665.95 7582.69 4.00 93.87 MWD+IFR+MS 9400.00 74.06 310.10 3909.89 3837.89 6003214.14 558589.69 7678.53 4.00 92.75 MWD+IFR+MS 9500.00 73.99 314.26 3937.42 3865.42 6003278.05 558517.91 7773.49 4.00 91.62 MWD+IFR+MS 9600.00 74.00 318.43 3965.00 3893.00 6003346.99 558450.97 7867.11 4.00 90.47 MWD+IFR+MS 9700.00 74.08 322.59 3992.51 3920.51 6003420.62 558389.19 7958.93 4.00 89.32 MWD+IFR+MS 9800.00 74.25 326.74 4019.80 3947.80 6003498.58 558332.88 8048.50 4.00 88.18 MWD+IFR+MS 9900.00 74.50 330.89 4046.75 3974.75 6003580.50 558282.31 8135.39 4.00 87.05 MWD+IFR+MS 9938.48 74.61 332.48 4057.00 3985.00 6003612.99 558264.43 8168.02 4.00 85.93 SBF2-NA 10000.00 74.82 335.02 4073.22 4001.22 6003665.97 558237.72 8219.18 4.00 85.50 MWD+IFR+MS 10014.46 74.87 335.62 4077.00 4005.00 6003678.60 558231.78 8231.01 4.00 84.83 SBF1-NB 10091.84 75.18 338.80 4097.00 4025.00 6003747.24 558202.23 8293.04 4.00 84.68 SBE4-NC 10100.00 75.22 339.14 4099.08 4027.08 6003754.58 558199.34 8299.44 4.00 83.85 MWD+IFR+MS 10131.16 75.35 340.42 4107.00 4035.00 6003782.77 558188.67 8323.68 4.00 83.77 SBE2-NE 10200.00 75.69 343.24 4124.21 4052.21 6003845.90 558167.34 8375.81 4.00 83.44 MWD+IFR+MS 10300.00 76.23 347.33 4148.49 4076.49 6003939.48 558141.89 8447.89 4.00 82.74 MWD+IFR+MS 10314.78 76.31 347.93 4152.00 4080.00 6003953.47 558138.69 8458.17 4.00 81.74 SBE1-NF 10400.00 76.83 351.39 4171.79 4099.79 6004034.86 558123.11 8515.35 4.00 81.60 MWD+IFR+MS 10422.98 76.98 352.33 4177.00 4105.00 6004056.99 558119.75 8530.16 4.00 80.80 TSBD-OA 10500.00 77.50 355.44 4194.01 4122.01 6004131.59 558111.09 8577.85 4.00 80.59 MWD+IFR+MS 10537.31 77.77 356.94 4202.00 4130.00 6004167.93 558108.35 8599.84 4.00 79.90 TSBC (base OA) 10600.00 78.24 359.46 4215.03 4143.03 6004229.19 558105.89 8635.09 4.00 79.58 MWD+IFR+MS 10700.00 79.02 3.46 4234.76 4162.76 6004327.18 558107.53 8686.79 4.00 79.05 MWD+IFR+MS 10738.59 79.34 5.00 4242.00 4170.00 6004365.00 558110.00 8705.20 4.00 78.26 MPS-34 T1 10800.00 79.34 5.00 4253.36 4181.36 6004425.15 558114.73 8733.81 0.00 180.00 MWD+IFR+MS 10900.00 79.34 5.00 4271.86 4199.86 6004523.12 558122.43 8780.40 0.00 180.00 MWD+IFR+MS 10954.83 79.34 5.00 4282.00 4210.00 6004576.83 558126.66 8805.94 0,00 180.00 SBA5 (base 08) 11000.00 79.34 5.00 4290.36 4218.36 6004621.08 558130.14 8826.98 0.00 180.00 MWD+IFR+MS 11104.83 79.34 5.00 4309.75 4237.75 6004723.77 558138.21 8875.82 0.00 180.00 MWD+IFR+MS bp COMPANY DETAILS REFERENCE INFORMATION DP Amoco Co-ordinate (NÆ) Reference: Well Centre: Plan MPS-34, True North Vertical (1VD) Reference; S-Pad Dev n.(() Section (VS) Relèrence: User Defined (44S1.88N,-7454.11E) Measured Depth Reference: S-Pad Dev 72.00 Calculation Method; Minimum Curvature Calculation Method; Minimum Curvature Error System: !SCWSA Scan Method: Trav Cylinder North Error Surface: Elliptical + Casing Warnin~ Method: Rules Based o 1000 I fJrP I fJOO &1 <9000 ~OO ÔOOO $000 '000 Iý .9000 ~ <000 /" /000 .§' ..../000 " :s 4000- ¢: o o :!. .c Õ. Ö ~ .€ ~ '" => ¡:; 4400 = ______ 9/ Start Dir 12/100': - ____.f - ,:·A.,.(,:i :_~¡'UI; ~ 10675' MD, 4229.95'TVD End Dir : 11135.62' MD, 4252.81' TVD / Start Dir 12/100': 11331.51' MD, 4254.52'TVD i... .;. '"I o 400 800 1200 1600 Vertical Section at 36.19' [400ft/in] SURVEY PROGRAM Plan: MPS-34 wp07 (Plan MPS-34/Plan MPS-34 OB) Depth Fm Depth To SurveyIPJan 10675.00 13393.45 Planned: MPS-34 wp07 V11 Tool Created By: Ken Allen Checked: Dale Dale: 7/21/2003 MWD+IFR+MS Reviewed: Date WELL DETAILS N"", +NI-S +EI-W Northing Basting Latitude Longitude Slot Plan MPS-34 -54.52 -746.89 5999916.85 565598.69 70024'36.792N 149°27'57.063W N/A TARGET DETAILS N"", TVD +NI-S +EI-W Northing Easting Shape MPS-34 T3 Wp 4 4227.00 589021 -6407.82 6005750.00 559140.00 Point MPS-34T4 4242.00 6615.59 -5871.38 6006480.00 559670.00 Point MPS-34T2.1 4242.00 5105.52 -7024.79 6004960.00 558530.00 Point SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target I 10675.00 78.82 2.46 4229.95 4451.88 -7454.11 0.00 0.00 8277.59 2 10739.00 86.50 2.46 4238.12 4515.24 -7451.38 12.00 0.00 8323.17 3 11135.62 89.50 50.00 4252.81 4860.55 -7281.05 12.00 87.48 8468.38 4 11331.51 89.50 50.00 4254.52 4986.47 -7131.00 0.00 0.00 8462.95 5 11492.30 99.38 33.36 4242.00 5105.52 -7024.79 12.00 -58.78 8481.49 MPS-34 TZ.l e 6 11595.27 9û.43 38.4 7 4233.20 5188.48 -6964.68 10.00 150.12 8503.64 7 12462.87 90.43 38.4 7 4226.71 5867.78 -6425.01 0.00 0.00 8653.48 8 12491.13 88.41 36.48 4227.00 5890.21 -6407.82 10.00 -135.50 8658.84 MPS-34 T3 Wp 4 9 12497.50 89.05 36.48 4227.14 5895.33 -6404.03 10.00 0.00 8660.16 10 13393.45 89.05 36.48 4242.00 6615.59 -5871.38 0.00 0.00 8845.29 MPS-34 T4 FORMATION TOP DETAILS No. TVDPath MDPath Formation 4242.00 10806.14 TSBB-OB CASING DETAILS No. TVD MD Name Size 4242.00 13393.44 41/2" 4.500 All TVD depths are ssTVD plus 72'for RKBE. e Start Dir 10/100': 12462.87' MD, 4226.71'TVD / EndDir: 12497.5'MD.4227.14'TVD / ~ ,... !,,, MPS-34 wp07 i.il/lll; 2000 2400 , I ' 2800 I I I I I I bp COMPANY DETAILS REFERENCE INFORMA nON BP Amoco Co-ordinate (NÆ) Reference: Well Centre: Plan MPS-34, True North Vertical (TVD) Reference: S·Pad l)ev 72.00 Section (VS) Reference: User Defined (445L88N.-7454.l1E) Measured Depth Reference: S-Pad Dev n.(() Calculation Method: Minimum Curvature Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: TmvCylinderNortb Error Surface: Elliptical + Casing Wamilt9; Method: Rules Based FORMATION TOP DETAILS No. TVDPath MDPath Formation All TVD depths are ssTVD plus 72'for RKBE. 4242.00 10806.14 TSBB-OB CASING DETAILS No. TVD MD Name 4242.00 13393.44 4 112" 6600 Size 4.500 wp07 Depth: 13393.45' MD, 4242' TVD 6000 C ~ 0 0 :£. +" :E 5400 t 0 ~ ,s " 0 r/J 4800 4200 , , I , I I I I' Iff r I If. , , , I ' -5400 -7800 -7200 -6000 -6600 West(-)/East(+) [600ft/in] I I I I J I I SURVEY PROGRAM Plan: MPS-34 wp07 (plan MPS-34/Plan MPS-34 DB) Depth Fm Depth To SurveylPlan Tool Created By: Ken AUen Date: 7/21/2003 10675.00 13393.45 Planned: MPS·34 wp07 VII MWD+IFR+MS Checked: Date Reviewed: Date WELL DETAILS """" +NI-S +E/-W Northing Easting Latitude Longitude Slot PlanMPS-34 -54.52 -746.89 5999916.85 565598.69 70"24'36.792N 149"27'57.06JW NiA TARGET DETAILS """" TVD +NJ-S +E)-W Northing Easling Shape MPS-34 T3 Wp 4 4227,00 589021 ·6407,82 6005750.00 559140,00 Point MPS·34 T4 4242.00 6615.59 ·587LJ8 6006480.00 559670,00 Point MPS-34 12.1 4242.00 5105.52 -7024.79 6004960.00 558530.00 Point SECTION DETAILS Sec MD Inc Azi TVD +N/-S +EI-W DLeg TFace VSec Target 1 10675.00 78.82 2.46 4229.95 4451.88 -7454. II 0.00 0.00 0.00 2 10739.00 86.50 2.46 4238.12 4515.24 -7451.38 12.00 0.00 52.75 3 11135.62 89.50 50.00 4252.81 4860.55 -7281.05 12.00 87.48 432.02 4 I I331.51 89.50 50.00 4254.52 4986.47 -7 I3 1.00 0.00 0.00 622.24 5 11492.30 99.38 33.36 4242.00 5105.52 -7024.79 12.00 -58.78 781.03 MPS-34 T2.l 6 I I 595.27 9û.43 38.47 4233.20 5188.48 -6964.68 10.00 150.12 883.48 e 7 12462.87 90.43 38.47 4226.71 5867.78 -6425.01 0.00 0.00 1750.37 8 12491.13 88.41 36.48 4227.00 5890.21 -6407.82 10.00 -135.50 1778.62 MPS-34 T3 Wp 4 9 12497.50 89.05 36.48 4227.14 5895.33 -6404.03 10.00 0.00 1784.99 10 13393.45 89.05 36.48 4242.00 6615.59 -5871.38 0.00 0.00 2680.80 MPS-34 T4 o e l I ,¡ I I 1,# '#' ##' ## , .§> ;;;. <%>00 ."bOO 6000 $000 .¥o~Ooo ...;11-11 ""000 /' /000 Ä:> "'/000 ~ e . ....____.._,____......_.........__.~.._'.h"_... "_0' .._...._.._ .......