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100-036
From:McLellan, Bryan J (OGC) To:AOGCC Records (CED sponsored) Subject:Iko Bay 1 (PTD 100-036) wellfile Date:Thursday, August 8, 2024 10:22:10 AM Attachments:Iko Bay_1 Post Well Sundry Packet_Signed.pdf Please include the attached in the wellfile. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Zach Sayers Date: May 22nd, 2023 RE: Iko Bay #1 Executive Summary Well Background The Iko Bay #1 well was drilled by the U.S. Navy in 1975. The well was completed and flowed gas. When the well was no longer necessary, it was shut in at the master valve. In April of 2016 an unsuccessful attempt was made to plug and abandon the previously leaking well, efforts were halted the end of the season and well was left secured. A second attempt to plug and abandon the well was made in 2017. The attempt was partially successful and left the well plugging incomplete. The well was secured at the end of the 2017 season. Operations Summary: OOS began the rig up on location on 3/13/2023. A snow pad was built to level the wellsite and provide a working area for the well equipment. The wellsite was lined with a single layer of Canadian rig mats to provide additional height clearance for the rig above ethe existing wellhead. During a pre-rig site visit, it was discovered that the wellhead pressure were all 0 psi and the planned rig up procedure was modified to allow the cut-off of the existing wellhead and a new starting head to be used near tundra level. Once the rig mats were set and the pad was leveled and surveyed, an arctic tent structure was erected to house the small core drill rig. All well equipment was spotted into place to include a cement unit, steam boiler, fresh water car, tool conex, hose conex, pit, and the DeLorean Drill Rig. The rig was erected inside of the tent structure and all equipment was un-thawed. The rig was commissioned and BOP testing completed. The existing well was entered on 3/28/2023 with the wash over BHA and found Top Of Cement (TOC) in the wellbore at surface level. No pressure or flow was observed on the wellbore. Washover milling operations continued until 4/10/2023 at which time a depth of 570’ was reached. The wash over operations washed over the existing 2-7/8” tubing inside of the 7” casing. It was found that the cement seemed competent during the entirety of the milling operations. When attempting to clean up the well and pull out of hole, the BHA was stuck and ultimately left a fish in the wellbore with a top of Fish at 398’. A bridge plug was set at 395’, then a cement plug was placed on top of the plug and fish from 398’ to 316’. The first cement plug was in place on 4/12/2023. A second cement plug was set on 4/15/2023 from 316’ to surface. Once the 7” casing was properly abandoned to surface, the wellhead was cut off 5’ below tundra level and an API marker plate was subsequently welded onto the 10-3/4” casing. The surface equipment was rigged down and removed from location. The well cellar area was back filled with fresh fill and all surface debris was cleaned from location. Operations were completed on 4/16/2023. Sincerely, Zach Sayers, P.E. Petroleum Engineer Clear Creek Energy, LLC. tĞůůWŚŽƚŽZĞƉŽƌƚ tĞůůEĂŵĞΘEƵŵďĞƌ͗/ŬŽĂLJtĞůůηϭ W/tĞůůEƵŵďĞƌ͗ ϱϬͲϬϮϯͲϮϬϬϬϳͲϬϬͲϬϬ &ŝĞůĚ͗ EĂƚŝŽŶĂůWĞƚƌŽůĞƵŵZĞƐĞƌǀĞ͕ůĂƐŬĂ ^ƵƌĨĂĐĞƉƌŝŽƌƚŽƉůƵŐŐŝŶŐĂĐƚŝǀŝƚŝĞƐĞŵĞŶƚƚŽƐƵƌĨĂĐĞĂĨƚĞƌǁĞůůŚĞĂĚĐƵƚŽĨĨ ϬϮͬϮϭͬϮϬϮϯϬϰͬϭϲͬϮϬϮϯ tĞůůŵĂƌŬĞƌƉůĂƚĞ^ƵƌĨĂĐĞƉŚŽƚŽĂĨƚĞƌĂďĂŶĚŽŶŵĞŶƚĂĐƚŝǀŝƚŝĞƐ ϰͬϭϲͬϮϬϮϯϬϰͬϮϮͬϮϬϮϯ ϭϭ͘ϮηDƵĚ EĂƚŝŽŶĂůWĞƚƌŽůĞƵŵZĞƐĞƌǀĞůĂƐŬĂ ĂƌƌŽǁ͕ůĂƐŬĂ /ŬŽĂLJηϭ Z<ʹ'>͗ϭϮ͘ϬΖ W/ηϱϬͲϬϮϯͲϮϬϬϬϳ d͗Ϯ͕ϳϯϭΖD ůĞǀĂƚŝŽŶ<͗ϰϬ͘ϬΖƌĂǁŶLJ͗ ĂƚĞ ϱͬϮϮͬϮϬϮϯWdηϭϬϬͲϬϯϲ :^ WƌŽĚƵĐƚŝŽŶĂƐŝŶŐ ϳΗ͕Ϯϯη͕Ͳϵϱ͕^'ƚŽϭ͕ϮϳϬΖDͬds ϯϮũƚƐZϯ&ůƵƐŚ:ƚĐĂƐŝŶŐ ;ϲ͘ϯϲϲΗ/͕ϲ͘ϮϰϭΗƌŝĨƚ͕ϳ͕ϱϯϬƵƌƐƚ͕ϰ͕ϭϰϬŽůůĂƉƐĞ͕ϲϯϮŬLJŝĞůĚͿ ĞŵĞŶƚĞĚǁŝƚŚϯϲϬƐdžŽĨƉĞƌŵĂĨƌŽƐƚĐŵƚ ĂůĐƵůĂƚĞĚdK͗ϮϱΖDΎ ΎĂƐƐƵŵŝŶŐϬ͘ϵϯĐƵ͘&ƚͬƐŬΘϰ͘ϳϲŐĂůͬƐŬ͕ϰϬйK, džĐĞƐƐĨĂĐƚŽƌ ĂƌĚǁĞůůDŽĚĞů,ZŝŐEŽ͘ϯ ^ƉƵĚ͗&ĞďƌƵĂƌLJϭƐƚ͕ϭϵϳϱ ŽŵƉůĞƚĞĚ͗DĂƌĐŚϴƚŚ͕ϭϵϳϱ ϭϮΖDͬds;KƌŝŐŝŶĂů'ƌŽƵŶĚ>ĞǀĞůͿ ŽŶĚƵĐƚŽƌĂƐŝŶŐ:ĂĐŬĞƚ ϮϰΗ^'ƚŽϭϴΖDͬds ŽŶĚƵĐƚŽƌĂƐŝŶŐ ϭϲΗ͕ϳϱη͕EͲϴϬ͕ϴƌĚ͕^'ƚŽнͬͲϭϰϵΖDͬds ΎEŽƚKďƐĞƌǀĞĚĂƚ^ƵƌĨĂĐĞ ϰũŽŝŶƚƐƌĂŶŐĞ///dΘ ;ϭϱ͘ϭϮϰΗ/͕ϭϰ͘ϵϯϲΗƌŝĨƚ͕Ϯ͕ϲϯϬƉƐŝƵƌƐƚ͕ϭ͕ϬϮϬƉƐŝ ŽůůĂƉƐĞͿ ĞŵĞŶƚĞĚǁŝƚŚϲϲϬƐdžŽĨƉĞƌŵĂĨƌŽƐƚĐĞŵĞŶƚ 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ZĞŵŽǀĞϮΗƌĞĚƵĐĞƌďƵƐŚŝŶŐŽŶ/ǀĂůǀĞĂŶĚƌĞŵŽǀĞďůĞĞĚĞƌǀĂůǀĞƐ͘ /ŶƐƉĞĐƚ/ǀĂůǀĞƐĂŶĚĨůŽǁůŝŶĞƐĨŽƌďůŽĐŬĂŐĞ͘ĞŵĞŶƚŽďƐĞƌǀĞĚũƵƐƚŝŶĨƌŽŶƚ;ŶĞĂƌǁĞůůŚĞĂĚͿŽĨϮŶĚ/ǀĂůǀĞ͘ůĞĂƌŽƵƚ ĐĞŵĞŶƚƵŶƚŝůĐůĞĂƌůŝŶĞŽĨƐŝƚĞŽďƐĞƌǀĞĚƚŽƚŚĞϮͲϳͬϴΗƚƵďŝŶŐ͘ EŽĨůŽǁŽďƐĞƌǀĞĚ͕ϬƌĞĂĚŝŶŐŽĨĐŽŵďƵƐƚŝďůĞƐĂŶĚϬ,Ϯ^ƌĞĂĚŝŶŐ͕ϬKƌĞĂĚŝŶŐ͘ K͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ /͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ d'͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ K͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ /͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ d'͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ K͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ /͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ d'͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ K͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ /͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ d'͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ dŽƚĂů,ŽƵƌƐ͗ K͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ /͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ d'͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ ^/DKW^͗ƉƌŽĨŝůĞǁĞůůŚĞĂĚĂŶĚĂůůĐŽŵƉŽŶĞŶƚƐ͘ K͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ /͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ d'͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ K͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ /͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ d'͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ K͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ /͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ d'͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ K͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ /͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ d'͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ K͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ /͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ d'͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ K͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ /͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ d'͗ϬĨůŽǁ͕K͗Ϭ͕,Ϯ^͗Ϭ͕> >͗Ϭ ZĞƐƚŽƌĞǁĞůůŚĞĂĚŶĞĞĚůĞǀĂůǀĞƐĂŶĚĐůŽƐĞĂůůǀĂůǀĞƐ͘ ZĞŵŽǀĞƉĂƌĂĐŚƵƚĞĂŶĚŚĞĂƚƚƌƵŶŬƐ ĞŵŽďďĂĐŬƚŽĂƌƌŽǁ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗Ϯ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϴͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗ŽŽŶĞůĂŬĞŶĞLJ WŚŽŶĞη͗ϵϬϳͲϮϯϬͲϮϬϵϰ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗Ͳϴ ϯϬ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗Ϯ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϴͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϴͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ ϲ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ ELJŵĂŶ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ůĞĂƌƌĞĞŬ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ ϳ͗ϬϬ ϳ͗ϭϱ Ϭ͗ϭϱ ϳ͗ϭϱ ϵ͗ϭϱ Ϯ͗ϬϬ ϵ͗ϭϱ ϭϭ͗ϯϬ Ϯ͗ϭϱ ϭϭ͗ϯϬ ϭϯ͗ϬϬ ϭ͗ϯϬ ϭϯ͗ϬϬ ϭϵ͗ϬϬ ϲ͗ϬϬ ϭϮ͗ϬϬ ZĞŵĂƌŬƐ͗ dŽƚĂů,ŽƵƌƐ͗ džĐĂǀĂƚĞĂƌŽƵŶĚĐĞůůĂƌĂƌĞĂƚŽĞdžƉŽƐĞƐƵƌĨĂĐĞĐĂƐŝŶŐ͕ĂŶĚĐŽŶĚƵĐƚŽƌ͘ hŶůŽĂĚƐĐĂĨĨŽůĚŝŶŐĨŽƌďƵŝůĚŝŶŐƚĞŶƚĂƌŽƵŶĚǁĞůůŚĞĂĚƚŽŵŽƌƌŽǁ͘ hŶĂďůĞƚŽŐĞƚůĂƌŐĞĞdžĐĂǀĂƚŽƌǁŽƌŬŝŶŐĚƵĞƚŽĨƌŽnjĞŶ &ƚĂŶŬ͘'ŽƚƐŵĂůůĞdžĐĂǀĂƚŽƌƌƵŶŶŝŶŐ͘ KĨĨůŽĂĚ,ŽƐĞĂŶĚdŽŽůŽŶŶĞdžƐ͘ Ϯ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ dĂŬĞǁĞůůƌĞĂĚŝŶŐƐĂŶĚŵĞĂƐƵƌĞŵĞŶƚƐ͕ƐĞƚƵƉĐŽŵŵƐ͕ĚŝŐŽƵƚĐĞůůĂƌĂƌĞĂ͘ ƵŝůĚƚĞŶƚĂƌŽƵŶĚǁĞůůĂŶĚƐĐĂĨĨŽůĚŝŶŐǁŽƌŬƉůĂƚĨŽƌŵ͘ƵƚĐŽŶĚƵĐƚŽƌĂŶĚϭϬͲϯͬϰΗĐĂƐŝŶŐ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ ,ŽůĚW:^D͘ŽůĚǁĞĂƚŚĞƌĞdžƉŽƐƵƌĞ͕ƉŽůĂƌďĞĂƌĂǁĂƌĞŶĞƐƐ͕ŚĂŶĚƉůĂĐĞŵĞŶƚ͘ ŚĞĐŬƉƌĞƐƐƵƌĞƐŽŶǁĞůůŚĞĂĚ͗ KƵƚĞƌ/ǀĂůǀĞƐĨƵŶĐƚŝŽŶĞĚ͘ KƉĞŶ/ǀĂůǀĞƐƚŽƉƌĞƐƐƵƌĞŐĂƵŐĞ͗ϬƉƐŝŽďƐĞƌǀĞĚ KƉĞŶďůĞĞĚĞƌƉŽƌƚŽŶ/ƚŽƐĞĐŽŶĚĂƌLJĐŽŶƚĂŝŶŵĞŶƚ͗EŽĨůŽǁŽďƐĞƌǀĞĚ͕ϬƌĞĂĚŝŶŐŽĨĐŽŵďƵƐƚŝďůĞƐĂŶĚϬ,Ϯ^ƌĞĂĚŝŶŐ͕Ϭ KƌĞĂĚŝŶŐ͘ KƉĞŶƚƵďŝŶŐŵĂƐƚĞƌǀĂůǀĞ;ϮϬƚƵƌŶƐƚŽŽƉĞŶͿ͕KƉĞŶŶĞĞĚůĞǀĂůǀĞƚŽƉƌĞƐƐƵƌĞŐĂƵŐĞ͗ϬƉƐŝŽďƐĞƌǀĞĚ KƉĞŶŶĞĞĚůĞǀĂůǀĞƚŽǁĞĞƉƉŽƌƚ͗ŽĨůŽǁŽďƐĞƌǀĞĚ͘^ŵĂůů> >ƌĞĂĚŝŶŐŽďƐĞƌǀĞĚĨƌŽŵŚĞĂƚŝŶŐĂŶĚǀĞŶƚŝŶŐŽĨĚŝĞƐĞů ŝŶƐŝĚĞŽĨƚŚĞƚƵďŝŶŐƚŚĂƚĚŝƐƐŝƉĂƚĞĚŝŶΕϭϱƐĞĐŽŶĚƐ͘ŽŶƚŝŶƵĞŵŽŶŝƚŽƌŝŶŐƚďŐ͗EŽĨůŽǁŽďƐĞƌǀĞĚ͕ϬƌĞĂĚŝŶŐŽĨ ĐŽŵďƵƐƚŝďůĞƐĂŶĚϬ,Ϯ^ƌĞĂĚŝŶŐ͕ϬKƌĞĂĚŝŶŐ͘ tŽƌŬŽŶĐĞůůƉŚŽŶĞƐƚĞƌ͕ǁŚŝůĞŐĞƚƚŝŶŐĞdžĐĂǀĂƚŽƌƚŽƌƵŶ͘ďůĞƚŽŐĞƚdΘdĐĞůůƐĞƌǀŝĐĞĨŽƌƉŚŽŶĞĐĂůůƐĂŶĚƚĞdžƚƐ͘ ϰ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ĚŝĞƐĞů ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ ϯϬϬ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ DŽƐƚůLJůŽƵĚLJ EŽƌƚŚ ĂƐƚ ϭϭͲϮϯDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϯ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϵͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗ŽŽŶĞůĂŬĞŶĞLJ WŚŽŶĞη͗ϵϬϳͲϮϯϬͲϮϬϵϰ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ͲϮϬ Ͳϲ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϯ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϵͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϴͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ ϲ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ ELJŵĂŶ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ůĞĂƌƌĞĞŬ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ ϳ͗ϬϬ ϳ͗ϭϱ Ϭ͗ϭϱ ϳ͗ϭϱ ϴ͗ϭϱ ϭ͗ϬϬ ϴ͗ϭϱ ϭϯ͗ϯϬ ϱ͗ϭϱ ϭϯ͗ϯϬ ϭϲ͗ϯϬ ϯ͗ϬϬ ϭϲ͗ϯϬ ϭϴ͗ϬϬ ϭ͗ϯϬ ϭϴ͗ϬϬ ϭϵ͗ϬϬ ϭ͗ϬϬ ϭϵ͗ϬϬ ϭϵ͗ϯϬ Ϭ͗ϯϬ ϭϮ͗ϯϬ ZĞŵĂƌŬƐ͗ ϯϬϬ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ ůĞĂƌ^ŬŝĞƐ ĂƐƚ ϮͲϭϱDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ĚŝĞƐĞů ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ ϰ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ /ŶƐƚĂůůĨůŽǁƉĂŶĂŶĚƐƉůŝƚďŽǁůŽŶǁĞůůŚĞĂĚ͗ ZĞŵŽǀĞƚŽƉƚĞƐƚĨůĂŶŐĞ͕ŝŶƐƚĂůůĐƌŽƐƐͲŽǀĞƌƉůĂƚĞ͕ďŽůƚƵƉĨůŽǁƉĂŶ͕ŝŶƐƚĂůůƐƉŝƚďŽǁů͘ Ϯ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ ƵŝůĚƚĞŶƚĂƌŽƵŶĚǁĞůůĂŶĚƐĐĂĨĨŽůĚŝŶŐǁŽƌŬƉůĂƚĨŽƌŵ͘ZhĨůŽǁƉĂŶ͘ ŽůůĞĐƚĨƌĞƐŚǁĂƚĞƌ͕DŝdžEĂůďƌŝŶĞĂŶĚĚŝƐƉůĂĐĞŽƵƚƚŚĞĚŝĞƐĞůĨƌŽŵƚďŐ͘ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ ,ŽůĚW:^D͗&ƵĞůŝŶŐƐƉŝůůƐĂĨĞƚLJ͕ǁŝŶĚĐŽŶĚŝƚŝŽŶƐ͕ǁŽƌŬŝŶŐĂƚŚĞŝŐŚƚƐ͕ŽǀĞƌŚĞĂĚůŽĂĚƐ͘ ŚĞĐŬƉƌĞƐƐƵƌĞƐŽŶǁĞůůŚĞĂĚ͗ KƉĞŶ/ǀĂůǀĞƐƚŽƉƌĞƐƐƵƌĞŐĂƵŐĞ͗ϬƉƐŝŽďƐĞƌǀĞĚ EŽĨůŽǁŽďƐĞƌǀĞĚ͕ϬƌĞĂĚŝŶŐŽĨĐŽŵďƵƐƚŝďůĞƐĂŶĚϬ,Ϯ^ƌĞĂĚŝŶŐ͕ϬKƌĞĂĚŝŶŐ͘ KƉĞŶƚƵďŝŶŐŵĂƐƚĞƌǀĂůǀĞ;ϮϬƚƵƌŶƐƚŽŽƉĞŶͿ͕KƉĞŶŶĞĞĚůĞǀĂůǀĞƚŽƉƌĞƐƐƵƌĞŐĂƵŐĞ͗ϬƉƐŝŽďƐĞƌǀĞĚ EŽĨůŽǁŽďƐĞƌǀĞĚ͘EŽĨůŽǁŽďƐĞƌǀĞĚ͕ϬƌĞĂĚŝŶŐŽĨĐŽŵďƵƐƚŝďůĞƐĂŶĚϬ,Ϯ^ƌĞĂĚŝŶŐ͕ϬKƌĞĂĚŝŶŐ͘ KƉĞŶK͗ϬƉƐŝŽďƐĞƌǀĞĚ EŽĨůŽǁŽďƐĞƌǀĞĚ͘EŽĨůŽǁŽďƐĞƌǀĞĚ͕ϬƌĞĂĚŝŶŐŽĨĐŽŵďƵƐƚŝďůĞƐĂŶĚϬ,Ϯ^ƌĞĂĚŝŶŐ͕ϬKƌĞĂĚŝŶŐ͘ ƵŝůĚ^ĐĂĨĨŽůĚŝŶŐ;ϯůĞǀĞůƐƚĂůůͿ͘ DŽǀĞŚĞĂƚĞƌƚŽǁĞůůĂŶĚƐĞƚƵƉŚĞĂƚƚƌƵŶŬƐŽŶǁĞůůŚĞĂĚ͘ ZĞƉĂŝƌŐĂƐŽůŝŶĞǁĞůĚĞƌ dĂĐŬǁĞůĚĂĚĂƉƚĞƌƉůĂƚĞĂŶĚĨůŽǁƉĂŶ͘ ůĞĂŶǁŽƌŬƐŝƚĞĂŶĚƐĞĐƵƌĞǁĞůů͘ dŽƚĂů,ŽƵƌƐ͗ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϰ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϭϬͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗ŽŽŶĞůĂŬĞŶĞLJ WŚŽŶĞη͗ϵϬϳͲϮϯϬͲϮϬϵϰ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗Ͳϭϴ ϭϲ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϰ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϭϬͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϴͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ ϳ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ ELJŵĂŶ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ůĞĂƌƌĞĞŬ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ ϳ͗ϬϬ ϳ͗ϭϱ Ϭ͗ϭϱ ϳ͗ϭϱ ϴ͗ϬϬ Ϭ͗ϰϱ ϴ͗ϬϬ ϵ͗ϬϬ ϭ͗ϬϬ ϵ͗ϬϬ ϭϬ͗ϬϬ ϭ͗ϬϬ ϭϬ͗ϬϬ ϭϬ͗ϯϬ Ϭ͗ϯϬ ϭϬ͗ϯϬ ϭϯ͗ϬϬ Ϯ͗ϯϬ ϭϯ͗ϬϬ ϭϰ͗ϬϬ ϭ͗ϬϬ ϭϰ͗ϬϬ ϭϱ͗ϯϬ ϭ͗ϯϬ ϭϱ͗ϯϬ ϭϲ͗ϭϱ Ϭ͗ϰϱ ϭϲ͗ϭϱ ϭϳ͗ϬϬ Ϭ͗ϰϱ ϭϳ͗ϬϬ ϭϳ͗ϯϬ Ϭ͗ϯϬ ϭϳ͗ϯϬ ϭϴ͗ϬϬ Ϭ͗ϯϬ ϭϴ͗ϬϬ ϭϴ͗ϯϬ Ϭ͗ϯϬ ϭϴ͗ϯϬ ϭϵ͗ϬϬ Ϭ͗ϯϬ ϭϮ͗ϬϬ ZĞŵĂƌŬƐ͗ dŽƚĂů,ŽƵƌƐ͗ ŚĞĐŬƉƌĞƐƐƵƌĞƐŽŶǁĞůůŚĞĂĚ͗ KƉĞŶ/ǀĂůǀĞƐƚŽƉƌĞƐƐƵƌĞŐĂƵŐĞ͗ϬƉƐŝŽďƐĞƌǀĞĚ EŽĨůŽǁŽďƐĞƌǀĞĚ͕ϬƌĞĂĚŝŶŐŽĨĐŽŵďƵƐƚŝďůĞƐĂŶĚϬ,Ϯ^ƌĞĂĚŝŶŐ͕ϬKƌĞĂĚŝŶŐ͘ KƉĞŶƚƵďŝŶŐŵĂƐƚĞƌǀĂůǀĞ;ϮϬƚƵƌŶƐƚŽŽƉĞŶͿ͕KƉĞŶŶĞĞĚůĞǀĂůǀĞƚŽƉƌĞƐƐƵƌĞŐĂƵŐĞ͗ϬƉƐŝŽďƐĞƌǀĞĚ EŽĨůŽǁŽďƐĞƌǀĞĚ͘EŽĨůŽǁŽďƐĞƌǀĞĚ͕ϬƌĞĂĚŝŶŐŽĨĐŽŵďƵƐƚŝďůĞƐĂŶĚϬ,Ϯ^ƌĞĂĚŝŶŐ͕ϬKƌĞĂĚŝŶŐ͘ KƉĞŶK͗ϬƉƐŝŽďƐĞƌǀĞĚ EŽĨůŽǁŽďƐĞƌǀĞĚ͘EŽĨůŽǁŽďƐĞƌǀĞĚ͕ϬƌĞĂĚŝŶŐŽĨĐŽŵďƵƐƚŝďůĞƐĂŶĚϬ,Ϯ^ƌĞĂĚŝŶŐ͕ϬKƌĞĂĚŝŶŐ͘ /ŶƐƚĂůůĂĚĂƉƚĞƌƉůĂƚĞƚŽǁĞůůŚĞĂĚ͕ďŽůƚƵƉƚŽDĂƚĞƌǀĂůǀĞĂŶĚƉĂƐƚĞƐĞĂůůŽǁƉƌĞƐƐƵƌĞƐŝĚĞǁŝƚŚĂĚŚĞƐŝǀĞƐĞĂůĂŶƚ͘Ƶƚ ŶŽƚĐŚŽƵƚŽĨǁŽƌŬƉůĂƚĨŽƌŵƚŽƌĞƚƵƌŶƐŽƵƚŽĨĨůŽǁƉĂŶ͘ ^ĞĐƵƌĞƚŽĞďŽĂƌĚƐĂŶĚƐĐĂĨĨŽůĚŝŶŐǁŝƚŚůĂĚĚĞƌ͘ ^ƚĂŐĞĚEĂůŶĞdžƚƚŽǁĞůů͕ŵĂŬĞƵƉƌĞƚƵƌŶůŝŶĞŚŽƐĞĨŝƚƚŝŶŐƐ͘ ^ĞĐƵƌĞƚĂƌƉƐǁŝƚŚƌŽƉĞƐƚŽƐĞĐƵƌĞŝŶƚŚĞŚŝŐŚǁŝŶĚƐĞŶǀŝƌŽŶŵĞŶƚ͘ ĚĚĂĚĚŝƚŝŽŶĂůƐĞĂůĂŶƚĂƌŽƵŶĚĂĚĂƉƚĞƌƉůĂƚĞ͘ KĨĨůŽĂĚĞŵƉƚLJƚŽƚĞĂŶĚƐƚĂŐĞŶĞĂƌǁĞůůŚĞĂĚƚŽƚĂŬĞƌĞƚƵƌŶƐ͘ KĨĨůŽĂĚĨƌĞƐŚǁĂƚĞƌĨƌŽŵƚĂĐŽƐůĞĚĂŶĚƐƚĂŐĞŶĞĂƌǁĞůůŚĞĂĚ͘ ƵŝůĚĂĚĚŝƚŝŽŶĂůƐĐĂĨĨŽůĚŝŶŐĂŶĚƉĂƌĂĐŚƵƚĞ;džϮͿϯϬϬŐĂůƚŽƚĞƐ͘^ĞƚŚĞĂƚĞƌƚƌƵŶŬŽŶƚŽĨƌĞƐŚǁĂƚĞƌƚŽƚĞ͘ KĨĨůŽĂĚϯϬϬΖŽĨϭΗŵĂĐĂƌŽŶŝƚƵďŝŶŐŽƵƚŽĨŽŶĞdžĂŶĚƐƚĂŐĞŶĞĂƌǁĞůůĨŽƌƚŽŵŽƌƌŽǁ͘ ƵŝůĚǁŽŽĚďůŽĐŬŝŶŐƵƉƵŶĚĞƌƌĞƚƵƌŶƐƚŽƚĞƚŽďƌŝŶŐƚŽƌĞƚƵƌŶƐůŝŶĞƚŽƉƌĞǀĞŶƚƐƉŝůůƐ͘ ůĞĂŶǁŽƌŬƐŝƚĞĂŶĚƐĞĐƵƌĞǁĞůů͘ tĞůĚ^ƚƵĚƐŽŶƚŽǁĞůůŚĞĂĚĂĚĂƉƚĞƌƉůĂƚĞ͘ &ŝŶŝƐŚƚĂƌƉŝŶŐŝŶƐĐĂĨĨŽůĚŝŶŐ͘ Ϯ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ ŽůůĞĐƚĨƌĞƐŚǁĂƚĞƌĂŶĚƚƌĂŶƐƉŽƌƚƚŽǁĞůů͕^ĞƚƵƉĨůŽǁƉĂŶĂŶĚƚŽƚĞƐƚŽƚĂŬĞƌĞƚƵƌŶƐ͘ DŝdžEĂůďƌŝŶĞĂŶĚĚŝƐƉůĂĐĞŽƵƚƚŚĞĚŝĞƐĞůĨƌŽŵƚďŐ͘ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ ,ŽůĚW:^D͗,ŝŐŚtŝŶĚƐ͕ůŽǁŝŶŐ^ŶŽǁ &ƵĞů ƋƵŝƉŵĞŶƚ ZĞͲKƌŝĞŶƚƚƌƵŶŬŚĞĂƚĞƌ͘,ĞĂƚƵƉǁĞůĚĞƌĂŶĚǁĞůůƚƌĞĞ KĨĨůŽĂĚŬůŝŵƉďŽdžŽĨEĂůƐĂůƚ͘ ĞŐŝŶƚŽƚĞŶƚŝŶƐĐĂĨĨŽůĚŝŶŐ͘ ϱ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ĚŝĞƐĞů ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ ϯϬϬ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ >ŝŐŚƚ^ŶŽǁ͕/ĐĞ&ŽŐ EŽƌƚŚͲtĞƐƚĂŶĚ ĂƐƚ ϭϮͲϭϱDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϱ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϭϭͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗ŽŽŶĞůĂŬĞŶĞLJ WŚŽŶĞη͗ϵϬϳͲϮϯϬͲϮϬϵϰ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗Ͳϭϳ ͲϮ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϱ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϭϭͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϴͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ ϳ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ ELJŵĂŶ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ůĞĂƌƌĞĞŬ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ ϳ͗ϬϬ ϳ͗ϭϱ Ϭ͗ϭϱ ϳ͗ϭϱ ϴ͗ϭϱ ϭ͗ϬϬ ϴ͗ϭϱ ϵ͗ϬϬ Ϭ͗ϰϱ ϵ͗ϬϬ ϭϰ͗ϯϬ ϱ͗ϯϬ ϭϰ͗ϯϬ ϭϱ͗ϬϬ Ϭ͗ϯϬ ϭϱ͗ϬϬ ϭϴ͗ϯϬ ϯ͗ϯϬ ϭϴ͗ϯϬ ϭϵ͗ϬϬ Ϭ͗ϯϬ ϭϮ͗ϬϬ ZĞŵĂƌŬƐ͗ dŽƚĂů,ŽƵƌƐ͗ ŚĞĐŬƉƌĞƐƐƵƌĞƐŽŶǁĞůůŚĞĂĚ͗ KƉĞŶ/ǀĂůǀĞƐƚŽƉƌĞƐƐƵƌĞŐĂƵŐĞ͗ϬƉƐŝŽďƐĞƌǀĞĚ EŽĨůŽǁŽďƐĞƌǀĞĚ͕ϬƌĞĂĚŝŶŐŽĨĐŽŵďƵƐƚŝďůĞƐĂŶĚϬ,Ϯ^ƌĞĂĚŝŶŐ͕ϬKƌĞĂĚŝŶŐ͘ KƉĞŶƚƵďŝŶŐŵĂƐƚĞƌǀĂůǀĞ;ϮϬƚƵƌŶƐƚŽŽƉĞŶͿ͕KƉĞŶŶĞĞĚůĞǀĂůǀĞƚŽƉƌĞƐƐƵƌĞŐĂƵŐĞ͗ϬƉƐŝŽďƐĞƌǀĞĚ EŽĨůŽǁŽďƐĞƌǀĞĚ͘EŽĨůŽǁŽďƐĞƌǀĞĚ͕ϬƌĞĂĚŝŶŐŽĨĐŽŵďƵƐƚŝďůĞƐĂŶĚϬ,Ϯ^ƌĞĂĚŝŶŐ͕ϬKƌĞĂĚŝŶŐ͘ KƉĞŶK͗ϬƉƐŝŽďƐĞƌǀĞĚ EŽĨůŽǁŽďƐĞƌǀĞĚ͘EŽĨůŽǁŽďƐĞƌǀĞĚ͕ϬƌĞĂĚŝŶŐŽĨĐŽŵďƵƐƚŝďůĞƐĂŶĚϬ,Ϯ^ƌĞĂĚŝŶŐ͕ϬKƌĞĂĚŝŶŐ͘ ŚĂŶŐĞŽĨƐĐŽƉĞǁŚŝůĞǁĂŝƚŝŶŐŽŶƐĞĂůĂŶƚƚŽĐƵƌĞ͗ ƵƚŽĨĨĐŽŶĚƵĐƚŽƌĐĂƐŝŶŐũĂĐŬĞƚ;ϮϰΗĚŝĂŵĞƚĞƌͿ͘ ƵƚĐŽŶĚƵĐƚŽƌĐĂƐŝŶŐŽĨĨĂŶĚĐŚŝƉĂǁĂLJĐĞŵĞŶƚƚŽŐĂŝŶĂĐĐĞƐƐƚŽƚŚĞϭϬͲϯͬϰΗĐĂƐŝŶŐ͘ ĞŵĞŶƚŽďƐĞƌǀĞĚĂƚƐƵƌĨĂĐĞŝŶƚŚĞϭϬͲϯͬϰΗdžϭϲΗĐĂƐŝŶŐ ůĞĂŶǁŽƌŬƐŝƚĞĂŶĚƐĞĐƵƌĞǁĞůů͘ >ĞĂŬƚĞƐƚĂĚĂƉƚĞƌƉůĂƚĞĂŶĚĨůŽǁƉĂŶ͘ZĞƉĂŝƌůĞĂŬŝŶŐƐĞĂůĂŶĚƚŝŐŚƚĞŶĂůůďŽůƚƐ͘ Ϯ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ DŝdžEĂůďƌŝŶĞĂŶĚĐƵƚŽĨĨϮϰΗĐŽŶĚƵĐƚŽƌũĂĐŬĞƚĂŶĚϭϲΗĐŽŶĚƵĐƚŽƌ͘ ŝƐƉůĂĐĞŽƵƚƚŚĞĚŝĞƐĞůĨƌŽŵƚďŐ͘ƵƚϭϬͲϯͬϰΗĐĂƐŝŶŐ͘ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ ,ŽůĚW:^D͗&ůƵŝĚdƌĂŶƐĨĞƌWƌŽƚŽĐŽů͕^ƉŝůůƉƌĞǀĞŶƚŝŽŶ &ƵĞů ƋƵŝƉŵĞŶƚ dƌĂŶƐĨĞƌĨƌĞƐŚǁĂƚĞƌƚŽĞŵƉƚLJƚŽƚĞĂŶĚŵŝdžϵ͘ϴƉƉŐEĂůďƌŝŶĞ ϱ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ĚŝĞƐĞů ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ ϯϬϬ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ ^ƵŶŶLJ͕ůĞĂƌ^ŬŝĞƐ ĂƐƚ ϵͲϭϮDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϲ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϭϮͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗ŽŽŶĞůĂŬĞŶĞLJ WŚŽŶĞη͗ϵϬϳͲϮϯϬͲϮϬϵϰ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ͲϮϬ Ͳϭϳ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϲ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϭϮͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϴͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ ϲ͘ϴ ϭ͘ϳϵ ϭ͘ϳϵ ϳ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ ELJŵĂŶ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ůĞĂƌƌĞĞŬ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ ϳ͗ϬϬ ϳ͗ϭϱ Ϭ͗ϭϱ ϳ͗ϭϱ ϴ͗ϬϬ Ϭ͗ϰϱ ϴ͗ϬϬ ϴ͗ϯϬ Ϭ͗ϯϬ ϴ͗ϯϬ ϭϲ͗ϯϬ ϴ͗ϬϬ ϭϲ͗ϯϬ ϭϳ͗ϯϬ ϭ͗ϬϬ ϭϳ͗ϯϬ ϭϴ͗ϯϬ ϭ͗ϬϬ ϭϴ͗ϯϬ ϭϵ͗ϬϬ Ϭ͗ϯϬ ϭϮ͗ϬϬ ZĞŵĂƌŬƐ͗ dŽƚĂů,ŽƵƌƐ͗ ZĞͲĂƐƐĞŵďůĞƉůƵŵďŝŶŐŽŶK͕ĨŝůůǁŝƚŚďƌŝŶĞ͘KƚŽŽŬΕϱŐĂůŽĨϵ͘ϴηďƌŝŶĞƚŝůůĨƵůů͘ ZĞͲĂƐƐĞŵďůĞƉůƵŵďŝŶŐŽŶ/͕ĨŝůůǁŝƚŚďƌŝŶĞ͘/ƚŽŽŬΕϱŐĂůŽĨϵ͘ϴηďƌŝŶĞƚŝůůĨƵůů͘ ^ŶŝĨĨǁĞůůĂŶĚĐĞůůĂƌĨŽƌŚŽƚǁŽƌŬƉĞƌŵŝƚ͘WƌĞƉϭϬͲϯͬϰΗĐĂƐŝŶŐĨŽƌƌĞŵŽǀĂůƚŽŵŽƌƌŽǁ͘ ůĞĂŶǁŽƌŬƐŝƚĞĂŶĚƐĞĐƵƌĞǁĞůů͘ d/,ǁŝƚŚϭΗŵĂĐĂƌŽŶŝƚƵďŝŶŐĨƌŽŵƐƵƌĨĂĐĞƚŽϮϳϲΖďĞůŽǁƚŚĞĨůŽǁƉĂŶ͘dĂŐŚĂƌĚĂƚϮϳϲΖďĞůŽǁĨůŽǁƉĂŶ͘ ŝƐƉůĂĐĞŽƵƚĚŝĞƐĞůǁŚŝůĞd/,ǁŝƚŚǁŽƌŬƐƚƌŝŶŐ͘ΕϳϱŐĂůůŽŶƐƌĞƚƵƌŶĞĚ͘ ŽůůĞĐƚƐĂŵƉůĞŽĨǁĞůůĨůƵŝĚƐĨŽƌWƚĞƐƚŝŶŐ͘ dKK,͕>ϭΗǁŽƌŬƐƚƌŝŶŐ͘ Ϯ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ ŝƐƉůĂĐĞŽƵƚƚŚĞĚŝĞƐĞůĨƌŽŵƚďŐ͘ ƵƚϭϬͲϯͬϰΗĐĂƐŝŶŐ͘,ŽƚͲƚĂƉϳΗĐĂƐŝŶŐ͕ĐƵƚϳΗĐĂƐŝŶŐĂŶĚƉƌĞƉĨŽƌƐůŝƉͲŽŶǁĞůůŚĞĂĚ͘ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ ,ŽůĚW:^D͗ŽǀĞƌŚĞĂĚůŽĂĚƐ͕ƉŝƉĞŚĂŶĚůŝŶŐƐĂĨĞƚLJ͕ƉŝŶĐŚƉŽŝŶƚƐ͕ǁŽƌŬŝŶŐĂƚŚĞŝŐŚƚƐ͘ &ƵĞů ƋƵŝƉŵĞŶƚ ŚĞĐŬƉƌĞƐƐƵƌĞƐŽŶǁĞůůŚĞĂĚ͗ KƉĞŶ/ǀĂůǀĞƐƚŽƉƌĞƐƐƵƌĞŐĂƵŐĞ͗ϬƉƐŝŽďƐĞƌǀĞĚ EŽĨůŽǁŽďƐĞƌǀĞĚ͕ϬƌĞĂĚŝŶŐŽĨĐŽŵďƵƐƚŝďůĞƐĂŶĚϬ,Ϯ^ƌĞĂĚŝŶŐ͕ϬKƌĞĂĚŝŶŐ͘ KƉĞŶƚƵďŝŶŐŵĂƐƚĞƌǀĂůǀĞ;ϮϬƚƵƌŶƐƚŽŽƉĞŶͿ͕KƉĞŶŶĞĞĚůĞǀĂůǀĞƚŽƉƌĞƐƐƵƌĞŐĂƵŐĞ͗ϬƉƐŝŽďƐĞƌǀĞĚ EŽĨůŽǁŽďƐĞƌǀĞĚ͘EŽĨůŽǁŽďƐĞƌǀĞĚ͕ϬƌĞĂĚŝŶŐŽĨĐŽŵďƵƐƚŝďůĞƐĂŶĚϬ,Ϯ^ƌĞĂĚŝŶŐ͕ϬKƌĞĂĚŝŶŐ͘ KƉĞŶK͗ϬƉƐŝŽďƐĞƌǀĞĚ EŽĨůŽǁŽďƐĞƌǀĞĚ͘EŽĨůŽǁŽďƐĞƌǀĞĚ͕ϬƌĞĂĚŝŶŐŽĨĐŽŵďƵƐƚŝďůĞƐĂŶĚϬ,Ϯ^ƌĞĂĚŝŶŐ͕ϬKƌĞĂĚŝŶŐ͘ ϱ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϵ͘ϴηEĂůďƌŝŶĞ ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ ϯϬϬ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ ^ƵŶŶLJ͕ůĞĂƌ^ŬŝĞƐ ĂƐƚ ϭϱͲϭϵDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϳ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϭϯͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗ŽŽŶĞůĂŬĞŶĞLJ WŚŽŶĞη͗ϵϬϳͲϮϯϬͲϮϬϵϰ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗Ͳϭϱ ͲϮϮ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϳ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϭϯͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϭϯͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ ϭϴ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ ELJŵĂŶ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ϭ ůĞĂƌƌĞĞŬ <Θ ϱ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ ϳ͗ϬϬ ϳ͗ϭϱ Ϭ͗ϭϱ ϳ͗ϭϱ ϴ͗ϬϬ Ϭ͗ϰϱ ϴ͗ϬϬ ϴ͗ϯϬ Ϭ͗ϯϬ ϴ͗ϯϬ ϭϬ͗ϬϬ ϭ͗ϯϬ ϭϬ͗ϬϬ ϭϬ͗ϯϬ Ϭ͗ϯϬ ϭϬ͗ϯϬ ϭϭ͗ϯϬ ϭ͗ϬϬ ϭϭ͗ϯϬ ϭϯ͗ϬϬ ϭ͗ϯϬ ϭϯ͗ϬϬ ϭϱ͗ϬϬ Ϯ͗ϬϬ ϭϱ͗ϬϬ ϭϲ͗ϬϬ ϭ͗ϬϬ ϭϲ͗ϬϬ ϭϲ͗ϯϬ Ϭ͗ϯϬ ϭϲ͗ϯϬ ϭϵ͗ϬϬ Ϯ͗ϯϬ ϭϮ͗ϬϬ ZĞŵĂƌŬƐ͗ ϮϳϲΖ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ ^ƵŶŶLJ͕ůĞĂƌ^ŬŝĞƐ ĂƐƚ͕^ŽƵƚŚ ϰͲϵDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ϵ͘ϴηEĂůďƌŝŶĞ ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ ϵ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ƵƚͲŽĨĨϭϬͲϯͬϰΗĐĂƐŝŶŐďĞůŽǁŐƌĂĚĞ͘ ΎΎΎEŽƚĞ͗ĐĞŵĞŶƚŽďƐĞƌǀĞĚƚŽƐƵƌĨĂĐĞŽŶϳΗdžϭϬͲϯͬϰΗĂŶŶƵůƵƐ͘ ϭ Ϯ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ ƵƚϭϬͲϯͬϰΗĐĂƐŝŶŐ͘,ŽƚͲƚĂƉϳΗĐĂƐŝŶŐ͕ĐƵƚϳΗĐĂƐŝŶŐĂŶĚŝŶƐƚĂůůƐůŝƉͲŽŶǁĞůůŚĞĂĚ͘ WƌĞƉůŽĐĂƚŝŽŶĨŽƌƌŝŐĂŶĚĂƌĐƚŝĐƚĞŶƚƐƚƌƵĐƚƵƌĞ͘ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ ,ŽůĚW:^D͗ŚŽƚǁŽƌŬƉĞƌŵŝƚƚŝŶŐ͕ďůŽǁͲŽƵƚƐĂĨĞƚLJ͕ƐŝƚĞĞǀĂĐĚƌŝůů͘ &ƵĞů ƋƵŝƉŵĞŶƚ ŚĞĐŬƉƌĞƐƐƵƌĞƐŽŶǁĞůůŚĞĂĚ͗ KƉĞŶ/ǀĂůǀĞƐƚŽƉƌĞƐƐƵƌĞŐĂƵŐĞ͗ϬƉƐŝŽďƐĞƌǀĞĚ EŽĨůŽǁŽďƐĞƌǀĞĚ͕ϬƌĞĂĚŝŶŐŽĨĐŽŵďƵƐƚŝďůĞƐĂŶĚϬ,Ϯ^ƌĞĂĚŝŶŐ͕ϬKƌĞĂĚŝŶŐ͘ KƉĞŶƚƵďŝŶŐŵĂƐƚĞƌǀĂůǀĞ;ϮϬƚƵƌŶƐƚŽŽƉĞŶͿ͕KƉĞŶŶĞĞĚůĞǀĂůǀĞƚŽƉƌĞƐƐƵƌĞŐĂƵŐĞ͗ϬƉƐŝŽďƐĞƌǀĞĚ EŽĨůŽǁŽďƐĞƌǀĞĚ͘EŽĨůŽǁŽďƐĞƌǀĞĚ͕ϬƌĞĂĚŝŶŐŽĨĐŽŵďƵƐƚŝďůĞƐĂŶĚϬ,Ϯ^ƌĞĂĚŝŶŐ͕ϬKƌĞĂĚŝŶŐ͘ KƉĞŶK͗ϬƉƐŝŽďƐĞƌǀĞĚ EŽĨůŽǁŽďƐĞƌǀĞĚ͘EŽĨůŽǁŽďƐĞƌǀĞĚ͕ϬƌĞĂĚŝŶŐŽĨĐŽŵďƵƐƚŝďůĞƐĂŶĚϬ,Ϯ^ƌĞĂĚŝŶŐ͕ϬKƌĞĂĚŝŶŐ͘ ŽŵƉůĞƚĞ,ŽƚtŽƌŬWĞƌŵŝƚ ƚƚĞŵƉƚƚŽĨŝůů/ǁŝƚŚďƌŝŶĞ;ƚŽƉͲŽĨĨͿ͘/ƚŽŽŬϬŐĂůŽĨϵ͘ϴηďƌŝŶĞƚŝůůĨƵůů;ĂůƌĞĂĚLJĨƵůůͿ͘ ŚŝƉŽĨĨĐĞŵĞŶƚďŽŶĚĞĚƚŽƚŚĞϳΗĐĂƐŝŶŐǁŚĞƌĞϭϬͲϯͬϰΗĐĂƐŝŶŐǁĂƐĐƵƚŽĨĨ͘ tĞůĚŽŶ,ŽƚƚĂƉŶŝƉƉůĞƚŽƚŚĞϳΗĐĂƐŝŶŐďĞůŽǁƚŚĞƉůĂŶŶĞĚĐƵƚͲŽĨĨĚĞƉƚŚ͘ ƵƚŽĨĨƚŚĞϳΗĐĂƐŝŶŐďĞůŽǁƚƵŶĚƌĂůĞǀĞů͘ ŚŝƉĂǁĂLJĐĞŵĞŶƚĂŶĚĐƵƚϮͲϳͬϴΗƚƵďŝŶŐ͘ ΎΎΎEŽƚĞ͗ĐĞŵĞŶƚŽďƐĞƌǀĞĚƚŽƐƵƌĨĂĐĞŽŶϮͲϳͬϴΗdžϳΗĂŶŶƵůƵƐ͘ ůĞĂŶƵƉĐĞŵĞŶƚŝŶ/ĂŶĚĚƌĞƐƐϳΗĐĂƐŝŶŐĨŽƌŶĞǁƐƚĂƌƚŝŶŐŚĞĂĚ͘ tĞůĚŽŶϳΗƐƚĂƌƚŝŶŐŚĞĂĚ͘dŽƉ&ůĂŶŐĞΕϲΗĂďŽǀĞƚƵŶĚƌĂůĞǀĞů͘ WůĂĐĞƉůƵŐŝŶƐŝĚĞŽĨƐƚĂƌƚŝŶŐŚĞĂĚĂŶĚƌƵŶŝŶůŽĐŬĚŽǁŶƐĐƌĞǁƐ;Z/>^Ϳ͘ ƌĞĂŬĚŽǁŶƐĐĂĨĨŽůĚŝŶŐ͕ĐůĞĂŶĂŶĚĐůĞĂƌůŽĐĂƚŝŽŶ͘ dŽƚĂů,ŽƵƌƐ͗ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϴ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϭϰͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗ŽŽŶĞůĂŬĞŶĞLJ WŚŽŶĞη͗ϵϬϳͲϮϯϬͲϮϬϵϰ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ͲϮϮ Ͳϭϱ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϴ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϭϰͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϭϯͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ ϭϴ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ ELJŵĂŶ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ϭ ůĞĂƌƌĞĞŬ <Θ ϱ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ ϳ͗ϬϬ ϳ͗ϭϱ Ϭ͗ϭϱ ϳ͗ϭϱ ϴ͗ϬϬ Ϭ͗ϰϱ ϴ͗ϬϬ ϵ͗ϬϬ ϭ͗ϬϬ ϵ͗ϬϬ ϭϵ͗ϬϬ ϭϬ͗ϬϬ ϭϮ͗ϬϬ ZĞŵĂƌŬƐ͗ ϮϳϲΖ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ ^ƵŶŶLJ͕ůĞĂƌ^ŬŝĞƐ ĂƐƚ͕^ŽƵƚŚͲ ĂƐƚ ϳͲϴDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ϵ͘ϴηEĂůďƌŝŶĞ ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ ϵ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ /ŶƐƚĂůůͲZŝŶŐƐŽŶƚŽZŝŐDĂƚƐƚŽƐĞĐƵƌĞĂŶĐŚŽƌƐĨŽƌƌĐƚŝĐƚĞŶƚƐƚƌƵĐƚƵƌĞ͘ ^/DKW^͗^ƉƌĞĂĚƐŶŽǁĂŶĚŐƌĂĚĞƉĂĚƚŽďƌŝŶŐƚŽůĞǀĞů͘ ϭ Ϯ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ WƌĞƉůŽĐĂƚŝŽŶĨŽƌƌŝŐĂŶĚĂƌĐƚŝĐƚĞŶƚƐƚƌƵĐƚƵƌĞ͘ WƌĞƉůŽĐĂƚŝŽŶĨŽƌƌŝŐĂŶĚĂƌĐƚŝĐƚĞŶƚƐƚƌƵĐƚƵƌĞ͘ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ ,ŽůĚW:^D͗ĂŵƉKƌŝĞŶƚĂƚŝŽŶ͕WŽůĂƌĞĂƌ^ĂĨĞƚLJ͕ŽůĚtĞĂƚŚĞƌĂǁĂƌĞŶĞƐƐ &ƵĞů ƋƵŝƉŵĞŶƚ ^ŚƵƚƚůĞ<ΘƌŝŐĐƌĞǁƚŽǁĞůůƐŝƚĞ͘ ^/DKW^͗&ŝŶŝƐŚĐůĞĂŶŝŶŐƵƉĐĞůůĂƌĂŶĚǁĞůůƐŝƚĞ͘ dŽƚĂů,ŽƵƌƐ͗ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϵ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϭϱͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗ŽŽŶĞůĂŬĞŶĞLJ WŚŽŶĞη͗ϵϬϳͲϮϯϬͲϮϬϵϰ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ͲϮϵ Ͳϭϳ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϵ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϭϱͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϭϯͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ Ϭ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ ELJŵĂŶ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ůĞĂƌƌĞĞŬ <Θ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ ϳ͗ϬϬ ϭϵ͗ϬϬ ϭϮ͗ϬϬ ϭϮ͗ϬϬ ZĞŵĂƌŬƐ͗ dŽƚĂů,ŽƵƌƐ͗ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ tŽƌŬŽŶƌĐƚŝĐƚĞŶƚƐƚƌƵĐƚƵƌĞ͘ tŽƌŬŽŶƌĐƚŝĐƚĞŶƚƐƚƌƵĐƚƵƌĞ͘ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ tŽƌŬŽŶƌĐƚŝĐ^ƚƌƵĐƚƵƌĞ͘ZĞŵŽǀĞƌŝďƐĞĐƚŝŽŶƐĨƌŽŵĐƌĂƚĞƐĂŶĚƵŶĨŽůĚ͘ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϵ͘ϴηEĂůďƌŝŶĞ ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ ϮϳϲΖ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ ^ƵŶŶLJ͕ůĞĂƌ^ŬŝĞƐ EŽƌƚŚtĞƐƚ ϴͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϭϬ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϭϲͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗ŽŽŶĞůĂŬĞŶĞLJ WŚŽŶĞη͗ϵϬϳͲϮϯϬͲϮϬϵϰ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ͲϮϲ Ͳϭϱ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϭϬ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϭϲͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϭϯͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ Ϭ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ ELJŵĂŶ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ůĞĂƌƌĞĞŬ <Θ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ ϳ͗ϬϬ ϭϵ͗ϬϬ ϭϮ͗ϬϬ ϭϮ͗ϬϬ ZĞŵĂƌŬƐ͗ dŽƚĂů,ŽƵƌƐ͗ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ tŽƌŬŽŶƌĐƚŝĐƚĞŶƚƐƚƌƵĐƚƵƌĞ͘ tŽƌŬŽŶƌĐƚŝĐƚĞŶƚƐƚƌƵĐƚƵƌĞ͘ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ tŽƌŬŽŶƌĐƚŝĐ^ƚƌƵĐƚƵƌĞ͘&ŝŶŝƐŚƵŶĨŽůĚŝŶŐƌŝďƐĞĐƚŝŽŶŽĨƚŚĞĂƌĐƚŝĐƐƚƌƵĐƚƵƌĞ͘WƌĞƉƉĞĚƚŽůĂLJŽƵƚƌŽŽĨƐƚƌƵĐƚƵƌĞ;ĨůLJͿŽǀĞƌ ƌŝďƐƚŽŵŽƌƌŽǁ͘ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϵ͘ϴηEĂůďƌŝŶĞ ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ ϮϳϲΖ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ ^ƵŶŶLJ͕ůĞĂƌ^ŬŝĞƐ EŽƌƚŚtĞƐƚ ϳͲϭϬDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϭϭ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϭϳͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗ŽŽŶĞůĂŬĞŶĞLJ WŚŽŶĞη͗ϵϬϳͲϮϯϬͲϮϬϵϰ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ͲϮϬ Ͳϴ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϭϬ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϭϳͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϭϯͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ Ϭ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ ELJŵĂŶ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ůĞĂƌƌĞĞŬ <Θ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ ϳ͗ϬϬ ϭϵ͗ϬϬ ϭϮ͗ϬϬ ϭϮ͗ϬϬ ZĞŵĂƌŬƐ͗ dŽƚĂů,ŽƵƌƐ͗ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ tŽƌŬŽŶƌĐƚŝĐƚĞŶƚƐƚƌƵĐƚƵƌĞ͘ tŽƌŬŽŶƌĐƚŝĐƚĞŶƚƐƚƌƵĐƚƵƌĞ͘ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ tŽƌŬŽŶƌĐƚŝĐ^ƚƌƵĐƚƵƌĞ͘tŽƌŬŽŶůĂLJŝŶŐŽƵƚƚŚĞƌŽŽĨƐƚƌƵĐƚƵƌĞ;ĨůLJͿŽǀĞƌƌŝďƐ͘ŝĨĨŝĐƵůƚƚŽŵĂŶŝƉƵůĂƚĞƚŚĞƉůĂƐƚŝĐŝŶƚŚĞ ĐŽůĚƚĞŵƉĞƌĂƚƵƌĞƐ͘ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϵ͘ϴηEĂůďƌŝŶĞ ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ ϮϳϲΖ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ KǀĞƌĐĂƐƚƚŚĞŶ^ƵŶŶLJ EŽƌƚŚ ϵDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϭϮ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϭϴͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗ŽŽŶĞůĂŬĞŶĞLJ WŚŽŶĞη͗ϵϬϳͲϮϯϬͲϮϬϵϰ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ͲϮϰ Ͳϭϭ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϭϬ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϭϴͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϭϯͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ Ϭ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ ELJŵĂŶ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ůĞĂƌƌĞĞŬ <Θ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ ϳ͗ϬϬ ϭϵ͗ϬϬ ϭϮ͗ϬϬ ϭϮ͗ϬϬ ZĞŵĂƌŬƐ͗ dŽƚĂů,ŽƵƌƐ͗ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ tŽƌŬŽŶƌĐƚŝĐƚĞŶƚƐƚƌƵĐƚƵƌĞ͘ tŽƌŬŽŶƌĐƚŝĐƚĞŶƚƐƚƌƵĐƚƵƌĞ͘ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ tŽƌŬŽŶƌĐƚŝĐ^ƚƌƵĐƚƵƌĞ͘tŽƌŬŽŶůĂLJŝŶŐŽƵƚƚŚĞƌŽŽĨƐƚƌƵĐƚƵƌĞ;ĨůLJͿŽǀĞƌƌŝďƐ͘ŝĨĨŝĐƵůƚƚŽŵĂŶŝƉƵůĂƚĞƚŚĞƉůĂƐƚŝĐŝŶƚŚĞ ĐŽůĚƚĞŵƉĞƌĂƚƵƌĞƐ͘,ĂǀĞϭŽĨƚŚĞϯĨůLJŵŝĚĚůĞƐĞĐƚŝŽŶƐĐŽŵƉůĞƚĞĚ͘ZĞĂƌƉŽƌƚŝŽŶĂƚƚĂĐŚĞĚƚŽƚŚĞĨůLJ͘&ƌŽŶƚƉŽƌƚŝŽŶƐƚŝůů ŶĞĞĚƐƚŽďĞĂƚƚĂĐŚĞĚ͘ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϵ͘ϴηEĂůďƌŝŶĞ ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ ϮϳϲΖ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ ^ƵŶŶLJ͕ůĞĂƌ^ŬŝĞƐ EŽƌƚŚͲtĞƐƚ ϭϭͲϭϲDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϭϯ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϭϵͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗ŽŽŶĞůĂŬĞŶĞLJ WŚŽŶĞη͗ϵϬϳͲϮϯϬͲϮϬϵϰ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗Ͳϭϱ ϭ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϭϬ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϭϵͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϭϯͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ Ϭ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ ELJŵĂŶ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ůĞĂƌƌĞĞŬ <Θ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ ϳ͗ϬϬ ϭϵ͗ϬϬ ϭϮ͗ϬϬ ϭϮ͗ϬϬ ZĞŵĂƌŬƐ͗ dŽƚĂů,ŽƵƌƐ͗ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ tŽƌŬŽŶƌĐƚŝĐƚĞŶƚƐƚƌƵĐƚƵƌĞ͘ tŽƌŬŽŶƌĐƚŝĐƚĞŶƚƐƚƌƵĐƚƵƌĞ͘ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ tŽƌŬŽŶƌĐƚŝĐ^ƚƌƵĐƚƵƌĞ͘tŽƌŬŽŶůĂLJŝŶŐŽƵƚƚŚĞƌŽŽĨƐƚƌƵĐƚƵƌĞ;ĨůLJͿŽǀĞƌƌŝďƐ͘ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϵ͘ϴηEĂůďƌŝŶĞ ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ ϮϳϲΖ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ ^ƵŶŶLJ͕ůĞĂƌ^ŬŝĞƐ EŽƌƚŚͲtĞƐƚ ϵͲϭϲDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϭϰ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϮϬͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗ŽŽŶĞůĂŬĞŶĞLJ WŚŽŶĞη͗ϵϬϳͲϮϯϬͲϮϬϵϰ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϭϮϭ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϭϬ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϮϬͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϭϯͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ Ϭ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ ELJŵĂŶ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ůĞĂƌƌĞĞŬ <Θ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ ϳ͗ϬϬ ϭϵ͗ϬϬ ϭϮ͗ϬϬ ϭϮ͗ϬϬ ZĞŵĂƌŬƐ͗ dŽƚĂů,ŽƵƌƐ͗ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ tŽƌŬŽŶƌĐƚŝĐƚĞŶƚƐƚƌƵĐƚƵƌĞ͘ tŽƌŬŽŶƌĐƚŝĐƚĞŶƚƐƚƌƵĐƚƵƌĞ͘ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ tŽƌŬŽŶƌĐƚŝĐ^ƚƌƵĐƚƵƌĞ͘tŽƌŬŽŶůĂLJŝŶŐŽƵƚƚŚĞƌŽŽĨƐƚƌƵĐƚƵƌĞ;ĨůLJͿŽǀĞƌƌŝďƐ͘ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϵ͘ϴηEĂůďƌŝŶĞ ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ ϮϳϲΖ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ KǀĞƌĐĂƐƚƚŚĞŶ^ƵŶŶLJ EŽƌƚŚͲtĞƐƚ ϲͲϭϯDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϭϱ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϮϭͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗ŽŽŶĞůĂŬĞŶĞLJ WŚŽŶĞη͗ϵϬϳͲϮϯϬͲϮϬϵϰ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ͲϮ ϭϰ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϭϬ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϮϭͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϭϯͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ Ϭ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ ELJŵĂŶ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ůĞĂƌƌĞĞŬ <Θ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ ϳ͗ϬϬ ϭϮ͗ϬϬ ϱ͗ϬϬ ϭϮ͗ϬϬ ϮϬ͗ϬϬ ϴ͗ϬϬ ϮϬ͗ϬϬ Ϭ͗ϬϬ ϰ͗ϬϬ ϭϳ͗ϬϬ ZĞŵĂƌŬƐ͗ dŽƚĂů,ŽƵƌƐ͗ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ tŽƌŬŽŶƌĐƚŝĐƚĞŶƚƐƚƌƵĐƚƵƌĞ͘ tŽƌŬŽŶƌĐƚŝĐƚĞŶƚƐƚƌƵĐƚƵƌĞ͘ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ tŽƌŬŽŶƌĐƚŝĐ^ƚƌƵĐƚƵƌĞ͘^ƚĂƌƚŝŶĨůĂƚŝŽŶŽĨƚŚĞƌŝďƐĞĐƚŝŽŶƐĂŶĚƚŚĞĨƌŽŶƚĂŶĚƌĞĂƌ͘^ƚĂƌƚĞĚŝŶĨůĂƚŝŽŶĂƚϬϴ͗ϬϬ͘ &ŝŶŝƐŚĨŝŶĂůĐŚĞĐŬƐ͘ƚϬϳ͗ϯϬďĞŐŝŶƚŽŝŶĨůĂƚĞĐŽůƵŵŶƐ͘^ŝŵŽƉƐ͗ƐƚĂŐĞĂŶĚƐĞƚƵƉǁĂůŬĂƌŽƵŶĚƐ͘ůĞĂŶͬŽƌŐĂŶŝnjĞƚŽŽůĂŶĚ ƉĂƌƚƐĐŽŶĞdž͘ ŽŶƚŝŶƵĞ/ŶĨůĂƚŝŶŐdĞŶƚ͘^ŝŵŽƉƐ͗ŝŶƐƚĂůůƌŝŐŵĂƚŚŽůĚĚŽǁŶƉůĂƚĞƐ͘ƵŝůĚĞƋƵĂůŝnjĞƌŚŽƐĞƐ͘ŽŶƚŝŶƵĞƚŽƉƌĞƉůŽĂĚƐĨŽƌ ƌŝŐŐŝŶŐƵƉĞ>ŽƌĞĂŶƌŝŐ͘ ^ĞƚƐŶŽǁͬǁĂƚĞƌŝŶƉůĂĐĞƐŶĞĞĚĞĚŽŶƚŚĞƉĂĚĂƌŽƵŶĚƚŚĞĐĞůůĂƌĂƌĞĂĂŶĚƵŶĚĞƌƌŝŐŵĂƚƐ͘>ĞǀĞůŽƵƚǁŝƚŚĞƋƵŝƉŵĞŶƚ͘ ĞŐŝŶƚŽƐƚƌŝŶŐůŝŐŚƚŝŶƐŝĚĞƚŚĞWt W/͘ ^ƚŝůůŝŶĨůĂƚŝŶŐĂƚϬ͗ϬϬ͘EŽǁǁŽƌŬŝŶŐϮϰŚƌŽƉĞƌĂƚŝŽŶƐ͘ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϵ͘ϴηEĂůďƌŝŶĞ ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ ϮϳϲΖ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ DŽƐƚůLJůŽƵĚLJƚŚĞŶ^ƵŶŶLJ EŽƌƚŚͲtĞƐƚ ϳͲϭϮDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϭϲ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϮϮͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗ŽŽŶĞůĂŬĞŶĞLJ WŚŽŶĞη͗ϵϬϳͲϮϯϬͲϮϬϵϰ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϭϮϭ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϭϬ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϮϮͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϭϯͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ Ϭ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ ELJŵĂŶ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ůĞĂƌƌĞĞŬ <Θ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϲ͗ϬϬ ϲ͗ϬϬ ϲ͗ϬϬ ϭϮ͗ϬϬ ϲ͗ϬϬ ϭϮ͗ϬϬ ϭϴ͗ϬϬ ϲ͗ϬϬ ϭϴ͗ϬϬ Ϭ͗ϬϬ ϲ͗ϬϬ Ϯϰ ZĞŵĂƌŬƐ͗ dŽƚĂů,ŽƵƌƐ͗ ZŝŐƵƉĂŶĚƐĞƚƚĞŵƉŽƌĂƌLJƐƚĂŝƌƐ͕ƌŝŐĨůŽŽƌǁĂůŬĂƌŽƵŶĚƐ͕ƐƵďĨůŽŽƌ͕ ^/DKW^͗ŽŶƚŝŶƵĞƚŽƐƚĂŐĞƌŝŐĞƋƵŝƉŵĞŶƚŶĞĂƌWt W/ĨŽƌƐŵŽŽƚŚƚƌĂŶƐŝƚŝŽŶĨŽƌZͬh͘ ůĞĐƚƌŝĐŝĂŶŽŶƐŝƚĞĂƚϮϬ͗ϯϬŚƌƐ͘^Ğƚ ĞůĞĐƚƌŝĐŝĂŶƵƉƚŽǁŽƌŬŽŶƉŽǁĞƌƐLJƐƚĞŵĨŽƌƚŚĞƌŝŐ͘ZͬƵŬŶĞĞďƌĂĐĞƐĨƌŽŵũĂĐŬƐƚŽďĞĂŵƐ͘WŝŶďƌŝĚŐĞĐƌĂŶĞƌĂŝůƐŝŶƉůĂĐĞ ĂŶĚƐĞƚƵƉƚƌŽůůĞLJƐ͘ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ tŽƌŬŽŶƌĐƚŝĐƚĞŶƚƐƚƌƵĐƚƵƌĞ͘ tŽƌŬŽŶƌĐƚŝĐƚĞŶƚƐƚƌƵĐƚƵƌĞ͘ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ ,ĂŶŐůŝŐŚƚƐŝŶƐŝĚĞWt W/͘;ϱ,ƌƐͿĐŽŶƚŝŶƵĞƚŽƉƌĞƉĐĞůůĂƌĂŶĚƉĂĚǁŝƚŚƐŶŽǁĂŶĚǁĂƚĞƌ͘ DĂƌŬŽƵƚƚŝŵďĞƌĐƌĂĚůĞƉůĂĐĞŵĞŶƚ͘ hŶůŽĂĚϱϯΗĨůĂƚĨƌŽŵ>LJŶĚĞŶĐŽŶƚĂŝŶŝŶŐďŽƉĞĂŶĚƉŽǁĞƌƉĂĐŬ͘^ĞƚƚŝŵďĞƌĐƌĂĚůĞƐ͘ ^ĞĐƵƌĞƌĞĂƌƐĞĐƚŝŽŶŽĨĨůLJ͘WƌĞƉƐƵďƐƚƌƵĐƚƵƌĞĨŽƌƌŝŐƵƉ͘;ZĞŵŽǀĞŝĐĞƐĂŶĚƐŶŽǁĨƌŽŵďŽůƚŚŽůĞƐ͕ĂƚƚĂĐŚƌŝŐŐŝŶŐͿƐĞƚƵƉ ƚŽŽůƐŶĞĞĚĞĚĨŽƌƌŝŐƵƉŝŶƐŝĚĞƚŚĞWt W/͘ ^Ğƚ:ĂĐŬŝŶŐůĞŐƐŝŶƉůĂĐĞŽŶƚŝŵďĞƌĐƌĂĚůĞƐ͘^ĞƚĂŶĚƐĞĐƵƌĞďĞĂŵηϯ͘sĞƌŝĨLJǁĞůůĐĞŶƚĞƌŵĞĂƐƵƌĞŵĞŶƚƐ͘WƌŽĐĞĞĚƚŽƌŝŐ ƵƉƌĞŵĂŝŶŝŶŐƐĞĐƚŝŽŶƐŽĨƐƵďƐƚƌƵĐƚƵƌĞďĞĂŵƐ͘ϭ͕Ϯ͕ϰ͕ϱ͕ϲĂŶĚŽƵƚĞƌǁŝŶŐƐ͘ ^/DKW^͗ƐĞƚĞůĞĐƚƌŝĐĂůƉĂŶĞůƐŶĞĂƌƉƌŽƉĞƌůŽĐĂƚŝŽŶ͘^ĞƚĞůĞĐƚƌŝĐĂůĐĂďůĞƐ͕YƵĂĚĐŽďŽdžĞƐŝŶǁĂƌŵƵƉƐŚĂĐŬ͘hŶůŽĂĚŽŝů ĚƌƵŵƐĂŶĚƐĞƚKW ŶĞĂƌWt W/͘ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϵ͘ϴηEĂůďƌŝŶĞ ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ ϮϳϲΖ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ ^ƵŶŶLJ͕ůĞĂƌ^ŬŝĞƐ tĞƐƚ ϴͲϭϮDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϭϳ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϮϯͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭϱϱϲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬϭϬ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϭϬ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϮϯͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϭϯͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ Ϭ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ ELJŵĂŶ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ůĞĂƌƌĞĞŬ <Θ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϲ͗ϬϬ ϲ͗ϬϬ ϲ͗ϬϬ ϭϮ͗ϬϬ ϲ͗ϬϬ ϭϮ͗ϬϬ ϭϴ͗ϬϬ ϲ͗ϬϬ ϭϴ͗ϬϬ Ϭ͗ϬϬ ϲ͗ϬϬ Ϯϰ ZĞŵĂƌŬƐ͗ dŽƚĂů,ŽƵƌƐ͗ ^ĞƚĞƌƌŝĐŬŝŶƉůĂĐĞďĞŚŝŶĚƐƵďƐƚƌƵĐƚƵƌĞ͘&ŝŶŝƐŚƉůƵŵƉŝŶŐƌŝŐŚLJĚƌĂƵůŝĐƐ͘'ĞƚŚĞĂƚŽŶƌŝŐŚLJĚƌĂƵůŝĐƐĂŶĚŝŶƐƉĞĐƚ ŚŽƐĞƐͬĨŝƚƚŝŶŐƐ͘^ƉůŝŶĞĞůĞĐƚƌŝĐŵŽƚŽƌƚŽŐĞƚŚĞƌǁŝƚŚ,Wh͘ZĞŵŽǀĞƌŝŶŶĞƌĐĂďůĞƐďĞƚǁĞĞŶĐŽůƵŵŶƐŝŶƉƌĞƉĂƌĂƚŝŽŶƚŽƌĂŝƐĞ ĚĞƌƌŝĐŬ͘&ƵŶĐƚŝŽŶƚĞƐƚŚLJĚƌĂƵůŝĐƐ͕ŝŶƐƉĞĐƚĨŽƌůĞĂŬƐĂŶĚĂĚĚƌĞƐƐ͘ǁĂƌŵƵƉƌĂŝƐŝŶŐĐLJůŝŶĚĞƌƐ͕ĂůůŐŽŽĚ͘WŝŶƌĂŝƐŝŶŐĐLJůŝŶĚĞƌƐ ƚŽĨĞĞĚĨƌĂŵĞ͘ZĞŵŽǀĞĨůŽŽƌƉůĂƚĞƐƵŶĚĞƌĨĞĞĚĨƌĂŵĞ͕ƚĞƐƚƌƵŶƌĂŝƐŝŶŐĨĞĞĚĨƌĂŵĞ͘KďƐĞƌǀĞŚŽƐĞĨĂŝůƵƌĞ͘ƐŚƵƚĚŽǁŶƚŽ ƌĞƉůĂĐĞŚŽƐĞ͘ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ tŽƌŬŽŶƌĐƚŝĐƚĞŶƚƐƚƌƵĐƚƵƌĞ͘ tŽƌŬŽŶƌĐƚŝĐƚĞŶƚƐƚƌƵĐƚƵƌĞ͘ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ ^Ğƚ^ƚĂŶĚƉŝƉĞŵĂŶŝĨŽůĚ͕ƐĞƚĂŶĚƐĞĐƵƌĞƚƵŐŐĞƌǁŝŶĐŚ͕ƐĞƚĂŶĚƐĞĐƵƌĞĐŚŽŬĞŵĂŶŝĨŽůĚ͘^ĞƚĂŶĚƐĞĐƵƌĞĚƌĂǁǁŽƌŬƐ͘ DŽǀĞƉŽǁĞƌĚŝƐƚƌŝďƵƚŝŽŶƉĂŶĞůƐŝŶĚĞƐŝŐŶĂƚĞĚƐƉŽƚƐŝŶƐŝĚĞͬŽƵƚƐŝĚĞŽĨWt W/͘ DĂŬĞĂǁŝŶĚďůŽĐŬĂƌŽƵŶĚϭϱΖĚŽŽƌŽƉĞŶŝŶŐ͘tŽƌŬŽŶƐŝĚĞŵĂŶĚŽŽƌƐĂŶĚƌŽƵƚĞŚĞĂƚĞƌƐĨŽƌǁĂƌŵŝŶŐƵƉŝŶƐŝĚĞWt W/͘ 'ĞƚŚĞĂƚŽŶ'ĞŶĞƌĂƚŽƌ͕ŝŶƐƚĂůůĞdžŚĂƵƐƚƐƚĂĐŬ͕ĐŽŶƚŝŶƵĞǁŽƌŬŝŶŐŽŶƉŽǁĞƌĚŝƐƚƌŝďƵƚŝŽŶĐŽŶŶĞĐƚŝŽŶƐ͘^ĞƚĚĂǀŝƚƉŽƐƚŝŶ ƉůĂĐĞ͕ƐĞƚĚĂǀĞƚƚƌŽůůLJŝŶƉůĂĐĞ͘ ZŝŐƵƉƐĐŽƌƉŝŽŶƚŽŶŐƐ͘^ĞƚĨĞĞĚĨƌĂŵĞŝŶƉůĂĐĞĂŶĚƐĞĐƵƌĞƚŽĚƌĂǁǁŽƌŬƐƐŬŝĚ͘/ŶƐƚĂůůƌŽƚĂƚŝŶŐŚĞĂĚ͘'ĞƚƉŽǁĞƌŐŽŝŶŐ ĨŽƌƚŚĞĞ>ŽƌĞĂŶ͘&ƵŶĐƚŝŽŶƚĞƐƚƉŽǁĞƌĚŝƐƚƌŝďƵƚŝŽŶƉĂŶĞůƐĂŶĚĞůĞĐƚƌŝĐŵŽƚŽƌ͘^Ğƚ<ŽŽŵLJŝŶƐŝĚĞWt W/ĂŶĚǁĂƌŵƵƉ ǁŝƚŚŚĞĂƚĞƌƐ͘ƌŝŶŐĚĞƌƌŝĐŬŝŶƚŽWǁĞƉŝ͘ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϵ͘ϴηEĂůďƌŝŶĞ ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ ϮϳϲΖ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϭϴ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϮϰͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬϭϬ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϭϭ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϮϰͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϭϯͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ Ϭ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ ELJŵĂŶ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ůĞĂƌƌĞĞŬ <Θ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϲ͗ϬϬ ϲ͗ϬϬ ϲ͗ϬϬ ϭϮ͗ϬϬ ϲ͗ϬϬ ϭϮ͗ϬϬ ϭϴ͗ϬϬ ϲ͗ϬϬ ϭϴ͗ϬϬ Ϭ͗ϬϬ ϲ͗ϬϬ Ϯϰ ZĞŵĂƌŬƐ͗ ϮϳϲΖ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ϵ͘ϴηEĂůďƌŝŶĞ ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ tŽƌŬŽŶĐŽǀĞƌŝŶŐƵƉĚĞƌƌŝĐŬƌĂŝƐŝŶŐƐƉůŝƚ͘,ŽŽŬĐŽůƵŵŶĐĂďůĞƐďĂĐŬƚŽŐĞƚŚĞƌĂŶĚŝŶĨůĂƚĞĐŽůƵŵŶ͘ dƌŽƵďůĞƐŚŽŽƚũĂĐŬŝŶŐŚLJĚƌĂƵůŝĐƐ͘ŽŶƚŝŶƵĞƚŽƌŝŐƵƉŵŝƐĐ͘ŚŝŐŚƉƐŝŚŽƐĞƐ͘,LJĚƌĂƵůŝĐ:ĂĐŬƐƵŶĂďůĞƚŽƐĐŽƉĞŽƵƚ͘ϭŽĨϰ ũĂĐŬƐĐƵƌƌĞŶƚůLJǁŽƌŬŝŶŐ͘ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ ZĂŝƐĞĞƌƌŝĐŬ^ĞƚƉŝƚƐ ZĂŝƐĞ^ƵďEŝƉƉůĞƵƉKWƐ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ ŽŶƚŝŶƵĞƚŽƉƌĞƉƚŚĞĨůLJĨŽƌƌĂŝƐŝŶŐƚŚĞĚĞƌƌŝĐŬ͘^ĞƚƉŝƚĂůŝŐŶŵĞŶƚĨƌĂŵĞŝŶƉůĂĐĞ͘^ĞƚǁĂƚĞƌƚĂŶŬƉŝƚ͘,ŽŽŬƵƉĐŚŽŬĞĂŶĚ ŬŝůůůŝŶĞ͘,ŽŽŬƵƉƐƚĂŶĚƉŝƉĞŚŽƐĞĂŶĚĨůĂƌĞůŝŶĞŚŽƐĞ͘ ^ĞƚŚŽƉƉĞƌƉŝƚ͕ŐĂƐďƵƐƚĞƌƉŝƚ͕ĂŶĚƐŚĂŬĞƌƉŝƚ͘,ŽŽŬƵƉŝŶŶĞƌĐŽŶŶĞĐƚƐ͘ /ŶƐƉĞĐƚ,Wh͘&ƵŶĐƚŝŽŶƚĞƐƚĐLJůŝŶĚĞƌƐĂŶĚƌĞͲƚŝŵĞƚŚĞŵ͘WŝŶĨĞĞĚĨƌĂŵĞƚŽĐLJůŝŶĚĞƌƐ͘ZŝŐƵƉĂŶĚƐĞƚĚŽƵďůĞĚĞƌƌŝĐŬŝŶ ƉůĂĐĞǁŝƚŚĨĞĞĚĨƌĂŵĞ͕ďŽůƚĂŶĚƐĞĐƵƌĞ͘ ZĂŝƐĞĚĞƌƌŝĐŬͲϭϱ͗ϬϬŚŽƵƌƐ͕ĚĞƌƌŝĐŬƵƉ͕ƐĞĐƵƌĞĚĞƌƌŝĐŬ͕ƐĞƚďĂĐŬďƌĂĐĞƐŝŶƉůĂĐĞĂŶĚƉŝŶ͘^ĂĨĞŽƵƚƌŝŐĨůŽŽƌĂŶĚƉƵƚ ůĂŶĚŝŶŐďĂĐŬŝŶƉůĂĐĞ͘ĐŽŶƚŝŶƵĞƚŽƌŝŐƵƉƉŝƚƐ͕YƵĂĚĐŽŽŶůŽĐĂƚŝŽŶƐĞƚƚŝŶŐƵƉĞƋƵŝƉŵĞŶƚ͘ dŽƚĂů,ŽƵƌƐ͗ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϭϵ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϮϱͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬϭϬ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϭϮ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϮϱͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϭϯͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ Ϭ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ ELJŵĂŶ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ůĞĂƌƌĞĞŬ <Θ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϲ͗ϬϬ ϲ͗ϬϬ ϲ͗ϬϬ ϭϮ͗ϬϬ ϲ͗ϬϬ ϭϮ͗ϬϬ ϭϴ͗ϬϬ ϲ͗ϬϬ ϭϴ͗ϬϬ Ϭ͗ϬϬ ϲ͗ϬϬ Ϯϰ ZĞŵĂƌŬƐ͗ ϮϳϲΖ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ϵ͘ϴηEĂůďƌŝŶĞ ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ /ŶƐƚĂůůĨůŽǁůŝŶĞĂŶĚĐĞŶƚƌŝĨƵŐĂůƉƵŵƉƐ͘DŽǀĞƉƵŵƉƐƚŽƉŽƐŝƚŝŽŶŶĞĂƌƌŝŐ͘ZĞŵŽǀĞϰΗƌĂŵƐĂŶĚ/ŶƐƚĂůůϯ͘ϱΗƌĂŵƐ͘Dͬh ĐƌŽƐƐŽǀĞƌƐƚŽƚĞƐƚƉůƵŐĂŶĚŵĞĂƐƵƌĞ͘ƌŝůůϭͬϮΗŚŽůĞŝŶďŽƚƚŽŵŽĨWƉĞƌŵĞĂƐƵƌĞŵĞŶƚŽĨƚĞƐƚƉůƵŐĨŽƌƵƐĞĂƐĂƚĞƐƚũŶƚ͘ DͬhĂŶĚƚŽƌƋƵĞϮd/t͕ĂƌƚĂŶĚWƵŵƉ/Ŷ^Ƶď͘tŽƌŬŽŶƐĐŽƌƉŝŽŶƚŽŶŐƐ͘WƵƚƵƉǀŝƐƋƵŝŶĞƚŽĐŽǀĞƌͬŚĞĂƚŚŽƐĞĂůůĞLJĂŶĚ ĐĞůůĂƌ͘DͬhĐŚŽŬĞĂŶĚŬŝůůůŝŶĞƐ͘ƌŽƵŐŚƚϮϱϬŐĂůŽĨǁĂƚĞƌŝŶƚŽĐĞůůĂƌĨŽƌKWƚĞƐƚ͘ZͬhĂůůĞƋƵŝƉŶĞĞĚĞĚĨŽƌKWƚĞƐƚ͘ ƵĞƚŽǁŝŶĚŚĂĚƚŽŝŶƐƚĂůůŶĞǁŚĞƌĐƵůŝƚĞƚŽĐŽǀĞƌĨƌŽŶƚĚŽŽƌ͘ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ ZĂŝƐĞ^ƵďĂŶĚƉŝŶ͕EŝƉƉůĞƵƉKWƐ͕ZŝŐƵƉĂĐĐƵŵĂůŽƌůŝŶĞƐ͕ZŝŐƵƉWsd &ŝŶŝƐŚƚĞƐƚŝŶŐ͕ƵŝůĚďƌŝŶĞ͕ZŝŐƵƉŵƵĚƉƵŵƉƐ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ ^ĞĂůƵƉŽƉĞŶŚŽůĞƐŝŶWt W/͘tŝŶĚƉŝĐŬĞĚƵƉ͕ƚŽŽŬƚŚĞŶĞĐĞƐƐĂƌLJƚŝŵĞƚŽĂĚĚƌĞƐƐŐĂƌĂŐĞĚŽŽƌŽƉĞŶŝŶŐƐ͕ĚĞƌƌŝĐŬĨůLJ ŽƉĞŶŝŶŐĂŶĚĐŽŶƚĂŝŶƚŚĞWt W/͘ ŽŶƚŝŶƵĞƚŽǁĂƌŵƵƉƌŝŐũĂĐŬŝŶŐŚLJĚƌĂƵůŝĐƐLJƐƚĞŵĂŶĚƚƌŽƵďůĞƐŚŽŽƚ͘ ŽŶƚŝŶƵĞƚŽƉĂƚĐŚĂŶĚĐůŽƐĞŽĨĨĚĞƌƌŝĐŬƌĂŝƐŝŶŐŽƉĞŶŝŶŐ͘tŽƌŬŽŶŚLJĚƌĂƵůŝĐƐLJƐƚĞŵ͘YƵĂĚĐŽƌŝŐŐŝŶŐƵƉƉǀƚƐLJƐƚĞŵ͘ dĞƐƚƌŝŐũĂĐŬŝŶŐƐLJƐƚĞŵ͘ZĂŝƐĞƐƵďƐƚƌƵĐƚƵƌĞƚŽƉƌŽƉĞƌŚĞŝŐŚƚĂŶĚƉŝŶŝŶƉůĂĐĞĂƚϭϰ͗ϯϬ͘ƐƉŽŽůƚƵŐŐĞƌůŝŶĞǁŝŶĐŚ͕ƐƉŽŽů ĚƌĂǁǁŽƌŬƐǁŝŶĐŚ͘ZĞŵŽǀĞƚƵďŝŶŐŚĂŶŐĞƌ͘ZŝŐƵƉ^ƌŝŐĨůŽŽƌƐƚĂŝƌƐ͘EŝƉƉůĞƵƉKWŽŶǁĞůůŚĞĂĚ͘ZŝŐƵƉůĂŶĚŝŶŐĂŶĚ ƐƚĂŝƌƐĨƌŽŵƉŝƚƐƚŽƌŝŐĨůŽŽƌ͘^Ğƚ<ŽŽŵĞLJŝŶƉůĂĐĞĂŶĚƌƵŶŚŽƐĞƐ͘^ĞƚƚĞƐƚƉƵŵƉŝŶƉůĂĐĞ͘ dŽƚĂů,ŽƵƌƐ͗ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϮϬ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϮϲͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬϭϬ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϭϯ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϮϲͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϭϯͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ Ϭ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ ELJŵĂŶ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ůĞĂƌƌĞĞŬ <Θ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϲ͗ϬϬ͗ϬϬ ϲ͗ϬϬ ϲ͗ϬϬ ϭϮ͗ϬϬ ϲ͗ϬϬ ϭϮ͗ϬϬ ϭϴ͗ϬϬ ϲ͗ϬϬ ϭϴ͗ϬϬ Ϭ͗ϬϬ ϲ͗ϬϬ Ϯϰ ZĞŵĂƌŬƐ͗ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ EŽŶĞ<ŶŽǁŶ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ϮϳϲΖ ϵ͘ϴηEĂůďƌŝŶĞ ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ ƵŝůĚƌŝŶĞ͕^ƚĂƌƚǁĂƐŚŽǀĞƌŽƉĞƌĂƚŝŽŶƐ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ ,ĞĂƚƵƉKW^ĂŶĚŚŽŬĞŵĂŶŝĨŽůĚ͕dĞƐƚKWƐ͕&ŝŶŝƐŚƌŝŐŐŝŶŐƵƉ dŽƚĂů,ŽƵƌƐ͗ DŝdžƵƉƌŝŶĞƚŽĂŶϭϭ͘ϮƉƉŐĂů͕ĐŽŶƚŝŶƵĞƚŽŽƌŐĂŶŝnjĞŝŶƐŝĚĞ^ƚƌƵĐƚƵƌĞ͘ŽŶƚŝŶƵĞǁŽƌŬƚŽŝŶƐƚĂůůƚĞŵƉĚŽŽƌƐŽŶ ƐƚƌƵĐƚƵƌĞ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ dĂƌƉŝŶ^ƵďƐƚƌƵĐƚƵƌĞ,ĞĂƚƵƉKW^͕,ĞĂƚƵƉĐŚŽŬĞŵĂŶŝĨŽůĚ͕ŽŶƚŚŽŽŬƵƉĐĐƵŵƵůĂƚŽƌůŝŶĞƐ͘ZŝŐƵƉƚĞƐƚƉƵŵƉ͕ ƐĞĐƵƌĞǀŝƐƋƵĞĞŶĂƌŽƵŶĚĐĞůůĂƌĂŶĚĐŚŽŬĞŵĂŶŝĨŽůĚ͕ŽŶƚŝŶƵĞƌŝŐƵƉƉŝƚĂŶĚƉǀƚƐLJƐƚĞŵ͕ƚĞƐƚŐĂƐĚĞƚĞĐƚŽƌƐ DĂŬĞƵƉϯϭͬϮΖΖƚĞƐƚũŽŝŶƚĂŶĚĐƌŽƐƐŽǀĞƌƚŽƚŚĞƚĞƐƚƉůƵŐ͕ƐĞƚƚĞƐƚƉůƵŐ͕&ŝůůKW ǁŝƚŚǁĂƚĞƌĂŶĚƉƌĞĨŽƌŵďŽĚLJƚĞƐƚ͘ƚ ϭϬ͗ϰϱĂŵďĞŐŝŶƚĞƐƚηϭŽĨKW ƚĞƐƚƐĞƋƵĞŶĐĞ͘dĞƐƚKWƐϮϱϬƉƐŝĂŶĚϭϱϬϬƉƐŝǁŝƚŚ>DƌĞƉ:ĂŬĞ&ƵůŬĞƌƐŽŶǁŝƚŶĞƐƐƚĞƐƚ͘ ŽŶƚŝŶƵĞƚŽƚĞƐƚKW ͘ϮϱϬƉƐŝůŽǁͬϭϱϬϬƉƐŝŚŝŐŚ͕ϱŵŝŶĞĂĐŚ͘dĞƐƚĂůůĐŚŽŬĞǀĂůǀĞƐ͕ϭͲϵ͕ŵĂŶƵĂůĐŚŽŬĞΘ͕ϯ͘ϱΗ ƌĂŵƐ͕ŶŶƵůĂƌ͕ůŝŶĚƌĂŵƐ͕,ZĐŚŽŬĞ͕DĂŶ͘ŚŽŬĞŽŶƐƚĂĐŬ͕/ŶŶĞƌŬŝůů͘dŝtdžϮ͕ĂŶĚĂƌƚǀĂůǀĞ͘ZŝŐĚŽǁŶKW ƚĞƐƚŝŶŐ ĞƋƵŝƉŵĞŶƚĂŶĚďůŽǁĚŽǁŶ͘ŽŶƚŝŶƵĞƚŽĨŝŶŝƐŚƉŝƚƉůƵŵďŝŶŐĂŶĚďĞƌĞĂĚLJƚŽƚĂŬĞŽŶϲϬďďůƐŽĨĨƌĞƐŚǁĂƚĞƌ͘ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗Ϯϭ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϮϳͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬϭϬ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϭϰ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϮϳͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϭϯͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ ϭ͕Ϯ dDϯϬ ϯWD ϭ͕ϮϬϬ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ ϭϭ ϭϭϬ ϭϭϬ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ ϭϲ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ LJŶĂŵŝĐ Ϯ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ůĞĂƌƌĞĞŬ <Θ ϭϯ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϲ͗ϬϬ͗ϬϬ ϲ͗ϬϬ ϲ͗ϬϬ ϭϮ͗ϬϬ ϲ͗ϬϬ ϭϮ͗ϬϬ ϭϴ͗ϬϬ ϲ͗ϬϬ ϭϴ͗ϬϬ Ϭ͗ϬϬ ϲ͗ϬϬ Ϯϰ ZĞŵĂƌŬƐ͗ dŽƚĂů,ŽƵƌƐ͗ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ DŝdžϲϬďďůƐŽĨϭϭ͘ϮƉƉŐďŝŶĞ͘WhŚĂŶĚůŝŶŐĞƋƵŝƉŵĞŶƚƚŽƚŚĞƌŝŐĨůŽŽƌ͘^ĞƚƵƉĐĂƚǁĂůŬ͕ƐůŝĚĞ͕ĂŶĚƉŝƉĞƌĂĐŬƐ͘^ĞƚĚƌŝůů ƉŝƉĞĂŶĚǁĂƐŚƉŝƉĞŽŶƉŝƉĞƌĂĐŬƐ͘ZŝŐƵƉŚĂƌĚůŝŶĞĨƌŽŵƚŚĞĐŚŽŬĞŵĂŶŝĨŽůĚŽƵƚƐŝĚĞƚŽƚŚĞǀĞŶƚŝŶŐƚĂŶŬ͕ϭϬϬΖƉĂƐƚ ŝŐŶŝƚŝŽŶƐŽƵƌĐĞƐ͘dĞƐƚŐĂƐĂůĂƌŵƐǁŝƚŚŵĞƚŚĂŶĞ͘ ŽŶƚŝŶƵĞƚŽŵŝdžϭϭ͘ϮƉƉŐďƌŝŶĞ͘^ĞƚƵƉĂŶĚƉŝŶĚĞƌƌŝĐŬďƌĂĐĞƐ͘,h,WhĐŽŽůĞƌ͕ŚŽŽŬƵƉůƵďĞĐŽŽůŝŶŐƉƵŵƉĨŽƌƌŽƚĂƚŝŶŐ ŚĞĂĚ͘ƌĂŝŶŽŝůŽƵƚŽĨ,Wh͘ŚĂŶŐĞĨŝůƚĞƌƐĂŶĚĐůĞĂŶƐƵĐƚŝŽŶƐĐƌĞĞŶƐŽŶ,Wh͘&ŝůůǁŝƚŚŶĞǁŽŝůďĞŝŶŐƉƵŵƉĞĚƚŚƌŽƵŐŚ ƚŚĞĨŝůƚĞƌĐĂƌƚ͘ ůŽǁĚŽǁŶŐĂƐǀĞŶƚŝŶŐĨůŽǁƉĂƚŚĨƌŽŵƚŚĞƌŝŐ͕ƚŚƌŽƵŐŚƚŚĞĐŚŽŬĞĂŶĚŽƵƚƚŽƚŚĞǀĞŶƚƚĂŶŬ͘/ŶƐƉĞĐƚĂůůĐŽŶŶĞĐƚŝŽŶƐ͘ WůƵŐͬĐĂƉĂŶLJŽƉĞŶŽƵƚůĞƚƐŽŶƚŚĞĐŝƌĐƵůĂƚŝŶŐƐLJƐƚĞŵŶŽƚďĞŝŶŐƵƐĞĚ͘&ŝůůƌŽƚĂƚŝŶŐŚĞĂĚǁŝƚŚŐĞĂƌŽŝů͘,ŽŽŬƵƉŚŽƐĞƐĂŶĚ ƌŽƚĂƚŝŶŐŚĞĂĚ͘WƵůůďŽƉƐƚĂĐŬĐĞŶƚĞƌŽǀĞƌǁĞůů͘,ŽŽŬƵƉƉŽƉŽĨĨůŝŶĞƐĨƌŽŵŵƵĚƉƵŵƉƐƚŽƚŚĞƉŝƚƐĂŶĚƐĞĐƵƌĞ͘dŝĞŽĨĨ KWƐƚŽƐƵď DŝdžƵƉϱϬďďůƐŵŽƌĞďƌŝŶĞ͕dĞƐƚĐŝƌĐƵůĂƚŝŶŐƐLJƐƚĞŵ͕ĨŝůůŚŽůĞ͘ /ŶƐƉĞĐƚĂŶĚƚĞƐƚƌŽƚĂƚŝŶŐŚĞĂĚĨƵŶĐƚŝŽŶƐ͘ŚĂŶŐĞƌŽƚĂƚŝŶŐŚĞĂĚĚŝĞƐ͕ƐĞƚƐĐŽƌƉŝŽŶƚŽŶŐƐƵƉĨŽƌϱϯͬϰΗǁĂƐŚƉŝƉĞ͘ /ŶƐƉĞĐƚďĂŬĞƌƚŽŽůƐ͘&ŝŶŝƐŚŚŽŽŬŝŶŐƵƉŐƌŽƵŶĚĐĂďůĞƐĨŽƌƚŚĞƌŝŐ͘ůĞĂŶĂŶĚĐůĞĂƌĨůŽŽƌŝŶƉƌĞƉĂƌĂƚŝŽŶĨŽƌŵĂŬŝŶŐƵƉ ƚŽŽůƐ͕ĞůŝŵŝŶĂƚĞƚƌŝƉŚĂnjĂƌĚƐ͘ŽŶƚŝŶƵĞƚŽƚĂƌƉŽĨĨĂƌĞĂƐĂŶĚďƵŝůĚŚŽŽƚĐŚĞƐĨŽƌƉŝƚƐͬƉůƵŵďŝŶŐƚŽĂǀŽŝĚĨƌĞĞnjŝŶŐůŝŶĞƐ͘ tĂƐŚŽǀĞƌϮϳͬϴΖΖƚƵďŝŶŐ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϭ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ ƵŝůĚďƌŝŶĞ͕ĨŝŶŝƐŚƌŝŐŐŝŶŐƵƉ͕ƚĞƐƚŽƵƚĂůůƐLJƐƚĞŵƐ͕&ŝůůŚŽůĞ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ < ZZ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ <> ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ EŽŶĞ<ŶŽǁŶ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ϮϳϲΖ ϵ͘ϴηEĂůďƌŝŶĞ ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϮϮ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϮϴͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬϭϬ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϭϱ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϮϴͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϭϯͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ ϭ͕Ϯ dDϯϬ ϯWD ϭ͕ϮϬϬ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ ϭϭ ϭϭϳ ϭϭϳ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ Ϯϱ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ LJŶĂŵŝĐ Ϯ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ϭ ůĞĂƌƌĞĞŬ <Θ ϭϯ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϳ͗ϬϬ͗ϬϬ ϳ͗ϬϬ ϳ͗ϬϬ ϭϮ͗ϬϬ ϱ͗ϬϬ ϭϮ͗ϬϬ ϭϱ͗ϬϬ ϯ͗ϬϬ ϭϱ͗ϬϬ ϮϬ͗ϬϬ ϱ͗ϬϬ ϮϬ͗ϬϬ Ϭ͗ϬϬ ϰ͗ϬϬ Ϯϰ ZĞŵĂƌŬƐ͗ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ EŽŶĞ<ŶŽǁŶ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ϮϳϲΖ ϭϭη<> ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ < ZZ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ <> ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ ŽŶƚŝŶƵĞǁĂƐŚŽǀĞƌϮϳͬϴΖΖƚďŐ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϴ ϭ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ DĂŬĞƵƉǁĂƐŚŽǀĞƌĂƐƐĞŵďůLJ͕ƌĞĂŬĐŝƌĐƵůĂƚŝŽŶ͕ǁĂƐŚĚŽǁŶϭϮΖ dŽƚĂů,ŽƵƌƐ͗ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ DĂŬĞƵƉϱϯͬϰΗǁĂƐŚŽǀĞƌƉŝƉĞĂƐƉĞƌďĂŬĞƌƌĞƉ͘DĂŬĞƵƉŬĞůůLJŚŽƐĞ͕ůŝŶĞƵƉƚŽĐŝƌĐƵůĂƚĞ͘dĂŐϮͲϳͬϴΗƚƵďŝŶŐƐƚƵďĂƚ ϭϱΖ͘&ŝůůWŝƉĞĂŶĚƚĞƐƚĐŝƌĐƵůĂƚŝŶŐĞƋƵŝƉŵĞŶƚǁŝƚŚϭϭ͘ϮWW'Ăů͘ ƐƚĂďůŝƐŚƉĂƌĂŵĞƚĞƌƐĂƚϰϮ'WD͕ϮϬWƐŝ͕ϳйƌĞƚƵƌŶ ĨůŽǁ͘ ƌĞĂŬĐŝƌĐƵůĂƚŝŽŶ͕tĂƐŚĚŽǁŶϭϮΖ͕ŝƌĐƵůĂƚĞĂƚϭďƉŵϯϬƉƐŝ͕ϭϬϬZWD͕EŽĨůƵŝĚůŽƐƐ͘ DŝůůĨƌŽŵϭϱΖZ<ƚŽϮϳΖZ<ĂƚϭϬϬZWD͕ϰϮ'WD͕ϰϬͲϮϬϬW^/͕ϯϬйƌĞƚƵƌŶĨůŽǁ͘^ŝŵŽƉƐ͗ďƌŝŶŐƌĞŵĂŝŶŝŶŐũŽŝŶƚƐŽĨ ǁĂƐŚƉŝƉĞŝŶƐŝĚĞĂŶĚƐĞƚŽŶĐĂƚǁĂůŬ͘;ϳƚƚůũŽŝŶƚƐͿ͘^ĞƚĂďƵŶĚůĞŽĨϯ͘ϱΗWŽŶĐĂƚǁĂůŬ͘tŽƌŬŽŶƐĞĂůŝŶŐƵƉŐĂƌĂŐĞ ĚŽŽƌƐ͘ƚϭϭ͗ϯϬĂŵ͕ƉŽŽŚ&ͬϮϳΖƚŽƐƵƌĨĂĐĞĂŶĚůĂLJĚŽǁŶǁĂƐŚŽǀĞƌĂƐƐĞŵďůLJ͘ ZŝŐƵƉƚŽƚĞƐƚKW ͘DĂŬĞƵƉĨůŽŽƌǀĂůǀĞƐ͕ƌŝŐƵƉƚĞƐƚƉƵŵƉĂŶĚƚĞƐƚŚŽƐĞƐ͘>ŝŶĞƵƉƚĞƐƚŝŶŐĞƋƵŝƉŵĞŶƚĂŶĚĨŝůů͘ ZͬhĞƋƵŝƉ͘ƚŽWͬhĂŬĞƌ,͘Dͬh,ƉĞƌĂŬĞƌZĞƉĂĚĚŝŶŐϵΖŽĨŶĞǁǁĂƐŚƉŝƉĞ͘ƌĞĂŬĐŝƌĐ͘Z/,ƚͬϮϳΖΛϮϯϬϬDŝůů &ͬϮϳΖdͬϯϯΖZWDсϭϮϬ'WDсϱϰΛϭϬϬͲϮϬϬW^/͘ ZĞͲƚĞƐƚKW ͘dĞƐƚĐŚŽŬĞǀĂůǀĞƐϭͲϵ͕ƚĞƐƚd/tĂŶĚĂƌƚǀĂůǀĞ͕dĞƐƚĂŶŶƵůĂƌǁŝƚŚϯ͘ϱΗƚĞƐƚũŽŝŶƚ͘dĞƐƚϯ͘ϱΗWŝƉĞƌĂŵƐ͘dĞƐƚ /ŶŶĞƌ͕ŽƵƚĞƌĂŶĚƌŝŐĨůŽŽƌŬŝůůůŝŶĞ͘WĞƌĨŽƌŵŬŽŽŵLJĚƌĂǁĚŽǁŶ͘dĞƐƚϮϱϬƉƐŝůŽǁͬϱŵŝŶ͕ϭϱϬϬƉƐŝŚŝŐŚĨŽƌϱŵŝŶ͘dĞƐƚ ǁŝƚŶĞƐƐĞĚďLJ>DƌĞƉƌĞƐĞŶƚĂƚŝǀĞYƵŝŶŶ^ĂǁLJĞƌ͘ZŝŐĚŽǁŶƚĞƐƚŝŶŐĞƋƵŝƉŵĞŶƚĂŶĚďůŽǁĚŽǁŶůŝŶĞƐ͘ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗Ϯϯ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϮϵͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬϭϬ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϭϲ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϮϵͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϭϯͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ ϭ͕Ϯ dDϯϬ ϯWD ϭ͕ϮϬϬ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ ϭϭ ϭϭϳ ϭϭϳ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ Ϯϱ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ LJŶĂŵŝĐ Ϯ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ϭ ůĞĂƌƌĞĞŬ <Θ ϭϯ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϲ͗ϬϬ͗ϬϬ ϲ͗ϬϬ ϲ͗ϬϬ ϭϭ͗ϯϬ͗ϬϬ ϱ͗ϯϬ ϭϭ͗ϯϬ ϭϮ͗ϯϬ͗ϬϬ ϭ͗ϬϬ ϭϮ͗ϯϬ ϭϯ͗ϯϬ ϭ͗ϬϬ ϭϯ͗ϯϬ ϭϰ͗ϯϬ ϭ͗ϬϬ ϭϰ͗ϯϬ ϭϲ͗ϯϬ Ϯ͗ϬϬ ϭϲ͗ϯϬ ϮϬ͗ϯϬ ϰ͗ϬϬ ϮϬ͗ϯϬ Ϯϭ͗ϯϬ ϭ͗ϬϬ Ϯϭ͗ϯϬ Ϭ͗ϬϬ Ϯ͗ϯϬ Ϯϰ ZĞŵĂƌŬƐ͗ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ EŽŶĞ<ŶŽǁŶ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ϮϳϲΖ ϭϭη<> ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ < ZZ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ <> ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ ŽŶƚŝŶƵĞǁĂƐŚŽǀĞƌϮϳͬϴΖΖƚďŐ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϴ ϭ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ tĂƐŚŽǀĞƌϮϳͬϴΖΖƚŽϲϰΖ͕ƚƚĞŵƉƚƚŽĐƵƚƚƵďŝŶŐ dŽƚĂů,ŽƵƌƐ͗ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ DŝůůĐĞŵĞŶƚĂŶĚǁĂƐŚŽǀĞƌϮͲϳͬϴΗƚďŐĨƌŽŵϮϳΖƚŽϱϰΖ͘ϱϬϬůďƐtK͕ϭϱϬϬĨƚͬůďƐŽĨƚƋ͕ϰϴ'WD͕ϰϬͲϲϬƉƐŝ͘ϭϬϬZWD͘ >ĂLJĚŽǁŶǁĂƐŚŽǀĞƌ,ĂƐƉĞƌĂŬĞƌƌĞƉͬ͘ĚĐŚŽŬĞůŝŶĞƚŽƚŝŐĞƌƚĂŶŬ͘/ŶƐƚĂůůǁĞŝŐŚƚŝŶĚŝĐĂƚŽƌǁŚŝůĞďůŽǁŝŶŐĚŽǁŶ ůŝŶĞƐ͘ Z/,ǁŝƚŚĐƵƚƚĞƌĂŶĚůŽĐĂƚĞĐŽůůĂƌŽŶƚŚĞϮͲϳͬϴƚďŐ͘&ƌĞĞƉŝĐŬƵƉǁƚсϭϮϬϬůďƐ͕ƉƵůůƵƉƚŽϰϱϬϬůďƐƚŽǀĞƌŝĨLJĐƵƚƚĞƌƐĂƌĞ ŽƵƚďĞůŽǁƚŚĞƚďŐĐŽůůĂƌ͘tŝƚŚĐƵƚƚĞƌĂƚϰϬ͘ϱΖ͗ZŽƚĂƚĞƉŝƉĞΛϴϬZWD͕ϮϬϬϬĨƚͬďůƐĂŶĚƐůŽǁůLJƉŝĐŬƵƉĂƐƉĞƌĂŬĞƌƌĞƉ͘ WKK,ƚŽǀĞƌŝĨLJƚƵďŝŶŐŝƐĐƵƚ͘ dƌŽƵďůĞƐŚŽŽƚŚLJĚƌĂƵůŝĐƐ͘EŽƚƌĞĐĞŝǀŝŶŐĞŶŽƵŐŚƉƌĞƐƐƵƌĞƚŽƚŽƌƋƵĞŽǀĞƌƐŚŽƚƚŽƐƉĞĐƐ͘ DŝůůĐĞŵĞŶƚĂŶĚǁĂƐŚŽǀĞƌϮͲϳͬϴΗƚďŐĨƌŽŵϱϰΖƚŽϲϰΖ͘ϱϬϬůďƐtK͕ϭϱϬϬĨƚͬůďƐŽĨƚƋ͕ϰϴ'WD͕ϰϬͲϲϬƉƐŝ͘ϭϬϬZWD͘ WKK,ĨƌŽŵϲϰΖƚŽƐƵƌĨĂĐĞͬ͘ĚĚŽǁŶŬĞůůLJŚŽƐĞ͘ DĂŬĞƵƉƵƚƚŝŶŐ,ǁŝƚŚŬŶŝĨĞƐƚLJůĞĐƵƚƚĞƌƉĞƌĂŬĞƌƌĞƉ͘ WKK,͕ŽďƐĞƌǀĞĚŶŽϮͲϳͬϴΗƚďŐ͘ƵƚƚĞƌƐƐƚŝůůŝŶƚĂĐƚ͕,ůŽŽŬĞĚŶŽƌŵĂů͘ŚĂŶŐĞŽƵƚ,ůĞŶŐƚŚƚŽϰϰ͘ϯϮΖZ/,ƚŽĂƚƚĞŵƉƚ ĂŐĂŝŶ͘KďƐĞƌǀĞĚƚŚĞƐĂŵĞŽƵƚĐŽŵĞ͘ ƌĞƐƐŽǀĞƌƐŚŽƚĂŶĚWͬh,ĨŽƌďůŝŶĚďƌĞĂŬŽƵƚ͘ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗Ϯϯ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϯϬͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬϭϬ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϭϳ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϯϬͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϭϯͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ ϭ͕Ϯ dDϯϬ ϯWD ϭ͕ϮϬϬ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ ϭϭ ϭϭϳ ϭϭϳ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ Ϯϱ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ LJŶĂŵŝĐ Ϯ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ϭ ůĞĂƌƌĞĞŬ <Θ ϭϯ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϭ͗ϯϬ͗ϬϬ ϭ͗ϯϬ ϭ͗ϯϬ ϯ͗ϬϬ ϭ͗ϯϬ ϯ͗ϬϬ ϲ͗ϬϬ ϯ͗ϬϬ ϲ͗ϬϬ ϵ͗ϬϬ ϯ͗ϬϬ ϵ͗ϬϬ ϭϭ͗ϬϬ Ϯ͗ϬϬ ϭϭ͗ϬϬ ϭϮ͗ϬϬ ϭ͗ϬϬ ϭϮ͗ϬϬ ϭϴ͗ϬϬ ϲ͗ϬϬ ϭϴ͗ϬϬ ϮϬ͗ϬϬ Ϯ͗ϬϬ ϮϬ͗ϬϬ Ϭ͗ϬϬ ϰ͗ϬϬ Ϯϰ ZĞŵĂƌŬƐ͗ ŽŶƚŝŶƵĞƚŽĂƚƚĞŵƉƚƚŽďůŝŶĚďĂĐŬŽĨĨϮͲϳͬϴΗĨŝƐŚ͘KďƐĞƌǀĞďĂĐŬŽĨĨǁŝƚŚĨƌĞĞƚƋ͘WŽŽŚĂŶĚƌĞƚƌŝĞǀĞĨŝƐŚ͘>ͬĨŝƐŚĂŶĚ ŽǀĞƌƐŚŽƚĂƐƐĞŵďůLJ͘dŽƚĂůĨŝƐŚůĞŶŐƚŚсϮϳ͘ϮϵΖKсϮͲϳͬϴΗ͕/сϮͲϯͬϴΗ͘dŚƌĞĂĚƚLJƉĞсŚLJĚƌŝů͕KŽĨĐŽŶŶĞĐƚŝŽŶсϯ͘ϮϰΗ tĂƐŚŽǀĞƌϮͲϳͬϴΗĨƌŽŵϲϰΖƚŽϵϮΖĂƚϭϬϬZWD͕ϭϱϬϬͲϯϬϬϬŬƚƋ͕ϱϬ'WD͕ϱϱW^/͘ϯϬW^/ŽĨĨďŽƚƚŽŵ͕ϭϱϬϬŬƚƋŽĨĨďŽƚƚŽŵ͘ ůĞĂŶŝŶŐŽĨĨŵĂŐŶĞƚƐĞǀĞƌLJƚŝŵĞǁĞĐŽŵĞŽƵƚŽĨƚŚĞŚŽůĞ͕ŶŽĂďŶŽƌŵĂůŵĞƚĂůŽďƐĞƌǀĞĚ͘ dŽƚĂů,ŽƵƌƐ͗ DĂŬĞƵƉϱͲϯͬϰΗtĂƐŚƉŝƉĞ͘ϲϮ͘ϮϵΖKǀĞƌĂůů,ůĞŶŐƚŚ͘Z/,ĂŶĚƚĂŐĂƚϲϰΖ͘;ϰϮ͘ϮϵΖсdŽƉŽĨ&ŝƐŚͿ ĞŐŝŶǁĂƐŚŝŶŐĚŽǁŶĨƌŽŵϲϰΖ͘ϭϬϬZWD͕ϭϱϬϬŬdY͕ϱϬ'WD͕ϱϬW^/͘ůĞĂŶƵƉŚŽůĞƉƌŝŽƌƚŽǁĂƐŚŝŶŐƉĂƐƚϲϰΖ͘ WͬhĂŶĚDͬhdžϭϯϬΖǁĂƐŚƉŝƉĞ͘dŽƚĂů,сϵϮ͘ϯϵΖ tĂƐŚĚŽǁŶ&ͬϵϭΖdͬϭϬϯΖΛϭϬϬZWD͕ϭϳϬϬƚƋͬϭϯϬϬŽĨĨďŽƚƚŽŵƚƋ͘͘Ϯϳϱ^WD͕ϱϬ'WD͕ϯϮW^/͕ϮϬW^/ŽĨĨďŽƚƚŽŵ͘ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ DͬhŽǀĞƌƐŚŽƚĂŶĚĂŬĞƌ,ƚŽƌĞƋƵŝƌĞĚƐƉĞĐƐ͘EͬhƌŽƚĂƚŝŶŐ,ĞĂĚ͘Z/,ǁŝƚŚŽǀĞƌƐŚŽƚ͘ ƚƚĞŵƉƚƚƉĞŶŐĂŐĞĨŝƐŚ͘ZŽƚĂƚĞƵƉϭΖƚŽƚŚĞůĞĨƚ͘ŽƵůĚŶŽƚďĂĐŬŽĨĨd'ǁŝƚŚŽƵƚĚŝƐĞŶŐĂŝŶŐŐƌĂƉƉůĞ͘ tŽƌŬŝŶŐŽŶŵĂŬŝŶŐƚŚĞŐƌĂƉƉůĞďŝƚĞ͘tŽƌŬĂƐĚŝƌĞĐƚĞĚďLJƚŚĞĂŬĞƌƌĞƉ͘ƌĞĂŬŽƵƚƚŽŽůƐƚŽŝŶƐƉĞĐƚ͕ŵĂŬĞƵƉĂŶĚ ĂƚƚĞŵƉƚƚŽĞŶŐĂƵŐĞĨŝƐŚ͘ ŶŐĂŐĞĨŝƐŚ͕ĂƚƚĞŵƉƚŽďĂĐŬŽĨĨǁŝƚŚƌŽƚĂƚŝŶŐŚĞĂĚ͘ ŽŶƚŝŶƵĞǁĂƐŚŽǀĞƌϮϳͬϴΖΖƚďŐ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϴ ϭ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ ĂĐŬŽĨϮϳ͘ϮϵΖŽĨƚďŐ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ < ZZ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ Ăů ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ EŽŶĞ<ŶŽǁŶ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ϮϳϲΖ ϭϭη<> ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗Ϯϯ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϯϬͲDĂƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬϭϬ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϭϳ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϯͬϯϬͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϭϯͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ ϭ͕Ϯ dDϯϬ ϯWD ϭ͕ϮϬϬ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ ϭϭ ϭϭϳ ϭϭϳ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ Ϯϱ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ LJŶĂŵŝĐ Ϯ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ϭ ůĞĂƌƌĞĞŬ <Θ ϭϯ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϳ͗ϬϬ͗ϬϬ ϳ͗ϬϬ ϳ͗ϬϬ ϴ͗ϯϬ ϭ͗ϯϬ ϴ͗ϯϬ ϭϮ͗ϬϬ ϯ͗ϯϬ ϭϮ͗ϬϬ ϭϲ͗ϯϬ ϰ͗ϯϬ ϭϲ͗ϯϬ ϭϳ͗ϯϬ ϭ͗ϬϬ ϭϳ͗ϯϬ ϭϴ͗ϬϬ Ϭ͗ϯϬ ϭϴ͗ϬϬ Ϯϭ͗ϬϬ ϯ͗ϬϬ Ϯϭ͗ϬϬ Ϯϯ͗ϬϬ Ϯ͗ϬϬ Ϯϯ͗ϬϬ Ϭ͗ϬϬ ϭ͗ϬϬ Ϯϰ ZĞŵĂƌŬƐ͗ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ EŽŶĞ<ŶŽǁŶ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ϮϳϲΖ ϭϭη<> ŶͬĂ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ < ZZ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ Ăů ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ ŽŶƚŝŶƵĞǁĂƐŚŽǀĞƌϮϳͬϴΖΖƚďŐ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϴ ϭ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ tĂƐŚĚŽǁŶƚŽϭϯϰΖ ϭƐƉŝůů͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ ŽŶƚ͘ǁĂƐŚŝŶŐŽǀĞƌϮͲϳͬϴΗƚƵďŝŶŐ&ͬϭϬϰΖdͬϭϮϬΖ͕ZWDсϴϬͲϭϬϬ͕ϮϭϬϬͲϮϯϬϬƚƋ͕͘ϭϯϬϬŽĨĨďŽƚƚŽŵƚƋ͘^WDсϮϵϬ͕'WDсϱϰ͕ ϲϬƉƐŝ͕&ůŽǁϭϳй͕DƵĚǀŽů͘сϭϮϮďďůƐ͕tKсϮϰϬϬ͘WƌĞƐƐƵƌĞƐĂŶĚƚŽƌƋƵĞƐƵƉƉĞƌŝŽĚŝĐĂůůLJ͘ůĞĂŶƚŚĞŚŽůĞŽĨĐĞŵĞŶƚƉƌŝŽƌ ƚŽWKK,͘ WKK,ƚŽĂĚĚĂŶŽƚŚĞƌũŽŝŶƚŽĨϱͲϯͬϰΗǁĂƐŚƉŝƉĞ͘ƌĞĂŬŽƵƚĂŶĚůĂŝĚĚŽǁŶϮƐŝŶŐůĞƐŽĨĚƌŝůůƉŝƉĞ͘DĂŬĞƵƉϰƚŚũŽŝŶƚŽĨϱͲ ϯͬϰΗǁĂƐŚƉŝƉĞ͘dƋĂůůĐŽŶŶĞĐƚŝŽŶƐƚŽƐƉĞĐ͘DĂŬĞƵƉĚƌŝůůƉŝƉĞĂŶĚƐǁŝǀĞů͘dĂŐďŽƚƚŽŵĂŶĚďƌĞĂŬĐŝƌĐƵůĂƚŝŽŶ͘ϱϬŐƉŵ͕ ϲϬƉƐŝ͘ tĂƐŚŽǀĞƌϮͲϳͬϴΗƚƵďŝŶŐ&ͬϭϮϬΖdͬϭϮϱΖ͕ZWDсϴϬͲϭϬ͕ϮϭϬϬͲϯϬϬϬŬƚƋ͕͘ϭϯϬϬŽĨĨďŽƚƚŽŵƚƋ͘^WDсϮϵϬ͕'WDсϱϰ͕ϲϬƉƐŝ͕ &ůŽǁϭϳй͕DƵĚǀŽů͘сϭϮϮďďůƐ͕tKсϮϰϬϬ͘DŝŶŝŵŝnjĞĚŽǁŶǁĞŝŐŚƚƚŽĂǀŽŝĚƉĂĐŬŝŶŐŽĨĨ͘ ŝƌĐƵůĂƚĞƚŚĞǁĞůůĐůĞĂŶ͘ůŽǁĚŽǁŶĐĞŵĞŶƚƉƵŵƉ͕ĂŶĚƌŝŐƉƵŵƉ͘WƌĞƉĨůŽŽƌĨŽƌ>ͬtĂƐŚƉŝƉĞĂƐƐĞŵďůLJ͘DŽŶŝƚŽƌƚŚĞ ǁĞůů͕ǁĞůůƐƚĂƚŝĐ͘ tŚŝůĞ>ͬ,ϮϳͬϴΗƚƵďŝŶŐŝŶϮŶĚũŶƚŽĨtW͘ƵƚĂŶĚ>ͬƚƵďŝŶŐĂŶĚ,͘Ƶƚ&ŝƐŚ>ĞŶŐƚŚƐϮϳ͘ϱϮ͕ϭϱ͘Ϭϱ͕ϯϬ͘ϳϱ͘ ƵƚŽƵƚƚƵďŝŶŐĂŶĚůĂLJĚŽǁŶϯũŽŝŶƚƐƚƵďŝŶŐ DĂŬĞǁĂƐŚƉŝƉĞĂƐƐĞŵďůLJ͕Z/, ^ƚĂƌƚǁĂƐŚŝŶŐŽǀĞƌϮϳͬϴΗƚƵďŝŶŐ&ͬϭϮϳΖdͬϭϯϴΖZWDсϭϬϬ͕^WDсϮϳϴ͕&ůŽǁϱϭ͕KĨĨďŽƚƚŽŵdY͘сϭϯϬϬ͕ŽŶŽƚƚŽŵсϮϱϬϬ dŽƚĂů,ŽƵƌƐ͗ tĂƐŚŽǀĞƌϮͲϳͬϴΗƚƵďŝŶŐ&ͬϭϮϱΖdͬϭϯϰΖ͕ZWDсϴϬͲϭϬ͕ϮϭϬϬͲϯϬϬϬŬƚƋ͕͘ϭϯϬϬŽĨĨďŽƚƚŽŵƚƋ͘^WDсϮϵϬ͕'WDсϱϰ͕ϱϬƉƐŝ͕ &ůŽǁϭϳй͕DƵĚǀŽů͘сϭϮϮďďůƐ͕tKсϮϰϬϬ͘DŝŶŝŵŝnjĞĚŽǁŶǁĞŝŐŚƚƚŽĂǀŽŝĚƉĂĐŬŝŶŐŽĨĨ͘ZŝŐƵƉĞdžƚĞƌŝŽƌĐĞŵĞŶƚƉƵŵƉ ĂŶĚƚŝĞŝŶƚŽƌŝŐΖƐƐLJƐƚĞŵ͘ƌŝŶŐƉƵŵƉŽŶůŝŶĞƚŽĂƚƚĞŵƉƚƚŽŐĞƚŵŽƌĞƉƌĞƐƐƵƌĞĂŶĚĨůŽǁƌĂƚĞ͘ZĂƚĞƐĐĂŵĞƵƉƚŽϯ >ͬŵŝŶ͕ϵϬƉƐŝ͕ϮϳйƌĞƚƵƌŶĨůŽǁ͘EŽĞdžƚƌĂĐƵƚƚŝŶŐƐŽƌƉĞŶĞƚƌĂƚŝŽŶƌĂƚĞŽďƐĞƌǀĞĚǁŝƚŚƚŚĞĞdžƚƌĂĨůŽǁƌĂƚĞ͘hŶĂďůĞƚŽ ǁĂƐŚƉĂƐƚϭϯϰΖ ůŽǁĚŽǁŶůŝŶĞƐ͕WKK,ǁŝƚŚϯ͘ϱΗĚƉĂŶĚǁĂƐŚƉŝƉĞ͘ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗Ϯϰ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϭͲƉƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬϭϬ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϭϴ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϰͬϭͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϯϬͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ ϭ͕Ϯ dDϯϬ ϯWD ϭ͕ϮϬϬ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ ϭϭ͘ϭ ϭϭϳ ϭϭϳ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ Ϯϯ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ LJŶĂŵŝĐ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ϭ ůĞĂƌƌĞĞŬ <Θ ϭϯ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϲ͗ϬϬ͗ϬϬ ϲ͗ϬϬ ϲ͗ϬϬ ϵ͗ϬϬ͗ϬϬ ϯ͗ϬϬ ϵ͗ϬϬ ϭϮ͗ϬϬ͗ϬϬ ϯ͗ϬϬ ϭϮ͗ϬϬ ϭϴ͗ϬϬ ϲ͗ϬϬ ϭϴ͗ϬϬ Ϭ͗ϬϬ ϲ͗ϬϬ Ϯϰ ZĞŵĂƌŬƐ͗ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ ŽŶƚ͘ǁĂƐŚŝŶŐŽǀĞƌϮͲϳͬϴΗƚƵďŝŶŐƉĞƌĂŬĞƌZĞƉ͘&ͬϭϯϳΖdͬϭϰϴΖ͕ZWDсϭϬϬ͕ϭϴϬϬƚƋ͕͘ϭϯϬϬŽĨĨďŽƚƚŽŵƚƋ͘^WDсϮϳϴ͕ 'WDсϱϭ͕ϴϬƉƐŝ͕&ůŽǁϭϳй͕ϭϭ͘ϭWW'͕tKсϮϯϬϬ͘ ŽŶƚ͘ǁĂƐŚŝŶŐŽǀĞƌϮͲϳͬϴΗƚƵďŝŶŐƉĞƌĂŬĞƌZĞƉ͘&ͬϭϲϴΖdͬϭϴϳΖ͕ZWDсϭϬϬ͕ϭϴϬϬƚƋ͕͘ϭϯϬϬŽĨĨďŽƚƚŽŵƚƋ͘ϯWD͕ϮϮϱ ƉƐŝ͕&ůŽǁϰϮй͕ϭϭ͘ϭWW'͕tKсϮϯϬϬ͘ ^/DKW^͗^ĞƌǀŝĐĞƐǁŝǀĞůƐĂŶĚƉƌĞƉďĂĐŬƵƉƐŝĨŶĞĞĚĞĚ͘ŽŶƚŝŶƵĞƚŽŵŽŶŝƚŽƌĚŝƚĐŚŵĂŐŶĞƚƐĂŶĚĐůĞĂŶŽĨĨŵĞƚĂů͘Ƶƚ ƌĞƚƌŝĞǀĞĚĂŶĚƚĂůůŝĞĚƚƵďŝŶŐŝŶƚŽŵĂŶĂŐĞĂďůĞůĞŶŐƚŚƐĂŶĚƐƚĂŐĞŽŶĂƉĂůůĞƚ͘ ŽŶƚ͘tĂƐŚŝŶŐŽǀĞƌϮͲϳͬϴΗƚƵďŝŶŐƉĞƌĂŬĞƌZĞƉ͘&ͬϭϴϳΖdͬϮϭϯΖZWDсϭϬϬ͕ϮϰϬϬdƋ͘KĨĨďŽƚƚŽŵdY͘сϭϰϬϬ͕ϯWD͕ ϮϴϰW^/͕ϰϯйĨůŽǁ͕ϭϭ͘ϭƉƉŐ͕tKсϮϰϬϬ͘^/DͲKW^͕^ǁĂƉĐƵƚƚŝŶŐƐďŝŶ͘ƌŝŶŐŝŶďƵŶĚůĞŽĨĚƌŝůůƉŝƉĞ͘ dŽƚĂů,ŽƵƌƐ͗ ŽŶƚ͘ǁĂƐŚŝŶŐŽǀĞƌϮͲϳͬϴΗƚƵďŝŶŐƉĞƌĂŬĞƌZĞƉ͘&ͬϭϰϴΖdͬϭϲϬΖ͕ZWDсϭϬϬ͕ϭϴϬϬƚƋ͕͘ϭϯϬϬŽĨĨďŽƚƚŽŵƚƋ͘^WDсϮϳϴ͕ 'WDсϱϭ͕ϴϬƉƐŝ͕&ůŽǁϭϳй͕ϭϭ͘ϭWW'͕tKсϮϯϬϬ͘^ŝŵŽƉƐ͗ZŝŐƵƉƐŽǁĞĐĂŶƉƵŵƉǁŝƚŚĐĞŵĞŶƚƉƵŵƉŝŶůŝŶĞǁŝƚŚƌŝŐ ŵƵĚƉƵŵƉĨŽƌŝŶĐƌĞĂƐĞĚĨůŽǁƌĂƚĞ͘ ŽŶƚ͘ǁĂƐŚŝŶŐŽǀĞƌϮͲϳͬϴΗƚƵďŝŶŐƉĞƌĂŬĞƌZĞƉ͘&ͬϭϲϬΖdͬϭϲϴΖ͕ZWDсϭϬϬ͕ϭϴϬϬƚƋ͕͘ϭϯϬϬŽĨĨďŽƚƚŽŵƚƋ͘ϯWD͕ϭϳϱͲ ϮϬϬƉƐŝ͕&ůŽǁϯϵй͕ϭϭ͘ϭWW'͕tKсϮϯϬϬ͘^ŝŵŽƉƐ͗ǁŽƌŬŝŶŐŽŶŶĞǁĚƌŝǀĞŵŽƚŽƌĨŽƌ<ĞƌƌŵƵĚƉƵŵƉηϭ͘&ŝŶĂůŝnjŝŶŐ ĞƋƵŝƉŵĞŶƚŶĞĞĚĞĚĨŽƌĂĚĚŝŶŐŚLJĚƌĂƵůŝĐƉƵŵƉŽŶƚŽƚŚĞƐLJƐƚĞŵ͘tŝůůƚĂŬĞƚŚĞŶĞĐĞƐƐĂƌLJƚŝŵĞƚŽĂĚĚƚŚĞƉƵŵƉǁŚĞŶĂůů ĞƋƵŝƉŵĞŶƚŝƐϭϬϬйƌĞĂĚLJĂŶĚǁŚĞŶ,ŝƐŽƵƚŽĨƚŚĞŚŽůĞ͘ ŽŶƚŝŶƵĞǁĂƐŚŽǀĞƌϮϳͬϴΖΖƚďŐ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϴ ϭ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ tĂƐŚĚŽǁŶƚŽϮϭϯΖ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ < ZZ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ Ăů ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ EŽŶĞ<ŶŽǁŶ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ϮϳϲΖ ϭϭηĂů ϯͬϮϴͬϮϬϮϯ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗Ϯϱ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϮͲƉƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬϭϬ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϭϵ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϰͬϮͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϯϬͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ ϭ͕Ϯ dDϯϬ ϯWD ϭ͕ϮϬϬ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ ϭϭ͘ϭ ϭϭϳ ϭϭϳ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ Ϯϯ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ LJŶĂŵŝĐ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ϭ ůĞĂƌƌĞĞŬ <Θ ϭϯ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϯ͗ϯϬ͗ϬϬ ϯ͗ϯϬ ϯ͗ϯϬ ϳ͗ϬϬ ϯ͗ϯϬ ϳ͗ϬϬ ϭϮ͗ϬϬ ϱ͗ϬϬ ϭϮ͗ϬϬ ϭϯ͗ϬϬ ϭ͗ϬϬ ϭϯ͗ϬϬ ϮϬ͗ϬϬ ϳ͗ϬϬ ϮϬ͗ϬϬ ϮϮ͗ϬϬ Ϯ͗ϬϬ ϮϮ͗ϬϬ Ϯϯ͗ϬϬ ϭ͗ϬϬ Ϯϯ͗ϬϬ Ϭ͗ϬϬ ϭ͗ϬϬ Ϯϰ ZĞŵĂƌŬƐ͗ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ ŽŶƚ͘ǁĂƐŚŝŶŐŽǀĞƌϮͲϳͬϴΗƚƵďŝŶŐƉĞƌĂŬĞƌZĞƉ͘&ͬϮϭϯΖdͬϮϮϰΖ͕ZWDсϭϬϬ͕ϮϬϬϬƚƋ͕͘ϭϯϬϬŽĨĨďŽƚƚŽŵƚƋ͘ϯWD͕ϭϬϬͲ ϮϬϬƉƐŝ͕ƌĞƚƵƌŶĨůŽǁϰϯй͕ϭϭ͘ϭWW'͕tKсϮϯϬϬ͘ůĞĂŶŵĂŐŶĞƚĂƐŶĞĐĞƐƐĂƌLJ͘ WKK,&ͬϮϮϰΖdͬϱϵΖ͘>ͬϯ͘ϱΗW͘ &ŝƌƐƚǁĂƐŚƉŝƉĞƚŽĐŽŵĞŽƵƚŽĨƚŚĞŚŽůĞŚĂĚϮϳΖϮͲϳͬϴΗƚƵďŝŶŐŝŶƐŝĚĞ͘&ŝƐŚƌĞĐŽǀĞƌLJсϮϯ͘ϱΖ͘ ŽŶƚŝŶƵĞƚŽ>ͬĂŶĚŝŶƐƉĞĐƚǁĂƐŚƉŝƉĞ͘^/DͲKW^ǁŚŝůĞůĂLJŝŶŐĚŽǁŶƉŝƉĞĐŚĂŶŐĞƉĂĐŬŝŶŐŽŶŵƵĚƉƵŵƉ͘ DͬƵŶĞǁDŝůůŝŶŐƐŚŽĞĂŶĚϯũƚƐŽĨϱͲϯͬϰΗǁĂƐŚƉŝƉĞ͘d/,ƚŽϮϮϰΖ͘ dĂŐƵƉĂƚϭϲϴΖĂŶĚϭϵϰΖ͘ZŽƚĂƚĞĂŶĚǁĂƐŚĚŽǁŶƉĂƐƚƚŝŐŚƚƐƉŽƚƐ͘ϯWD͕ϮϯϬƉƐŝ͕ϰϳйƌĞƚƵƌŶĨůŽǁ͘ϭϬϬƌƉŵ͕ϭϱϬϬŬƚƋ͘ ZĞƉůĂĐĞǁĂƚĞƌƐǁŝǀĞů͘>ͬĚƐǁŝǀĞůĂƐƐĞŵďůLJĂŶĚƌĞƉůĂĐĞ͕ŐƌĞĂƐĞŶĞǁƐǁŝǀĞů͕ƚŽƌƋƵĞĐŽŶŶĞĐƚŝŽŶƐĂŶĚƚĞƐƚ͘ tĂƐŚŽǀĞƌϮͲϳͬϴƚďŐĨƌŽŵϮϮϰΖƚŽϮϰϱΖ͘ϭϬϬZWD͕ϭϱϬϬŬͲϮϬϬϬŬƚƋ͘ϯWD͕ϮϬϬͲϮϰϱW^/͕ϰϱйƌĞƚƵƌŶĨůŽǁ͘ϮͲϯŬǁŽď͘ DŽŶŝƚŽƌĚŝƚĐŚŵĂŐŶĞƚƐĨŽƌĞdžĐĞƐƐŝǀĞŵĞƚĂů͘DŝdžϮϬďďůƐŽĨĂ/͘ WKK,&ͬϮϲϬΖdͬϵϯΖ dŽƚĂů,ŽƵƌƐ͗ >ŽƐƚZŝŐƉŽǁĞƌ͘ůŽǁĚŽǁŶƉƵŵƉƐĂŶĚůŝŶĞƐ͘ ŽŶƚ͘>ͬ,dͬϵϯΖϮͲϳͬϴΗƚƵďŝŶŐŝŶĨŝƌƐƚũŶƚ͘ŽĨǁĂƐŚƉŝƉĞŽƵƚŽĨƚŚĞŚŽůĞ͘ƵƚĂŶĚƐƚƌĂƉƚƵďŝŶŐĂƐƚŚĞLJĐŽŵĞŽƵƚ͘dŽƚĂů ůĞŶŐƚŚŽĨƌĞƚƌŝĞǀĞĚϮͲϳͬϴΗƚƵďŝŶŐсϲϭ͘ϵϭΖ ŽŶƚŝŶƵĞǁĂƐŚŽǀĞƌϮϳͬϴΖΖƚďŐ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϴ ϭ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ tĂƐŚĚŽǁŶƚŽϮϲϬΖ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ < ZZ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ Ăů ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ EŽŶĞ<ŶŽǁŶ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ϮϳϲΖ ϭϭηĂů ϯͬϮϴͬϮϬϮϯ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗Ϯϲ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϯͲƉƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬϭϬ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϮϬ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϰͬϯͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϯϬͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ ϭ͕Ϯ dDϯϬ ϯWD ϭ͕ϮϬϬ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ ϭϭ͘ϭ ϭϭϳ ϭϭϳ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ Ϯϯ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ LJŶĂŵŝĐ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ϭ ůĞĂƌƌĞĞŬ <Θ ϭϯ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϯ͗ϯϬ͗ϬϬ ϯ͗ϯϬ ϯ͗ϯϬ ϲ͗ϯϬ ϯ͗ϬϬ ϲ͗ϯϬ ϭϮ͗ϬϬ ϱ͗ϯϬ ϭϮ͗ϬϬ ϭϴ͗ϬϬ ϲ͗ϬϬ ϭϴ͗ϬϬ Ϭ͗ϬϬ ϲ͗ϬϬ Ϯϰ ZĞŵĂƌŬƐ͗ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ EŽŶĞ<ŶŽǁŶ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ϮϳϲΖ ϭϭηĂů ϯͬϮϴͬϮϬϮϯ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ < ZZ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ Ăů ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ ŽŶƚŝŶƵĞǁĂƐŚŽǀĞƌϮϳͬϴΖΖƚďŐ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϴ ϭ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ tĂƐŚĚŽǁŶƚŽϯϭϵΖ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ >ŽƐƐŽĨZŝŐƉŽǁĞƌ͕ƚƌŽƵďůĞƐŚŽŽƚƉŽǁĞƌŽƵƚĂŐĞ͘^ǁĂƉƉĞĚŐĞŶĞƌĂƚŽƌƐĂŶĚZĞƚƵƌŶĞĚƉŽǁĞƌƚŽƌŝŐ;ůŽƐƚĂůƚĞƌŶĂƚŽƌŽŶ ƌĞŶƚĂůŐĞŶĞƌĂƚŽƌͿ͘&ŝŶŝƐŚůĂLJŝŶŐĚŽǁŶƚƵďŝŶŐĂŶĚǁĂƐŚƉŝƉĞ͘dŽƚĂůŽĨϳϱΖŽĨϮͲϳͬϴΗƚďŐƌĞƚƌŝĞǀĞĚ͘ Dͬh,ĂŶĚZ/,ƉĞƌĂŬĞƌZĞƉĨƌŽŵƐƵƌĨĂĐĞƚŽϮϲϬΖ͘dĂŐĂŶĚǁĂƐŚŽǀĞƌĂƚϯďƉŵ͕ϮϯϬƉƐŝ͕ϰϴйƌĞƚƵƌŶĨůŽǁ͕ϭϬϬ ZWD͕ϭϱϬϬͲϮϬϬϬŬƚƋ͘ tĂƐŚŽǀĞƌϮͲϳͬϴΗƚďŐĨƌŽŵϮϲϬΖƚŽϮϳϯΖ͘ϯWD͕ϮϰϱW^/͕ϰϴйĨůŽǁ͕ϭϬϬƌƉŵ͕ϮϬϬϬŬƚƋ͘ϮŬǁŽď͘ϭϴϱƉƐŝŽĨĨďŽƚƚŽŵ͕ ϭϱϬϬŬƚƋŽĨĨďŽƚƚŽŵ͘ůĞĂŶĚŝƚĐŚŵĂŐŶĞƚƐĂƐŶĞĞĚĞĚ͘ tĂƐŚŽǀĞƌϮͲϳͬϴΗƚďŐĨƌŽŵϮϳϯΖƚŽϮϵϬΖ͘ϯWD͕ϮϱϬW^/͕ϰϴйĨůŽǁ͕ϭϬϬƌƉŵ͕ϮϬϬϬŬƚƋ͘ϮŬǁŽď͘ϭϴϱƉƐŝŽĨĨďŽƚƚŽŵ͕ ϭϱϬϬŬƚƋŽĨĨďŽƚƚŽŵ͘ůĞĂŶĚŝƚĐŚŵĂŐŶĞƚƐĂƐŶĞĞĚĞĚ͘/ŶƐƉĞĐƚyYϱϬϬŐĞŶĞƌĂƚŽƌ͘ŚĞĐŬĂŶĚƚŽƉŽĨĨŶĞĐĞƐƐĂƌLJĨůƵŝĚƐ͘ dƌŽƵďůĞƐŚŽŽƚďĂƚƚĞƌŝĞƐ͘ĞƚĞƌŵŝŶĞĚƚŚĞĂůƚĞƌŶĂƚŽƌǁĂƐŶŽƚůŽŶŐĞƌĐŚĂƌŐŝŶŐϮϰǀŽůƚƐLJƐƚĞŵ͘DĂĚĞĂƌƌĂŶŐĞŵĞŶƚƐĨŽƌ ƉĂƌƚƐƚŽďĞƐŚŝƉƉĞĚǀŝĂŐŽůĚƐƚƌĞĂŬ͘ tĂƐŚŽǀĞƌϮͲϳͬϴΗƚďŐ&ͬϮϵϬΖdͬϯϭϵΖ͕ϯWD͕ϮϱϰƉƐŝ͕ϱϭйĨůŽǁ͕ZWDсϭϬϬ͕dY͘сϭϱϬϬͬϮϭϬϬ͕tKсϮϰϬϬ͕ůĞĂŶĚŝƚĐŚ ŵĂŐŶĞƚƐĂƐŶĞĞĚĞĚ͘ dŽƚĂů,ŽƵƌƐ͗ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗Ϯϳ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϰͲƉƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬϭϬ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗Ϯϭ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϰͬϰͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϯϬͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ ϭ͕Ϯ dDϯϬ ϯWD ϭ͕ϮϬϬ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ ϭϭ͘ϭ ϭϭϳ ϭϭϳ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ Ϯϯ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ LJŶĂŵŝĐ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ϭ ůĞĂƌƌĞĞŬ <Θ ϭϯ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϲ͗ϬϬ͗ϬϬ ϲ͗ϬϬ ϲ͗ϬϬ ϭϬ͗ϬϬ ϰ͗ϬϬ ϭϬ͗ϬϬ ϭϬ͗ϯϬ Ϭ͗ϯϬ ϭϬ͗ϯϬ ϭϭ͗ϯϬ ϭ͗ϬϬ ϭϭ͗ϯϬ ϭϮ͗ϬϬ Ϭ͗ϯϬ ϭϮ͗ϬϬ ϭϯ͗ϬϬ ϭ͗ϬϬ ϭϯ͗ϬϬ ϭϰ͗ϬϬ ϭ͗ϬϬ ϭϰ͗ϬϬ ϭϱ͗ϬϬ ϭ͗ϬϬ ϭϱ͗ϬϬ ϭϴ͗ϬϬ ϯ͗ϬϬ ϭϴ͗ϬϬ Ϭ͗ϬϬ ϲ͗ϬϬ Ϯϰ ZĞŵĂƌŬƐ͗ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ EŽŶĞ<ŶŽǁŶ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ϮϳϲΖ ϭϭηĂů ϯͬϮϴͬϮϬϮϯ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ < ZZ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ Ăů ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ ŽŶƚŝŶƵĞǁĂƐŚŽǀĞƌϮϳͬϴΖΖƚďŐ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϴ ϭ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ tĂƐŚĚŽǁŶƚŽϯϴϵΖ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ tĂƐŚŽǀĞƌϮͲϳͬϴΗƚďŐƉĞƌĂŬĞƌZĞƉ͘&ͬϯϭϵΖdͬϯϯϴΖϯWD͕ϮϲϲW^/͕ϰϯй&ůŽǁ͕ZWDсϭϬϬ͕ϮϰϬϬdY͘tKсϮϯϬϬ͕ϭϴϱƉƐŝ ŽĨĨďŽƚƚŽŵ͕ϭϱϬϬdY͘KĨĨŽƚƚŽŵ͘ůĞĂŶĚŝƚĐŚŵĂŐŶĞƚƐĂƐŶĞĞĚĞĚ͘tĂƚĐŚĨŽƌĞdžĐĞƐƐŝǀĞŵĞƚĂůƐŚĂǀŝŶŐƐ͘ tĂƐŚŽǀĞƌϮͲϳͬϴΗƚďŐƉĞƌĂŬĞƌZĞƉ͘&ͬϯϯϴΖdͬϯϰϴΖϯWD͕ϮϬϯW^/͕ϰϯй&ůŽǁ͕ZWDсϭϬϬ͕ϮϰϬϬdY͘tKсϮϯϬϬ͕ϭϴϱƉƐŝ ŽĨĨďŽƚƚŽŵ͕ϭϱϬϬdY͘KĨĨŽƚƚŽŵ͘ůĞĂŶĚŝƚĐŚŵĂŐŶĞƚƐĂƐŶĞĞĚĞĚ͘tĂƚĐŚĨŽƌĞdžĐĞƐƐŝǀĞŵĞƚĂůƐŚĂǀŝŶŐƐ͘ ůŽǁĚŽǁŶĐĞŵĞŶƚƉƵŵƉ͘DŽŶŝƚŽƌƚŚĞǁĞůů͕ǁĞůůŝƐƐƚĂƚŝĐ͘^ĞƚĨůŽŽƌĂŶĚƉŝƉĞƌĂĐŬĨŽƌWKK,͘ WKK,ĨƌŽŵϯϰϴΖƚŽϵϬΖ͘WhǁƚсϰϮϬϬůďƐ͘ǁĂƚĐŚĨŽƌƚŝŐŚƚƐƉŽƚƐ͘>ͬĚĚƌŝůůƉŝƉĞŝŶϯϬΖƐĞĐƚŝŽŶƐŽŶĐĞŚŽůĞĨĞůƚĐůĞĂŶ͘ ZĞŵŽǀĞƌŽƚĂƚŝŶŐŚĞĂĚ͘DŽŶŝƚŽƌƚŚĞǁĞůů͕ŝŶƐƚĂůůďĂŝůƐĂŶĚĞůĞǀĂƚŽƌƐ͘>ͬĚϭũŽŝŶƚŽĨϱͲϯͬϰΗǁĂƐŚƉŝƉĞ͘ ŽŶƚŝŶƵĞƚŽ>ͬĚǁĂƐŚƉŝƉĞĂŶĚϮͲϳͬϴΗdďŐĨƌŽŵϲϬΖƐƵƌĨĂĐĞ͘dŽƚĂůϮͲϳͬϴΗƌĞĐŽǀĞƌĞĚсϯũŽŝŶƚƐǁŽƌƚŚ͕ŝŶĐůƵĚŝŶŐƚŚĞt>Z ƉůƵŐ͘ dŽƚĂů,ŽƵƌƐ͗ DĂŬĞƵƉŶĞǁϱͲϯͬϰΗǁĂƐŚƉŝƉĞĂƐƐĞŵďůLJĨƌŽŵƐƵƌĨĂĐĞƚŽϵϰΖ͘/ŶƐƉĞĐƚũŽŝŶƚƐŐŽŝŶŐŝŶƚŚĞŚŽůĞĨŽƌĞdžĐĞƐƐŝǀĞǁĞĂƌ͘ dŽƌƋƵĞĂůůũŽŝŶƚƐƚŽƐƉĞĐ͘ dƌŝƉŝŶƚŚĞŚŽůĞĨƌŽŵϵϰΖƚŽϯϮϴΖǁŝƚŚϯ͘ϱΗĚƌŝůůƉŝƉĞ͘^ͬKǁƚсϯϱϬϬůďƐ͘ /ŶƐƚĂůůƌŽƚĂƚŝŶŐŚĞĂĚ͘tĂƐŚŽǀĞƌϮͲϳͬϴΗƚďŐĨƌŽŵϯϮϴΖ;dŽƉŽĨĨŝƐŚͿƚŽϯϱϬΖΛϯWD͕ϮϭϬW^/͕ϭϬϬZWD͕ϭϱϬϬŬdY͕ϭϱϬϬŬ tK͕KĨĨďŽƚƚŽŵƉƐŝсϭϳϱ͕ƚƋсϭϬϬϬŬ tĂƐŚŽǀĞƌϮͲϳͬϴΗƚďŐĨƌŽŵϯϱϬΖƚŽϯϴϵΖΛϯWD͕ϮϭϱƉƐŝ͕ϰϰйƌĞƚƵƌŶĨůŽǁ͕ϭϬϬƌƉŵ͕ϮϬϬϬŬƚƋ͕ϭϱϬϬŬtK͘DŽŶŝƚŽƌ ŵĂŐŶĞƚƐ͘ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗Ϯϴ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϱͲƉƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬͲϭϱ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϮϮ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϰͬϱͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϯϬͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ ϭ͕Ϯ dDϯϬ ϯWD ϭ͕ϮϬϬ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ ϭϭ͘ϭ ϭϭϳ ϭϭϳ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ Ϯϯ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ LJŶĂŵŝĐ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ϭ ůĞĂƌƌĞĞŬ <Θ ϭϯ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϲ͗ϬϬ͗ϬϬ ϲ͗ϬϬ ϲ͗ϬϬ ϭϬ͗ϯϬ ϰ͗ϯϬ ϭϬ͗ϯϬ ϭϮ͗ϬϬ ϭ͗ϯϬ ϭϮ͗ϬϬ ϭϰ͗ϬϬ Ϯ͗ϬϬ ϭϰ͗ϬϬ ϭϴ͗ϬϬ ϰ͗ϬϬ ϭϴ͗ϬϬ Ϭ͗ϬϬ ϲ͗ϬϬ Ϯϰ ZĞŵĂƌŬƐ͗ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ tĂƐŚŽǀĞƌϮͲϳͬϴΗƚďŐƉĞƌĂŬĞƌZĞƉ͘&ͬϯϴϵΖdͬϰϭϬΖϯWD͕ϮϳϭW^/͕ϱϭй&ůŽǁ͕ZWDсϭϬϬ͕ϮϰϬϬdY͘tKсϮϯϬϬ͕ϭϴϱƉƐŝ ŽĨĨďŽƚƚŽŵ͕ϭϱϬϬdY͘KĨĨŽƚƚŽŵ͘ůĞĂŶĚŝƚĐŚŵĂŐŶĞƚƐĂƐŶĞĞĚĞĚ͘tĂƚĐŚĨŽƌĞdžĐĞƐƐŝǀĞŵĞƚĂůƐŚĂǀŝŶŐƐ͘ tĂƐŚŽǀĞƌϮͲϳͬϴΗƚďŐƉĞƌĂŬĞƌZĞƉ͘&ͬϰϭϬΖdͬϰϮϯΖϯWD͕ϮϮϱW^/͕ϱϭй&ůŽǁ͕ZWDсϭϬϬ͕ϮϰϬϬdY͘tKсϮϯϬϬ͕ϭϴϱƉƐŝ ŽĨĨďŽƚƚŽŵ͕ϭϱϬϬdY͘KĨĨŽƚƚŽŵ͘ůĞĂŶĚŝƚĐŚŵĂŐŶĞƚƐĂƐŶĞĞĚĞĚ͘tĂƚĐŚĨŽƌĞdžĐĞƐƐŝǀĞŵĞƚĂůƐŚĂǀŝŶŐƐ͘ ͬĚĐĞŵĞŶƚƉƵŵƉ͕ŵŽŶŝƚŽƌƚŚĞǁĞůůĂŶĚWKK,ĨƌŽŵϰϮϯΖƚŽϯϬϬΖWͬƵǁƚсϰϱϬϬůďƐ͘tĂƚĐŚƚŝŐŚƚƐƉŽƚƐĂŶĚƌŽƚĂƚĞĂƐ ŶĞĞĚĞĚ͘ ŽŶƚŝŶƵĞƚŽWKK,ĂŶĚ>ͬϱͲϯͬϰΗǁĂƐŚƉŝƉĞĨƌŽŵϯϬϬΖƚŽƐƵƌĨĂĐĞ͘DŽŶŝƚŽƌŚŽůĞĨŝůůĂŶĚŽďƐĞƌǀĞƚŚĞǁĞůůĨŽƌĨůŽǁ͕ǁĞůů ŝƐƐƚĂƚŝĐ͘EŽd'ŽďƐĞƌǀĞĚŝŶƐŝĚĞƚŚĞǁĂƐŚƉŝƉĞ͘dĞƐƚŵƵĚƉƵŵƉηϭͲŐŽŽĚƚŽŐŽ͘ DĂŬĞƵƉǁĂƐŚƉŝƉĞĂƐƐĞŵďůLJǁŝƚŚĂƚŽƚĂůŽĨϰǁĂƐŚƉŝƉĞũŽŝŶƚƐ͘Z/,ŽŶϯ͘ϱΗĚƌŝůůƉŝƉĞƚŽϰϬϬΖ͘dĂŐƚŽƉŽĨĨŝƐŚĂƚϯϱϬΖĂŶĚ ǁŽƌŬƉŝƉĞŽǀĞƌϮͲϳͬϴΗd'͘ tĂƐŚŽǀĞƌϮͲϳͬϴΗƚďŐƉĞƌĂŬĞƌZĞƉ͘&ͬϰϮϯΖdͬϰϯϲΖϯWD͕ϮϮϱƉƐŝ͕&ůŽǁсϱϭйŽƵƚ͕ZWDсϭϬϬ͕ϮϰϬϬdY͕͘tKсϮϰϬϬ͕ ϭϴϱƉƐŝŽĨĨďŽƚƚŽŵ͕ϭϱϬϬͲϭϴϬϬdY͘ dŽƚĂů,ŽƵƌƐ͗ ŽŶƚŝŶƵĞǁĂƐŚŽǀĞƌϮϳͬϴΖΖƚďŐ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϴ ϭ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ tĂƐŚŽǀĞƌƚŽϰϯϲΖ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ < ZZ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ Ăů ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ EŽŶĞ<ŶŽǁŶ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ϮϳϲΖ ϭϭηĂů ϯͬϮϴͬϮϬϮϯ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗Ϯϵ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϲͲƉƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬͲϭϱ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗Ϯϯ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϰͬϲͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϯϬͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ ϭ͕Ϯ dDϯϬ ϯWD ϭ͕ϮϬϬ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ ϭϭ͘ϭ ϭϭϳ ϭϭϳ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ Ϯϯ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ LJŶĂŵŝĐ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ϭ ůĞĂƌƌĞĞŬ <Θ ϭϯ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϲ͗ϬϬ͗ϬϬ ϲ͗ϬϬ ϲ͗ϬϬ ϭϭ͗ϬϬ ϱ͗ϬϬ ϭϭ͗ϬϬ ϭϮ͗ϬϬ ϭ͗ϬϬ ϭϮ͗ϬϬ ϭϯ͗ϯϬ ϭ͗ϯϬ ϭϯ͗ϯϬ ϭϱ͗ϯϬ Ϯ͗ϬϬ ϭϱ͗ϯϬ ϭϲ͗ϯϬ ϭ͗ϬϬ ϭϲ͗ϯϬ ϭϴ͗ϯϬ Ϯ͗ϬϬ ϭϴ͗ϯϬ Ϭ͗ϬϬ ϱ͗ϯϬ Ϯϰ ZĞŵĂƌŬƐ͗ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ EŽŶĞ<ŶŽǁŶ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ϮϳϲΖ ϭϭηĂů ϯͬϮϴͬϮϬϮϯ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ < ZZ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ Ăů ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ ŽŶƚŝŶƵĞǁĂƐŚŽǀĞƌϮϳͬϴΖΖƚďŐ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϴ ϭ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ tĂƐŚŽǀĞƌƚŽϰϵϬΖ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ tĂƐŚŽǀĞƌϮͲϳͬϴΗƚďŐƉĞƌĂŬĞƌZĞƉ͘&ͬϰϯϲΖdͬϰϱϳΖϯWD͕ϮϰϭW^/͕ϱϬй&ůŽǁ͕ZWDсϭϬϬ͕ϮϰϬϬdY͘tKсϮϯϬϬ͕ϭϴϱƉƐŝ ŽĨĨďŽƚƚŽŵ͕ϭϱϬϬdY͘KĨĨŽƚƚŽŵ͘ůĞĂŶĚŝƚĐŚŵĂŐŶĞƚƐĂƐŶĞĞĚĞĚ͘tĂƚĐŚĨŽƌĞdžĐĞƐƐŝǀĞŵĞƚĂůƐŚĂǀŝŶŐƐ͘ tĂƐŚŽǀĞƌϮͲϳͬϴΗƚďŐƉĞƌĂŬĞƌZĞƉ͘&ͬϰϱϳΖdͬϰϳϭΖϯWD͕ϮϲϴW^/͕ϰϯй&ůŽǁ͕ZWDсϭϬϬ͕ϮϰϬϬdY͘tKсϮϯϬϬ͕ϭϴϱƉƐŝ ŽĨĨďŽƚƚŽŵ͕ϭϱϬϬdY͘KĨĨŽƚƚŽŵ͘ůĞĂŶĚŝƚĐŚŵĂŐŶĞƚƐĂƐŶĞĞĚĞĚ͘tĂƚĐŚĨŽƌĞdžĐĞƐƐŝǀĞŵĞƚĂůƐŚĂǀŝŶŐƐ͘ ͬƉƵŵƉƐĂŶĚŵŽŶŝƚŽƌƚŚĞǁĞůůͲƐƚĂƚŝĐ͘WKK,ĨƌŽŵϰϳϭΖƚŽϯϯϲΖ͘WͬhǁƚсϱϴϬϬůďƐ WKK,ĨŽƌŵϯϯϲΖƚŽϭϮϬΖ͘DŽŶŝƚŽƌƚŚĞǁĞůůĂŶĚĐŚĂŶŐĞĞůĞǀĂƚŽƌƐĨŽƌǁĂƐŚƉŝƉĞ͘ >ͬĚǁĂƐŚƉŝƉĞĂŶĚĐƵƚͬƌĞŵŽǀĞϮͲϳͬϴΗƚďŐĨƌŽŵǁĂƐŚƉŝƉĞ͘ ƐƚŝŵĂƚĞĚƌĞĐŽǀĞƌLJсϮũŽŝŶƚƐ͘ DĂŬĞƵƉŶĞǁŵŝůů͘DĂŬĞƵƉǁĂƐŚƉŝƉĞĂƐƉĞƌďĂŬĞƌĨƌŽŵƐƵƌĨĂĐĞƚŽϭϭϴΖ tĂƐŚŽǀĞƌϮͲϳͬϴΗƚďŐƉĞƌĂŬĞƌZ W͘&ͬϰϳϭΖdͬϱϬϯΖϯďƉŵ͕&ůŽǁ͕ZWDсϭϬϬ͕ϮϲϬϬdY͘tKсϮϯϬϬ͕ϭϴϱƉƐŝŽĨĨďŽƚƚŽŵ͘ ϭϯϬϬdY͘ŽĨĨďŽƚƚŽŵ͘ůĞĂŶĚŝƚĐŚŵĂŐŶĞƚƐĂƐŶĞĞĚĞĚ͘ dŽƚĂů,ŽƵƌƐ͗ Z/,ĨƌŽŵϭϭϴΖƚŽϰϳϭΖǁŝƚŚϯ͘ϱΗW͘dĂŐŐĞĚĨŝƐŚΛϯϵϲΖ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϯϬ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϳͲƉƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬͲϭϱ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗Ϯϰ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϰͬϳͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϯϬͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ ϭ͕Ϯ dDϯϬ ϯWD ϭ͕ϮϬϬ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ ϭϭ͘ϭ ϭϭϳ ϭϭϳ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ Ϭ͘ϬϬ Ϯϯ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ LJŶĂŵŝĐ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ϭ ůĞĂƌƌĞĞŬ <Θ ϭϯ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ Ϯ͗ϬϬ͗ϬϬ Ϯ͗ϬϬ Ϯ͗ϬϬ ϱ͗ϬϬ ϯ͗ϬϬ ϱ͗ϬϬ ϴ͗ϬϬ ϯ͗ϬϬ ϴ͗ϬϬ ϭϬ͗ϬϬ Ϯ͗ϬϬ ϭϬ͗ϬϬ ϭϯ͗ϯϬ ϯ͗ϯϬ ϭϯ͗ϯϬ ϭϴ͗ϬϬ ϰ͗ϯϬ ϭϴ͗ϬϬ ϮϮ͗ϬϬ ϰ͗ϬϬ ϮϮ͗ϬϬ ϮϮ͗ϯϬ Ϭ͗ϯϬ ϮϮ͗ϯϬ Ϭ͗ϬϬ ϭ͗ϯϬ Ϯϰ ZĞŵĂƌŬƐ͗ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ tĂƐŚŽǀĞƌϮͲϳͬϴΗƚďŐƉĞƌĂŬĞƌZĞƉ͘&ͬϱϬϯΖdͬϱϭϲΖϯWD͕ϮϰϭW^/͕ϱϬй&ůŽǁ͕ZWDсϭϬϬ͕ϮϰϬϬdY͘tKсϮϯϬϬ͕ϭϴϱƉƐŝ ŽĨĨďŽƚƚŽŵ͕ϭϱϬϬdY͘KĨĨŽƚƚŽŵ͘ůĞĂŶĚŝƚĐŚŵĂŐŶĞƚƐĂƐŶĞĞĚĞĚ͘tĂƚĐŚĨŽƌĞdžĐĞƐƐŝǀĞŵĞƚĂůƐŚĂǀŝŶŐƐ͘ WKK,&ͬϱϭϲΖdͬ^hZ&͘Wͬhǁƚсϳ͘ϮŬ^ͬKǁƚсϲ͘ϱŬ͘DŽŶŝƚŽƌƚŚĞǁĞůůĚƵƌŝŶŐƚƌŝƉĂŶĚĐͬŽŽĨĞůĞǀĂƚŽƌƐ͘EŽ&ŝƐŚ͘ DͬhĐƵƚƚĞƌ,ƉĞƌĂŬĞƌZĞƉ͘&ͬ^ƵƌĨ͘dͬϰϮϵΖWͬhǁƚсϳŬ^ͬKǁƚсϲ͘ϲŬ͘dĂŐĨŝƐŚĂŶĚĂƚƚĞŵƉƚƚŽǁŽƌŬŽǀĞƌǁŝƚŚ ĐƵƚƚŝŶŐĂƐƐĞŵďůLJ͘EŽƚƐƵĐĐĞƐƐĨƵůǁŽƌŬŝŶŐƉĂƐƚƚƵďŝŶŐĐƵƚƚĞƌďĂƐŬĞƚ͘ƚƚĞŵƉƚƚŽƉŝĐŬƵƉƚŽĐĂƚĐŚĂĐŽůůĂƌĐŽŶŶĞĐƚŝŽŶƚŽ ĞŶŐĂŐĞĐƵƚƚĞƌƐ͕ŶŽĐŽŶŶĞĐƚŝŽŶĨŽƵŶĚ͘ WKK,ĨƌŽŵϰϮϵΖƚŽ^ƵƌĨĂĐĞ͘Wͬhǁƚϲ͘ϱŬ͕^ͬKǁƚсϲ͘ϮŬ͘<ĞĞƉŚŽůĞĨƵůůĂŶĚŵŽŶŝƚŽƌƚŚĞǁĞůů͘ DĂŬĞƵƉ,ǁŝƚŚŶĞǁŵŝůůƚŽĚƌĞƐƐƚŚĞƚŽƉŽĨĨŝƐŚ͘Z/,ǁŝƚŚϯ͘ϱΗƉĨƌŽŵϭϱϭΖƚŽϰϮϵΖ͘tŽƌŬŽǀĞƌĨŝƐŚĂƐƉĞƌĂŬĞƌ͘ ŽŶƚŝŶƵĞƚŽǁĂƐŚŽǀĞƌϮͲϳͬϴΗd'ĨƌŽŵϰϮϵΖƚŽϰϴϴΖϯWD͕ϭϱϲƉƐŝ͕ϭϬϬZWD͕ϭ͘ϱŬƚƋ͘ϯϳйƌĞƚƵƌŶĨůŽǁ͘ dŽƚĂů,ŽƵƌƐ͗ ŽŶƚŝŶƵĞƚŽǁĂƐŚŽǀĞƌϮͲϳͬϴΗd'ĨƌŽŵϰϴϴΖΖƚŽϰϵϳΖϯWD͕ϭϱϲƉƐŝ͕ϭϬϬZWD͕ϭ͘ϱŬƚƋ͘ϯϳйƌĞƚƵƌŶĨůŽǁ͘ >ŽƐƚƌŽƚĂƚŝŽŶ͘WƵůůĞĚĨƌĞĞ͕ĞƐƚĂďůŝƐŚĞĚƌŽƚĂƚŝŽŶ͘ ŽŶƚŝŶƵĞƚŽǁĂƐŚŽǀĞƌϮͲϳͬϴΗd'&ͬϰϵϳΖdͬϰϵϵΖϯWD͕ϭϱϲƉƐŝϭϬϬZWD͕ϭ͘ϱƚƋ͘ϯϳйƌĞƚƵƌŶĨůŽǁ͘ ŽŶƚŝŶƵĞǁĂƐŚŽǀĞƌϮϳͬϴΖΖƚďŐ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϴ ϭ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ tĂƐŚŽǀĞƌƚŽϱϭϲΖ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ < ZZ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ Ăů ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ EŽŶĞ<ŶŽǁŶ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ϮϳϲΖ ϭϭηĂů ϯͬϮϴͬϮϬϮϯ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϯϭ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϴͲƉƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬͲϮϱ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗Ϯϱ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϰͬϴͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϯϬͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ ϭ͕Ϯ dDϯϬ ϯWD ϭ͕ϮϬϬ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ ϭϭ͘ϭ ϭϬϳ ϭϬϳ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ ϭͬϮďďůŵĞƚĂůĐƵƚƚŝŶŐĨŽƌŵŵĂŐŶĞƚƐ ϭϬďďůƐĐĞŵĞŶƚĨƌŽŵƐŚĂŬĞƌ ϭϬ͘ϱďďůƐ Ϯϯ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ LJŶĂŵŝĐ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ϭ ůĞĂƌƌĞĞŬ <Θ ϭϯ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϯ͗ϯϬ͗ϬϬ ϯ͗ϯϬ ϯ͗ϯϬ ϲ͗ϬϬ Ϯ͗ϯϬ ϲ͗ϬϬ ϴ͗ϯϬ Ϯ͗ϯϬ ϴ͗ϯϬ ϭϬ͗ϬϬ ϭ͗ϯϬ ϭϬ͗ϬϬ ϭϭ͗ϬϬ ϭ͗ϬϬ ϭϭ͗ϬϬ ϭϮ͗ϬϬ ϭ͗ϬϬ ϭϮ͗ϬϬ ϭϰ͗ϬϬ Ϯ͗ϬϬ ϭϰ͗ϬϬ ϭϴ͗ϬϬ ϰ͗ϬϬ ϭϴ͗ϬϬ Ϭ͗ϬϬ ϲ͗ϬϬ Ϯϰ ZĞŵĂƌŬƐ͗ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ EŽŶĞ<ŶŽǁŶ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ϮϳϲΖ ϭϭηĂů ϯͬϮϴͬϮϬϮϯ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ < ZZ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ Ăů ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ ŽŶƚŝŶƵĞǁĂƐŚŽǀĞƌϮϳͬϴΖΖƚďŐ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϴ ϭ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ tĂƐŚŽǀĞƌƚŽϱϭϮΖ >ͬϱͲϯͬϰΗtĂƐŚŽǀĞƌƉŝƉĞĂƐƉĞƌĂŬĞƌƌĞƉ͘ZĞĐŽǀĞƌĞĚϯũŽŝŶƚƐŽĨϮͲϳͬϴΗd'͕ĐƵƚĂŶĚƌĞŵŽǀĞĨƌŽŵǁĂƐŚƉŝƉĞ͘ DŽŶŝƚŽƌƚŚĞǁĞůů͕ǁĞůůŝƐƐƚĂƚŝĐ͘ DĂŬĞƵƉŶĞǁϱͲϯͬϰΗǁĂƐŚŽǀĞƌĂƐƐĞŵďůLJĨƌŽŵƐƵƌĨĂĐĞƚŽϭϮϬΖĂƐƉĞƌĂŬĞƌ͘ ϰϭͬϰΗǁĂƐŚŽǀĞƌƐŚŽĞǁŝƚŚϰũƚƐŽĨǁĂƐŚƉŝƉĞ͘ Z/,ĨƌŽŵϭϮϬΖƚŽϯϭϱΖ͘DŽŶŝƚŽƌĚŝƐƉůĂĐĞŵĞŶƚ͘ dŽƚĂů,ŽƵƌƐ͗ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ tĂƐŚŽǀĞƌϮͲϳͬϴΗƚďŐƉĞƌĂŬĞƌZĞƉ͘&ͬϰϵϵΖdͬϱϬϲΖϯWD͕ϮϰϭW^/͕ϱϬй&ůŽǁ͕ZWDсϭϬϬ͕ϮϰϬϬdY͘tKсϮϯϬϬ͕ϭϴϱƉƐŝ ŽĨĨďŽƚƚŽŵ͕ϭϱϬϬdY͘KĨĨŽƚƚŽŵ͘ůĞĂŶĚŝƚĐŚŵĂŐŶĞƚƐĂƐŶĞĞĚĞĚ͘tĂƚĐŚĨŽƌĞdžĐĞƐƐŝǀĞŵĞƚĂůƐŚĂǀŝŶŐƐ͘ ƚϱϬϲΖ͕ZWDсϴϬͲϭϬϬ͕ϯͲϰŬƚƋ͘ϯďƉŵ͕ϮϰϬW^/͘ZŽƚĂƚŝŽŶƐƚĂůůĞĚŽƵƚ͕ǁŽƌŬƚŽĨƌĞĞƉŽŝŶƚΛϰϵϭΖĂŶĚĞƐƚĂďůŝƐŚĞĚƌŽƚĂƚŝŽŶ ĂŶĚĐŝƌĐƵůĂƚŝŽŶ͘WͬƵǁƚсϳ͕ϱŬ͘^ͬKǁƚсϲ͘ϱŬ͘ WKK,ĨŽƌŵϰϵϭΖƚŽϭϱϬΖ͘Wͬhǁƚсϳ͘ϱŬ͕^ͬKǁƚсϲ͘ϲŬ͘DŽŶŝƚŽƌǁĞůůĨŽƌƉƌŽƉĞƌĚŝƐƉůĂĐĞŵĞŶƚ͘ Z/,ĨƌŽŵϯϭϱΖƚŽϱϬϲ͕/ŶƐƚĂůůƌŽƚĂƚŝŶŐŚĞĂĚ͘ tĂƐŚŽǀĞƌϮͲϳͬϴΗƚďŐƉĞƌĂŬĞƌZĞƉ͘&ͬϱϬϲΖdͬϱϭϬΖϯWD͕ϭϱϬW^/͕ϰϬй&ůŽǁ͕ZWDсϴϬͲϭϬϬ͕ϮϰϬϬdY͘tKсϭ͘ϱͲϮŬ͕ϭϯϬ ƉƐŝŽĨĨďŽƚƚŽŵ͕ϭϱϬϬdY͘KĨĨŽƚƚŽŵ͘ůĞĂŶĚŝƚĐŚŵĂŐŶĞƚƐĂƐŶĞĞĚĞĚ͘tĂƚĐŚĨŽƌĞdžĐĞƐƐŝǀĞŵĞƚĂůƐŚĂǀŝŶŐƐ͘ tĂƐŚŽǀĞƌϮͲϳͬϴΗd'ƉĞƌĂŬĞƌZĞƉ͘&ͬϱϭϬΖdͬϱϭϰΖϯWD͕ϭϱϬW^/͕ϱϮй&ůŽǁ͕ZWDсϭϮϬ͕ϮϰϬϬdY͕͘tKсϮŬ͕ϭϯϬƉƐŝŽĨĨ ďŽƚƚŽŵ͕ϭϱϬϬdY͘KĨĨďŽƚƚŽŵ͘ DŝůůŝŶŐƵƉƉŝĞĐĞƐŽĨƚƵďŝŶŐĂůŽŶŐƐŝĚĞŽĨƚƵďŝŶŐƐƚƌŝŶŐ͘ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϯϮ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϵͲƉƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬͲϮϱ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗Ϯϲ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϰͬϵͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϯϬͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ ϭ͕Ϯ dDϯϬ ϯWD ϭ͕ϮϬϬ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ ϭϭ͘ϭ ϭϬϳ ϭϬϳ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ ϭͬϮďďůŵĞƚĂůĐƵƚƚŝŶŐĨŽƌŵŵĂŐŶĞƚƐ ϭϬďďůƐĐĞŵĞŶƚĨƌŽŵƐŚĂŬĞƌ ϭϬ͘ϱďďůƐ Ϯϯ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ LJŶĂŵŝĐ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ϭ ůĞĂƌƌĞĞŬ <Θ ϭϯ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϲ͗ϬϬ͗ϬϬ ϲ͗ϬϬ ϲ͗ϬϬ ϭϮ͗ϬϬ ϲ͗ϬϬ ϭϮ͗ϬϬ ϭϴ͗ϯϬ ϲ͗ϯϬ ϭϴ͗ϯϬ ϮϮ͗ϬϬ ϯ͗ϯϬ ϮϮ͗ϬϬ Ϭ͗ϬϬ Ϯ͗ϬϬ Ϯϰ ZĞŵĂƌŬƐ͗ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ tĂƐŚŽǀĞƌϮͲϳͬϴΗƚďŐƉĞƌĂŬĞƌZĞƉ͘&ͬϱϭϰΖdͬϱϮϱΖ͕ϯWD͕ϮϰϭW^/͕ϱϬй&ůŽǁ͕ZWDсϭϬϬ͕ϮϰϬϬdY͘tKсϮϯϬϬ͕ϭϴϱƉƐŝ ŽĨĨďŽƚƚŽŵ͕ϭϱϬϬdY͘KĨĨŽƚƚŽŵ͘ůĞĂŶĚŝƚĐŚŵĂŐŶĞƚƐĂƐŶĞĞĚĞĚ͘tĂƚĐŚĨŽƌĞdžĐĞƐƐŝǀĞŵĞƚĂůƐŚĂǀŝŶŐƐ͘ tĂƐŚŽǀĞƌϮͲϳͬϴΗƚďŐƉĞƌĂŬĞƌZĞƉ͘&ͬϱϮϱΖdͬϱϰϳΖ͕ϯWD͕ϮϰϭW^/͕ϱϬй&ůŽǁ͕ZWDсϭϬϬ͕ϮϰϬϬdY͘tKсϮϯϬϬ͕ϭϴϱƉƐŝ ŽĨĨďŽƚƚŽŵ͕ϭϱϬϬdY͘KĨĨŽƚƚŽŵ͘ůĞĂŶĚŝƚĐŚŵĂŐŶĞƚƐĂƐŶĞĞĚĞĚ͘tĂƚĐŚĨŽƌĞdžĐĞƐƐŝǀĞŵĞƚĂůƐŚĂǀŝŶŐƐ͘ tĂƐŚŽǀĞƌϮͲϳͬϴΗd'ƉĞƌĂŬĞƌZĞƉ͘&ͬϱϰϳΖdͬϱϱϯΖ͕ϯWD͕ϮϴϬW^/͕ϱϭй&ůŽǁ͕ZWDсϭϬϬ͕ϮϱϬϬdY͘tKсϮϯϬϬ͕ϭϴϱƉƐŝ ŽĨĨďŽƚƚŽŵ͕ϭϱϬϬƚƋ͘KĨĨďŽƚƚŽŵ͘ WKK,&ͬϱϱϯΖdͬ^ƵƌĨ͘DŽŶŝƚŽƌŝŶŐƚŚĞǁĞůů͘>ͬWĂŶĚtĂƐŚƉŝƉĞ͘ƉƉƌŽdž͘ϭϬΖŽĨƚƵďŝŶŐŝŶǁĂƐŚƉŝƉĞ͘ WͬhĂŶĚDͬhŶĞǁ,ƉĞƌĂŬĞƌZĞƉĂŶĚZ/,&ͬ^ƵƌĨ͘dͬϭϯϬΖ͘DhϰͲϭͬϰΗǁĂƐŚŽǀĞƌƐŚŽĞǁŝƚŚϰũŶƚƐŽĨtĂƐŚƉŝƉĞŝŶ ƐƚƌŝŶŐ͘ dŽƚĂů,ŽƵƌƐ͗ ŽŶƚŝŶƵĞǁĂƐŚŽǀĞƌϮϳͬϴΖΖƚďŐ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϴ ϭ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ tĂƐŚŽǀĞƌƚŽϱϱϯΖ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ < ZZ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ Ăů ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ EŽŶĞ<ŶŽǁŶ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ϮϳϲΖ ϭϭηĂů ϯͬϮϴͬϮϬϮϯ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϯϯ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϭϬͲƉƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬͲϭϬ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗Ϯϳ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϰͬϭϬͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϯϬͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ ϭ͕Ϯ dDϯϬ ϯWD ϭ͕ϮϬϬ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ ϭϭ͘ϭ ϭϬϳ ϭϬϳ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ ϭͬϮďďůŵĞƚĂůĐƵƚƚŝŶŐĨŽƌŵŵĂŐŶĞƚƐ ϭϬďďůƐĐĞŵĞŶƚĨƌŽŵƐŚĂŬĞƌ ϭϬ͘ϱďďůƐ Ϯϯ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ LJŶĂŵŝĐ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ϭ ůĞĂƌƌĞĞŬ <Θ ϭϯ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϲ͗ϬϬ͗ϬϬ ϲ͗ϬϬ ϲ͗ϬϬ ϭϮ͗ϬϬ ϲ͗ϬϬ ϭϮ͗ϬϬ ϭϳ͗ϬϬ ϱ͗ϬϬ ϭϳ͗ϬϬ ϭϴ͗ϬϬ ϭ͗ϬϬ ϭϴ͗ϬϬ Ϯϭ͗ϯϬ ϯ͗ϯϬ Ϯϭ͗ϯϬ Ϭ͗ϬϬ Ϯ͗ϯϬ Ϯϰ ZĞŵĂƌŬƐ͗ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ Z/,ĨƌŽŵϭϯϬΖƚŽϱϱϭΖĂŶĚƚĂŐƚƵďŝŶŐ͕ǁŽƌŬƚŚƌŽƵŐŚũƵŶŬƚŽϱϱϯΖ tĂƐŚŽǀĞƌϮͲϳͬϴΗd'ƉĞƌĂŬĞƌZĞƉ&ͬϱϱϯΖdͬϱϲϯΖ͕ϯWD͕ϮϱϬW^/͕ϱϬй&ůŽǁ͕ZWDсϭϬϬ͕ϮϱϬϬdY͕tKсϮϮϬϬ͕ϭϴϬW^/ ŽĨĨ͕ϭϱϬϬdY͕ůĞĂŶDĂŐŶĞƚƐĂƐŶĞĞĚĞĚ͕ŵŽŶŝƚŽƌĨŽƌĐĂƐŝŶŐǁĞĂƌ͘ tĂƐŚŽǀĞƌϮͲϳͬϴΗd'ƉĞƌĂŬĞƌZĞƉ&ͬϱϲϯΖdͬϱϳϬΖ͕ϯWD͕ϮϮϬW^/͕ϱϭй&ůŽǁ͕ZWDсϭϬϬ͕ϮϬϬϬdY͕tKсϮϱϬϬ͕ϭϴϬW^/ ŽĨĨ͕ϭϲϬϬdY͕ůĞĂŶDĂŐŶĞƚƐĂƐŶĞĞĚĞĚ͕ŵŽŶŝƚŽƌĨŽƌĐĂƐŝŶŐǁĞĂƌ͘ KďƐĞƌǀĞZĂƚƚLJƚŽƌƋƵĞĂŶĚŽǀĞƌƉƵůů͘tŽƌŬWŝƉĞĨƌĞĞĂŶĚƉƌĞƉƚŽĐŽŵĞŽƵƚŽĨŚŽůĞ͘ WƵůůĞĚϰũŶƚƐŽĨϯ͘ϱΗW͘;ϱϮϮΖͿ>ŽƐƚĂďŝůŝƚLJƚŽƉŝĐŬƵƉŽƌƐůĂĐŬŽĨĨ͘tŽƌŬĞĚƉŝƉĞĂŶĚĂƚƚĞŵƉƚĞĚƚŽĨƌĞĞŝƚƵƉǁŝƚŚŽƵƚ ƐƵĐĐĞƐƐ͘WĞƌĨŽƌŵZŝŐ/ŶƐƉĞĐƚŝŽŶƐƚŚƌŽƵŐŚŽƵƚ͘ ƌŽƵŐŚƚŝŶǁŝƌĞůŝŶĞƵŶŝƚĂŶĚƉƌĞƉĂƌĞĚƌŝŐĨŽƌǁŝƌĞůŝŶĞŽƉĞƌĂƚŝŽŶƐ͘ dŽƚĂů,ŽƵƌƐ͗ ŽŶƚŝŶƵĞǁĂƐŚŽǀĞƌϮϳͬϴΖΖƚďŐ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϴ ϭ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ tĂƐŚŽǀĞƌƚŽϱϳϬΖ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ < ZZ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ Ăů ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ EŽŶĞ<ŶŽǁŶ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ϮϳϲΖ ϭϭηĂů ϯͬϮϴͬϮϬϮϯ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϯϰ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϭϭͲƉƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬͲϭϬ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗Ϯϴ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϰͬϭϭͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϯϬͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ ϭ͕Ϯ dDϯϬ ϯWD ϭ͕ϮϬϬ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ ϭϭ͘ϭ ϭϬϳ ϭϬϳ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ ϭͬϮďďůŵĞƚĂůĐƵƚƚŝŶŐĨŽƌŵŵĂŐŶĞƚƐ ϭϬďďůƐĐĞŵĞŶƚĨƌŽŵƐŚĂŬĞƌ ϭϬ͘ϱďďůƐ Ϯϯ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ LJŶĂŵŝĐ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ϭ ůĞĂƌƌĞĞŬ <Θ ϭϯ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϲ͗ϬϬ͗ϬϬ ϲ͗ϬϬ ϲ͗ϬϬ ϭϮ͗ϬϬ͗ϬϬ ϲ͗ϬϬ ϭϮ͗ϬϬ ϭϴ͗ϯϬ͗ϬϬ ϲ͗ϯϬ ϭϴ͗ϯϬ Ϭ͗ϬϬ ϱ͗ϯϬ Ϯϰ ZĞŵĂƌŬƐ͗ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ EŽŶĞ<ŶŽǁŶ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ϮϳϲΖ ϭϭηĂů ϯͬϮϴͬϮϬϮϯ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ < ZZ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ Ăů ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ ^ĞƚƌŝĚŐĞƉůƵŐ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϴ ϭ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ WŝƉĞ^ƚƵĐŬĂƚϱϮϮΖ͘ZŝŐƵƉǁŝƌĞůŝŶĞƚŽƉƌĞƉĨŽƌďĂĐŬͲŽĨĨ͘ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ tĂŝƚŽŶǁŝƌĞůŝŶĞĞƋƵŝƉŵĞŶƚ͕tŚŝůĞĐŝƌĐƵůĂƚŝŶŐǁĞůůƐƚĂƌƚĞĚƉĂĐŬŝŶŐŽĨĨ͕ŝƌĐϭͬϮWDϰϬϬƉƐŝ ^/DKW^͗WĞƌĨŽƌŵZŝŐDĂŝŶƚĞŶĂŶĐĞĂŶĚůĞĂŶŝŶŐ dŽƚĂů,ŽƵƌƐ͗ tĂŝƚŽŶǁŝƌĞůŝŶĞĞƋƵŝƉŵĞŶƚ͕tŚŝůĞĐŝƌĐƵůĂƚŝŶŐǁĞůůƐƚĂƌƚĞĚƉĂĐŬŝŶŐŽĨĨ͕ŝƌĐϭͬϮWDϰϬϬƉƐŝ ^/DKW^͗ŚĞĐŬŽŝůŝŶEŐĞŶĞƌĂƚŽƌƐ͕ƉĞƌĨŽƌŵƌŝŐŵĂŝŶƚĞŶĂŶĐĞĂŶĚĐůĞĂŶŝŶŐ͕ƉƌĞƉĨŽƌƉůĂŶĨŽƌǁĂƌĚ͕ǁĂƌŵƵƉƉŽůůĂƌĚ ǁŝƌĞůŝŶĞƵŶŝƚ͘ ǁĂŝƚŽŶǁŝƌĞůŝŶĞĞƋƵŝƉŵĞŶƚ͕tŚŝůĞĐŝƌĐƵůĂƚŝŶŐǁĞůůƐƚĂƌƚĞĚƉĂĐŬŝŶŐŽĨĨ͕ŝƌĐϭͬϮWDϰϬϬƉƐŝ ^/DKW^͗ůĞĂŶƵƉĂƌŽƵŶĚƐƚƌƵĐƚƵƌĞ͕ŐĂƚŚĞƌƵƉĂŬĞƌƚŽŽůƐƚŽƐŚŝƉŽƵƚ͕ƉĞƌĨŽƌŵĚĞƌƌŝĐŬĂŶĚĐƌŽǁŶŝŶƐƉĞĐƚŝŽŶ͘ŝƌĐ͘ŶĚ ŵŽŶŝƚŽƌƚŚĞǁĞůů͘ ^ƚĂŐĞǁŝƌĞůŝŶĞƚŽŽůƐĂŶĚŚĂŶĚůŝŶŐĞƋƵŝƉŵĞŶƚ͘ZŝŐƵƉ< Ϭ>ŝŶĞǁŝƌĞůŝŶĞ͕ŵĂŬĞƵƉƐƚƌŝŶŐƐŚŽŽƚ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϯϱ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϭϮͲƉƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬͲϭϬ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗Ϯϵ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϰͬϭϮͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϯϬͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ ϭ͕Ϯ dDϯϬ ϯWD ϭ͕ϮϬϬ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ ϭϭ͘ϭ ϭϬϳ ϭϬϳ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ ϭͬϮďďůŵĞƚĂůĐƵƚƚŝŶŐĨŽƌŵŵĂŐŶĞƚƐ ϭϬďďůƐĐĞŵĞŶƚĨƌŽŵƐŚĂŬĞƌ ϭϬ͘ϱďďůƐ Ϯϯ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ LJŶĂŵŝĐ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ϭ ůĞĂƌƌĞĞŬ <Θ ϭϯ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϭ͗ϬϬ͗ϬϬ ϭ͗ϬϬ ϭ͗ϬϬ Ϯ͗ϬϬ ϭ͗ϬϬ Ϯ͗ϬϬ ϯ͗ϬϬ ϭ͗ϬϬ ϯ͗ϬϬ ϰ͗ϬϬ ϭ͗ϬϬ ϰ͗ϬϬ ϲ͗ϬϬ Ϯ͗ϬϬ ϲ͗ϬϬ ϵ͗ϬϬ ϯ͗ϬϬ ϵ͗ϬϬ ϭϬ͗ϬϬ ϭ͗ϬϬ ϭϬ͗ϬϬ ϭϰ͗ϬϬ ϰ͗ϬϬ ϭϰ͗ϬϬ ϭϲ͗ϬϬ Ϯ͗ϬϬ ϭϲ͗ϬϬ ϭϴ͗ϬϬ Ϯ͗ϬϬ ϭϴ͗ϬϬ ϮϬ͗ϯϬ Ϯ͗ϯϬ ϮϬ͗ϯϬ Ϭ͗ϬϬ ϯ͗ϯϬ Ϯϰ ZĞŵĂƌŬƐ͗ WƵŵƉϳ͘ϴďďůƐ;ϭϲ͘ϬηĚĞŶƐŝƚLJͿĐĞŵĞŶƚƵƐŝŶŐĐĞŵĞŶƚƉƵŵƉ͕ŝƐƉůĂĐĞǁŝƚŚ͘ϱďďůƐďƌŝŶĞƵƐŝŶŐƌŝŐƉƵŵƉ͕ĞŵĞŶƚŝŶƉůĂĐĞ ĂƚϮϬ͗ϯϬ͕WKK,ǁŝƚŚĐĞŵĞŶƚƐƚƌŝŶŐ ŚĂŶŐĞŽǀĞƌŚĂŶĚůŝŶŐĞƋƵŝƉŵĞŶƚ͕Z/,ǁŝƚŚϭ͘ϵϬƉŝƉĞ͕ƚĂŐƉůƵŐĂƚϯϵϮΖ DĂŬĞƵƉƌŝĚŐĞƉůƵŐ͕ZƵŶŝŶŚŽůĞ&ͬ^ƵƌĨ͘dͬϯϵϱΖĂŶĚƚĂŐΛdK&;ϯϵϴΖͿ͕ƉŝĐŬƵƉϯΖ;ϯϵϱΖͿ͕ƉŝĐŬƵƉϯΖƚŽƐĞƚƚŝŶŐĚĞƉƚŚ ŽŶĨŝƌŵƐĞƚƚŝŶŐĚĞƉƚŚǁŝƚŚƚŽǁŶ͕ŵĂŬĞƵƉϭϬΖũŽŝŶƚƐŽĨϭ͘ϵϬΗƉŝƉĞŝŶƚŽϯϬΖũŽŝŶƚƐŽŶƉŝƉĞƌĂĐŬ͘ WƵůůŽƵƚŽĨŚŽůĞǁŝƚŚϯ͘ϱΗWĨͬϯϵϮΖƚͬƐƵƌĨĂĐĞ͕ŝŶƐƉĞĐƚZƵŶŶŝŶŐƚŽŽů 'Ğƚ/^KƚĂŶŬƐƐƉŽƚƚĞĚ͘ůŽǁŽǁŶƐƵĐƚŝŽŶĂŶĚŵƵĚƉƵŵƉƐ͘>ŽĂĚĂŬĞƌďĂƐŬĞƚ͘ůĞĂŶĂŶĚĐůĞĂƌƚŽƉŽĨƉŝƚƐ͘ZĞŵŽǀĞ ĨůŽǁůŝŶĞ͘WƵŵƉŽƵƚƉŝƚƐŝŶƚŽ/^KƚĂŶŬƐ dŽƚĂů,ŽƵƌƐ͗ ĂĐŬŽĨĨWĨƌŽŵ&ŝƐŚ͕^Ğƚ/W͕ĞŵĞŶƚϮϬϬΖƉůƵŐŝŶƐŝĚĞϳΖΖĐĂƐŝŶŐ tŝƚŚ ͲůŝŶĞ͗Z/,͕ƐĞƚĐŚĂƌŐĞĂƚϯϵϴΖ͕ĂĐŬŽĨĚƌŝůůƉŝƉĞĂƚϯϵϴΖ WKK,ǁͬϯϵϴΖŽĨϯ͘ϱΗW͘EŽdžͲŽǀĞƌŽƌtĂƐŚƉŝƉĞ͘ ^ĞƚWĂĐŬĞƌĂƚϯϵϮΖ͕ƉƌĞƐƐƵƌĞƐĞƚĂƚϭ͕ϮϬϬƉƐŝ ZŝŐƵƉƚŽĐŝƌĐƵůĂƚĞ͕ƌŝŐƵƉĐĞŵĞŶƚƉƵŵƉ͕ďƌĞĂŬĐŝƌĐƵůĂƚŝŽŶ͕ϭWDсϰϱW^/ ƌŝŶŐϭϭ͘ϰϱΖĐĂƐƚŝƌŽŶďƌŝĚŐĞƉůƵŐdͬƌŝŐĨůŽŽƌ͘'Ğƚ/ͬ͘K͕͘ůĞŶŐƚŚ͘dY͘yͲŽǀĞƌĂŶĚĐŽŶŶĞĐƚŝŽŶƐƉĞƌŵĂŶƵĨĂĐƚƵƌĞƐƉĞĐƐ͘ ϴ ϭ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ DĂŬĞƵƉƐƚƌŝŶŐƐŚŽƚ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ < ZZ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ Ăů ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ tĂŝƚŽŶĐĞŵĞŶƚ EŽŶĞ<ŶŽǁŶ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ϮϳϲΖ ϭϭηĂů ϯͬϮϴͬϮϬϮϯ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϯϲ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϭϯͲƉƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬͲϭϬ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϯϬ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϰͬϭϯͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϯϬͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ ϭ͕Ϯ dDϯϬ ϯWD ϭ͕ϮϬϬ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ ϭϭ͘ϭ ϭϮϬďďůƐ ϲďďůƐ ϭϳďďůƐ ϭϰϯďďůƐ Ϯϯ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ LJŶĂŵŝĐ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ϭ ůĞĂƌƌĞĞŬ <Θ ϭϯ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϲ͗ϬϬ͗ϬϬ ϲ͗ϬϬ ϲ͗ϬϬ ϭϮ͗ϬϬ ϲ͗ϬϬ ϭϮ͗ϬϬ ϭϴ͗ϬϬ ϲ͗ϬϬ ϭϴ͗ϬϬ Ϭ͗ϬϬ ϲ͗ϬϬ Ϯϰ ZĞŵĂƌŬƐ͗ ϮϳϲΖ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ ϭϭηĂů ϯͬϮϴͬϮϬϮϯ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ < ZZ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ ϴ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ ůĂƐƐůů͗ĂůďƌŝŶĞ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ tK ^/DKW^͗>ŽǁĞƌZŝŐ͘ZͬŚŽŬĞŵĂŶŝĨŽůĚ͕ŵƵĚŵĂŶŝĨŽůĚ͕ĐůĞĂƌƌŝŐĨůŽŽƌ͕ůŽǁĞƌĂůƵŵŝŶƵŵƐƵƉƉŽƌƚƐ͕ƌĞŵŽǀĞƌŽƚĂƚŝŶŐ ŚĞĂĚ͕ƐĐŽƌƉŝŽŶƐ͘ ϭ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ tK͕ZŝŐŽǁŶZŝŐ dĞƐƚĐĞŵĞŶƚ͕ZŝŐĚŽǁŶZŝŐ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ tK ^/DKW^͗WƵŵƉŽƵƚƉŝƚƐŝŶƚŽ/^KƐƚŽƌĂŐĞƚĂŶŬƐ͘ZĞŵŽǀĞYƵĂĚĐŽƐĐƌĞĞŶƐĂŶĚƐĞŶƐŽƌƐĂŶĚƐƚŽƌĞƉƌŽƉĞƌůLJ͘ůĞĂƌŝŶŐƌŝŐ ĨůŽŽƌ͕ƉŝƚƐĂŶĚĐĞůůĂƌĂƌĞĂƐŽĨƵŶŶĞĞĚĞĚƚŽŽůƐĂŶĚĞƋƵŝƉ͘ŽŶƚŝŶƵĞƌŝŐŐŝŶŐĚŽǁŶĨůĂƌĞůŝŶĞ͘ tK ^/DKW^͗ŽŶƚ͘ZŝŐŐŝŶŐĚŽǁŶWŝƚƐ͕ZŝŐĚŽǁŶŐĂƐĚĞƚĞĐƚŝŽŶƐLJƐƚĞŵ͕ƌŝŐĚŽǁŶĐĞŶƚƌŝĨƵŐĂůƉƵŵƉƐĂŶĚŵƵĚƉƵŵƉƐ͕ƉŝĐŬƵƉ ĂŶĚƐƚŽƌĞƚŽŽůƐĂŶĚĞƋƵŝƉ͕͘WƌĞƉEŐĞŶĨŽƌƚƌĂŶƐƉŽƌƚ͕ďƌĞĂŬĚŽǁŶϭ͘ϵϬƉŝƉĞ͕ƌŝŐĚŽǁŶƐĐŽƌƉŝŽŶƚŽŶŐƐ tK ^/DKW^͗ZŝŐĚŽǁŶďĞĂǀĞƌƐůŝĚĞ͕ƉŝƉĞƌĂĐŬƐĂŶĚĐĂƚǁĂůŬ͕ŵŽǀĞĂůůƉŝƉĞŽƵƚƐŝĚĞĂŶĚƐƚĂŐĞĨŽƌƚƌĂŶƐƉŽƌƚ͕ƐƚŽƌĞĂůůƚƌĂŶƐĨĞƌ ŚŽƐĞƐ͕ƌŝŐĚŽǁŶĂŶĚĚƌĂŝŶŵƵĚƉƵŵƉƐ͕ƐƚĂŐĞŚĂŶĚŝŶŐĞƋƵŝƉŝŶKK^ŽŶŶĞdž dŽƚĂů,ŽƵƌƐ͗ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϯϳ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϭϰͲƉƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬͲϭϬ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϯϭ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϰͬϭϰͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϯϬͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ ϭ͕Ϯ dDϯϬ ϯWD ϭ͕ϮϬϬ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ ϭϭ͘ϭ ϭϮϬďďůƐ ϲďďůƐ ϭϳďďůƐ ϭϰϯďďůƐ Ϯϯ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ LJŶĂŵŝĐ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ϭ ůĞĂƌƌĞĞŬ <Θ ϭϯ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϲ͗ϬϬ͗ϬϬ ϲ͗ϬϬ ϲ͗ϬϬ ϵ͗ϬϬ ϯ͗ϬϬ ϵ͗ϬϬ ϭϭ͗ϬϬ Ϯ͗ϬϬ ϭϭ͗ϬϬ ϭϮ͗ϬϬ ϭ͗ϬϬ ϭϮ͗ϬϬ ϭϯ͗ϬϬ ϭ͗ϬϬ ϭϯ͗ϬϬ ϭϴ͗ϬϬ ϱ͗ϬϬ ϭϴ͗ϬϬ Ϭ͗ϬϬ ϲ͗ϬϬ Ϯϰ ZĞŵĂƌŬƐ͗ >ŽǁĞƌĚĞƌƌŝĐŬ͕ĚĞƌƌŝĐŬĚŽǁŶĂƚϭϮ͗ϰϱƉŵ ZĞŵŽǀĞĚĞƌƌŝĐŬ͕ĐƵƚƉŽǁĞƌƚŽƌŝŐƵŶƉůƵŐĂŶĚƌŝŐĚŽǁŶĚŝƐƚƌŝďƵƚŝŽŶƉĂŶĞůƐĂŶĚůŽĂĚŽŶEŐĞŶƚƌĂŝůĞƌƐ͘ZŝŐĚŽǁŶĨůŽŽƌ ĞƋƵŝƉ͘ĂŶĚƐƚĂŐĞĨŽƌƚƌĂŝůĞƌƐ͘ ZͬĨůŽŽƌƐĞĐƚŝŽŶƐĂŶĚƐƚĂŐĞĨŽƌůŽĂĚŝŶŐ͘ZĞŵŽǀĞƐƚĂŝƌƐ͘ŽŝůƵƉŚLJĚƌĂƵůŝĐŚŽƐĞƐĨŽƌůŝĨƚũĂĐŬƐ͘^ŚƵƚĚŽǁŶ'ĞŶĞƌĂƚŽƌĂŶĚ ůŽĂĚƚƌĂŝůĞƌǁͬYƵĂĚĐŽƚŽŽůƐĂŶĚĞƋƵŝƉŵĞŶƚ͕ϯ͘ϱΗW͕ĚŝƐƚƌŝďƵƚŝŽŶƉĂŶĞůƐĞƚĐ͘ dŽƚĂů,ŽƵƌƐ͗ KƉĞŶƵƉĨůLJŽŶƐƚƌƵĐƚƵƌĞĨŽƌĚĞƌƌŝĐŬ͘ ϭ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ tK͕dĞƐƚϮϬϬΖƉůƵŐƚŽϱϬϬƉƐŝ;ƉĂƐƐĞĚͿ͕ZŝŐŽǁŶZŝŐ ^ƵƌĨĂĐĞĐĞŵĞŶƚƉůƵŐ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ tK ^/DKW^͗ůĞĂƌƌĞŵĂŝŶŝŶŐŝƚĞŵƐŽĨĨƌŝŐĨůŽŽƌ͘ůĞĂŶĂŶĚĐůĞĂƌƐƚƌƵĐƚƵƌĞŽĨŵŝƐĐƚŽŽůƐĂŶĚĞƋƵŝƉ͘dƌĂŝůĞƌƐĂƌƌŝǀĞĚϭD͘ >ŽĂĚŝŶŐƚƌĂŝůĞƌƐ͘>ŽĂĚϮĂŶĚŚĂůĨ>LJŶĚĞŶƚƌĂŝůĞƌƐǁŝƚŚƉŝƚƐ͕ĐĂƚǁĂůŬ͕ƉŝƉĞƌĂĐŬƐ͕ďĞĂǀĞƌƐůŝĚĞ͕ŵƵĚƉƵŵƉĂŶĚĐĞŶƚƌŝĨƵŐĂů ƉƵŵƉƐ tK ^/DKW^͗ĚũƵƐƚůŽĂĚƐŽŶƚƌĂŝůĞƌƐĨŽƌ>LJŶĚĞŶĚƌŝǀĞƌƐ͕ĐŚĂŶŐĞŽƵƚĚĞƌƌŝĐŬĐLJůŝŶĚĞƌĂŶĚƚŝŵĞĂƐƉĂŝƌ ZŝŐƵƉƚĞƐƚĞƋƵŝƉĂŶĚĂŝƌŽƵƚůŝŶĞƐ͕ƉƌĞƐƐƵƌĞƚĞƐƚϳΗĐĂƐŝŶŐƚŽƚŚĞƚŽƉŽĨƚŚĞĐĞŵĞŶƚƉůƵŐĂƚ; ƐƚŝŵĂƚĞĚdKнͬͲϭϵϰΖͿƚŽ ϱϬϬƉƐŝĨŽƌϯϬŵŝŶͲŐŽŽĚƚĞƐƚ͘ WƌĞƉƌŝŐĨůŽŽƌƚŽůĂLJĚĞƌƌŝĐŬŽǀĞƌ ϴ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ ůĂƐƐůů͗ĂůďƌŝŶĞ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϭϭηĂů ϯͬϮϴͬϮϬϮϯ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ < ZZ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ ϮϳϲΖ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϯϴ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϭϱͲƉƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ WŚŽŶĞη͗ϮϴϭͲϲϭϱͲϭϰϬϴ tŝŶĚŝƌĞĐƚŝŽŶ͗ >DWD͗ůůŝĞ^ĐŚŽĞƐƐůĞƌ tŝŶĚ'ƵƐƚƐ;ŵƉŚͿ͗ >DW/͗ dĞŵƉ͘;>Žǁ͕,ŝŐŚͿ͗ϬͲϭϬ d͗ '>͕Ĩƚ͗ WůĂŶŶĞĚĂLJƐ͗ŶͬĂ Wd͗ Z<͕Ĩƚ͗ϭϮ ^ƚĂƌƚĂƚĞ͗ϮϭͲ&ĞďͲϮϯ &ůƵŝĚŝŶtĞůů͗ K,/͕ŝŶ͗ŶͬĂ KƉĞƌĂƚŝŽŶĂLJƐ͗ϯϮ >ĂƐƚKWdĞƐƚ͗ >ĂƐƚ^ĂĨĞƚLJDƚŐ͗ϰͬϭϱͬϮϬϮϯ >ĂƐƚ ǀĂĐƌŝůů͗ϯͬϯϬͬϮϬϮϯ ƐŐ^ƚƌŝŶŐ K;ŝŶͿ ĞƉƚŚ;ĨƚͿ tĞŝŐŚƚ;ηͬĨƚͿ ŽŶĚƵĐƚŽƌ͗ ϭϲΗ ϭϰϵ ϳϱ ^ƵƌĨĂĐĞ͗ ϭϬͲϯͬϰΗ ϭ͕ϭϵϬ ϱϭ WƌŽĚƵĐƚŝŽŶ͗ ϳΗ ϭ͕ϮϳϬ Ϯϯ WƵŵƉη DŽĚĞů ZĂƚĞ;WDͿ WƌĞƐƐƵƌĞ;ƉƐŝͿ ϭ͕Ϯ dDϯϬ ϯWD ϭ͕ϮϬϬ tĞŝŐŚƚ;ƉƉŐͿ sŽůƵŵĞ;ďďůƐ͘Ϳ tĞŝŐŚƚ;ƉƉŐͿ ĂŝůLJsŽůƵŵĞ;ďďůƐ͘Ϳ ϭϭ͘ϭ ϭϮϬďďůƐ ϭϮďďůƐ ϭϳďďůƐ ϭϰϵďďůƐ Ϯϯ ŽŵƉĂŶLJ ŽŵƉĂŶLJ ηWĞŽƉůĞ ŽŵƉĂŶLJ ηWĞŽƉůĞ KůŐŽŽŶŝŬ LJŶĂŵŝĐ >D ^ĂůĂ K' ƌƚŝĐĂƚĞƌŝŶŐ ϭ ůĞĂƌƌĞĞŬ <Θ ϭϯ Ϯϰ,ŽƵƌ ^ƵŵŵĂƌLJ͗ Ϯϰ,ŽƵƌ &ŽƌĞĐĂƐƚ͗ ,^ ^ƵŵŵĂƌLJ͗ &ƌŽŵ dŽ ,ŽƵƌƐ Ϭ͗ϬϬ ϰ͗ϬϬ͗ϬϬ ϰ͗ϬϬ ϰ͗ϬϬ ϲ͗ϬϬ͗ϬϬ Ϯ͗ϬϬ ϲ͗ϬϬ ϴ͗ϯϬ͗ϬϬ Ϯ͗ϯϬ ϴ͗ϯϬ ϭϬ͗ϯϬ͗ϬϬ Ϯ͗ϬϬ ϭϬ͗ϯϬ ϭϮ͗ϯϬ Ϯ͗ϬϬ ϭϮ͗ϯϬ ϭϯ͗ϯϬ ϭ͗ϬϬ ϭϯ͗ϯϬ ϭϱ͗ϬϬ ϭ͗ϯϬ ϭϱ͗ϬϬ ϭϴ͗ϬϬ ϯ͗ϬϬ ϭϴ͗ϬϬ Ϭ͗ϬϬ ϲ͗ϬϬ Ϯϰ ZĞŵĂƌŬƐ͗ ŽŶƚŝŶƵĞŵŽǀŝŶŐƌŝŐĐŽŵƉŽŶĞŶƚƐŽƵƚŽĨƐƚƌƵĐƚƵƌĞ ZĞŵŽǀĞĂůůƚŽŽůƐĂŶĚĞƋƵŝƉŵĞŶƚĨƌŽŵƐƚƌƵĐƚƵƌĞĂŶĚƐƚŽƌĞƉƌŽƉĞƌůLJ͕ĐůĞĂŶƵƉĂůůƚƌĂƐŚĂŶĚǁŽŽĚ͘ dŽƚĂů,ŽƵƌƐ͗ ůĞĂŶƵƉĂŶĚƉƵƚĂǁĂLJĐĞŵĞŶƚŝŶŐĞƋƵŝƉŵĞŶƚĂŶĚƉŝƉĞ ϭ KƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ ZZŝŐ͕WĞƌĨŽƌŵĐĞŵĞŶƚũŽďĨƌŽŵϯϭϲΖƚŽƐƵƌĨĂĐĞ͕ŽŶƚŝŶƵĞƚŽZZŝŐ ƵƚǁĞůůŚĞĂĚŽĨĨ EŽ^ƉŝůůƐ͕EŽ/ŶũƵƌŝĞƐ͕EŽ/ŶĐŝĚĞŶƚƐ KƉĞƌĂƚŝŽŶĂůĞƚĂŝůƐ;ϲ͗ϬϬͲϲ͗ϬϬͿ ZͬĐƌŽƐƐŵĞŵďĞƌƐĂŶĚƐƚĂŐĞĨŽƌůŽĂĚŝŶŐ͘ŽŝůƵƉĂŶĚƉĂĐŬŬŽŽŵĞLJŚŽƐĞƐ͘ WƵŵƉϭϮďďůƐĐĞŵĞŶƚ;ϭϱ͘ϴηĚĞŶƐŝƚLJͿ͕ϭWDϮϬϬƉƐŝ͕ϭďďůĐĞŵĞŶƚƌĞƚƵƌŶƐ WƵůůKƵƚŽĨŚŽůĞĂŶĚůĂLJĚŽǁŶǁŽƌŬƐƚƌŝŶŐ EŝƉƉůĞŽǁŶ^ƚĂĐŬĂŶĚƉƵƚŽŶƉĞĚĞƐƚĂůĨŽƌƚƌĂŶƐƉŽƌƚ͘ ZŝŐƵƉŽŶǁĞůůŚĞĂĚǁŝƚŚĨĂůƐĞƚĂďůĞ Z/,ƚŽϭ͘ϵϬΗĐĞŵĞŶƚƐƚƌŝŶŐƚŽϯϭϲΖ͕ƚĂŐdKĨƌŽŵWůƵŐηϭĂƚϯϭϲΖ ϴ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ tĂƐƚĞ&ůƵŝĚƐ &ůƵŝĚdLJƉĞ ůĂƐƐůů͗ĂůďƌŝŶĞ >^^/͗ĞŵĞŶƚZŝŶƐĂƚĞ >^^//͗ĞŵĞŶƚZĞƚƵƌŶƐ ƵŵƵůĂƚŝǀĞsŽůƵŵĞ;ďďůƐͿ͗ WĞƌƐŽŶŶĞů WĞƌƐŽŶŶĞůŽŶŽĂƌĚ͗ ηWĞŽƉůĞ ϭϭηĂů ϯͬϮϴͬϮϬϮϯ /ŶƚĞŐƌŝƚLJ/ƐƐƵĞƐ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ EŽŶĞ<ŶŽǁŶ WƵŵƉWĂƌĂŵĞƚĞƌƐ dLJƉĞ < ZZ DƵĚͬƌŝŶĞWƌŽƉĞƌƚŝĞƐ &ůƵŝĚdLJƉĞ ϮϳϲΖ ĂŝůLJKƉĞƌĂƚŝŽŶƐZĞƉŽƌƚ /ŬŽĂLJηϭ 'ĂƐtĞůů džƉůŽƌĂƚŝŽŶ EWZ ŽŶƚĂĐƚƐ tĞĂƚŚĞƌ /ĐĞ&ŽŐ͕KǀĞƌĐĂƐƚ tĞƐƚ ϵͲϭϭDW, tĞůů^ƚĂƚƵƐ Ϯ͕ϳϯϭ KZ/ŬŽĂLJϭ tĞůůEĂŵĞ͗ KƉĞƌĂƚŽƌ͗>D ZĞƉŽƌƚη͗ϯϵ tĞůůdLJƉĞ͗ W/η͗ ZĞƉŽƌƚĂƚĞ͗ϭϲͲƉƌͲϮϯ &ŝĞůĚ͗ Wdη͗ ŽŶƚƌĂĐƚη͗ ^ƵƉĞƌǀŝƐŽƌ͗^ŚĂŶĞDĐ'ĞĞŚĂŶ WŚŽŶĞη͗ϴϬϭͲϱϱϲͲϬϵϰϲ 'ĞŶ͘ŽŶĚŝƚŝŽŶƐ͗ WĞƚƌ͘ ŶŐ͗͘ĂĐŚ^ĂLJĞƌƐ 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Date 04.17.2023 Start Time 0800 End Time 1100 Well Name Iko Bay #1 Rep on Site Contractor: Shane McGeehan BLM: Quinn Sawyer Temperature 0F Min: -18° F Max: 1° F Weather Conditions Clear, W wind 10-15 mph Project Status (24 Hour Summary) Crews change to 12 hour operations. BLM representative off-site for remainder of project. Narrative Report (please submit pictures with report) Today crew’s swapped to 12 hour operations, working from noon until midnight. Rigging down The Tent and packing it up into connexes requires 10-12 man crews, and therefore it was necessary to get all personnel working the same shift. AK Drilling and Completions and Ridgeline made the decision that noon to midnight would be a benefical shift due to warmer temperatures during this time of day making The Tent easier to work with. Approxiametly 75% of The Tent had been rigged down and moved away from the well area. The sections removed have been drug off to the side in flat areas where it will be easier to work with them to roll up and pack away. The cellar area remains covered with plywood and it could be a couple days before further dirt work is completed (Figure 1). The future excavation plan is shown below in Figure 2. The dark yellow area is what has already been excavated around the well. The lighter yellow area requires excavation 1.5’ deeper than previously done, and the purple area requires excavation 3’ deeper. There is already around a dozen supersacks of clean fill and a pile of clean fill that has been brought in from Utqiagvik. Additional clean fill is being hauled in to ensure there is enough volume to backfill the excavation and mound five yards of clean fill over the well. At 1230 I departed the Iko Bay camp heading for Utqiagvik and a flight back to Anchorage. This is the final BLM legacy well report of the 2023 winter season. See page below for pictures. Signature: Title: QUINN SAWYER Petroleum Engineering Technician 2 Figure 1: Iko Bay #1 cellar covered with plywood, The Tent is removed from this portion Figure 2: Excavation plan to remove further contaminated soils 1 Legacy Well Site Inspection – Daily Report Contract No: 140L0622F0256 Contract Name: Iko Bay Contractor: Olgoonik Oilfield Services Date 04.16.2023 Start Time 0700 End Time 1830 Well Name Iko Bay #1 Rep on Site Contractor: Shane McGeehan BLM: Quinn Sawyer Temperature 0F Min: -12° F Max: -1° F Weather Conditions Clear, N wind 5-15 mph with gusts up to 22mph Project Status (24 Hour Summary) Cut off starting head and all casing to 4’ BGL. Topped off 5.5’ of cement in 7” casing, all other annuli have cement to surface. Welded on marker plate. Deflated The Tent and began rigging down for transport. Narrative Report (please submit pictures with report) At 0700 the water/brine on top of the surface cement plug had been pumped out and I tagged top of cement 10.3’ below the starting head. Rig crew dewatered the remainder of the cellar into 275 gallon IBC totes and removed all of the boards and plywood covering the cellar area. Lynden arrived with two more piston bullies to haul trailers loaded with rig components to Deadhorse. After lunch the starting head was cut off using a cutting torch and the 7” production ca sing was cut down to 4’ BGL. The 10-3/4” suface casing and the 16” conductor were also cut down to 4’ BGL. The 24” suface jacket had previously been cut down a few inches lower than the 16” conductor and did not require any further cutting. After the cut-off cement in the 7” production casing was measured to be 5.5’ below the cut off depth (Figure 1). All other annuli where already filled with cement to surface (Figure 2). The 7” casing was topped off with 9 gallons of permafrost cement (Figure 3). The 16” conductor casing was cleaned up with a grinder and a ¼’ thick steel plate was welded over the top of the cut-off casing. A weep hole was left in the cover plate per regulation. A name plate was attahced to the cover plate with the following information (Figure 4): Iko Bay #1 U.S. Navy API # 50-023-20007-00-00 PTD #100 036 Coordinates for the Iko Bay #1 wellsite are: 71° 10’ 17.10” N, 156° 10’ 26.63” W. At 1630 The Tent was deflated and wellsite personnel began to rig down The Tent, beginning with the cables and eye-bolts that tie together all of the pieces (Figure 5). By 1830 the western section of the top cover that includes the smaller 15’ door was being rolled up for transport. See pages below for pictures. Signature: Title: QUINN SAWYER Petroleum Engineering Technician 2 Figure 1: Cement in the 7" production casing, 5.5' below the cut-off depth Figure 2: All annuli filled with cement to surface 3 Figure 3: 7" prodcution casing topped off with cement Figure 4: Iko Bay #1 name plate welded on 4 Figure 5: Rigging down the cables and eye-bolts on deflated tent 1 Legacy Well Site Inspection – Daily Report Contract No: 140L0622F0256 Contract Name: Iko Bay Contractor: Olgoonik Oilfield Services Date 04.15.2023 Start Time 0700 End Time 2000 Well Name Iko Bay #1 Rep on Site Contractor: Shane McGeehan BLM: Quinn Sawyer Temperature 0F Min: -14° F Max: -3° F Weather Conditions Clear, N wind 5-10 mph with occasional gusts up to 20mph Project Status (24 Hour Summary) Tag bottom cement plug at 316’ RKB. Pump surface cement plug, cement returns to surface. Narrative Report (please submit pictures with report) Overnight rig crews nippled down BOP and accumulator and the rest of the rig apart from the substructure (Figure 1). At 0800 nippled up flow pan on the starting head and rigged up hoses to take returns from the 2” valve on the starting head and into plastic totes. Ran in hole with 23 joints of 1.9” worsktring without tagging the bottom cement plug. Set slips and rigged up a circulating head on the workstring to break circulation. Circulation was achieved demonstrating that the workstring was not being ran into green cement. After lunch an additional 7 joints of tubing were ran in hole and the top of the cement plug was tagged at a depth of 316’ RKB. The workstring was picked up 2’ off bottom and the circulating head was attached to enable the surface cement plug job to pumped. At 1315 began mixing 4 supersacks (~16 bbls) of permafrost cement in batch mixer for the surface plug (Figure 2). A sample was taken at and the weight was 15.8 ppg (Figure 3). 12 bbls were pumped down the workstring with returns up the 1.9” x 7” annulus before consistent cement returns were observed at surface. At 1430 cement job was completed and rig crew began tripping pipe out of hole. Wellsite crew began cleaning up cementing equipement and batch mixer. UIC arrived with two piston bullies to collect more trailers of the rig components and hauled it off to Deadhorse (Figure 5). By 2000 this evening the rig had been completely removed from The Tent along with most of the other support equipment and parts (Figure 6). See pages below for pictures. Signature: Title: QUINN SAWYER Petroleum Engineering Technician 2 Figure 1: BOPs ND, fluid level is at the top of the starting head Figure 2: Mixing cement for surface plug 3 Figure 3: Surface cement plug sample weighing 15.8 ppg Figure 4: UIC loading up their trailer with the accumulator and power panel 4 Figure 5: The Tent almost empty and ready to be rigged down From:Schoessler, Allie M To:McLellan, Bryan J (OGC); Rixse, Melvin G (OGC); Regg, James B (OGC) Subject:Re: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Date:Friday, April 14, 2023 3:05:51 PM Attachments:image001.png 12APR2023.pdf 13APR2023.pdf 11APR2023.pdf Bryan, Here are the last few reports: The plan went as described on Wednesday. The first cement plug was tested today and passed. Should be pumping cement to surface this evening. Have a good weekend, Allie From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Wednesday, April 12, 2023 9:00 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Chmielowski, Jessie L C (OGC) <jessie.chmielowski@alaska.gov>; Brumbaugh, Robert <rbrumbau@blm.gov>; Svejnoha, Wayne <wsvejnoh@blm.gov> Subject: Re: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Bryan, Here is a recap of our discussion for next steps at Iko: Due to shallow depth using jars to fish is not an option. Received updated information from site and the top of the fish is at397' 1. Set plug at 392' (5 feet above top of fish) 2. Pump plug #1 - 8 bbls of cement (~200' plug) 3. Wait 36-48 hours for cement to set then test to 500 psi attempt to hold 30 minutes (charted) 4. Set DP weight on plug and confirm depth 5. Pump plug #2 to surface 6. RD surface equipment 7. Cut and weld cap Please let me know if you have any further questions, Allie From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, April 12, 2023 8:12 AM To: Schoessler, Allie M <aschoessler@blm.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Chmielowski, Jessie L C (OGC) <jessie.chmielowski@alaska.gov> Subject: RE: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports There’s no option to fish the remaining BHA with jars? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Wednesday, April 12, 2023 8:04 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: Re: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Good morning Bryan, Overnight we started to have decreased circulation rates indicating junk starting pack off the well. This removed our option to pump the lubricant to free the entire BHA. They ran in with wireline and backed of the drill pipe the crossover at 398' RKB. This leaves us only one option of setting a 7" plug/packer at 370' then pumping cement. We are available to call and talk about this before we proceed with any of the plugging steps. Allie From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Tuesday, April 11, 2023 9:01 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: Re: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Bryan, Here is yesterdays report and the current situation update. Yesterday evening the mill reached a depth of 570'. Started to torque up and have difficulty making progress. We worked the pipe for a while then made the decision to TOOH and investigate. Have difficulties TOOH, work pipe and remove 4 joints of Drill Pipe. Get to 505' and unable to continue OOH. Work pipe for several hours. Current status is the pipe is stuck at 505'. Plan forward is to pump lubricant as the first method to free up the pipe. The second option is to back off the wash pipe. We will keep you updated as we work on getting the pipe out of the hole. Once we get out of hole with either the current full BHA or just the drill pipe the next steps will be setting a plug. Please let me know if you have any questions. I will be traveling back to Anchorage this afternoon/evening so my service will be limited. Allie From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Monday, April 10, 2023 11:37 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: Re: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Bryan, Here is the report for 04-09-2023. Finally go through the tough section from 506' - 516' then TOOH and found 4 chunks of tubing wedged in the end of the wash pipe and the mill was completely worn down. Ran in with a new mill last night. As of 1100 4-10-2023 Current mill depth: 564' Current depth cleared of tubing: ~ 516' Let me know if you have any questions prior to this afternoons meeting, Allie From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Sunday, April 9, 2023 10:05 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: Re: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Bryan, Here is yesterdays report. Made some good progress this morning after milling thought the junk piled up from 506'-516'. Milled to 538' as of 0915 this morning. Allie From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Saturday, April 8, 2023 11:21 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: Re: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Bryan, Here is yesterdays report. We recovered 3 JTS of tubing this morning down to ~500'. Currently RIH with mill assembly to continue down. Allie From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Friday, April 7, 2023 2:36 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: Re: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Bryan, Here is yesterdays report, having internet issues today so its a bit later than I anticipated. Milled to 516' overnight, did not pull any tubing to surface. Indications showed that tubing was most likely not mangled and the crew ran in with a cutter early this morning. Allie From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Thursday, April 6, 2023 4:59 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: Re: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Bryan, Here is yesterdays report. Currently milled down to 471' and pulled additional tubing from the well today. I will send an update with todays report and current depths around lunchtime tomorrow. Allie From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Wednesday, April 5, 2023 2:32 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: Re: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Bryan, Here are the reports for the past few days. Current depth as of this morning is 423'. Allie From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, April 3, 2023 3:51 PM To: Schoessler, Allie M <aschoessler@blm.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Sounds good to me. I probably don’t have the full picture, but I suspect your washpipe is getting wedged between the cemented tubing and the casing, so you are grinding on both the inside of casing and outside of tubing. Tubing is unable to center itself because it’s held in place by the cement. Have you considered using a flat-bottomed or concave mill and just mill up tubing and cement? Sometimes that’s the answer. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Monday, April 3, 2023 3:43 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: Re: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Great! How does 1-2 PM sound? From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, April 3, 2023 3:41 PM To: Schoessler, Allie M <aschoessler@blm.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Allie, I can meet any time after 11:30 Monday Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Monday, April 3, 2023 1:56 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: Re: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Bryan, Here is the report for 4-02-2023. Would you be able to meet Monday 4/10 anytime between 10am and 3pm (via teams or in person)? We would like to have a quick chat regarding progress on the well. Thank you, Allie From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, April 3, 2023 9:25 AM To: Schoessler, Allie M <aschoessler@blm.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Allie, Thanks for the pictures. Very interesting set-up. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Friday, March 31, 2023 3:50 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: Re: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Bryan, Here is the daily report for 03-30-2023. Attached are also some picture of the rig. These are for AOGCC information only and are confidential information (not shareable). Please let me know if you have any questions, Allie From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Thursday, March 30, 2023 2:34 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Re: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Here it is! From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, March 30, 2023 2:27 PM To: Schoessler, Allie M <aschoessler@blm.gov> Subject: RE: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Hi Allie. I think you forgot to attach the report. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Thursday, March 30, 2023 2:19 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: Re: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Bryan, Here is the daily Report from 03-29-2023. I will have Quinn get some photos for tomorrows report. Please let me know if you have any questions, Allie From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, March 29, 2023 3:05 PM To: Schoessler, Allie M <aschoessler@blm.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Thanks Allie. We would love to see more photos of the rig inside the tent and also from outside the tent. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Wednesday, March 29, 2023 2:22 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: Re: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Bryan, Work on Iko Bay has started. There were some issues with the first BOPE test. The gauges were not consentient with the chart readout due to air and environmental factors. We requested that they retest prior to continuing with work (they had just started). The test charts and yesterdays report are attached. No issues with the verification test. Let me know if you have any questions, Allie From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Friday, March 24, 2023 6:07 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: Re: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Bryan, The rig is being assembled and the BOPE test is in the 24 hour forecast. Daily well reports should start this weekend. I will keep you updated. Allie From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Thursday, March 23, 2023 9:30 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: Re: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Bryan, The tent structure is in place and the rig is being assembled. Here is a photo of the inside of the structure. More to come soon, Allie From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Friday, March 17, 2023 5:13 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: Re: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Iko Bay update 03/17/2023 This week: Equipment continuing to arrive on site tent system getting set up BLM Contracting site inspection BLM inspector onsite Old wellhead removed, new one for rig work installed Found cement in the IA Next week: Rig assembled once tent is set up BOPE testing Begin well work Due to shipping, weather and logistical delays the project is about a week behind the anticipated schedule. Once we have well work I will include the daily reports. I think we can work something out for Jim to see the set up. Just reach out on a separate email and we can talk timing and logistics. Have a great weekend, Allie From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, March 2, 2023 9:55 AM To: Schoessler, Allie M <aschoessler@blm.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Allie, Thanks for the update. The AOGCC is interested in having a look at the tented-in rig arrangement since we anticipate seeing applications to use this equipment on state lands in the future. Please include Jim Regg on the daily reports once operations commence. He’ll likely try to coordinate a site visit if that’s possible. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Thursday, March 2, 2023 9:48 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Re: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports Bryan, The rig and tent are still on their way to location. Due to shipping and weather delays we do not anticipate starting any well work until this weekend or early next week. There is a possibility that equipment for starting the wellhead cut-off operations 3/5 or 3/6. I will keep you posted and definitely get you some photos once the equipment is in place. Let me know if you have any questions, Allie From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, March 2, 2023 9:44 AM CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. To: Schoessler, Allie M <aschoessler@blm.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] RE: Iko Bay 2023 Updates and Reports This email has been received from outside of DOI - Use caution before clicking on links, opening attachments, or responding. Hi Allie, Has the rig made it out to location yet? I’d love to see some photos of the tented rig. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Wednesday, February 22, 2023 5:32 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Iko Bay 2023 Updates and Reports Bryan, I am starting a new email chain for reporting and updates for the project. Update 02-22-2023 Pre-site visit completed to Iko Bay on 02-21-2023. No pressure was present on the well at initial observance or after a 12 hour monitoring period. Rig structure shipping delayed, will not be onsite until end of next week delaying project a few days Plan to move forward with the approved sundry permit plan dated 2/13/2023 steps 7-10 and omit steps 2-6. Please let me know if you have any questions or concerns, Allie Schoessler Petroleum Engineer / Inspector Legacy Well Contract Office Representative Office: 907-271-3127 Cell: 907-202-2445 222 W 7th Ave Stop 13 Anchorage, AK 99513 1 Legacy Well Site Inspection – Daily Report Contract No: 140L0622F0256 Contract Name: Iko Bay Contractor: Olgoonik Oilfield Services Date 04.14.2023 Start Time 0800 End Time 1830 Well Name Iko Bay #1 Rep on Site Contractor: Shane McGeehan BLM: Quinn Sawyer Temperature 0F Min: -13° F Max: -1° F Weather Conditions Fog and mist in the AM; clear in the PM, N wind 5-10 mph Project Status (24 Hour Summary) Pressure test bottom cement plug to 500 psi, good test. Rig down. Narrative Report (please submit pictures with report) This morning the hydraulic jacks on the rig derrick were repaired, one had been bent while trying to free the stuck milling BHA. Lynden piston bullies arrived to cary off several trailers worth of the rig components that have already been dissasembled and prepared for demobilization to Deadhorse (Figure 1). The test chart and pump were rigged up to the casing valve on the starting head to perform a pressure test on the bottom cement plug (Figure 2). The blinds, choke valves and kill valves were all used as barriers for the pressure test. Begin cement plug pressure test at 1030, initial pressure was 520 psi. After 15 minutes, pressure was 495 psi, and final pressure after 30 minutes was 475 psi (Figure 3). Rig crew laid down the derrick and began disassembling the drawworks, motor, driller’s console, and other rig floor equipment for demobilization (Figure 4 & 5). Two empty connexes arrived onsite to pack The Tent into for the ride out so that it will not have to be packed back into the smaller wooden crates in which it arrived. See pages below for pictures. Signature: Title: QUINN SAWYER Petroleum Engineering Technician 2 Figure 1: Piston bully hooking up trailers to haul to Deadhorse Figure 2: Test chart and test equipment setup for cement plug pressure test 3 Figure 3: Cement plug pressure test chart Figure 4: Laying down the derrick 4 Figure 5: Majority of the rig disassembled and ready for demobilization 1 Legacy Well Site Inspection – Daily Report Contract No: 140L0622F0256 Contract Name: Iko Bay Contractor: Olgoonik Oilfield Services Date 04.13.2023 Start Time 0800 End Time 1800 Well Name Iko Bay #1 Rep on Site Contractor: Shane McGeehan BLM: Quinn Sawyer Temperature 0F Min: -12° F Max: 2° F Weather Conditions Clear, NW wind 10-15 mph Project Status (24 Hour Summary) Waiting on cement. Begin rigging down and preparing to haul rig back to Deadhorse. Narrative Report (please submit pictures with report) This morning rig crews were rigging down their pits and pipe rack. In the afternoon they moved on to rigging down equipment on the rig floor and other miscellaneous tools and equipment around The Tent. The BOPs are remaining in place until a positive test has been achieved on the cement plug after WOC time of 36 hours which will be at 0830 tomorrow morning. See page below for pictures. Signature: Title: QUINN SAWYER Petroleum Engineering Technician 2 Figure 1: Rigging down pits Figure 2: Rig staged up waiting for trailers to haul it to Deadhorse 1 Legacy Well Site Inspection – Daily Report Contract No: 140L0622F0256 Contract Name: Iko Bay Contractor: Olgoonik Oilfield Services Date 04.12.2023 Start Time 0000 End Time 2100 Well Name Iko Bay #1 Rep on Site Contractor: Shane McGeehan BLM: Quinn Sawyer Temperature 0F Min: -12° F Max: -3° F Weather Conditions Partly cloudy, NW wind 10-15 mph Project Status (24 Hour Summary) Backoff BHA and pull drill pipe out of hole. Top of BHA left in hole is 398’ RKB. Run in with Permapack Packer and set top at 392’ RKB. Pump 8 bbls of 16.2 ppg permafrost cement on top of packer cement in place at 2030, WOC. Calculated TOC @ 183’ RKB. Narrative Report (please submit pictures with report) At 0000 Eline was rigging up their string shot tool (Figure 1) to run in hole and aide in backing off the connection between the drillpipe and the milling BHA. BHA tally includes 3.5’ mill, 4 joints of washpipe which