__._. Company: Field: Site: Well: Wellpath: BP Amoco Milne Point M Pt S Pad Plan MPS-34 Plan MPS-34 OB Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: M pt S Pad BP-GDB KW A Planning Report e Date: 7/21/2003 Time: 09:30:44 Page: Co-ordinate(NE) Reference: Well: Plan MPS-34, True North Vertical (fVD) Reference: S-Pad Dev 72.0 Section (VS) Reference: User (4451.88N,-7454.11 E,36.19Azi) Survey Calëulation Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site Position: Northing: 5999978.00 ft Latitude: 70 24 37.329 N From: Map Easting: 566345.00 ft Longitude: 149 27 35.171 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.51 deg Well: Plan MPS-34 Slot Name: Well Position: +N/-S -54.52 ft Northing: 5999916.85 ft Latitude: 70 24 36.792 N +E/-W -746.89 ft Easting : 565598.69 ft Longitude: 149 27 57.063 W Position Uncertainty: 0.00 ft Wellpath: Plan MPS-34 OB Current Datum: Magnetic Data: Field Strength: Vertical Section: S-Pad Dev 7/21/2003 57537 nT Depth From (TVD) ft 4229.95 Plan: MPS-34 wp07 Principal: Yes Casing Points MD ft 13393.44 TVD ft 4242.00 Diameter in Hole Size in 6.125 4.500 Formations MD ft 10806.14 TVD ft 4242.00 Formations TSBB-OB Targets Name Description Dip. Dlr. MPS-34 T3 Wp 4 MPS-34 T4 MPS-34 T2.1 TVD ft 4227.00 4242.00 4242.00 Height Drilled From: Tle-on Depth: 72.00 ft Above System Datum: Declination: Mag Dip Angle: +E/-W ft -7454.11 Plan MPS-34PB1 10675.00 ft Mean Sea Level 25.27 deg 80.84 deg Direction deg 36.19 5/27/2003 11 From: Definitive Path Dip Angle Dip Direction deg deg 0.00 0.00 ----...-.......-......,.....".."...---- <-- Latitude -> <- Longitude --> Deg Min Sec Deg Mln Sec ....----...-..--.-. 70 25 34.694 N 149 31 5.027 W 70 2541.832 N 149 3049.308 W 70 25 26.971 N 149 31 23.103 W Plan Section Information __, ___ ..... ..._n_.._____.,...____ MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/10OO deg/100ft deg ..._..m__..._"._.._. 10675.00 78.82 2.46 4229.95 4451.88 -7454.11 0.00 0.00 0.00 0.00 10739.00 86.50 2.46 4238.12 4515.24 -7451.38 12.00 12.00 0.00 0.00 11135.62 89.50 50.00 4252.81 4860.55 -7281.05 12.00 0.76 11.99 87.48 11331.51 89.50 50.00 4254.52 4986.47 -7131.00 0.00 0.76 11.99 0.00 11492.30 99.38 33.36 4242.00 5105.52 -7024.79 12.00 6.15 -10.35 -58.78 MPS-34 T2.1 +N/-S ft 4451.88 Date Composed: Version: Tied-to: Name 41/2" -'-----"..-.-'.--.......-...-.--.- ...... ..-....--- -,..-----.-.--" Lithology -.--......---.....-..... . +N/-S ft 5890.21 Map Map +EI-W Northing Eastlng ft ft ft _.__....__. -..·.-·.__..·0·.·.. -6407.82 6005750.00 559140.00 6615.59 -5871.38 6006480.00 559670.00 5105.52 -7024.79 6004960.00 558530.00 e BP-GDB e KW A Planning Report Company: BP Amoco Date: 7/21/2003 Time: 09:30:44 Page: 2 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPS-34, True North Site: MPtSPad Vertical (TVD) Reference: S-Pad Dev 72.0 Well: Plan MPS-34 Section (VS) Reference: User (4451.88N,-7454.11E,36.19Azi) Wellpath: Plan MPS-34 OB Survey Calculation Mcthod: Minimum Curvature Db: Oracle ..........-......---------.. ... .----.-----.----. . Plan Scction Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/10Oft deg .--0"-- .. ---.-- 11595.27 90.43 38.47 4233.20 5188.48 -6964.68 10.00 -8.70 4.96 150.12 12462.87 90.43 38.47 4226.71 5867.78 -6425.01 0.00 0.00 0.00 0.00 12491.13 88.41 36.48 4227.00 5890.21 -6407.82 10.00 -7.13 -7.01 -135.50 MPS-34 T3 Wp 4 12497.50 89.05 36.48 4227.14 5895.33 -6404.03 10.00 10.00 0.00 0.00 13393.45 89.05 36.48 4242.00 6615.59 -5871.38 0.00 0.00 0.00 0.00 MPS-34 T4 Survey MD lncl Azim TVD Sys TVD MapN MapE VS DLS TFO Too ft deg deg ft ft ft ft ft deg/10OO deg - - n___________. -..-.....-.-- .. . --------.... .--.- ...........---....-- - .--------.. 10675.00 78.82 2.46 4229.95 4157.95 6004302.67 558106.48 0.00 0.00 0.00 MWD+IFR+MS 10700.00 81.82 2.46 4234.15 4162.15 6004327.29 558107.32 20.49 12.00 0.00 MWD+IFR+MS 10725.00 84.82 2.46 4237.06 4165.06 6004352.10 558108.17 41.15 12.00 0.00 MWD+IFR+MS 10739.00 86.50 2.46 4238.12 4166.12 6004366.05 558108.65 52.75 12.00 0.00 MWD+IFR+MS 10750.00 86.56 3.79 4238.79 4166.79 6004377.02 558109.15 61.96 12.00 87.48 MWD+IFR+MS 10775.00 86.70 6.79 4240.26 4168.26 6004401.88 558111.23 83.37 12.00 87.40 MWD+IFR+MS 10800.00 86.85 9.79 4241.66 4169.66 6004426.61 558114.61 105.43 12.00 87.22 MWD+IFR+MS 10806.14 86.89 10.53 4242.00 4170.00 6004432.65 558115.64 110.94 12.00 87.05 TSBB-OB 10825.00 87.01 12.79 4243.00 4171.00 6004451.13 558119.29 128.07 12.00 87.01 MWD+IFR+MS 10850.00 87.18 15.79 4244.27 4172.27 6004475.37 558125.23 151.23 12.00 86.89 MWD+IFR+MS 10875.00 87.35 18.79 4245.47 4173.47 6004499.27 558132.44 174.86 12.00 86.74 MWD+IFR+MS 10900.00 87.53 21.78 4246.58 4174.58 6004522.77 558140.89 198.87 12.00 86.60 MWD+IFR+MS 10925.00 87.72 24.78 4247.62 4175.62 6004545.80 558150.56 223.22 12.00 86.46 MWD+IFR+MS 10950.00 87.91 27.78 4248.57 4176.57 6004568.29 558161.42 247.82 12.00 86.34 MWD+IFR+MS 10975.00 88.11 30.77 4249.44 4177.44 6004590.18 558173.45 272.62 12.00 86.22 MWD+IFR+MS 11000.00 88.32 33.77 4250.22 4178.22 6004611.42 558186.60 297.55 12.00 86.12 MWD+IFR+MS 11025.00 88.53 36.76 4250.90 4178.90 6004631.95 558200.84 322.54 12.00 86.03 MWD+IFR+MS 11050.00 88.74 39.75 4251.50 4179.50 6004651.71 558216.14 347.51 12.00 85.94 MWD+IFR+MS 11075.00 88.96 42.75 4252.00 4180.00 6004670.64 558232.45 372.40 12.00 85.87 MWD+IFR+MS 11100.00 89.18 45.74 4252.40 4180.40 6004688.70 558249.73 397.15 12.00 85.81 MWD+IFR+MS 11125.00 89.40 48.73 4252.71 4180.71 6004705.83 558267.93 421.68 12.00 85.76 MWD+IFR+MS 11135.62 89.50 50.00 4252.81 4180.81 6004712.81 558275.92 432.02 12.00 85.73 MWD+IFR+MS 11200.00 89.50 50.00 4253.38 4181.38 6004754.62 558324.87 494.54 0.00 0.00 MWD+IFR+MS 11300.00 89.50 50.00 4254.25 4182.25 6004819.56 558400.90 591.64 0.00 0.00 MWD+IFR+MS 11331.51 89.50 50.00 4254.52 4182.52 6004840.03 558424.86 622.24 0.00 0.00 MWD+IFR+MS 11350.00 90.65 48.10 4254.50 4182.50 6004852.26 558438.71 640.26 12.00 301.22 MWD+IFR+MS 11375.00 92.20 45.54 4253.88 4181.88 6004869.52 558456.78 664.82 12.00 301.22 MWD+IFR+MS 11400.00 93.75 42.96 4252.58 4180.58 6004887.55 558474.04 689.54 12.00 301.15 MWD+IFR+MS 11425.00 95.29 40.38 4250.60 4178.60 6004906.31 558490.44 714.35 12.00 301.02 MWD+IFR+MS 11450.00 96.83 37.79 4247.97 4175.97 6004925.74 558505.94 739.17 12.00 300.81 MWD+IFR+MS 11475.00 98.34 35.18 4244.67 4172.67 6004945.79 558520.50 763.95 12.00 300.54 MWD+IFR+MS 11492.30 99.38 33.36 4242.00 4170.00 6004960.00 558530.00 781.03 12.00 300.20 MPS-34 T2.1 11500.00 98.71 33.74 4240.79 4168.79 6004966.37 558534.15 788.63 10.00 150.12 MWD+IFR+MS 11550.00 94.37 36.24 4235.09 4163.09 6005007.29 558562.26 838.28 10.00 150.19 MWD+IFR+MS 11595.27 90.43 38.47 4233.20 4161.20 6005043.4 7 558589.38 883.48 10.00 150.47 MWD+IFR+MS 11600.00 90.43 38.47 4233.16 4161.16 6005047.20 558592.29 888.21 0.00 180.00 MWD+IFR+MS 11700.00 90.43 38.47 4232.42 4160.42 6005126.04 558653.79 988.13 0.00 180.00 MWD+IFR+MS 11800.00 90.43 38.47 4231.67 4159.67 6005204.87 558715.30 1088.05 0.00 180.00 MWD+IFR+MS 11900.00 90.43 38.47 4230.92 4158.92 6005283.70 558776.81 1187.96 0.00 180.00 MWD+IFR+MS 12000.00 90.43 38.47 4230.17 4158.17 6005362.53 558838.31 1287.88 0.00 180.00 MWD+IFR+MS 12100.00 90.43 38.47 4229.43 4157.43 6005441.37 558899.82 1387.80 0.00 180.00 MWD+IFR+MS 12200.00 90.43 38.47 4228.68 4156.68 6005520.20 558961.33 1487.72 0.00 180.00 MWD+IFR+MS 12300.00 90.43 38.47 4227.93 4155.93 6005599.03 559022.83 1587.64 0.00 180.00 MWD+IFR+MS 12400.00 90.43 38.47 4227.18 4155.18 6005677.86 559084.34 1687.56 0.00 180.00 MWD+IFR+MS 12462.87 90.43 38.47 4226.71 4154.71 6005727.42 559123.01 1750.37 0.00 180.00 MWD+IFR+MS e BP-GDB e KW A Planning Report Company: BP Amoco Date: 7/21/2003 Time: 09:30:44 Page: 3 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPS-34, True North Site: M Pt S Pad Vertical (fVD) Reference: S-Pad Dev 72.0 Well: Plan MPS-34 Section (VS) Reference: User (4451.88N,-7454.11E,36.19Azi) Wellpath: Plan MPS-34 DB Survey Calculation Method: Minimum Curvature Db: Oracle ...--.--.--...-.--------.- ...--...--. ....--.....-.----. Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Too ft deg deg ft ft ft ft ft deg/10OO deg 12491.13 88.41 36.48 4227.00 4155.00 6005750.00 559140.00 1778.62 10.00 224.50 MPS-34 T3 Wp 4 12497.50 89.05 36.48 4227.14 4155.14 6005755.15 559143.74 1784.99 10.00 360.00 MWD+IFR+MS 12500.00 89.05 36.48 4227.18 4155.18 6005757.17 559145.21 1787.49 0.00 0.00 MWD+IFR+MS 12600.00 89.05 36.48 4228.84 4156.84 6005838.08 559203.95 1887.47 0.00 0.00 MWD+IFR+MS 12700.00 89.05 36.48 4230.50 4158.50 6005918.98 559262.68 1987.46 0.00 0.00 MWD+IFR+MS 12800.00 89.05 36.48 4232.16 4160.16 6005999.88 559321.42 2087.44 0.00 0.00 MWD+IFR+MS 12900.00 89.05 36.48 4233.82 4161.82 6006080.78 559380.16 2187.43 0.00 0.00 MWD+IFR+MS 13000.00 89.05 36.48 4235.47 4163.47 6006161.69 559438.90 2287.41 0.00 0.00 MWD+IFR+MS 13100.00 89.05 36.48 4237.13 4165.13 6006242.59 559497.63 2387.40 0.00 0.00 MWD+IFR+MS 13200.00 89.05 36.48 4238.79 4166.79 6006323.49 559556.37 2487.38 0.00 0.00 MWD+IFR+MS 13300.00 89.05 36.48 4240.45 4168.45 6006404.39 559615.11 2587.37 0.00 0.00 MWD+IFR+MS -< 13393.45 89.05 36.48 4242.00 4170.00 6006480.00 559670.00 2680.80 0.00 0.00 MPS-34 T 4 . . P055092 DATE -1 6/9/2003 I ~ECK NO. 055092 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 6/9/2003 INV# CK060403L PERMIT TO DRILL FEE 0\?S·ól{ ·HE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 AK99519-6612 NATIONAl CITY BANK Ashland, Ohio 56-389 412 No. P 055092 CONSOLIDATED COMMERCIAL ACCOUNT ::JAY: OTHE IRDER F: ALASKA tplL &,GAS.CONSERVATION 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 AMOUNT Juhê 9. 2003 !. .\1 **7~***$10().OO******1 NQ'V"'·~KJ§;~'~i;l:~~?:t1t;;S:":\~'J (:,'~;i"tj}~'~¡~~~~~~;;~iiÂ~%:~ UIO 5 SO ii 2uI 1:0 L. ¡. 20 ~B c¡ 51: 0 ¡. 2 ?B c¡ bll· e e TRANSMITAL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME Ø/Pt{ S ~ 3/ PTD# 2-D 3 --15Ö CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing weD ~ Permit No, API No. Production should continue to be reported as a function· of the original API number stated above. HOLE 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 (SO 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates 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) assumes the liability of any protest to tbe spacing . exception that may occur. All dry ditcb sample sets submitted to the Commission must be in no greater than 30' sample intervals from below tbe permafrost or from wbere samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST Company BP EXPLORATION (ALASKA) INC Well Name: MILNE PT UNIT SB S-34 Program DEV Well bore seg PTD#:2031300 Field & Pool MILNE POINT. SCHRADER BLFF OIL - 525140 Initial ClasslType DEV / PEND GeoArea 890 Unit 11328 On/Off Shore ~ Annular Disposal Administration 1 p~(11)it.fee attacheO. . . . . . _ _ _ _ . . . _ _ _ _ _ _ _ _ . . . . . . Y~s . . . . . . . . . . . . . . . . . . . . . _ . _ _ . . . . . . . . . . . . . . _ . . _ . . . . . . . . . _ . . . . . . . . . _ . . _ _ 2 Leas~.nlJmber .appropriate. . . . . . _ _ . _ _ . . . . . . . . . . . . . . . . _ . . . . . . . . . . . Y~s . _ . . . . . . . . _ . . . . . . . . . . . _ _ _ . . . . . . . . . . . . . . . . . . . . . _ _ . _ . . . . . . . . . . . . _ _ . 3 .UniqlJe welLnam~aod OUlT!b.er . . . _ _ _ _ . . . . . . . . . . . . . . . _ . . . _ _ . . . . . . . .Y~s . . . _ _ . _ . . . . . . . _ . . . . . . . . . . . . . . . . . . . _ _ . . . . . . . . . . . . . . 4 WeUIQcat~d ina.d.efjneOPPQI. . . . _ _ _ . _ . . . . . . . Y~s . _. ..... _ . . . . . . . . . _ . . . _ . . . . . . . . . . . . _ _ . .. .......... _ _ _ 5 WeUIQcat~d pr9per .distaoçeJrom. dri)liog vnitbovnd<:lry . . . . . . .Y~s . . . _ . . . . . . . _ . . . . . . . .. . _ . . _ . . . . _ . . . . . . . . . _ _ .... _ . _ . . . .. ...... _ . . _ . . 6 Well IQcat~d prc:>per .distaOÇ6. from. Qther wells . . . . . . . . . . . . . _ . . . . .. Y~s.... _ . _ _ . . _ . . . . . . . . . . . . . . . _ . _ . . . . . . . . . . . . . . . . . . . . . . . . _ _ _ _ _ 7Sufficien!aereageayailable in_drilJiOQ unit . _ . . . . . . . . . . . . _ _ _ _ . . . . . . Y~s . _ _ . . . . . . . _ _ . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . _ 8 Ifd~viated. js weJlbQre plaUncJuded _ _. _................. _ . . . . . . Y~s . . . . _ _ . . . . . . . . _ . . . . . _ _ _ . . . . . . . . . . _ _ . . . . . . _ _ _ . 