have a total length of 117’ and 3’ of pipe for the top sub and crossover. Total length of fish that will be left in the hole is 123.5’. The string shot tool was wrapped in detonation cord and ran in hole along with a weight bar and casing collar locator (CCL). Using the CCL to correlate depths the string shot was centered on the connection between the crossover sub and 3.5” drillpipe. At 0200 torque was applied to the drillsting with the rig and Eline fired off the string shot charge. This broke loose the connection at 398’ RKB and freed the drillpipe. Pulled out of hole with all 27 joints of drill pipe while abandoning 123.5’ of the milling BHA downhole. Made up permapack packer to drillstring and ran in hole (Figure 2). The packer tagged on the top of the fish at 398’ RKB and picked up 2’ to 396’ RKB. After consulting with BLM and AOGCC the go ahead was given to set the packer with top of packer located at 392’ RKB. The packer is a hydraulic set, the ball was dropped into the pipe and test pump was hooked up to circuate downhole and seat the ball. The ball seated and pressured up to 2900 psi and held there. The test pump regualtor had to be adjusted to allow a higher pressure to be reached, pumped up to 3900 psi and held. Applied 4,000 lbs of tension with the rig and pins sheared on the packer setting tool and the packer set. Tripped out of hole to surface laying down singles for the 3.5” drillpipe. At 1300 Will Maerklein (BLM PE) departed Iko Bay to head back to Anchorage. Rig crew ran back in hole with 1.9” workstring and tagged top of packer at 392’ RKB and picked up 2’, rig up cementing equipement to set balanced plug. At 1915 began mixing 4 supersacks (~16 bbls) of permafrost cement in batch mixer (Figure 3). A sample was taken at and the weight was 16.2 ppg (Figure 4). The batch mixer capactiy is 0.57 bbls/in and the volume of cement pumped was measured by strapping. Intial strap from the top of cement mixer down to cement slurry was 48”, the final strap was 62”, indicating that 14” or 8 bbls of 16.2 permafrost cement was pumped on top of the packer. Cement was displaced with 0.5 bbls of brine, cement was in place at 2030. The 1.9” workstring was tripped out of the hole and laid down in 30’ sections. Wellsite personnel began cleaning up cement batch mixer and rig crew began rigging down the Delorean #1 (Figure 5). WOC is a minimum of 36 hours prior to tagging and pressure testing. See pages below for pictures. Signature: Title: QUINN SAWYER Petroleum Engineering Technician 2 Figure 1: Eline string shot tool, prior to being wrapped in detonation cord Figure 2: Permapack packer and setting tool 3 Figure 3: Mixing permafrost cement in batch mixer Figure 4: Mudscale weighing cement at 16.2 ppg Figure 5: Sunset behind The Tent as rig down begins 1 Legacy Well Site Inspection – Daily Report Contract No: 140L0622F0256 Contract Name: Iko Bay Contractor: Olgoonik Oilfield Services Date 04.11.2023 Start Time 1130 End Time 0000 Well Name Iko Bay #1 Rep on Site Contractor: Shane McGeehan BLM: Quinn Sawyer Temperature 0F Min: -23° F Max: -6° F Weather Conditions Partly cloudy with haze, SW wind 5-10 mph Project Status (24 Hour Summary) BHA is stuck in the wellbore at 522’ RKB. Wait for Eline personnel to arrive onsite. Well began to pack-off, circulation decreased to ½ BPM at 340 psi. Narrative Report (please submit pictures with report) Will Maercklein (BLM PE) and I arrived onsite at Iko Bay at 1100. I changed out with Allie Schoessler who had been onsite for the past 6 days. Current status of the well is the milling BHA got stuck while pulling out of hole. The rig had miled down to a depth of 570’ RKB before tripping out. During the trip the BHA became hung up down hole and attempts to free the pipe resulted in getting it further wedged into the well. The pipe is unabe to be moved up or down and cannot rotate (Figure 1). Two barrels of lubricant and wireline personnel are enroute to Iko with an ETA of 2130. While waiting on personnel and equipment to arrive rig crew have been servicing the rig, checking all of the bolts and inspecting substructure. At 2030 while circulating the wellbore it began to pack-off with rates dropping to ½ BPM and pressure climbing to 340 psi. The decision was made to skip attempts at trying to free the pipe with lubricant as the likehood of success was minimal and the hole conditions were deteriorating. Once Eline personnel arrive and are able to rig up their tools, attempts will be made to backoff the washpipe and get drillpipe out of the hole. See page below for a picture. Signature: Title: QUINN SAWYER Petroleum Engineering Technician 2 Figure 1: BHA and drillpipe stuck in hole at 522' RKB 1 Legacy Well Site Inspection – Daily Report Contract No: 140L0622F0256 Contract Name: Iko Bay Contractor: Olgoonik Oilfield Services Date 04/10/2023 Start Time 0600 End Time 2200 Well Name: Iko Bay #1 Rep on Site Contractor: Shane McGeehan BLM: Allie Schoessler Temperature 0F Minimum: - 12 Maximum: 3 Weather Conditions Snowing, winds 16 mph feels like -350F Project Status (24-hour Summary) Milled to 570’ started to TOOH and pipe became stuck at 505’. Worked pipe for several hours then stopped work until further equipment could be brought to site. Narrative Report (please submit pictures with report) 0630 continued milling overnight, worked past the section at 553’. At 1100 mill depth at 564’ continuing to slowly work down the hole getting cement in the returns. At 1500 reach a depth of 570’. At 1630 unable to make progress past 570’ pipe torquing up. Work pipe for a bit and at 1730 make the decision to TOOH and investigate. Pulling heavy and torquing up from 570’ to 505’ having to work the pipe the whole way. 1830 continuing to work the pipe until 2130 before stopping to evaluate alternate methods of getting free. Pipe stuck at 505’. E-line equipment is on site (Figure 1). Signature: Title: Allie Schoessler Petroleum Engineer & Inspector 2 Figure 1 - Eline unit onsite. 1 Legacy Well Site Inspection – Daily Report Contract No: 140L0622F0256 Contract Name: Iko Bay Contractor: Olgoonik Oilfield Services Date 04/09/2023 Start Time 0630 End Time 2300 Well Name: Iko Bay #1 Rep on Site Contractor: Shane McGeehan BLM: Allie Schoessler Temperature 0F Minimum: -21 Maximum: 1 Weather Conditions Partly cloudy, winds 5-10 mph feels like -430F at the coldest Project Status (24-hour Summary) Recovered an additional 10’-16’ of tubing and recovered the cement retainer that was at 415’ Narrative Report (please submit pictures with report) 0700 Milling in progress to 528’, crew made it though the tough spot early in the morning Continued milling throughout the day, at 1600’ milling at 553’. At 1830 mill had not progressed, TOOH. 2140 at surface the first 2 stands of was pipe were empty, the 3rd stand had 4 short chunks of tubing wedged in the end of the wash pipe (Figure 1), the 4th was empty, and the mill was completely worn down (Figure 2). MU new mill and RIH to continue. Signature: Title: Allie Schoessler Petroleum Engineer & Inspector 2 Figure 1 –Tubing chunks wedged into the wash pipe and the cement retainer from 415’. 3 Figure 2 – Mill that was worn down compared to new mill. 1 Legacy Well Site Inspection – Daily Report Contract No: 140L0622F0256 Contract Name: Iko Bay Contractor: Olgoonik Oilfield Services Date 04/08/2023 Start Time 0700 End Time 2330 Well Name: Iko Bay #1 Rep on Site Contractor: Shane McGeehan BLM: Allie Schoessler Temperature 0F Minimum: -22 Maximum: -7 Weather Conditions Partly cloudy, winds up to 8 mph feels like -370F at the coldest Project Status (24-hour Summary) Recovered an additional 3 JTS of tubing, continued to mill working through a tough spot likely filled with tubing scraps from 506’-516’ Narrative Report (please submit pictures with report) 0700 check in with crew, pipe continued to bind up at 506’ overnight. Worked the pipe for a few hours then came free and TOOH with indication of tubing in wash pipe. 0845 wash pipe at surface, nothing in the first 3 stands, 3 JTS recovered from the bottom 2 wash pipe stands (Figures 1 &2). 1005 MU mill assembly with 4 stands of wash pipe and RIH. 1355 Tag top of tubing at 506’ begin to mill down at 1410. Continue to work down to 510’ at the end of the day. Some tubing was slightly bent limiting rotation speed at surface, swapped out for straighter section resulting in better rotation speeds and noticeable progress down the well. Signature: Title: Allie Schoessler Petroleum Engineer & Inspector 2 Figure 1 – Top of the tubing in wash pipe at surface. 3 Figure 2 – Bottom of the tubing in wash pipe at surface. 1 Legacy Well Site Inspection – Daily Report Contract No: 140L0622F0256 Contract Name: Iko Bay Contractor: Olgoonik Oilfield Services Date 04/07/2023 Start Time 0600 End Time 2315 Well Name: Iko Bay #1 Rep on Site Contractor: Shane McGeehan BLM: Allie Schoessler Temperature 0F Minimum: -21 Maximum: -1 Weather Conditions Partly cloudy, winds up to 7 mph feels like -270F Project Status (24-hour Summary) Milled to 516’ and did not recover tubing RIH with different milling set up. Narrative Report (please submit pictures with report) Milled to 516' overnight, did not pull any tubing to surface. Indications showed that tubing was most likely not mangled and the crew ran in with a cutter early this morning. Cutting assembly went over the tubing easily but tagged up on tubing punches from 425'-429' that were across a collar. Unable to work past it. POOH to add a 5th Jnt of wash-pipe and a slightly smaller ID mill to either clean up the tubing at 425' and/or mill down to 546' and attempt to break-off and retrieve the tubing. Load of equipment arrived onsite (Figure 1) 2210 wash pipe torqued up at 500’ work pipe free. Continued milling. Signature: Title: Allie Schoessler Petroleum Engineer & Inspector 2 Figure 1 – Equipment that arrived on site. 1 Legacy Well Site Inspection – Daily Report Contract No: 140L0622F0256 Contract Name: Iko Bay Contractor: Olgoonik Oilfield Services Date 04/06/2023 Start Time 0600 End Time 2215 Well Name: Iko Bay #1 Rep on Site Contractor: Shane McGeehan BLM: Allie Schoessler Temperature 0F Minimum: -10 Maximum: -2 Weather Conditions Partly cloudy, winds up to 5 mph feels like -150F Project Status (24-hour Summary) Milled to 471’ and recovered 46’ of tubing. Continue milling operations overnight to estimated depth of 516’. Narrative Report (please submit pictures with report) Milled to 461’ RKB overnight, at 0915 reached a depth of 471’ RKB and stacked out. TOOH with wash- pipe, once at 350’ RKB (top of 2-7/8” tubing) had indication of tubing in pipe and continued TOOH. 1400 reached surface and recovered 46’ of tubing. One section of recovered tubing had visible perforations (Figure 1) and others were twisted (Figure 2). At 1520 the BHA was at surface with visible wear but no breakages or major damage. Mill was replaced and crew began to MU wash-pipe assemble at 1535. Over the last 24 hours an increase in the circulation has been observed from 60 degF to 69 degF. At 1822 tagged the top of the tubing string at 396’ (Joint #18) then continued to wash-over tubing and RIH to milling depth. Tagged previous depth of 471’ at 1930. At 2100 new joint (#25) was added on and continued milling. At 2130 mill depth was at 483’ RKB. Signature: Title: Allie Schoessler Petroleum Engineer & Inspector 2 Figure 1 – Perforated section of recovered tubing, perforations/tubing punches occurred in 2017 season. 3 Figure 2 – Twisted section of tubing being removed from the wash-pipe. 1 Legacy Well Site Inspection – Daily Report Contract No: 140L0622F0256 Contract Name: Iko Bay Contractor: Olgoonik Oilfield Services Date 04/05/2023 Start Time 0600 End Time 2045 Well Name: Iko Bay #1 Rep on Site Contractor: Shane McGeehan BLM: Allie Schoessler Temperature 0F Minimum: -12 Maximum: -2 Weather Conditions Partly cloudy, winds up to 9 mph feels like -210F Project Status (24-hour Summary) Reached a depth of 423’ with wash over and milling, no tubing to surface. RIH with additional stand of wash pipe to mill an additional 30’. Narrative Report (please submit pictures with report) 0800 at 416’ RKB on DP#22, milling down. At 1030 milled to 423’ where the tubing stacked out then began tripping back to surface. Working OOH the work string hung up at 391’ and they had to work pipe and rotate, then continued OOH. 1200 Allie Schoessler arrived on site to swap out with Quinn Sawyer. 1300 at surface with wash pipe, no tubing was brough up. Set up to RIH again with an additional stand of wash pipe. 1600 at 300’ MU rotating head then continue RIH. 1730 tag top of tubing at 350’, work pipe and continue to washdown to 423’. Tag up and begin milling operations at 1920 to continue overnight. Signature: Title: Allie Schoessler Petroleum Engineer & Inspector 2 Sun going down behind the wellsite. 1 Legacy Well Site Inspection – Daily Report Contract No: 140L0622F0256 Contract Name: Iko Bay Contractor: Olgoonik Oilfield Services Date 04.04.2023 Start Time 0600 End Time 2000 Well Name Iko Bay #1 Rep on Site Contractor: Shane McGeehan BLM: Quinn Sawyer Temperature 0F Min: -8° F Max: -2° F Weather Conditions Partly cloudy, W wind 10-15 mph Project Status (24 Hour Summary) Milled from 298’RKB to 348’ RKB. Pulled out of hole with milling BHA and 55’+ of tubing wedged in BHA. Ran back in hole with milling BHA, tagged at 328’ RKB and resumed milling to a depth of 365’ RKB. Narrative Report (please submit pictures with report) At 0600 this morning the rig was still milling. At 1000 milling slowed down progress at a depth of 348’ RKB. Milling BHA was tripped out of hole to surface. A total of 55’ of tubing was extracted from the washpipe. In addition to the 55’ removed and meaured, the bottom 30’ joint of washpipe had between 20’-40’ of tubing stuck in it. Efforts are continuing to clear out the washpipe and the exact length is difficult to know as the tubing is wedged two to three pipes wide in the washpipe. Part of the tubing that was recovered was the section from 300’ which contains the wireline retrievable plug (Figure 1). At 1400 the milling BHA was run back in hole replacing the bottom joint of washpipe with a spare piece that is free from obstructions. The new milling BHA has 92’ of washpipe in the assembly. The BHA tagged up at 328’ RKB which is now assumed to be the top of the tubing in the well. The kelly hose was hooked up and pumps were turned on to start circulation. The tubing top was washed over and continued tripping in hole to a depth of 348’ RKB. Milling resumed (Figure 2) and at 2000 a depth of 362’ RKB had been reached. See page below for pictures. Signature: Title: QUINN SAWYER Petroleum Engineering Technician 2 Figure 1: WRP inside of 2-7/8" tubing Figure 2: AK Drilling and Completion’s Delorean #1 rig actively milling deeper 1 Legacy Well Site Inspection – Daily Report Contract No: 140L0622F0256 Contract Name: Iko Bay Contractor: Olgoonik Oilfield Services Date 04.03.2023 Start Time 0000 End Time 1800 Well Name Iko Bay #1 Rep on Site Contractor: Shane McGeehan BLM: Quinn Sawyer Temperature 0F Min: 2° F Max: 7° F Weather Conditions Light snow, SW wind 10-15 mph Project Status (24 Hour Summary) Milled down to 260 RKB’, pulled out of hole with milling BHA and 80’-90’ of tubing wedged in BHA. Ran back in hole with milling BHA, tagged up at 260’ RKB and resumed milling to a depth of 298’ RKB. Narrative Report (please submit pictures with report) By 2200 yesterday evening the rig had milled down to a depth of 260’ RKB. The milling BHA was tripped out of hole to surface. 80’-90’ of 2-7/8” tubing was brought up in the BHA (Figure 1). 61.9’ of tubing was removed from the wash pipe and measured. The tubing is still coming up partially milled through and mangeled. The bottom joint of washpipe which is 30’ long had two additional pieces of tubing wedged together inside of it and were unable to be removed and measured. While tripping out of hole with the milling BHA the generator was experiencing mechanical/electrical issues and cut out power a couple of times. Rig crew and wellsite personnel warmed up the back-up generator and got it running so that operation could continue. At 0330 the milling BHA with 3 joints of washpipe (~93’) was ran in hole (Figure 2). I returned to camp to get some sleep and went out later in the morning to check progress. The milling BHA tagged up at 260’ RKB and resumed making hole. The rig had made 10’ of progress and was milling at a depth of 270’ RKB at 1030. By 1800 a depth of 298’ RKB had been reached. See page below for pictures. Signature: Title: QUINN SAWYER Petroleum Engineering Technician 2 Figure 1: 2-7/8" tubing pulled out of washpipe Figure 2: Overshot mill that is being run downhole 1 Legacy Well Site Inspection – Daily Report Contract No: 140L0622F0256 Contract Name: Iko Bay Contractor: Olgoonik Oilfield Services Date 04.02.2023 Start Time 0600 End Time 1800 Well Name Iko Bay #1 Rep on Site Contractor: Shane McGeehan BLM: Quinn Sawyer Temperature 0F Min: -4° F Max: 7° F Weather Conditions Light snow, E wind 15-20 mph Project Status (24 Hour Summary) Pulled out 23.5’ of tubing that was wedged in milling BHA. Milled from 224’ RKB down to 244’ RKB. Narrative Report (please submit pictures with report) The night rig crew milled down to a depth of 224’ RKB. Tripped out of hole to surface with 23.5’ of 2-7/8” tubing in the mill BHA. The bottom section of the tubing pulled out of hole was a partially milled pin connection (Figure 1). The length of tubing retrieved from the well led to a calculated top of tubing in the well at 158’ RKB. Made up mill BHA with 93’ of wash pipe and tripped back in hole. Tagged top of tubing at 168’ RKB. The driller slowly rotated and washed over tubing stub and continued in hole to a depth of 194’ RKB. At 194’ RKB a tight spot was encountered and the workstring had to be rotated and began circulating to wash through the tight section. Continued running in to a depth of 222’ RKB were the workstring tagged up on fill. The driller ramped up pumps to full circulation and increased rotation speed on workstring and resumed milling of annular cement and potential metal shavings/pieces from tubing. By 1800 the rig had milled down to a depth of 244’ RKB. Figure 1: Pin end of milled tubing Signature: Title: QUINN SAWYER Petroleum Engineering Technician 1 Legacy Well Site Inspection – Daily Report Contract No: 140L0622F0256 Contract Name: Iko Bay Contractor: Olgoonik Oilfield Services Date 04.01.2023 Start Time 0900 End Time 1700 Well Name Iko Bay #1 Rep on Site Contractor: Shane McGeehan BLM: Quinn Sawyer Temperature 0F Min: 0° F Max: 5° F Weather Conditions Freezing fog, SE wind 0-10 mph Project Status (24 Hour Summary) Mill from 134’ RKB to 185’ RKB. Narrative Report (please submit pictures with report) At 0900 the rig had made progress milling from 134’ RKB down to 160’ RKB. There is 90’ of washpipe on the BHA to allow for milling up to ~210’ prior to tripping out of hole. The triplex pump on the batch mixer had been started up and tied into the pump manifold on the rig to allow for increased circulation rates (Figure 1). The triplex pump from the batch mixer adds approximately 60 GPM of circulation rate. By 1700 a depth of 185’ RKB had been reached with the mill. See page below for an additional picture. Figure 1: Rig pump manifold and dual triplex pumps Signature: Title: QUINN SAWYER Petroleum Engineering Technician 2 Figure 2: Delorean #1 milling 1 Legacy Well Site Inspection – Daily Report Contract No: 140L0622F0256 Contract Name: Iko Bay Contractor: Olgoonik Oilfield Services Date 03.31.2023 Start Time 0900 End Time 0000 Well Name Iko Bay #1 Rep on Site Contractor: Shane McGeehan BLM: Quinn Sawyer Temperature 0F Min: 4° F Max: 10° F Weather Conditions Light snow, freezing fog and mist, W wind 0-5 mph Project Status (24 Hour Summary) Mill down to depth of 134’ RKB and have difficulty running deeper. Pulled out of hole with mill BHA and ~ 90 of tubing twisted off inside. Run back in hole to continue milling at 134’ RKB. Narrative Report (please submit pictures with report) At 0900 the rig had milled down to a depth of 121’ RKB. Pump rate has been limited to 55 GPM as one of the two triplex pumps is not working. Parts are being ordered to fix the down pump. By 1800 the rig had milled down to 134’RKB and was meeting additional resistance. The milling BHA was pulled out of hole and laid down. When breaking apart the connection on the 2nd joint of wash pipe 2-7/8” tubing was observed inside the wash pipe (Figure 1). Using a combination of C-clamps, elevators, and straps the tubing was cut into workable pieces and pulled out of the wash pipe as it was tripped out of the hole and laid down on the pipe skate (Figure 2). The tubing was firmly wedged in the bottom of the mill. Upon getting the whole BHA to surface multiple pieces of milled and corckscrewed tubing were found wedged in the bottom of the BHA (Figure 3). Several pieces of metal fell out from the bottom of the mill at surface (Figure 4). Approximately 92’ of 2-7/8” tubing was recovered from the well inside the wash pipe and mill assembly. A new mill BHA was made up and ran into hole to tag up at 134’ RKB. Milling resumed at a slow rate to continue milling down on the spiraled top of the tubing stub left in the well at 134’. Rig crew will continue milling through the evening. See pages below for pictures. Signature: Title: QUINN SAWYER Petroleum Engineering Technician 2 Figure 1: 2-7/8” Tubing inside 5-1/2” wash pipe Figure 2: Tubing that was milled in half 3 Figure 2: Corkscrewed tubing wedged at the bottom of the BHA Figure 3: Tubing pieces that fell out of the mill at surface 1 Legacy Well Site Inspection – Daily Report Contract No: 140L0622F0256 Contract Name: Iko Bay Contractor: Olgoonik Oilfield Services Date 03.30.2023 Start Time 0800 End Time 1800 Well Name Iko Bay #1 Rep on Site Contractor: Shane McGeehan BLM: Quinn Sawyer Temperature 0F Min: -2° F Max: 13° F Weather Conditions Clear, E wind 5-10 mph Project Status (24 Hour Summary) Fish 27.3’ top joint of tubing out of well. Mill down with wash pipe to a depth of 90’ RKB. Narrative Report (please submit pictures with report) Overnight the rig crew was able to fix the power tongs hydaulic issue (Figure 1). With the tong functioning properly the rig crew made up the overshot fishing tool and ran in hole to a depth of 15’ RKB to latch on to the 2-7/8” tubing stub. After grabbing onto the tubing stub the rotating head was able to apply enough torque to break loose the tubing connection at 42’ RKB. The driller tripped out of hole with the fishing BHA and tubing joint attached. The tubing was cut on the rig floor just below the bottom of the fishing BHA and laid down on the pipe skate (Figure 2). The total length pulled out of hole was 27.3’. It was determined that the tool joint on the tubing was not an 8RD as the records indicated but is a Hydril connection and that is why the outside cutter attempts proved unsuccessful. At 0900 rig crew was making up the mill and wash pipe and ran in hole to 55’ RKB. Pumps were turned on and circulated for 5-10 minutes. Over two bottoms up circulation was completed, due to the currently shallow depth the bottoms up volume is less than 1 bbl and pumps were circulating at 55 gpm. The mill was ran in hole and tagged up at a depth of 64’ RKB (only 1’ different then the measured depth at which milling stopped the previous day). By 1800 milling had made progress to a depth of 90’ RKB and another 30’ joint of wash pipe was being made up to continue milling operations through the night crew. See page below for pictures. Signature: Title: QUINN SAWYER Petroleum Engineering Technician 2 Figure 1: Power Tongs Figure 2: 2-7/8” tubing joint with Hydril connection 1 Legacy Well Site Inspection – Daily Report Contract No: 140L0622F0256 Contract Name: Iko Bay Contractor: Olgoonik Oilfield Services Date 03.29.2023 Start Time 0900 End Time 0000 Well Name Iko Bay #1 Rep on Site Contractor: Shane McGeehan BLM: Quinn Sawyer Temperature 0F Min: 4° F Max: 15° F Weather Conditions Cloudy, SE wind 10-20mph Project Status (24 Hour Summary) Mill out cement with 5-1/2” wash pipe to depth of 65’ RKB. Run in with outside cutter tool, unsuccessful attempts. Troubleshoot power tongs hydraulics. Narrative Report (please submit pictures with report) Overnight the rig crew had made a few feet of progress in milling down over the 2-7/8” tubing. Cement returns were visible across the shale shakers during milling operations (Figure 1). By 1130 a depth of 65’ RKB was reached and the milling BHA was tripped out of hole. Ditch magnets were inspected for significant metal shavings (Figure 2). The top of the 2-7/8” tubing where it had been cut off during the wellhead cut- off was tagged at 15’ RKB. The outside cutting tool BHA was made up and ran in hole to a depth of 45’ RKB. A collar was located at 41’ RKB as expected. Steps were followed in the cutting procedure, the tool was ran past the collar, picked up to catch on the collar to a tension weight of 4,000 lbs. Then the tool was rotated while slowly pulling up out of the hole which should have engaged the cutter and severed the tubing while capturing the cut section in the tool. Upon pulling the tool out of hole and breaking down the cutting BHA no tubing was found inside the tool. The cutting tool was inspected for damage, but nothing was found. The tool was redressed and ran back in hole to the collar depth and multiple attempts were made to engage the cutting blades below the collar on the 2-7/8” tubing. The tool was unable to engage on the tubing and it was pulled out of hole and laid down. While attempting to make up an overshot fishing tool (Figure 3) the hydraulics on the power tongs were unable to reach sufficent pressure to torque the tool connections to specifications. At around 2200 troubleshooting to solve the hydarulic pressure issue began. By midnight I returned to camp and will wait and see in the moring if there was any success in getting the first joint of tubing out of the hole. See pages below for pictures. Signature: Title: QUINN SAWYER Petroleum Engineering Technician 2 Figure 1: Cement returns across the shaker 3 Figure 2: Ditch magnet Figure 3: Overshot fishing tool 1 Legacy Well Site Inspection – Daily Report Contract No: 140L0622F0256 Contract Name: Iko Bay Contractor: Olgoonik Oilfield Services Date 03.28.2023 Start Time 0700 End Time 1930 Well Name Iko Bay #1 Rep on Site Contractor: Shane McGeehan BLM: Quinn Sawyer Temperature 0F Min: 1° F Max: 12° F Weather Conditions Clear in AM, cloudy and light snow in PM, SW wind 15-20mph Project Status (24 Hour Summary) Mill out cement with 5-1/2” wash pipe to depth of 36’ RKB. Re-test multiple components on BOPE. Narrative Report (please submit pictures with report) Yesterday I arrived in Utqiagvik and spent the night there. This morning I met up with the Utqiagvik expediter and rode in the Tucker out to the Iko Bay wellsite. I arrived at the camp at 1100 and met up with Jake Fulkerson (BLM PET). We discussed the progress in the past week and current operations. Upon review of a couple of the BOPE test it was determined that they should be repeated to ensure a solid 5 minutes of sustained pressure on the high pressure. We went down to the wellsite to speak with Shane McGeehan regarding this decision to re-test BOPE components. The rig was currently rigged up and running in hole with the 5-1/2” wash pipe and had made it to a depth of 36’ RKB (Figure 1). Jake Fulkerson loaded up in the Tucker for its return to Utqiagvik and his flight home. Rig crew tripped out of hole with the wash pipe and laid it down on the pipe rack. Rig crew then began rigging up the 3.5” test joint and test chart recorder (Figure 2). At 1500 the BOP re-test began with all of the components that were determined to be insufficient on the first test. I witnessed the enterity of the re-test. All components passed without any failures and no repairs or adjustments were made. A koomey drawdown test was performed (Figure 3). The accumulator dropped from 3000 psi to 1900 psi after functioning the HCR, Pipe Ram x 2 (to the simulate blind rams), and Annular. One pump was turned on and 200 psi above drawdown pressure was achieved in 8 seconds at which time the second pump was turned on and full pressure was achieved in 48 seconds. Pre-charge pressure on the accumulator bottles was checked and found to be 1000 psi on all 4 bottles. The BOPE test finished at 1845 and test charts were sent into town. Rig crew began to rig down testing equipment and rig up wash pipe to run back in hole and continue milling operations. Rig is on 24-hour operations and milling operations will continue throughout the evening. See pages below for pictures. Signature: Title: QUINN SAWYER Petroleum Engineering Technician 2 Figure 1: 5-1/2" wash pipe mill Figure 2: BOPE test chart recorder 3 Figure 3: Accumulator unit ��J , r �js ��° ,�" � '•.'i�f� rye Ae� (. ��•�F� i u i i� • � \ + ��,: vet-ray�+M !'