9 .Operator only" affected party. . . _ . _ . . . . . . . . . . . . . . . . _ _ _ . . _ _ . . . Y~s. ... _ . . . . . . . . . . . . . . . . _ . . . . . .. ....... _ . . . _ . . . . . . . . . . .. .... _ _ _ _ _ . . 10 _Qperator bas.apprppriate.bood infQree . . . . . . . . . . . . . . . Y~s . . . . . . . . . _ . .. ........... . . . . . . . . . . . . . . _ _ . _ . _ 11 P~rlT!it C<iO be issued witbQut ço.nservaJion Qrder. . . . . . . . . . _ _ . _ _ _ _ . . . . . . . y ~s . . . . . _ . . . . _ . . . . . . . . . . . . .. ............ _ . . . . . . _ . . .. .. _ . . _ . _ _ . _ 12 P~rlT!itC<io be issued witbQut administrati\leapproval . . _ _ _ . _ . . . . . . . . Y~s . _ . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . _ _ _ . . . . . . . . . . . . . . . . . . . . _ . . . . 7/28/2003 13Cao permit be apprQv~d before .15-day. walt . . . . . . . . . . . . . . _ . . . . . . . . . . y ~s . _. ..... _ . . . . . . . . . . . . . . . . _ . . . _ _ . . . . . . . _ _ . . . _ . . _ . . . . _ . . 14 WelllQcat~d within area and.strata avthQrized by.lojeçtipl) Ord~r # (PlJtlOit inC9mm~ots).(fQr_ NA. ...... _ . _ . . . . . . . . . . . . . . . . _ _ _ . _ _ . . . . . . . . . . . . . . . . 15A)lwellswithin.1l4.roite.are.a.ofreyiewid~otified(Forservjc~.w.elJonly"!-.. _ _.......... NA.. .... _ _.. ........... _ .................. _.................. __ 16 Pre-produ.ced iojeçtor; ovrationof pre-produçtipn I~ss. than. 3 montbs (forservlce wen Qn)y) . . NA . . . _ _ _ _ _ _ .. .............. . . . . _ . . . . _ . . . _ . 17 ACMPFïndingof CQnßißteoçy.has been JsslJed fortbis pr9ieet . . _ . . . . _ _ . . . . . . . . . . NA . . . _ _... _ . . . . . . . . . . . . . . . _ _ . . . . . . . . . . . . . . Appr SFD e Engineering Appr Date TEM 7/29/2003 .~~~ Geology Appr SFD Date 7/28/2003 Geologic Commissioner: 1m o o Date 18C90ductor stringprQvided . _ . . . . _ . . . . . Y~s . . . . _ _ _ . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . _ . . . . . . . 19SJJrfa~_casing.prQteçtsallkoownUSDWs. ........ ......... _.. _ _ _.. NA...... .AnaqJJifersex~mpt~d4QCfß:147.102(b)(3) _ ..... _.... _. _ _.......... _. _..... _. 20CMT vol. adeQuateto CircJJlate.on.cond.uetor. & surfcsg . . . . . . . . . _ . _ . . . . . . . . Y~s . . . . . . . . . . . . . . _ . . . . . . . . _ . . . _ . . . . . . . . . . . _ . _ . . . . . _ . . . _ 21 .CMT v.ot adeQuateJo tie-lnlQng .striOg to.SlJrf csg" . _ _ _ _ _ _ _ . _ . . . . . . . . . _ . . _ . _ _ . No. . . . . . . . _ . _ _ . . . . . . . . . _ _ _ _ . . . . . . . . . . . . _ _ . . . . . . . . . . _ _ _ _ _ . . . . . . . . . _ . _ . _ . . . . . . . . 22CMT will ÇQyeraJl kl)Qwn pro.duçtiye bQriZQns _ . . . . . . . No. . _ . . . . . Slotted litler .completi.oo plaoned.. . . . . . _ . . . . . . . . . . . . . . _ _ . _ _ 23 _Casitlg desigos ad.eç¡ua.te for C,T~ B.&.p-e!l1Jafr9st . . . . . . _ _ _ .. .... .Y~s . . . . _ . .. .................... _ . . _ _ . . . . . . . . . . _ _ . . _ . . _ . . . . . . _ . . . 24 .Adequatetan.kage.orre.servepit.... _............... _ _ _. .. Y~s...... .RigisßqVippe.d.withst~elpits..No.rese",epjtplatll)e.d. AlIwasteto.Class)lweIJÜ¡),. 25 Ifa.re-drill~ has.a. 10:403 for abandQnment be~o approved. . . . . _ _ . . . _ _ . . . . . . . NA . . . . . . . . . . . . . . . . . . . . . . . . . _ _ _ _ . . . . . . . . . _ _ .. ......... _ . . . . . . . . . . _ . _ . 26 .Adequate.wellbore separation proposed . . . . . . _ . _ _ _ . . . . . . . Y~s . _ . . . . . NQ çJos.e.apprpachJdentjfi~d._ Gyros avaiJable.and Uk.elytQ be enmloyed.. 27 Ifdivecter req.uired, dQes it meet regulations. . _ . . . . . . . Y~s . _ . . . . . _ _ . . . . . . . . . . . _ _ _ . . . . . . . .. .... _ . . . _ 28 DrilJiog fluidp-rogralT! sçhematic_& eq.uiplistadequat~ . . . . . . . . . _. . _ _ . . . . . . . . . Y~s . . . . _ . . MaximulT! BHP 9..0EMW, expected .BHP8,35. Platlne.d.lT!u.d.weights8.6to 9.2witb 9.:1 Ji~eJy, . 