��! i� ` µt r � ;< y fEi ill w' ',.. ♦ ..a�t¢e-p ~'1� ,!r 'r� ` `�s Y7�+, ��'i ��.. AN �,i 'nF i f33'N.•�.Y, • f.'. �•{. f R � r .* Y b ,. 3 • �' t �� kir ?� -- d M^y+LH 5J'R Mi",(I6.� �""•r, I + � 1 lR e/ -k, /!. �j. •Iv ♦ C k _5a, v 0 0 f 0 f a CONDITIONS OF APPROVAL FOR SUNDRY NOTICE — NOTICE OF INTENT Olgoonik Oilfield Services Plug and Abandon Iko Bay #1 Project Specific Requirements 1. See attached pages sections 2.2 Materials and Supplies. Reporting Requirements: %SIR 1. The pressure test will be recorded on a separate form and submitted with the daily report. Notification Requirements: 1. All changes to the submitted Notice of Intent must be reported verbally or in writing to one of the following contacts listed below at the BLM Alaska State Office, Branch of Energy. An oral approval by phone or email may be given should circumstances warrant. However, this does not waive the written requirement which is to be submitted within 5 days of receiving verbal approval. 2. All notifications must be reported via email to BLM AK AKSO EnergvSection Notifications0b1m.eov and/or verbally to one of the contacts listed below: Allie Schoessler Petroleum Engineer/Inspector 907-271-3127 Mutasim Elganzoory Petroleum Engineer 907-271-4224 Will Maercklein Petroleum Engineer 907-271-4402 Quinn Sawyer BLM Inspector 907-271-5717 Stephen Garcia Petroleum Engineer 907-271-3159 After Hours Contact: Allie Schoessler 907-202-2445 aschoesslernq blm.eov melganzoorv(a blm.gov wmaercklein(a blm.gov gsaw na,blm.gov sbgarcia(ablm.gov COA Page t of 1 OIgoonikPlug & Abandonment Plan Oilfield Services LLC BLM - NPRA Legacy Well Remediation Task Order-140L0622FO256— Iko Bay #1 Well 2.2 Materials and Supplies: • Cased Hole Cement Baskets 2.2.1 Fluids Program: • Drilling Muds: Drilling muds will incorporate brine used for freeze protection and as a weighting agent. All additives will be environmentally safe and contain no heavy metals. Muds will be available on site in quantities able to contain wellbore pressure. • Workover Fluids will use CaCI as a primary weighting agent. • All additives will be environmentally safe and contain no heavy metals. • Fluids will be available on site in quantities able to contain well bore pressure. 2.2.2 Cementing Program: • P&A cement will be an artic blend designed for the sub -normal temperature regimes of the planned cement setting depths. • Cement in normal Temperature regimes will utilize premium API Class G or greater. • See below Figure 3, for example UCA Testing Data: • Primary water for the cement blending is expected to be sourced from Barrow City Water Supply Potable Water. If for any reason the Potable water cannot be used, the second option is to use treated fresh snow melt water. o If water other than potable or fresh snow melt needs to be used, a sample of the water source (lake, river, etc.) will be collected and sent to the lab for individual UCA and compatibility testing. Olgoonik Oilfield Services I Equipment & Supplies OlgooneS Oilfield Services L1 LC Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order-140L0622FO256— Iko Bay #1 Well 7 tum Laboratory Cement Test Report AS1 90 deg F 300 80deRF 28.0 28A 280 46.0 65 F 460 46.0 200 23,0 224 22.6 28.0 27.0 275 1 Me Me 190 24A 23.0 235 60 1 1" 15.5 19A 19A 19.0 30 14.0 17.0 155 15.0 1 15.0 155 6 10.0 9.0 95 9.0TA 8A 3 &0 6A 7A 7.0 6A 65 10 sec Cid 12 -12.81 ID010082 21 dea - 22.4107010082 14tt14S 1 _..._.. •4R.5klDt�44 ...... . 479 O R -4A@9.I opurp RMo- mtnW*d I VdCOSl r 14.516 CP Yield PaW . 13.44 070100112 I Msc - 33.361 cP Yk d Point 1102 a8t100tI2 Thickening Time Rdrmrk - Thiclwiuf �� time hlchtdes beth timQ 30 & *4h 6 4 hrmn Bc 05 hymn 70 8c 05.37 ME 100 Bc 05:39 hymn N r F Free Fluid Trace uU2S rnL In 2 hm M 80 OMF mid 45 deg Incl Sedin"tation. None Table 2: Laboratory Data for Artic Blend Cement schlumborpor fWMs�.�Oltti.�L 1Y LM 308c 52415 5013C 533.55 70SC 537.15 1000c: 53235 Iq --r am a .a. Figure 3: UCA for Artic Blend Cement Olgoonik Oilfield Services I Equipment & Supplies Olgoonik Plug & Abandonment Plan Oilfield Services��c BLM - NPRA Legacy Well Remediation Task Order-140L0622FO256— Iko Bay #1 Well 2.2.3 Water: OOS will plan to utilize water by melting snow on site (for camp) and resupply from permitted lakes near Iko Bay. OOS will apply for Temporary Water Use Permits (TWUPs) from the Alaska Department of Natural Resources (ADNR), Division of Mining, Lands, and Water for P&A operations support. All non -potable water will be tested to ensure compatibility with the cement used in the P&A Design. The well abandonment project will require approximately 13,230 gallons of water. Water use requirements are listed below. Table 4: Estimated Water Use Requirements Iko Bay #1 1 13,230 TOTAL ESTIMATED GALLONS 13,230 (Does not include camp water) 2.2.4 Methanol: On site as contingency to mitigate hydrate issues. Olgoonik Oilfield Services I Equipment & Supplies 01goonik Plug & Abandonment Plan Oilfield SelviceS L�c BLM - NPRA Legacy Well Remediation Task Order-140L0622FO256— Iko Bay #1 Well List of Acronyms Daily Drilling Report DE # pounds P&A Plug and Abandon / Abandonment AOGCC Alaska Oil and Gas Conservation Commission PCB Polychlorinated biphenyls bbl barrel POOH Pull Out Of Hole BLM U.S. Bureau of Land Management ppf pounds per foot BHA Bottom Hole Assembly ppg Pounds Per Gallon BOPE Blow Out Preventer Equipment PV Plastic Viscosity BTC Buttress psi pounds per square inch BU Bottoms Up PWS Performance Work Statement CBL Casing Bond Log CBU Circulate Bottoms Up Csg Casing CO Cased Hole DDR Daily Drilling Report DE Drilling Engineer DP Drill Pipe DPZ Distinct Permeable Zones EMW Equivalent Mud Weight EOJ Every Other Joint Est. Estimated FIT Formation Integrity Test ft Feet / Foot HES Halliburton Energy Services HWDP Heavy Weight Drill Pipe IADC International Association of Drilling Contractors ID Inside Diameter in inch INC Inclination KOP Kick Off Point KWF Kill Weight Fluid LD Lay Down LOT Leak Off Test LWD Logging While Drilling MD Measured Depth MU Make Up MWD Measurement While Drilling ND Nipple Down OOS Olgoonik Oilfield Services OD Outer Diameter OH Open Hole RIH RKB RPM RU sk / sx SLB SO SOW Tbg TD TOC TOL TVD TOOH UCA WBS WOC wt YP Run In Hole Relative Kelly Bushing Revolutions Per Minute Rig Up sack / sacks Schlumberger Slack Off Scope Of Work Tubing Total Depth Top Of Cement Top Of Liner True Vertical Depth Trip Out Of Hole Ultra Sonic Compressibility Analysis Well Bore Schematic Weight On Cement weight Yield Point Olgoonik Oilfield Services I General P&A Design Foran 3160-5 UNITED STATES OM NAPPROVED 10040-0 7D7 (June 2015) DEPARTMENT OF THE INTERIOR Expires: January 31,20 18 BUREAU OF LAND MANAGEMENT 5. Lease Serial No. ❑ Production (Stan/Resume) ❑ Water Shut -OR N/A SUNDRY NOTICES AND REPORTS ON WELLS ❑ Hydraulic Fracturing 6 If Indian, Allottee or Tribe Name Do not use this form for proposals to drill or to re-enter an ❑ Casing Repair abandoned well. Use Form 3160-3 APD /or such ro osals. N/A SUBMIT IN TRIPLICATE- Other instructions on page 2 71fUnit ofCA:Agnement, Name and/or No. I. Type of Well N/A ❑ Oil Well Gas Well m Other 8 Well Name and No. Iko Bay #1 2. Name of Operator Bureau of Land Management 9 9. API Well No. 50-023-20007-00-00 3a. Address 222 W 7th Ave, #13 Anchorage, AK 99513 3b. Phone No. (include men code) 10. Field and Pool or Exploratory Ana (907) 271-4354 National Petroleum Reserve, Alaska 4. Location of Well (Footage, Sec, TAX, or Sunry Description) 11. Country or Parish, Stale 1,850' FSL, 2,500' FWL, S16, T21N, R16W U.M.; 71.10'17.17993"N / 156'10'26.27626-W(NAD83) North Slope Borough, AK 12. CHECK THE APPROPRIATE BOX(ES) TO INDICATE NATURE OF NOTICE, REPORT OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION © Notice of Intent ❑ Amdize ❑ Deepen ❑ Production (Stan/Resume) ❑ Water Shut -OR ❑ Alter Casing ❑ Hydraulic Fracturing ❑ Reclamation ❑ Well Integrity ❑ Subsequent Report ❑ Casing Repair ❑ New Construction ❑ Recomplete ❑ Other ❑ Change Plans © Plug and Abandon ❑ Temporarily Abandon ❑ Final Abandonment Notice ❑ Convert to Injection ❑ Plug Back ❑ Woter Disposal 13. Describe Proposed or Completed Operation: Clearly state all Pertinent details, including estimated starting date of any proposed work and approximate duration thereof If the proposal is to deepen directionally or reeomplete horizontally, give subsurface locations and measured and We vertical depths of all pertinent markers and zones Attach the Bond under which the work will be performed or provide the Bond No on file with BLM/BIA Required subsequent reports most be filed within 30 da) s following completion of the involved opemlions. If the operation results in a multiple completion or recompletion in a new Interval, a Form 31604 must be filed once testing has been completed Final Abandonment Notices most be filed only after all requirements, including reclamation, have been completed and the operator has determined that the site is ready for final inspection ) Plug and Abandon the wellbore. Please see the attached procedures. RKB' 12 ft Conditions of Approval attached - 14. 1 ttached. 14.1 hereby certify that the foregoing is we and cornet, Name (PrintedMped) Zach Sayers, P.E. Title Petroleum Engineer Signature f_�. Cly I Date 02104/2023 THE SPACE OR DERAL OR STATE ONCE USE Approved b �ti Ito' _ Title 71 � I Date Condmrns ofarInl.h.lds re attached. Ap a hf this notice does not waraat or certify that the egal or eyuitab title o those rights in the subject ]rase Office which would esnt to conduct ope ti thenron. i7 v[R'rLC (/ Title 18 U.S.0 Section 1001 and Title 43 U.S.0 Section 121:, make it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent statements ar representations as to any matter within itsjurisd¢Ilon. (Instructions on page 2) OIgOOnil� Oilfield ServiceLc Plug and Abandonment Operations Program Iko Bay #1 (PTD #: 100-036) Iko Bay Legacy Well Remediation NPRA, Alaska February 2023 Prepared for: U.S. Bureau of Land Management National Operations Center Prepared By: Clear Creek Energy, LLC 303 E Rogers Street Houston, TX 77022 Under Contract to: Olgoonik Oilfield Services, LLC 3201 C Street, Suite 700 Anchorage, Alaska 99503 Olgoonik Oilfield Services Olgoonik Oilfield Services Acw VERSION HISTORY Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order-140L0622FO256— Iko Bay #1 Well Version # Implemented By Revision Date Approved By Approval Date Reason 1.0 Zach Sayers, P.E. 20423 Table of Contents 1 General P&A 1.1 Design & Approach Clarifications & Requests: ............. 3 3 2 Equipment & Supplies..................................................................................................................................... 4 2.1 Surface Equipment................................................................................................................................... 4 3 P&A Procedures.............................................................................................................................................. 6 3.1 Iko Bay#1................................................. Table of Figures M Figure 1: Typical Surface Rig Up Layout............................................................................................................... 5 Figure5: Iko Bay #1 BOP Diagram...................................................................................................................... 9 Figure 6: Iko Bay #1 Alternative BOP Diagram................................................................................................. 10 Figure 7: Iko Bay #I Current Wellhead Diagram................................................................................................. 15 Figure 8: Iko Bay #I Current Completion Schematic.......................................................................................... 16 Figure 9: Iko Bay #1 Proposed Plugging Schematic............................................................................................ 17 Figure10: Iko Bay #1 Annuli Diagram................................................................................................................ 18 Olgoonik Oilfield Services I General P&A Design 0Igoonik Plug & Abandonment Plan Oilfield Services LLC BLM - NPRA Legacy Well Remediation Task Order-140L0622FO256— Iko Bay #1 Well 1 General P&A Design The primary goal is to leave this well abandoned as per the task order specifications and requirements while reducing the amount of waste generated. The following assumptions will be used for each wellbore in the Task Order: • All P&A procedures will be agreed upon and in accordance with BLM regulations prior to execution. • Seventy -Two hours prior to P&A operations commence, BLM representatives will be notified. • All wellbore fluids will be sampled for PCBs per Performance Work Statement (PWS) Section 3.8.4. 1.1 Design & Approach Clarifications & Requests: I, Upon cutting off any wellhead / surface casing, if OOS is to find an annulus void larger than 1" the plan is to lower a'/4" string to 50' and perform a cement job. Should the void area not be great enough, OOS plans to perform a surface down top cement job (no annular entry) till cement at surface is observed. Onshore Order 2. III,G,5: "Annular Space. No annular space that extends to the surface shall be left open to the drilled hole below; If this condition exists, a minimum of the tap s0 feet ofamuthu shall be phtgged with cement. " 2. It is OOS' intention to use a clear brine system for the using of the thawing, circulating, providing over -balance to formation pressures, and to be used in between cement plugs. The unique nature of the extreme sub -zero surface operating temperatures make a clear brine with a crystallization temperature lower than 0°F a must have to ensure surface lines and equipment do not freeze up. While a clear brine meets the PWS 3.8.1 requirements, OOS wishes to apply for exception from 00#2.II.N definition of Mud: "Mud for Plugging Purposes means a slurry of bentonite of similar flocculent/viscosfer, water, and additive needed to achieve the desired weight and consistency to stabilize the hole ". OOS intends to use a clear brine that does meet the density requirement; however, OOS does not intend to use a flocculent additive; rather, a polymer based viscosifier will be used that is compatible with CaCI and not as sensitive to the high pH environment as bentonite will be used. High vise sweeps will be used for hole cleaning. 3. Given the limitations of the batch mixer (as compared to a mix on the fly system), the minimum cement that can be mixed is 12.30 bbls. The limiting factor is the volume of mix water has to exceed 6.0 bbls to reach the bottom mixing paddle in the batch tub. All cement volumes listed in the procedures below are pump in place minimums that will match the proceeding permits, and are to be met or exceeded by the field operations team. 4. The initial documentation indicated 0 pressure at surface and a field visit has not been completed due to award timing. Based on planning discussions with the BLM, the following procedures assume that a change condition exists (until proven otherwise) and there is pressure on the well thereby changing the rig up approach. Olgoonik Oilfield Services j General P&A Design a 1 goo n i k Plug & Abandonment Plan Oilfield ServicesLLC BLM - NPRA Legacy Well Remediation Task Order-140L0622FO256— Iko Bay #1 Well 2 Equipment & Supplies 2.1 Surface Equipment OOS and its team will provide the following well specific equipment: • DeLorean Ultra -Portable. Drilling Rig o Portable Weather Protective Enclosure (I 10'x144' Arctic Grade Domed Tent) 0 349 HP Range II Chuck Drive Drilling Rig o Drilling Workstring: 1,300' of 3.5" drill string w/ external upset tool joints o Depth capable of drilling, milling, and pulling tubulars to 1,300 of 6.75" hole o Pullback Force: 50,000 lbs 0 135 HP Triplex Pump capable of 142 GPM 0 208 bbl mud skid with 4 compartments equipped with (1) shale shaker, (1) centrifugal pumps, (6) agitators • Well Control Equipment 0 7-1/16" 3M Shaffer type SPH annular 0 7-1/16" 3M Single Gate Hydraulic BOP 0 7-1/16" 3M Single Gate Hydraulic BOP 0 7-1/16" 3M flow Cross 0 2-9/16" 3M Choke Manifold o Hydraulic Accumulator • Portable Cementing Equipment Including a 80 bbl Cement batch mixing unit o Triplex Pump used for cement • Fluids Tanks ❑ 200 barrels of storage tank capacity to contain circulated well fluids. ❑ Waste/ Slop Tank • Boiler Unit • Transfer pump, with Backup Pump, Heaters, Pipe, hoses, valves, fittings • Track Loader • Excavator • Well Equipment Tools and Hose Parts House • Plug and Abandonment Marker The well shall be capped with a metal 10-%" x V." thick metal marker plate, welded in place with the well information inscribed on the plate. The plate will have a weep hole and is sized for each production casing. o Well name and number ❑ Operator ❑ API Number o PTD Number Olgoonik Oilfield Services I Equipment & Supplies 0Igoonik Oilfield Services L AW RG WS xx0 rt Plan View Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order-140L0622FO256— Iko Bav #1 Well o= I � o� N A ❑= [I MMY MX/MM 0 Fluid Fluid ear R Transfer Transfer Tasks Tanks B 15 ft x5 fL SDft MMMMMMI IALY SAYERS Iko Bay g1 Site Rig UO Diagram REV. DFSCRIPnON DATE I BY y`� Iko Bay 1F1 Well A ORICdNALDRAFT ORAVaNG 11/71 L T L ISD 1�� NPRA, Alaska pigoonik-V�_ ra. Oaaa9rnkarx Figure 1: Typical Surface Rig Up Layout Olgoonik Oilfield Services I Equipment & Supplies Olgoonik'_ Plug & Abandonment Plan LLC Services �c BLM - NPRA Legacy Well Remediation Task Order-140L0622FO256— Iko Bay #1 Well 3 P&A Procedures 3.1 Iko Bay #] The Iko Bay #1 well was drilled by the U.S. Navy in 1975. The rig had an original RKB of 12 feet. The well was completed and flowed gas. When the well was no longer necessary, it was shut in at the master valve and a bull plug installed directly downstream of that. In April of 2016 an unsuccessful attempt was made to plug and abandon the previously leaking well, efforts were halted the end of the season and well was left secured. A second attempt to plug and abandon the well was made in 2017. The attempt was partially successful and left the well plugging incomplete. The well was secured at the end of the 2017 season. 3.1.1 Well Assumptions: • Thermistor cables are not present. • A change condition exists and the well has pressure to surface. — This is OOS's Primary Plan o The wellhead pressure will prevent cut off of the existing wellhead, an alternative BOP stack to the one proposed in the bid will need to be accepted to allow for RU below the rig floor. Any BOP stack over -satisfies BLM 00#2; however, a AOGCC drilling BOP stack will not be an option due to the shortened height constraints. 3.1.2 Deviation Requests & Clarifications: The 1/0" workstring used for the annular top job will be lowered into place, and the cement job will be pumped. It is OOS experience that this string is unable to be pulled out of hole due to clearance restrictions and surface rig up logistics. It is OOS' intention to leave this string cemented in the wellbore's annulus. Upon cutting off any wellhead / surface casing, if OOS is to find an annulus void larger than 1" the plan is to lower a 1/<" string to 50' and perform a cement job. Should the void area not be great enough, OCS plans to perform a surface down top cement job (no annular entry) till cement at surface is observed. Onshore Order 2. III,G,5: "Anntdar Space. No annular space that extends to the surface shall be left open to the drilled hole below, If this condition exists, a minimurn of the top 50 feet of arnndus shall be plugged with cement " OOS wishes to clarify that it intends to make use of a BOP system for the thaw out of this wellbore to provide a safety barrier in the event a hydrate was thawed or a gas bubble was thawed up. Upon completion of the cement abandonment of the perforations and subsequent positive test, OOS wishes to clarify that the BOPS can be removed as needed as operations require. BOP stack removal shall not occur until any possible access to formation pressure has been confirmed to be sealed off and approval is given from the BLM P.E. OOS wishes to clarify that the BOP choke line, kill lines and valves are planned to be either 2416" or 2-9/16", but not a full 3". While the equipment provided does overly satisfy 00#2 for Workover Well Operations, OOS wished to clarify this would not meet 00#2's drilling requirements for a 3,000 psi system. OOS wishes to clarify that BOP equipment used on this well comes from best practices and experience of the contractor completing thawing operations, but overly exceeds 00#2 as 00#2 does not require a BOP system for well plugging. Olgoonik Oilfield Services i P&A Procedures 0IgooneS Oilfield Services Li*t� LC Fluids Program: Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order-140L0622FO256— Iko Bay #1 Well Hole Size: Fluid Type: MWD/LWD: 6.366" ID CaCI Monovalent Brine system None. cs None. Est. TOC Density Funnel PV YP 6 Gel Strength Salinity PH Viscosity RPM 11.4 30-60 1.710 N/A 7" Artic 15.4 6 6,000- 9-11 8.7 bbl 1 , 2.2 Blend 0 ppg 164,000 3.1.4 Evaluation Program: 7" Cased Section: Lo ging Suite: MWD/LWD: None. Open Hole Logs: None. Cased Hole Logs: None. 3.1.5 Cementing Program: P&A Plug Cement Job Hole Csg Type Density Yield % Excess Volume Est. TOC # Size Size Class G 1 N/A 7" Artic 15.4 6 10% CH 8.7 bbl 1 , Blend 0 ppg ft3/9sx MD Class G 2 N/A 7 Artic 15.4 _ ppg 10% CH 6.7 bbl Surface Blendppg 16.0 ft3/9 x Additives: Class G Artic Blend: 0.130 gal/sk retarder, artic blend yield of 0.93 ft3/sk at 15.7 ppg density. Olgoonik Oilfield Services I P&A Procedures OigonikPlug & Abandonment Plan Oilfield ServICES LLC 7%hBLM - NPRA Legacy Well Remediation Task Order-140L0622FO256— Iko Bay #1 Well 3.1.6 Well Control Program: BOPE (if wellhead has 7-1/16" 3M Gate Ram pressure) Upper Ram — 2-7/8" x 3.5" Flex pipe ram 7-1116" 3M Gate Ram Lower Ram — blind ram Mud Cross, Sin le Gate BOPE (if able to cut-off 7-1/16" 3M Spherical Annular BOP wellhead) 7-1116" 3M Gate Ram Upper Ram — 3.5" Flex pipe ram 7-1116" 3M Gate Ram Lower Ram — blind ram Mud Cross, Single Gate HILL LINE 2-9/16" Line w/ l each 2-9/16" 3M Manual Valves CHOKE LINE 2-9/16" Line w/ 1 each 2-9/16" 3M Manual Valve CHOKE MANIFOLD 3M Choke Manifold, (x2) manual adjustable chokes, 2-9/16" Choke line w/ 2-9/16" inlet and 2-9/16" outlet, and (x9) 2- 9/16" Gate Valves, (xi) Hydraulic double acting 3-1/8" HCR choke valve ACCUMULATOR 44 gallon reservoir, 3 each 15 gallon bottles, nitrogen backup, pneumatic and electric pumps REMOTE BOP CONTROL Located at Driller's Station Maximum Anticipated BHP 867 psi — 13.42 ppg x 0.052 x 1,242 ft *(should the all fluid column com letely evacuated Maximum Anticipated Given well testing data researched, acarol resenoirproduces a much dryer gas Surface Pressure (MASP) yielding in a true measured surface slut in pressure of 810 psi. MASP Actual: 810 psi **594 psi = 867 psi — (0.22 psi/ft x 1,242 ft) *(should thefidlJluid column completely evaamted) **this MASP not used for planning, only shown for BLM peanilting infonnation Purposes. Planned BOP Test Pressure 250 psi low / 1,500 psi high (5 min each) 7-1/16" Rig BOP leak test and function test charted, witnessed by BLM inspector Casing Test Pressure 7" none Olgoonik Oilfield Services I P&A Procedures Dl goon ik Plug & Abandonment Plan Oilfield Services L�C BLM - NPRA Legacy Well Remediation Task Order-140L0622FO256— Iko Bay #1 Well BM lacarlan of Well Cardwell Medd H Ria Nix Go rnenrsectw: 1,850'F542,500'nN4516,721N,R16WUmiat Meddion Spud: February 10, 1975 Stare Plane raardinates: X:716,275 Y.' 6,281,650Zone 6N (NAD27) Completed: March 8'",1975 UNRudellonpitude. 71.10'1717993'N/ 156'70'26 27526'W (NA0 83) Droved nns I a35' Flax s Pipe R Om Blint! d Ra. Rem on Bhp •WwrMVw. rrrw>rr.rw 0.01n. 18.0Ia 30.0In. 60.0 in 2A0I SAYERS nn• 100-036 mu Iko Bay 41 Proposed BOP Cwrw>blwFan_r � I n,.r W.w fIM eQ �-Nw T1 -w G_aA ena�v, I wu L24 invur 01116/2023 ]�wr��rop I �,AeeN I NPM,ArWa n'Mmanaey 0IK I .rarwr_.r 1 0.01n. 18.0Ia 30.0In. 60.0 in Figure 2: Iko Bay #1 BOP Diagram Olgoonik Oilfield Services I P&A Procedures 2A0I SAYERS nn• 100-036 mu Iko Bay 41 Proposed BOP REV DESMMMN DATE I BY �-Nw T1 -w G_aA ena�v, u.r 50-013-20007 wu L24 invur 01116/2023 A ORWINAL DRAFT bNAWING 11/27J72 2J5 8 .,Mw/NEW0iM;nd BOP I 11)29/22 I 2J5 C UMAMDw/NEWBOP 1/19/23 215 Indy ormer. � NPM,ArWa Figure 2: Iko Bay #1 BOP Diagram Olgoonik Oilfield Services I P&A Procedures 01goonw II.Plug & Abandonment Plan Oilfield ServiceS u cIm BLM - NPRA Legacy Well Remediation Task Order-140L0622FO256— Iko Bay #1 Well LUwrion of well Cardwell Model N Rig No. 3 Govemmentsection 1,850'FS(,2,500'FWL, S16,723N, 816WUmi0r Meridian Spud: Februaryl',1975 Store Plane Coordinates). 716,275 r 6,281,650 Zone 6N(NAD27) Completed: March I .1975 Ladtude/Long/tude 7170''1717993-N/156']0'26.27626-W(NAD 83) nn:.. tom., an nIn mne. need wJ 3.5• Ipa Rams on Toa rents w/ And Raman 9tm Figure 3: Iko Bay #1 Alternative BOP Diagram Olgoonik Oilfield Services I P&A Procedures 2Aa64rFRs 106036 Iko all #1 Proposed BOP REV DESOOPTIONDATE BY www An. 50.023-20007 ssa 124 a 40 1212Vu A DNGINALDRAl I DRAWING 33/11/11 1rs B UPWIED w/NEW CNDaEab BOP 32/16/21 ZIB waa mw-+rn � n61Val NaRA. Ala" Figure 3: Iko Bay #1 Alternative BOP Diagram Olgoonik Oilfield Services I P&A Procedures Olgoonik1011 1h Plug & Abandonment Plan Oilfield Services LLC BLM - NPRA Legacy Well Remediation Task Order-140L0622FO256— Iko Bay #1 Well 3.1.7 Site & Well Prep Operations: 1) With Well's Team tools on site, RU to existing wellhead and check for pressures. o Should the IA on the wellhead have pressure (the PrimaryPlan), continue to step 2-6 using the modified BOP RU to shortened BOP stack (Figure 6). Skip steps 7-10. i o If the well does not have sustained pressure (the Secondmy Plan); Skip steps 2-6. 2) Set double row of rig mats or build a snow pad around perimeter of sub -structure area to allow for 12" of additional space for BOP placement. 3) Set 1 layer of mats around perimeter of Arctic Portable Weather Protective Enclosure to gain 6" of Tent height. A 4) Check tbg for pressure and ensure no flow prior to removal of master valve. it E o Should the IA on the wellhead have pressure, the WRP at 300' will be the mechanical barrier to allow for removal of the 3-1/8" master valve. 5) Remove 3-1/8" Master Valve & 7-1/16" 5M tbg hanger head adapter. o Inspect tbg hanger for thread profile and condition. 6) Modify BOP RU to shortened BOP stack (Figure 11) Excavate down 4-8' around casing to allow nipple up of BOPE. 8) Cut all casing string below the 7" casing, then cut the 7" casing and dress for new starting head. o Ensure casing pressure has maintained 0 psi for at least 16 hrs prior to continuing cutoff operations. 9) Verify current fluid depth in well. Collect fluid samples with a bailer per BLM TO requirements 3.8.4. If 0 fluids are frozen collect samples during circulation 10) Install wellhead, rig up BOPE. Inspect Annulus for Cement. c Weld on Starting Head and NU BOPE. l 1) RU Arctic Portable Weather Protective Enclosure. 3.1.8 Plugging Operations: 12) Assemble sub -structure and place rig matting to distribute rig load. 13) Assemble Drilling Rig. Complete winterizations, RU boiler and unthaw components. 14) Skid rig in place. Raise mast. 15) PU & RIH with I" Macaroni tubing string to top of WRP at 300'. Circulate out brine with a minimum of 11.0 ppg brine system. Continue circulating heated brine to allow well to thaw. o 11.0 ppg brine will provide additional hydrostatic pressure to the existing 6.8ppg diesel. 16) NU 7-1116" BOP system, function test to ensure operational. Test BOPs to 250 1,500 psi for 5 min each charted. ❑ The records indicate that the IA had 0 psi prior to the 2017 operations. The tbg was plug with several bridge plugs in 2017. The WRP at 300' will be the bottom for the BOP pressure test. 17) RU Eline. 18) RIH and pull RBP at + 300'. 19) MU multi -shot tool, RIH and shoot at 330'. Olgoonik Oilfield Services I P&A Procedures 01gooniRKPlug & Abandonment Plan Oilfield Services LLcIm BLM - NPRA Legacy Well Remediation Task Order-140L0622FO256— Iko Bay #1 Well o Continue shooting from 330' 165' (location of greater bond from CBL). o Shoot from 120' 70' (location of greater bond from CBL). 20) MU Jet cutter, cut tubing at 325'. Ensure cut point leave 25'+ of fish to spear into for future steps. 21) RD Eline. 22) Back Out Lock Down Screws (LDS) in tubing hanger. MU landing Joint, attempt to pull 2-7/8" tubing. o Tubing max pull 80,000 lbs (80"o of the tensile strength of the tubing). o Rig max pull is rated at 50k. o Perform stretch calculation if tubing does not pull free. 23) LD tubing from cut point. 24) RIH with spear and attempt to pull tubing. o If tubing will not come free, note stretch data while pulling. 25) Continue with efforts to pull tubing if any indication show that tubing sections are free. 26) Continue pulling tubing in sections as needed until a depth of 1,200' is reached. o Skip to step 33. 27) If unsuccessful, RU Eline to commence with secondary fishing plan. o MU Jet cutter, cut tubing at 65' o RU to pull 2-7/8" tubing, and pull tubing to surface 28) Install Ditch Magnets in Possum Belly for all fishing operations. 29) MU Wash pipe assembly and RIH to cut point o RIH Tag Top of existing tbg o RIH to top of cut tubing, clean out and circ as RIH o CBU x 2 with high vise sweep at him o Wash over tubing with 5-1Z' 17# wash pipe o Wash over in 90' sections ■ After each milling operation check ditch magnets for metal shavings. If significant metal shaving found, stop, discuss findings with project engineer and BLM. 30) PU outside cutter and grapple tool, RIH and make cut at bottom of section and engage grapple 31) POOH with cut piece of 2-7/8" tubing and LD o Prior to bringing the fish and wash pipe across the BOP, perform flow check to ensure that no flow occurs prior to pulling BHA through the BOP. Should the well begin to flow while a majority of the BOP (-32') is still in the well, plan to RIH with the fish until it is buried below the BOP stack to allow for shut in on drill pipe. If only 32' or less of BHA is left, simply pull out the remaining BHA and hang at surface to allow for shut in with the blind ram. 32) Continue prior steps to wash over and lay down tbg to a depth of •1,200' MD. Wash down to 1,200' 33) RIH on drill pipe open ended and CBU 34) RU cementing equipment and spot a balanced cement plug from 1,200' to 1,000' MD using 8.7 bbls of permafrost cement. A minimum of a 200' tall plug must be pumped and confirmed with tag height. o Collect a sample of: the dry bulk blend (-I-I Quart) & pre -pumped wet mix (s -16 oz) o Cement not to be pumped until a et batch sample weighed above 15.4 ppg 35) POOH to 600', CBU to clear workstring, close pipe rams and squeeze cement using 1,000 psi surface pressure. Continue to hold pressure on cement for over 18 hours. 36) WOC until cement reaches compressive strength. 37) Release holding squeeze pressure, RIH, Tag TOC. Olgoonik Oilfield Services I P&A Procedures 0Igoonik Plug & Abandonment Plan Oilfield Services u.c BLM - NPRA Legacy Well Remediation Task Order-140L0622FO256— Iko Bay #1 Well 38) RU and pressure test cement for 30 min to 1,000 psi charted o Note that expected lowest formation pressure is 8.33 ppge, therefore with TOC at 815' TVD and applied surface pressure of 870psi will provide a 1,000 psi differential across the plug using a 11.4 ppge MW. [ (11.4-8.33) ppg * (830 R) * 0.052 130 psi + 870 psi : 1,000 psi.] 39) Spot 11.4 ppg mud equivalent from 815' to 150'. o Note that if operationally preferred, removal of the BOP system can occur after the bottom plug has been pressure tested and KWM is placed in the well with BLM P.E. written approval. 40) PU cement platform, RIH to +/- 167' MD (155' below Tundra level) and set platform, dump sand on top of plug per spec sheet. 4l) POOH, LD running assembly, RIH open ended to - - 10-20' above platform. 42) RU cementing equipment and cement from 167' MD to surface with 6.7 bbls of permafrost cement through the work string pumping until clean cement is observed at surface. o Collect a sample of: the dry bulk blend ( 1 -I Quart) & pre -pumped wet mix ( -16 07) o Cement not to be pumped until wet batch sample weighed above 15.4 ppg 43) Clean pits, ND BOPS, prepare to release rig 44) Flush all surface equipment. RD flow pan, prepare rig for skid. Begin rig down of choke, hardline. 45) ND BOP. Cut off 7" starting head. Remove from cellar. 46) Release Rig 47) Cutoff wellhead, inspect all annuli o Top -off cement in annuli as needed Olgoonik Oilfield Services I P&A Procedures Olgoonik Plug & AbandonmentPlan Oilfield Services I.LC BLM - NPRA Legacy WellellRemediation Task Order-140L0622FO256— Iko Bay #1 Well 3.1.9 Post Rig Operations: 49) Using excavator, excavate around the wellhead to a depth up to 8' below tundra level. 50) Using a cutting torch or a casing saw, cut all casing and tubing strings off to leave well severed >5' below tundra level. o Cut 24" surfacejacket and 16" conductor. 51) Remove original cellar, wellhead and severed casing/tubing and prepare for transport. 52)Top off all annuli with cement if necessary. BLM representative to witness. 53) Photographically document the condition of the top of the well before welding on the marker plate. 54) Weld a 114" thick, 10-3r4" diameter steel marker plate over the top of the cut-off well casing. BLM representative to witness. 55) Marker plate to have the following information bead -welded onto the top. a. lko Bay # I b. U.S. Navy c. API# 50-023-20007-00-00 d. PTD# 100 036 56) Photographically document the welded -on marker plate. 57) Back -fill excavation with original soil. Top excavation with five yards of clean gravel, mounding it over the well to compensate for settling as soil thaws. 58) Clean location, obtain site clearance approval from BLM representative on location and prepare all personnel, equipment and materials for demobilization. Olgoonik Oilfield Services I P&A Procedures 0Igoones Oilfield Services u.c Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order-140L0622FO256— Iko Bay #1 Well BLM 1ataDa,aJ we Cardwell Model N Rig No.3 Government Section 1,850'M 2,500'Fa7, S16, 721N, R16W Umiut Meridian Spud: February 1•,1975 Store I tone cjo , otes X:716,275 r 6,281,650 Zone 6N (NAD27) Completed: March 8w, 1975 ladtude/Lonpirude 7170'1717993'N/156°1075.27626'W(NAD83) NOT TO SCALE — Awaiting Field Visit Mrf (APN WYVM I I I Existing Ground Level (Tundra Levey -------------- I 0.0 in. 1101. 3D.DIo. 60.01n. a.fwn 7aasaERs wef 100-036 1mx Iko Bay #1 Existing Wellhead IMV DESCNFDDN DATE I BY ana.n � r.,.,,xC_•,,,,.,o„ i• Y50-023-20007 fur lila iwun 11/12/2012 A 01UGNAL DRAFT DRAWING ](15/2l NS marrra mel.m� nvBA, Alaska Figure 4: Iko Bay #1 Current Wellhead Diagram Olgoonik Oilfield Services I P&A Procedures 0IgooneS Oilfield Services Li LC & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order-140L0622FO256— Iko Bay #1 Well BL I IOmtion of Well I Cardwell Model H Rig 5 Gowmmlrnt Section: ],850'FSL, 1,500'FWI, S76, T21N, RI6WUmiat MerJdion Spud: February Sa, 1975 lid llZ%FW State PJane Caordinmes:X:716,275 Y-6,281,6502ane6N(NAD271 Completed: Mardi 8'11, 1975 Imitude/tongitude: 71'10'17.17993 -N/156.10 -26.2762M (NAD 83) 12'MD/TVDS(2riBinal Ground Level)_____Inv ________� TCOndudor Casing Jacket I' "I��24CSGto18'MD/TVD 122- OH f/ IV MD t/ 166' MD/TVD OH f/ 149' 2.7/6•, 6.5#,1-55, Ord ibg to 1,300' MD/TVD 61 jts 132 thg, parted (2441' ID, 2.347" Drift, 7,260 Burst, 7,680 Collapse, 99,660 lbs joint yield strength, 3 668' Coupling 00) Conductor Casing 16", 7511, N-80, 8rd, CSG to+/ -149' MD/TVD Not Observed at Surface 4 Joints range III TSC (15124" ID, 14936" Dr#t, 2,630 psi Burs[, 1,020 psi Col:apse) Cemented with 660 sit of permafrost cement Calculated TOC: Surface• u "o•1,u 1110{ nrY/J,ammlw.aw Iimbpm . Surface Casing 10.3/4 51#,P-110,BTCCSGro1,190'MD/TVD 37 its 51# 8110, R3, BTC TSC w/1J151#,N-80, R3,8rd on top. (9.85• ID, 9.694" Drift, 8,060 Burst, 3,660 Co lapse Cemented with 810 u of permafrost cement Calculated TOC: 223' MD• av "asimrI/A a In pawl -N l+s fl ..v_ . e[.Y I:b 7', 23#, C-95, CSG to 1,270' MD/M 32 its R3 Flush If casing (6.356-ID,6241 Drift, 7,530 Burst, 4,140 Collapse, 632k yield) Cemented with 360 sx of permafrost ant Celailated TDC 25 MD- S -1/2", 20#,1-55, CSG from 1,212' to 1,950' MD/I VD (4.653-10,4 653' Drift, 466k body yield) nnraanwlrbxynwe. wl ue..lrl-vr rue-ssn.m-r¢Ir• tm um ter 7-5/8" OH f/ 2,702' MD t/ 2,731' MD/TVD 120 ss total (CIP 02/27/19751 lko Bay #1 Current Wellbore Schematic TD. Z73I' MD P87D: 300 MD National Petroleum Reserve Alaska Barrow, Alaska P' Elevation IIB: 40.0' RJ(B GL' 12-0'API p 50-023-20007 PTD # 100-036 LS -50- er.r G.•.4 wrrou 11/22/2022 Figure 5: Iko Bay #1 Current Completion Schematic Olgoonik Oilfield Services IP&A Procedures Camodaltdr 81FIM rr w,y p' I mr lt• nlr. rlgamN rt OH f/ 149' 2.7/6•, 6.5#,1-55, Ord ibg to 1,300' MD/TVD 61 jts 132 thg, parted (2441' ID, 2.347" Drift, 7,260 Burst, 7,680 Collapse, 99,660 lbs joint yield strength, 3 668' Coupling 00) Conductor Casing 16", 7511, N-80, 8rd, CSG to+/ -149' MD/TVD Not Observed at Surface 4 Joints range III TSC (15124" ID, 14936" Dr#t, 2,630 psi Burs[, 1,020 psi Col:apse) Cemented with 660 sit of permafrost cement Calculated TOC: Surface• u "o•1,u 1110{ nrY/J,ammlw.aw Iimbpm . Surface Casing 10.3/4 51#,P-110,BTCCSGro1,190'MD/TVD 37 its 51# 8110, R3, BTC TSC w/1J151#,N-80, R3,8rd on top. (9.85• ID, 9.694" Drift, 8,060 Burst, 3,660 Co lapse Cemented with 810 u of permafrost cement Calculated TOC: 223' MD• av "asimrI/A a In pawl -N l+s fl ..v_ . e[.Y I:b 7', 23#, C-95, CSG to 1,270' MD/M 32 its R3 Flush If casing (6.356-ID,6241 Drift, 7,530 Burst, 4,140 Collapse, 632k yield) Cemented with 360 sx of permafrost ant Celailated TDC 25 MD- S -1/2", 20#,1-55, CSG from 1,212' to 1,950' MD/I VD (4.653-10,4 653' Drift, 466k body yield) nnraanwlrbxynwe. wl ue..lrl-vr rue-ssn.m-r¢Ir• tm um ter 7-5/8" OH f/ 2,702' MD t/ 2,731' MD/TVD 120 ss total (CIP 02/27/19751 lko Bay #1 Current Wellbore Schematic TD. Z73I' MD P87D: 300 MD National Petroleum Reserve Alaska Barrow, Alaska P' Elevation IIB: 40.0' RJ(B GL' 12-0'API p 50-023-20007 PTD # 100-036 LS -50- er.r G.•.4 wrrou 11/22/2022 Figure 5: Iko Bay #1 Current Completion Schematic Olgoonik Oilfield Services IP&A Procedures Olgoonik Oilfield Services Acft!t Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order-140L0622FO256— Iko Bay #1 Well BLSGovermment5earion. Location oJWell Cardwell Model H Rg 185'FSI2,500'FW4 516,711N, RI6WUm of Meridian Spud: February 1°,1975 Stote Phne Coordncres:X:716,275 Y.6,18;65012x6N(NAD271 Completed: March B'", 1975 LotimdeAmiritude. 71'1017.17993'N/156'1076 .27625 -W (NAD 83) 12'IVI rVD_jOdginal Ground Leve___________________ — ..--------------------------- 5' Below Ground Level30-3/4' Marking Plate welded on with 1/8' weep hole __________ P&A Cement PlujZ 2 .^a�."a', ;;a' 4 Conductor Casing Jacket Balance Plug from 0'to 167' MD • o; a'd.' ` 24•CSG to 18' MD/TVD 6.7 bb6 total cement pumped ti'8,a� • o ! •nom? A!4 seHole Cemem Basket—Top Basket @ i/• 16T MD 405 sx Arctic Blend Oass'Gcent, 0.93 h3/sk yield, •;4;; •;a.r•`;a.c';a: lb.b PP9 22' OH OA Cement from 0' to 50' MD 149' MD P&A Cement Plug 1 Squeezed Plug from 1,000 to 1,200' MD 8 7 bbls ental cement pumped 52.3 sx Arctic Blend Class'G' amt, 0 93 ft3/sk yield, 61 Its R2 tbg parted (2.441" ID, 2.347' Drift, 7,260 Burst, 7,680 Collapse, 99,660 lbs joint yield strength, 3.668' Coupling OD) 7-5/8" OH f/ 2,702' MD t/ 2,731' MD/TVD Conductor Casing 16", 758, N-80, 8rd, CSG to */-149' MD/TVD ' Not observed at Surface 4joinu range III T&C (15.124" ID, 14.936" Drib, 2,630 psi Burn, 1,020 psi Collapse) Cemented with 660 sx of permafrost cement Calculated TOC: Surface' ,w�ry0.fl„ IIIYa tripVY,aM®{W.uulaNlum,++M1eu 10-3/4', 51#,P-110, BTC CSG to 1,190' MD/TVD 371n 518, P-110, R3, BTCT&C w/ 1,t 518, N-80, R3,grd on top. (9.85" ID, 9.694' Drat, B,D60 Burst, 3,660 Collapse) Cemented with 810 sx of permafrost cement Calculated TOC 223' MD' •,....ryasr". i/Ya. .oaw u,d tum 7', 23#, C-95, CSG to 1,270 MD/TVD 32 its R3 Flush Jt Lasing (6.366' ID, 6.241' Drift, 7,530 Bu• .t, 4,140 Collapse, 632k yield) Cemented with 360 sz of permaftost amt Calculated TOC 25'MD' •x,unrynftmrt 1. an awr.w a,v 5-1/2', 20#,135, CSG fmm 1,212'to 1,950' MD/TVD (4 778' ID, 4.653' Drift, 466k bogy yield) Yma mY.rmhyY,w4. tr.r-vu. Sur- vm ux-nrtvar-tu4 r>y t)rS.lf6 If'A Plug f/ 2,000' 1/ 2,210' MO 120 sx total lap: 02/27/19751 Iko Bay#1 Proposed Plugging Schematic TD: 2,731'MD PBTD: Surface National Petroleum Reserve Alaska Da gr Elevation lTR: 40.0' Rl(a—GL•12.0' Barrow. Alaska m API # 50-023-20007 Pm # 100.036 LS 12/28/2022 Figure 6: Iko Bay #1 Proposed Plugging Schematic Olgoonik Oilfield Services I P&A Procedures 0IgooneS Oilfield Services u.c 1 3/4" Schedule 40 1 Plug & Abandonment Plan BLM - NPRA Legacy Well Remediation Task Order-140L0622FO256— Iko Bay #1 Well 6ovemmeat Section 1,850 FSL, 2,500 FW1, S16, T21N, R16W Umiar Meridian State Plane Coordinates X 716,275 Y 6,281,6502one 6N(NA027) laatudeAtingitude 71.101717993-NIM-102627526-W(NAD 83) 10-3/4", 51#, P-110 Cardwell Model H Rig No. 3 Spud: February 1',1975 Completed: March B^,1975 Traditional Flush Joint Wash Pipe S' O.D. x 41/4" I.D. 5 1/2" O.D. x 4 5/8" I.D. 6 5/8" O.D. x 4 3/4" I.D. 7" O.D. x 5 7/8" I.D. 2-7/8", 6.50, J-55 L/2", 17#, Wash Pipe - . ZACH SAYERS 100-036 Iko Bay #1 DESMPR"NON DATE BY Annuli Diagram Onpnal Sketch 7/IS/MZ2 LS Mrurt 1, 1 1f . amuo: 50-023.20007 ^r^� Olgoonik� NPRA, Alaska Figure 7: Iko Bay #1 Annuli Diagram 1:4 111/22/2022 Olgoonik Oilfield Services I P&A Procedures 1 Guhl, Meredith D (OGC) From:Schoessler, Allie M <aschoessler@blm.gov> Sent:Thursday, June 16, 2022 7:20 AM To:McLellan, Bryan J (OGC) Cc:Guhl, Meredith D (OGC) Subject:Re: [EXTERNAL] Iko Bay 1 P&A Attachments:Iko Bay #1 Subsequent Report Signed 05-03-17.pdf Bryan and Meredith, Here is a much better copy of the Iko Bay 2017 Subsequent Report. Please let me know if you have any questions,, Allie From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, June 13, 2022 2:40 PM To: Schoessler, Allie M <aschoessler@blm.gov> Cc: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: RE: [EXTERNAL] Iko Bay 1 P&A Thank you! Please send the update to Meredith Guhl (copied on this email), as I’ll be out of the office next week and she will update the AOGCC records. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Monday, June 13, 2022 2:38 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Re: [EXTERNAL] Iko Bay 1 P&A I am not at the office today but will try to get a better copy when I am in the office this week. From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, June 13, 2022 2:36 PM You don't often get email from aschoessler@blm.gov. Learn why this is important 2 To: Schoessler, Allie M <aschoessler@blm.gov> Subject: RE: [EXTERNAL] Iko Bay 1 P&A Thanks for sending the reports. Some of the pages are pretty hard to read, especially the completion reports pages 17‐30 and some of the wellbore diagrams. Is there any chance that we could get a clearer copy? Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Thursday, June 9, 2022 4:05 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Re: [EXTERNAL] Iko Bay 1 P&A Bryan, Here is the Subsequent Well Operations Report for Iko Bay #1 in 2017. Let me know if you have any questions, Allie From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, June 7, 2022 6:16 PM To: Schoessler, Allie M <aschoessler@blm.gov> Subject: RE: [EXTERNAL] Iko Bay 1 P&A Allie, Are there any records we should have for Iko Bay 1? Or was that Jan 2017 sundried work not executed? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Schoessler, Allie M <aschoessler@blm.gov> Sent: Monday, June 6, 2022 3:02 PM 3 To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Re: [EXTERNAL] Iko Bay 1 P&A Bryan, The Oumalik paperwork is in the finalization process. Documents will be provided once complete. Who submitted the records request for Iko Bay? Allie From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, June 6, 2022 1:56 PM To: Schoessler, Allie M <aschoessler@blm.gov> Subject: [EXTERNAL] Iko Bay 1 P&A This email has been received from outside of DOI ‐ Use caution before clicking on links, opening attachments, or responding. Hi Allie, We received an information request regarding P&A records for well Iko Bay 1. The latest document we have in AOGCC wellfiles is a 1/27/17 approved BLM sundry application to P&A the well, but we don’t have any report of any work having been done to actually execute that work described in the Sundry. Does BLM have any more recent records for this well and if so can you send them to the AOGCC for our files? Also just want to make sure we will get a copy of any Oumalik P&A paperwork that has been filed, report of sundry operations, completion reports and schematics, etc… Has all that paperwork been finalized yet? Thank you and regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250‐9193 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. By Meredith Guhl at 10:07 am, Jun 16, 2022 .'� ) 0 NIARSHCREEK Bureau of Land Management NPRA Legacy Well Remediation Plug and Abandonment Subsequent Report Prepared by: Steve Tyler 1 Marty Lemon — Workover Engineering Advisor April 18, 2017 APINo: .................................................... Permit to Drill No: ................................... Field: ........................................................ WellType: .............................................. Surface Location: ................................... SpudDate: .............................................. Completion Date: .................................... Temporarily Abandon Date: .................. Status: ..................................................... Iko Bay #1 50-023-20007-00-00 100-036 NPRA Gas Exploratory Well Lat: 71.1702 N E 716,275 Sec, 16, T.21 N. R. 16W, M. Umiat Long: 156.1670 Feb. 01, 1975 Feb. 23, 1975 April 11, 2017 Temporary Abandonment On March 29. 2017 equipment was mobilized to the Iko Bay #1 wellsite. BLM Instructed Marsh Creek to suspend Abandonment operations on April 10. 2017 and the well was temporarily abandoned. Equipment was demobilized from Iko Bay #1 on April 11, 2017. (Picture taken in Aug .":- RM T-r Departure Status 4 � Iko Bay #1 Sundry Subsequent Report 04-27-2017.docx page 1 of 38 611) � � __' ' rn ,,.m MARSHCR8BK ���� Table ����ntents Overview..................................................................................... ........................................................................ .................. 2 WorkObjective ...................... ................................................. ......... .................................................................................... u WellHistory ....................... ..................................................................................................................................................... 2 Daily Operations Summary ................................... _.......................................................... ..... -........................................... a LogSummary ..................................................... ................... .......................................................... --............................... 4 Attachments.................. ............. -.... ^............................................................ _................................................................... p #01\Appnowed Revised Sundry Form 816O-5............................................ ................. -....................................... .......... 5 #02\Revised Sundry Procedure ................................... ................................................ --............................................... o VVhreNnmOperation: .............................................................................. ..... ......................................... —............. .......... m WorkString Opmrmftns.......... ...... ......................................................... _^^....................................... ....................... 6 #03)0rigino Approved Sundry Procedure Deviations ............................ -....... ............ ................................................. 1O #Q4)Previous VVellbqre Schematic .............................................................................. ..... -........ ................................... 12 #05)Current VVeUUormSchmnmaUo'............................................... .......................................................... -..................... 15 #O6\Current Wellhead —__--_'-^~....~~—.—.^.—~.--..--.---_--~~.-..~--....—_—...-16 #O7)VVeU Repp�m_—....—.~.�.--'_----^...--~.--.--..—.--..—._----_^.^......--..—. 17 #07)Annular Attempt Pressure Charts .......... ...................................................... -.--.-...................... J1 #08) 24hrmCirculation Temp Charts .^..................................................... ..................................................................... 43 #Q8>BOP Test Report & Charts .............. ....................................... ............................................................................ u5 Overview Equipment was mobilized to Wo Bay #1 on March 29,2O17 repeated unsuccessful attempts to establish circulation and place a cement plug in the 2 %" x 7' annulus that meets BLM 43 CFR 3160 "Onshore Oil and Gas Order No. 2, Drilling Operations" standards, BILM instructed Marsh Creek and PRA to suspend operations and temporarily abandon Iko Bay #1 for further evaluatlion. Wellisite equipment was demobilized from location on April 11, 2017. ��uxw��� °�~~ Objective The priorities mfthe attached Plug and Abandonment Procedure for IkoBay #1are listed mmfollows: 1. Perform all work in a safe and efficient manner, without causing harm to people. environment,mrequipmenL 2. Safely secure the surface ofthe well sothat accidental entry isimpossible. Well ��History � The U.8'Navy drilled the Iko Bay #1 well in March 1975 and reached a total depth of 2,731 feet, The well was drilled amanadditional exploration well bmthe Bvww1ladrilled inBarrow from 1953- 975.lhoBsy#1wasdd|Amdwith oNavy-owned Cardwell Model Hdrilling rig. One cement plug was set between 2.036 and 2.21Ofeet. The well was osuccessful producer oYnatural gas, |nApril 2O16 anabandonment attempted was attempted Marsh Creek andSoIshmn-Xp. They were unsuccessful in completing the well ab#nnomont Inthe winter season mY2016,operations were suspended and the well secured. UhoBay #1Sundry Subsequent 17.docn Page 3of 38 0 o r,Ar, h1ARSHCRERK Daily Operations Summary From: Jerry Otto To: JasonlMarty Innner annulus= 25OPS1 Bled off to zero in three minutes all raw gas (No fluid) In one hour no build up (remained zero) 08/24/2016 Tubing=250PSI Bled to 235PSI in ten minutes approximately one gallon fluid Fluid was very foaming looks to be a mixture of brine and diesel In 30 minutes pressure build up was 255 PSI about five pounds higher than starting pressure Final pressures after 2 hours Tuning= 255 PSI Inner Annulus= 0 PSI 03/29/2017 Inspect wellhead, Stage tool conexes, Boller, Accumulator, Power up equipment, Set in boom truck, Build work platform around well Heat up wellhead Spot Pollard wire line unit and equipment - Safety meeting regarding wellsite communications and working with explosives while running wireline. Tbg pressure was observed at 400 psi, 0 psi on csg. Attempted to bleed down well. Tbg bleed down from 400 psi to 100 psi, all gas. We were unsuccessful in bleeding the tbg down to 0 psi_ Make up lubricator, make up wireline tool string w12.24" gauge 03/30/2017 ring. Test lubricator to 250 psi (low) & 2500 psi (high) for 15 minutes each, no bleed off was detected. RIH wl gauge ring to 915', POH_ While running the gauge ring the tbg pressure built back up to 400 psi_ Make up WRP, RIH w/ WRP, set at 900'. Test WRP for 1500 psi for 30 minutes, no bleed off detected. 