29 BOPES,d9they meet regulation . _ _ . . .. ............... _ _ _ . _ . . . . . . . .Y~$ . . . . . . . _ . . . . . . _ _ . . _ _ . _ _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ 30 BDPEpress raJitlg appropriate;.test to.(pu.t psig in.comments). . . _ _ _ . . _ _ . . . . . . . . . . Y~s . . . . . . . CalçuJa.ted.MASP 1545 psi.. planned SPPtes! press.ure.3.50Q psI. . . . . . . . . . . _ _ _ 31ChokemanjfQld COlT!plies. w/APLRF'-53 (May 84) . . . . . _ _ _ . . _ _ . _ _ . . . . . . . Y~s . . . . .. . _ . . . . . . . . . . .. .. _ . . . . . _ _ 32 WQr~ wiJl pçCJJr withputoperation.sbutdQwn. . . . . . . . . . . . . . _ _ . . . _. _ _ . . . . . . . Y~s . _ _ .... _ . . . . . . . . . . . . . _ . . . . . _ _ . _ . . . . . . . . . 33 Is presençe_ Qf H2S gas. prob.able. . . . . . . . . . . . . . . . . . . No ..... _ _ . . . . . . . . . . . . . . _ _ . . _ . _ . . . _ . _ _ . . . . . . _ . . . _ . . . . . . . . . . _ 34 MeçbanicaLcPl)dJtion pf wells wiJhin AOR verified (For.s.erv¡~ we) only) _ . _ _ . . . . . . . . . NA . . . . . . . . . _ _ _ . . . . . . . . . . . _ . . . _ _ _ _ . . . . . _ . . . . . . . . . . _ _ - - - - - - - - - - - - - - - 35 PerlT!itcatl be issued ",,!o hydrogen.s.ulfide meaSJJres. 36 D.ata.presel)ted On po!e.ntial pverpres.surezones _ . _ _ . 37S~ism¡canalysjs of sballow gas.zooes. 38 .S~abedcondjtioo survey (if off-sh9re) . _ . . _ . . . 39 _ CQnta.ct nam.elpÌ1onefQrweekly prpgress.reports [exploratpry .only]. ..... _.... Y~s . Y~s. ~ - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - . Expeçted reservoir preßsure is 8.35 ppg EMW; wiJl be drHled with 9.1 ppg_mud, _ - - - - - - - - - - - - - - - - . NA... ...... NA _ _....... NA........ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Date: 7/21 / 3 Engineering Commissioner: Date Public commission~ . Da. te \. , C\.\,,~~ e e Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify fìnding infomlation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. $Revision: 3 $ LisLib $Revision: 4 $ Mon Oct 13 11:58:18 2003 j03--13Õ 't( ~ Sperry-Sun Dr~ng Services LIS Scan Utility Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/10/13 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/10/13 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPS-34 500292317100 B.P. Exploration (Alaska) Inc. Sperry-Sun Drilling Services 13 -OCT- 03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002600988 T. MCGUIRE E. VAUGHN MWD RUN 2 MW0002600988 C.A. DEMOSKI C. DIXON MWD RUN 3 MW0002600988 R. FRENCH L. BROWN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 12N 10E 3252 412 72.30 38.00 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 10.750 5518.0 # \~'~~~\,,\ C~ REMARKS: 1. ALL DEPTHStI!E MEASURED DEPTH (MD) UNLESS O~RWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP ALASKA, INC., DATED 9/5/2003. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1 - 3 REPRESENT WELL MPS-34 WITH API#: 50-029-23171-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11159'MD/4323'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) . SLIDE = NON-ROTATED INTERVALS, REFLECTING BIT DEPTHS $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/13 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 69.5 113.5 5505.5 5505.5 5505.5 5505.5 5505.5 STOP DEPTH 11122.0 11159.0 11114.0 11114.0 11114.0 11114.0 11114.0 # BASELINE CURVE FOR SHIFTS: . CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH . --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 MERGE TOP 69.5 5526.0 8846.0 MERGE BASE 5526.0 8846.0 11159.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type... ..0 Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 69.5 11159 5614.25 22180 69.5 11159 ROP MWD FT/H 0.7 5544.73 308.51 22092 113.5 11159 GR MWD API 9.01 130.95 67.8175 22106 69.5 11122 RPX MWD OHMM 1. 72 755.04 11.8578 11218 5505.5 11114 RPS MWD OHMM 0.25 248.53 11.1186 11218 5505.5 11114 RPM MWD OHMM 0.17 2000 12.6596 11218 5505.5 11114 RPD MWD OHMM 0.2 2000 14.9551 11218 5505.5 11114 FET MWD HOUR 0.05 56.07 0.733473 11218 5505.5 11114 First Reading For Entire File......... .69.5 Last Reading For Entire File.......... .11159 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/13 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF . File Header Service name............ .STSLIB.002 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/13 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 69.5 113.5 STOP DEPTH 5481.0 5526.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 13-AUG-03 Insite 66.37 Memory 5526.0 112.0 5526.0 .0 77.2 TOOL NUMBER 155790 13 .500 .0 Spud Mud 9.10 198.0 9.0 450 14.0 .000 .000 .000 .000 .0 78.8 .0 .0 $ . . REMARKS: # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record..... . . . . . . . .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD010 MWD010 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 69.5 5526 2797.75 10914 69.5 5526 ROP MWD010 FT/H 3.9 5544.73 276.28 10826 113.5 5526 GR MWD010 API 9.01 112.18 60.8705 10824 69.5 5481 First Reading For Entire File......... .69.5 Last Reading For Entire File.......... .5526 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/13 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/13 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD 3 header data for each bit run in separate files. 2 .5000 START DEPTH 5481.5 5505.5 5505.5 STOP DEPTH 8808.5 8801.0 8801.0 RPM RPX RPS ROP $ 5505.. 5505.5 5505.5 5526.5 8801.0 8801.0 8801.0 8846.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT . 16-AUG-03 Insite 66.37 Memory 8846.0 5526.0 8846.0 71. 9 77.0 TOOL NUMBER 126027 151812 9.875 5518.0 LSND 9.40 57.0 8.8 300 5.8 3.200 2.410 5.250 4.500 67.0 91. 3 67.0 67.0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 ROP MWD020 FT/H . 1 68 4 2 . GR MWD020 API 1 68 8 3 . RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5481.5 8846 7163.75 6730 5481.5 8846 ROP MWD020 FT/H 0.7 1452.54 417.726 6640 5526.5 8846 GR MWD020 API 15.84 126.39 74.5854 6655 5481.5 8808.5 RPX MWD020 OHMM 1. 72 57.84 9.16637 6592 5505.5 8801 RPS MWD020 OHMM 0.25 54.19 9.08132 6592 5505.5 8801 RPM MWD020 OHMM 0.17 2000 10.6593 6592 5505.5 8801 RPD MWD020 OHMM 0.2 2000 13 . 0508 6592 5505.5 8801 FET MWD020 HOUR 0.05 56.07 0.707524 6592 5505.5 8801 First Reading For Entire File......... .5481.5 Last Reading For Entire File.......... .8846 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generation...... .03/10/13 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/13 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 8801.5 8801.5 8801.5 8801.5 8801.5 8809.0 8846.5 STOP DEPTH 11114.0 11114.0 11114.0 11114.0 11114.0 11122.0 11159.0 # LOG HEADER DATA · DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing................... ..60 .1IN Max frames per record.......... ...Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 18-AUG-03 . Insite 66.37 Memory 1159.0 8846.0 1159.0 71. 8 80.1 TOOL NUMBER 126027 151812 9.875 5518.0 LSND 9.55 61. 0 8.2 300 5.0 2.500 .000 4.100 3.500 65.0 .0 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 .' . . " First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8801.5 11159 9980.25 4716 8801.5 11159 ROP MWD030 FT/H 3.99 1111.6 227.172 4626 8846.5 11159 GR MWD030 API 19.2 130.95 74.3344 4627 8809 11122 RPX MWD030 OHMM 2.35 755.04 15.6932 4626 8801.5 11114 RPS MWD030 OHMM 2.35 248.53 14.0217 4626 8801.5 11114 RPM MWD030 OHMM 2.34 1816.22 15.5101 4626 8801.5 11114 RPD MWD030 OHMM 2.41 2000 17.6687 4626 8801.5 11114 FET MWD030 HOUR 0.07 14.64 0.77045 4626 8801.5 11114 First Reading For Entire File......... .8801.5 Last Reading For Entire File.......... .11159 File Trailer Service name. ........... .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/10/13 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/10/13 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name. . . . . . . . . . .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/10/13 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File