30 gallons of diesel displaced downhole to pressure up well to 1500 psi, —70 gallons of diesel was recovered during bleed -back- Make up Halliburton temp log. Install decoder to Pollard wireline unit. Safety meeting regarding wellsite safety. RIH wl temperature log. Log from surface to 900'. At 90V temperature was 34 F, at 200' temp was 19 F, fluid interface was observed at —220'. Log second pass from 900' to surface. PU/MU CBL to wireline. RIH to 900', log to surface at 0 psi. Filled empty well column wl diesel in 2-7/8" tubing. Repeal CBL run from 900' to surface while holding 1000 psi on tbg. The CBL log struggled to find free pipe reference points and was decided 03131 /2017 to POOH and swap make up CBL back up tool. The pressure pass log is not valid. Repeal CBL from 900' to surface at 0 psi. The backup CBL produced the same results. Free pipe not detected. POOH lay down CBL. Make up Wireline Retrievable Plug (WRP) and set at 300', pressure test WRP to 1500 psi for 30 minutes, 100 psi bleed off was detected. Nipple down new master valve and remove from wellhead. Nipple down and remove old (leaky) master valve and remove from wellhead. Tubing head adapter seal area in good shape. Nipple up new master valve back onto wellhead. Safety meeting regarding wellsite safety, overhead loads and proper reflective equipment. Pressure test master valve to 250 psi (low) and 2000 psi (high) for 30 minutes each. NU 4-1/16" BOPS utilizing the crane. Rig up scaffolding around 04/01 /2017 BOPS and enclose w/ tarps to heat wellhead and BOPS. Rig up choke manifold and hard line to mud -cross. Change out 1.9" pipe rams w/ 1.315" pipe rams. Function test BOPS. Test Annular, inside kill valve and inside choke valve to 250 psi low for 30 minutes, passed test. Safety meeting regarding wellsite safety, proper equipment when handling CaC12 brine and caution around aline 04/02/2017 equipment. Test BOPS (annular, inside out outside kill vale & choke valve, choke manifold: 2 outside valves and 3 inside valves, floor valve and pipe rams and drawdown test on accumulator). Rig up hard line to diverter tank. Rig up aline, pressure test PCE on aline. RIH wl aline and retrieved WRP at 300'. Safety meeting regarding mixing chemicals and caution while lifting overhead loads. Rig up batch -mixer, build 30 bbls of 04/03/2017 10.4 ppg CaC12 brine. Rig up tbg handling equipment to handle 1" WS. Rig up flow line to diverter tanks (drums). RIH to 896. Broke circulation w/ diesel to fluid pack wellbore. Safety meeting regarding wellsite safety. Heat brine to 130 F, rig up batch mixer and rig up hard line from mud cross to 04/04/2017 circulating tank. Circulate 10.4 ppg CaC12 brine to displace diesel in wellbore. Rig down hard line. Rig up line from mud cross to brine tank. While beginning to circulate brine, the triplex pump suction cup failed causing 10.4 CaC12 brine to spill on the ground. Began circulating 10.4 ppg CaC12 brine at 130 F, weighed up to 11.4 at the beginning of circulation. Continued circulation w/ 11.4 ppg CaC12 brine. Safety meeting regarding wellsite safety. Weighed up brine from 10.7 to 11.4 ppg. Circulation was stopped after 24.5 hours of circulation. Rigged down batch -mixer and steam line from boiler. 04/05/2017 Rigged up tbg handling equipment. Pulled out of hole. Rigged down tbg handling equipment and false floor. Rigged up aline PCE and lubricator. Make up CBL tool to eline. Pressure test eline to 250 psi (low) and 2500 psi (high), hold for 15 minutes each. Log from 900' to surface at 0 psi. Repeat pass holding 1000 psi. Lay down CBL tool. Make up Temp. Tool. RIH w/ Temp. Tool attached to aline. Log from 900' to surface. Lay down Temp. Tool. R12 down aline. Safety meeting. Rig up pert gun to eline. Pressure up tbg to 500 psi, while maintaining pressure RIH and tie into recently run CBL. Punch tbg at 850', no pressure response was seen. POOH w/ eline. Pressure up on 2-7/8" tbg to 2000 psi and attempt to establish circulation, no circulation was established and no pressure response was seen. Make up Halliburton's Temp. Log, log from surface to 909, POOH. Rig up second pert gun to eline. Pressure up tbg to 500 04/06/2017 psi, while maintaining pressure RIH and tie into recently run CBL. Punch tbg at 330', a 30 psi bleed off was seen. POOH w/ aline. Pressure up on 2-718" tbg to 2000 psi and attempt to establish circulation, no circulation was established and —200 psi bleed off was seen on the tbg. Make up cement retainer to eline. RIH and set cement retainer at 837', POOH. Rig down aline and PCE. Rig up tbg handling equipment and false floor. RIH wl cement stinger attached to 1" WS to 837'. Rig up batch -mixer and circulate 11.4 CaC12 brine overnight. Iko Bay #1 Sundry Subsequent Report_04-27-2017.docx Page 3 of 38 7_W LF �o MARSHCREEK Safety meeting. Weighted up CaC12 brine to 11.4. Discontinued circulating. Stab Into cement retainer wl stinger. Attempted to circulate brine through the perforations at 850' and up the 2-718" x 7" annulus to 330'. Attempt to establish circulation was unsuccessful. Attempted to establish circulation down the 2-718" x 7" annulus, a small pressure bleed off 04/07/2017 was noted, circulation was unsucessfui. Pull 1" WS out of hole. Run Temperature Log from surface to 900' using aline Punch tbg at 790' using eline, all shots fired. RIH to —837' wl stinger. Stab Into cement retainer. Attempt to circulate from 85V to 790'. Pressure built to 2000 psi, tbg pressure bleed off was notice. No pressure response was noticed on the csg and no returns were seen at surface. Picked up out of retainer and circulated 11.4 ppg CaCl2 brine at 130 F a'i a rate of i BPM overnight to heat the wellbore. Safety meeting. Continued circulating CaC12 brine at 130 F to heat the wellbore Had safety meeting. Circulation was discontinued at 07.00, temperature properties were measured at 135 F (in) and 132 F (out). Weighted up brine from 11.3 to 11.4 ppg. POOH with stinger. RIH and set COP at 620'. Perforate at 600' and 335'. Set cement retainer at 04/08/2017 590'_ RIH wl stinger to top of cement retainer. Stab into cement retainer at 590' wl stinger. Attempted to circulate CaC12 brine through the perfs. at 600' and up the 2-718' x 7'" annulus to 335'. Attempt was unsuccessful, tbg pressure bled off to 1100 psi after stabilizing. Csg pressure remained at 0 psi and no returns were seen at surface. Pickup out of retainer. Rig up batch mixer. Circulate 11.4 CaCl2 brine at 130 F ovemi ht. Continued circulating CaC12 brine at 130 F to heat the wellbore. Had safety meeting. Circulation was discontinued at 07:00, temperature properties were measured at 138 F (in) and 133 F (out). POOH with stinger. Perforate at 425'. Set 04/09/2017 cement retainer at 416. RIH wl stinger to top of cement retainer. Stab into cement retainer at 415' wl stinger. Attempted to circulate CaC12 brine through the perfs. at 425' and up the 2-718' x 7" annulus to 335'. Attempt was unsuccessful, tbg pressure bled off to 1700 psi. Csg pressure remained at 0 psi and no returns were seen at surface POOH. Perforate at 385' and 350'. Set cement retainer at 375'. Safety meeting. RIH with Halliburton's Temperature Log. Log from surface to 375'. Temperature in wellbore was —42F surface and —36F from 200' - 376. RIH wl work string attached to stinger. At BLM's request we are suspending well operations on Iko Bay # 1 _ Circulate brine at 130 F to heat wellbore. Attempted to slab into retainer at 375' but was 04/10/2017 unsuccessful. Displaced wellbore from 375' to surface with diesel to freeze protect the well. POOH with workstring. Se{ WRP at 300'. Tested to 2000 psi for 30 min Pumped brine from batch -mixer tanks into'yellow waste manifest tank —45 bbls . Began rianIng down wellsite equipment 04/11/2017 Safety meeting. Nipple down BOPS. Change current pipe rams to 1.9" pipe rams. Rig down wellsite equipment, Nipple up tree cap and check surface gauges. Load oornnex's and mobilize equipment to S. Barrow #3. Log Summary Date Los Depth Temperature Log (pre -thaw), (2) Passes_ 03/31/2017 Radial Cement Bond Log, with 0 psi on well. 900' to Surface Radial Cement Bond L(Backup Tool), with 0 psi on well Radial Cement Bond Log, with 0 psi on well. 04/05/2017 Radial Cement Bond Log, with 1000 psi well 900' to Surface Temperature L(post-thaw) 04/06/2017 Temperature Log 900' to Surface 04/07/2017 Temperature Log I 900' to Surface 04/10/2017 1 Temperature Log 375' to Surface Iko Bay #1 Sundry Subsequent Report_04-27-2017.docx Page 4 of 38 '� ) 0 l!ir.+wACWiq 111ARSHCREEK Attachments tv -1l.Itl 1 y_ .1 Fenn 3160.5 UNITED STATES (lunc�l5) DEPARTMENTOFTHE INTERIOR FORM APPROVED OMB No. 1004-013T Expires lmamry31,2018 BUREAU OF LAND MANAGEMENT S Lease serial No SUNDRY NOTICES AND REPORTS ON WELLS 6 lflydowl AllonccorTnbeName Do not use this farm for proposals to ddll or to ra-enter an abandoned welt. Usa Form 31160.3 (t4eDj liar such propowls. W WWPLICATE- 011lerkutructlow an pW 2 7 1 Unit a Agrswmlk Name err No 1 Type nrWell ❑ od Weu ❑ c-a Wdl a) Other 8 well None and No Ike Bay No 1 2. Name of Operwor Burm of Land Mona0errmrsf API WOR We 50-023-2DW7-00-00 3a. Addrm 222 West 7Ih Avenue, 013 Anchorage, AK 3b Phone No. (mcJrde arra rode) 10 Field and Pool or rawry Ara 99513 1(907) 271.4429 NPR - Alaska 4 Location of Wdl (Feww. See., T.A..AL, orSgnx3 Desx-Hpdan) 11 CourstryorPainh.stwe Lat 71.1702 N E 71a,275 Sec-16, T11 N. R. 16W, M. Undat tong. IM1670 North Slope Borough, Alaska 13 CHECK TIIEAPPROPMATEBOx(FS)TOINDICATE NArjREOFNCMCE,REPORTORUniERDATA TYPE OF SUBMISSION I TYPEOFACTION m Notice oriment ❑ Subse aW ltgvn I__I Aced= I__I Deepen 0 Pladuetiat (Slaramme) ❑ Water Shut-off ❑ Alta Casing ❑ liydradle Franunng ❑ Reclamation ❑ Well Imc•Qrsq ❑ Casing Repair ❑ Near Cwwmmn ❑ Rccomp(ew ❑ Other m Clamp Plans ❑ Plug and Abtmdom ❑ Teslpararily A6andan ❑ Final Abandonmem Notice I ❑ Convert to Mjection ❑ Plug Back ❑ Water Deposal 13 Describe Pm f msed or Campleled Operation Clearly slide all paWtcnt delsils, mdwing estimated shrf ing date of soy prolose! wok amd approximate duratwn thereof If the pmposal a to decpea disaxionslly or recontplete hwixantally. give subsurface lowoons wl meuurai sad true retied depths ofall pemnent msrken and tone AUnch the Hord under which the work will be perroreed or provide she Bond No. an file with BLMIBIA Required subsequent reports must be feed w 1fis 30 days fd)aWmjl completion arthe involved operations. if the operwon mtdts in a multiple completion or reeaopletion in a new interval, n Form 3160.4 must be filed once tesung has been complekd Fusel Abandewcal Nobees must be We[ only after all regarremvw, meludrtsg rcdamauo% have been complete( mewl the operator has deaammed the she site Is rc* far final hspeedon ) Final Well Plug and Atsandonmenl Please ace aftached document RKB• 121L. Spud Date: 197L 14 1 hereby cemufy that die k egomg a tsar and carre t Name (P0mted17Awd) R M Lornort P.E. Try Was operations Manager Slgnawre l/►y Date 0411=17 THE SPACE FOR FEDERAL OR STATE OF10E USE Apmn,cd by Y T --------C4.M Tide Date �l1 7 I Cardit 2MZt nlorthis mmlee does not wammt arctrdrlypptttamo these rights in Ibe su*w least O[Fiee%bch d entitle thes thereon ri r< S>� Tdc 18 U S C Section 100120 We 43 U.S C Section 1I1Z make m a crime fix any person knwwuVly and wilfldly to make io Ay deportment or agony of the United Sates say false. fieutnaus or fraixWem statements or repr=mwom w to any mattervnthm Its lunsdielmn Iko Bay #1 Sundry Subsequent Report 04-27-2017.docx Page 5 of 38 �1 RA MAG+4 MARSHCRFIrK Sundry#02) Revised r Wirellrre Operation: 1. Inspect wellhead, grease valves on tree. Address any integrity discrepancies as required. 2. Record shut-in tubing and annuli pressures. Check for gas. Note in Mom Rpt. Attempt to bled pressure to zero. 3. Stage Tool & Parts Connexes, Boiler, Scaffolding, Generators, Heaters. 4. Spot surface support equip and crane. Build brine &preheat 5. Nipple Up (NU) wireline Blowout Preventer (BOP), Lubricator and heat sock. Pressure test Pressure Control Equipment (PCE) 250 psi low and 2500 psi high. Run In Hole (RIH) w/ Gauge Ring (GR). Tag Effective Total Depth (ETD) c@ -915'. Pull Out of Hole (POOH). Note: tbg was left full of diesel during April P&A attempt. 6. RIH w/ Wireline Retrievable Plug (WRP) on eline. Set same above existing tbg punched holes @ 910'. POOH. Pressure test WRP to 1500 psi for 30 min. Record fluid volume returned when tbg pressure is bled to zero. Note: Master valve leaks at 1500 psi. 7. RIH w/ CBL / Temp. Log. Tie-in to Halliburton Radial Cement Bond Log dated 22 Apr-2016. Log from -900' to surface. POOH LID logging tools - Utilize log results to determine the following: Establish Base Log to represent initial well conditions. 8. RIH w/ 2" d WRP. Set same at -300'. Pressure test tbg to 1500 psi for 30 min. Note difference in fluid volume returned when tbg is bled to zero from first WRP test. Rig Down (RD) eline. Note: Master valve leaks at 1500 psi. 9. Nipple Down (ND) tree. Remove leaky legacy Master valve and 5k FMC swab valve. Reattach 5k FMC swab valve (Master Valve) onto wellhead adapter, Pressure test 5k FMC master valve to 2000 psi for 30 min. 10. NU 4'tie BOPE onto wellhead. RU choke manifold, Kill line, return lines. Test same against WRP to 250/2500 psi for 30 min each. 11. RU wireline PCE. Pressure tesl same to 250/2500 psi. RIH latch retrieve WRP @ -300'. POOH LID WRP. RD wireline. Work SiVina Operations: 12. RU tbg handling equipment to run workstring (WS). 13. RIH w/ workstring to WRP set depth. Circulate heated 11-4 ppg brine down work string while taking returns out WS x 2 %" annulus. 14. Continue to circulate well w/ heated brine for 24 hours to thaw wellbore. Continuously monitor pressures on all annuli and returns temperature. POOH. 15. RU wireline PCE. Pressure test same to 250/2500 psi. 16. RIH with CBLlremp log. Tie-in to Halliburton Base Log_ Log from --900' to surface. Repeat logging run while holding 1000 psi on 2 % tbg. POOH LID logging tools. Utilize log results to determine the following: Wellbore thawing progress and depths of annulus obstructions. Finalize tbg punch depths to accomplish annular cmt squeeze. Compare data to previous run Base Log, 17. If Halliburton cement bond log indicates isolation above previous tubing perforations at 910' & 915' sufficient to prevent circulation go to step 20. 18. RIH latch retrieve WRP. POOH Lay -Down (LID) WRP. 19. Ensure tbg x csg annulus is open to take returns. Pressure up on 2 W tbg. Note: If pressure is leaking off, attempt to establish injection rate and pressure. Cement squeeze will be performed. If returns are noted, attempt to establish a circulation rate & pressure- Will circulate cement surface Max Allowable Surface Pressure is 2000 psi on tbg and/or csg. Maintain vigilance on wellbore conditions. High probability of trapped gas in tbg x csg annulus. In the event that circulation can be established to surface out 2'/," x 7" annulus thru the tubing punches in the well in excess of 1/2 bpm, circulate until return are consistent at 130F in & out, min of 2 hrs. Will circulate cement to surface. Procedure for that operation will be provided as required. 15.7 ppg Arctic Set 1 cement will be used. 15.7 ppg Arctic Set 1 cement specs, Slurry Density- 15.80 Ib/gal, Yield: 0.93 0/sk, Mix Fluid: 3.544 gaUsk. Iko Bay #1 Sundry Subsequent Report 04-27-2017.docx Page 6 of 38 O pd,.ud.;dlP�w.+wA4«4 MARSHCREEK In the event that injection down hole can be established in excess of 112 bpm, a bullhead sqz will be performed Procedure for that operation will be provided as required. 14 ppg cement will be used. 14 ppg cement specs. Slung Density: 14.00 Ib/gal, Yield. 1. IS fi3/sk, Mix Fluid: 5.251 gaUsk. In the event that circulation can be established in excess of 112 bpm between two sets of squeeze perfs the 14 ppg cement will be used. 14 ppg cement specs. Slurry Density. 14.001b/gal, Yield: 1.18 R3/sk, Mix Fluid: 5.251 gal/sk. 20. Attempt to establish circulation as follows. a) Punch tbg at 850' b) Pressure up on 2 7W tbg to 2,000 psi while monitoring tbg x csg annulus for returns thru perfs at 850' c) If unable to establish sufficient rates punch tbg at d) Pressure up on 2 %' tbg to 2,000 psi while monitoring tbg x csg annulus for returns thru perfs at 330' e) If unable to establish sufficient rates RIH wl cmt retainer. Set same @ 837' f) RIH with 1" work string g) Circulate for a minimum 6 hrs, 130F at 1 bpm h) Stab into retainer and attempt to stablish circulation between 1" tbg and 2 %" x 7" annulus. i) Ensure rates are greater than'/2bpm. 21. If unable to establish sufficient rates above Ma bpm thru retainer at 837'. a) POOH wl stinger. RUIRI wl eline. b) Tbg punch additional holes at @ 790' c) RIH wl stinger on 1" WS. Stab into retainer @ 837'. d) Pressure 1" work string to 2000 psi, while monitoring 2 718" tubing & 2 718" x 7" annulus. Attempt to establish circulation rates and pressures between tbg punch @ 850' and 790'. e) Ensure rates are greater than'/2 bpm. 22. If still unable to establish circulation or sufficient rates above'/: bpm thru retainer at 837' a) Circulate for a minimum 6 hrs, 130F at 1 bpm. b) POOH w/ stinger. RUIRI wl eline. c) RI set CIBP @ 620'. POOH d) Tbg punch additional holes at @ 600' e) RI wl cmt retainer. Set same @ 590' f) RIH wl stinger on 1" WS. Stab into retainer @ 690'. g) Pressure 1' work string to 2000 psi, while monitoring 2 718" tubing & 2 718" x 7" annulus. Attempt to establish circulation rates and pressures between tbg punch @ 600' and 330'. h) Ensure rates are greater than'/ bpm. 23. If still unable to establish circulation or sufficient rates above % bpm thru retainer at 590' a) Circulate for a minimum 6 hrs, 130F at 1 bpm b) POOH wl stinger. RUIRI wl eline c) Tbg punch additional holes at @ 430' d) RI wl cmt retainer. Set same @ 420' e) RIH wl stinger on 1" WS. Stab into retainer. f) Pressure 1" work string to 2000 psi, while monitoring 2 718" tubing & 2 718" x 7" annulus. Attempt to establish circulation rates and pressures between tbg punch @ 430' and 330'. g) Ensure rates are greater than 'h bpm. 24. If unable to establish sufficient rates above'/ bpm thru retainer at 415'. a) If able to complete this in the same day at the attempt thru the retainer at 415' no additional circulation required. If this goes into the next day, run a temperature log and base circulation time on log results and model. Iko Bay #1 Sundry Subsequent Report04-27-2017.docx Page 7 of 38 Q RA wAGwk. MARSHCREEK b) POOH wl workstring. RU Eline. c) Tbg punch additional holes at @ 385' and 350' d) RI wl cmt retainer. Set same @ 375' BLM directed Marsh Creek to suspend well operations. 25. RIH wl stinger on 1' WS. Stab into retainer. 26. Make a few circulations to get consistent warm brine returns 27. Attempt to circulate between the perforations at 385' and 350' 28. If successful circulate bottoms up and freeze protect the well with diesel 29. If un successful pull out of retainer and freeze protect the well with diesel 30. Set retrievable bridge plug (WRP) at 300' 31. Test WRP to 2000 psi 30 min 32. Nipple down BOP's 33. Install tree cap on master valve with needle valve 34. Insure master and annulus valves are closed, remove valve handles 35. Demob End of Sundry procedure Iko Bay #1 Sundry Subsequent Report 04-27-2017.docx Page 8 of 38 �1 �J9pM1d9 AGt1iA AIARSHCREEK 14 ppg Arctic Cement Blend h11o..rrt "Wart Omma p..lov Sf.rg9 ISlpti Sc` hA b1 rge r %=pZRr.d Tll.tv.r Hm Emp.Ouv Sump NA&t IWO- "Tt 1 mes "I.rar.T 0-optslvtWne9 Ilp Bison en14 Wpl i.dm �1i:Ja"Y. ra.0 n�1T to 11� Ip4-- -- i 1I TO -I 7W----.— .--.. -- 1 eo�. epo — fl ism I 1 Jo 4 1 30 S 7e ' 2w 0 Is >0 45 m 76 1Ww.It "1 Io•,9m W pl I KID Ili 1r. Id Np b" Unk i Ortb.t 500p1 31199e %Rp .r. tmp. NAA t15tnd 1:411161 $13191 I.M111 e.Q.l Mp.t ➢Aska".d SPIN- BfCr tr� Illr 1S]pl h.trd IA40111IId1IY B15T tr� Nlr A7 pi J.0 hW her I Ae Nr. ArcticSET1 (AS1) Cement Blend Indow..l WA L.rtp9re.*. S NOMlollp. Schlumberger 5.w4&MP.r.d 30uwM IdrlrunPwew.SR.ptr 1911Pa.l IlUx Proil"O TWMSw....191W.bry I.I.Poom .l 19I91eT166 I.c.Wd.- .1 P] IEi LIN 07 190 P II 1 Ism 1077 17 it I9 T00 1. T — 0.00 iP 1109 1Sm Inu1111A11Ai lots WorC,.A4 59p0 LIRA 141.n.r Mlaoel nuillu1 fad. r A..d.dd 5WP.t ZMW Sdp.aor. O wl Imp.- txrl I.q Sl.n.d 21TA B.Mv, Imirwad Imps WA :Awp91 1.99o91.d brim! IMAM dd 11551: Y04 179r. WA P.Md 4wp= 1I1,IIAAI JAW w h"r 74 WA pe 1.ret A.St Im Pori Iko Bay #1 Sundry Subsequent Report04-27-2017.docx Page 9 of 38 �o �. M.AAr. MARSHCREEK #03) Original Approved Sundry Procedure Deviation ..w. Change Notice Well Name: Iko Bay # 1 API No: 50-023-20007-00-00 Change Re uestor: Marty Lemon P.E. I Chan No: 1 Change Category (Check all that apply): ❑ Change from original requirements/deliverables ❑ Standby waiting on BLM decision ❑ Change in well conditions anticipated ❑ Revised Executive Procedure and Sundry ❑ Other (specify) Does this Change Affect (Check all that apply): *0 Agreed scope as noted in contract / Sundry ❑ Schedule C1 Cost ❑ Other (specify) Describe the Change Being Requested: Sundry procedure states to nm a Halliburton Cement Bond Log from --900' to surface and repeat logging run while holding 1000 psi on the 2 7N' tbg. The base log was run twice with two different tool, both indicate there was conductivity with the formation outside the 2 7/8" tubing over entire interval logged. No need for a pressure pass to improve log results. Describe the Reason for the Change: BLM and PRA agree no additional data would be obtained mating the log under pressure. Describe any Technical Changes Required to Implement this Change: None Describe Project Impacts: None Estimate Resources Needed to Implement this Change: None Estimate Costs to Implement this Change: None Describe impacts if any to meeting BLM Onshore Order # 2: None BLM Acknowledgment: Note: Acknowledgement does not imply approval By - of changes or cost impacts_ Thus form is for BLM Print Name awareness. Offictat approvals must be in writing from the COR or CO. Title: BLM Comments: Iko Bay #1 Sundry Subsequent Report_04-27-2017.docx Page 10 of 38 LU 47) Rr..�w.AG+4 MARSHCREEK �txrtucwr� �� Change Notice Well Name: Iko Bay # 1 f API No: 50-023-20007-00-00 Change Re uestor: Marty Leman P.E. Change No: 2 Change Category (Check all that apply): .`•_ ❑ Change from original requirements/deliverables ❑ Standby waiting on BLM decision ❑ Change in well conditions anticipated ❑ Revised Executive Procedure and Sundry ❑ Other (specify) Does this Change Affect (Check all that apply): `, ❑ Agreed scope as noted in contract / Sundry ❑ Schedule ❑ Cost ❑ Other (specify) Describe the Change Being Requested: Iko Bay # 1 Sundry Change Request # 1 __ 4-5-17 procedure calls for setting a cast iron bridge plug (CIBP) above the previous set of squeeze perforations before moving up hole to the next attempt. The purpose of the plug is to reduce the volume in the tubing prior to executing the cement job. Describe the Reason for the Change: The distance between the upper squeeze perforation and the lower squeeze perforation in the top two proposed squeeze intervals between 425' / 330' and 385' / 350' are short enough the CIBP are not required. Describe any Technical Changes Required to Implement this Change: None Describe Project Impacts: None Estimate Resources Needed to Implement this Change: None Estimate Costs to Implement this Change: None Describe impacts if any to meeting BLM Onshore Order # 2: None. No BLM requirement to run a cast iron bridge plug (CIBP) in this circumstance. BLM Acknowledgment: Note: Ack7owledgement does not imply approval By of changes or cost impacts. This form is for BLM Print Name awareness. Official approvals must be in writing from the COR or CO. Title: BLM Comments: Iko Bay #1 Sundry Subsequent Report 04-27-2017.docx Page 11 of 38 } mp..M.16 i11ARSHCREEK 4 Previous WellSchematic s1A1 �C R� l l' [ko Bay NIA Febma 7 19NPR - Alaska !Sud: eridian TownshipRange Section Created Umist 21N I I6W 16 Current Wellbore Schematic Last Mad I11=017 PHTD■916'MD 70-2731'MO CASING AND TUBING DETAIL SIZE WT IGRADE CONN ID MD TOP MD am 24" 1B' 16" 75t1 N .80 15 124" 149' 10.75' 514 P-110 9.85" 1,190' 7" 2311 C-95 6.366" 1,270' 5.5" 201i J-55 4 788" 1,212' 1,950' 2-675" 6.5# 1-55 2.441" Swfam 1,300' Cement Retainers NO Depth ID Item 1 TBD 2-5" 1 CIBP 2 TBD 25" CIBP Tubing Punches Date Depth Comments Apr. 2026 91W Apr. 2016 915' Winter 2017 TBD Depths will be determined based of COL REVISED. l IMOl7 DRAWN BY- Nolan Youngmun iko Bay #1 Sundry Subsequent Report04-27-2017.docx Page 12 of 38 1 0 F�A m..0 AIARSHCREEK 30' Mo ! TVD GROUND LEY"]) •r ° •CEMENT t• To SURFACE L9MD /TVD 660 SKS PERMAFROST 166' MD ! 7VD24' j75' OD CONDUCT s MD / TVDSET ®IB' GL 0 MD ! TVD 40` NV /TVD22'HoLe _ 330' M / TVD 166' ND ! TVD DIISEL 16' 75# N-80 R3 8 Rro . n K3 15.124' DID- 14 936' �; _ CEMENT T SURFACE SET 0 149' HD / TO •, �• SKS RHAFRDST • OBSTRUCTIONS IN ANNULUS DRILLING FLUID - FREEZE POINT 6°F � — �• NACL BRINE TO 9.6 PPG BASE OF PERMAFROST — 720' MD ! TVD - FLOW V SC PLUS POLYMER 720' MD ! TVD749' - MD /TVD BARITE TO 11.4 PPG, 2.5 PPG CEMI y 790' MD ! TO FORMATION Ftu D ~� 14.75' HOLE �� — 910' MD !TVD 1,220' MD ! TVD 915' MD !TVD 10.75' 51# P-I10 R2 BTC ID: 9.850' DID: 9,69L' B: 5,600 PSI C: 2 500 PSI CEMENT To SLwzCE 1,190' MD / TVD y - BID SKs P—,,— • ��1 — , L SHOT TUBING PUNCH SINGLE PHASE ORIENTATION . BROWN LINER HANGER yl J. • 7' 23# UKN GRADE (ASUME C-95) R3 f t ID: 6.366' DID: 6.241' , B: 5,000 Ps C: 2,500 PSI r �_'• 1,300' MD / TVD --'JT 2-716, TUBING 1,270' MD / TVD t CEMENT 5-5' 20# J-55 R3 r �. - 1,135' WGHT - 90 BBL, :2.5 PPG ARCTIC: SET CEMEr ID. 4.788' DID. 1-.653' TOP OF CEMENT NOT VISIBLE IN THE B, 5,000 Psi C: 5,000 PSI j '� •i� ANNULUS ON THE CBL, TOP: 1,212' MD / TVD - CEMENT TAGGED IN TUBING AT 915' BOTTOM- 1.950' MD ! TO ORANGE PEALED ON BOTTOM r '� SLOTTED, 1,2L2'-1,274' 1,562'-1,648' 1,307'4370' 1,732'-1,775' i• . ' - I,L69'-1,536- 1,905'-1,950' 1,950' MD ! TVD �' 1••+ 2.875' 6.5# J-55 R2 8 Rro 2�035- MD / TVD ID! 2.41,1'DID: 2.347' t4�T •• •:'_• B: 5,000 Pst C: 5,300 Psi CEMENT - 175' HE GHT VD Cur: 1,300' MD / TVERIFIED WITH CCL =; 1°� �° -120 SKS CLASS G CMT 1,942 MD !TVD �vvvvvvv 2,200' MD / TVD 9.625' HOLE i.vvvvvvv� 2.702' MD / TVD frrfrrrrr rfrffrrf fffffrrrr r rrffrr• 7fffffr.. •.rrrrrr fffffffrf rrrrrrff •.. • --_-- ref DRIµANG MUD r.rrrr.r• - 11.4 PPG LEGEND •.frrffr •....r rrr rrffrrrr 2,702' h0 /TVD CEMENT rrrffrrf• r • • • r • Da.1aw Fw a 7.625' CARE HOLE 2, ]31' MD ! TV()© DIESEL 2,731- MD I ND Q II.4 MVD/9.6 BR.E 12.5 CEMENT POMATmm Fwla o.s-ox • c.0 LAT. 71°I0`I7.180' N LONG. 156110126.276' W DATIM: NAD B3 US DEPARTMENT OF INTERIOR IKO BAY No. I API # 50-023-20007-00-00 PERMIT TO DRILL # I00-0360� ti � N I A R5 H �. R E E K EAST: 1,856,250 US FT NORTH: 6,281.360 US Fr ZONE: ASP 6 SECTION: 16 TowNsHIP: 21 N RANGE: 16 W MERIDIAN: UMIAT FWL, 2,500 Fs FSL: 1,850 FT ELEV: 28 FT RKB. 12 FT SRO DATE lCompLETioN DATE STATUS DATE STATUS 01 FEB 1975 1 23 FEB 1975 1 20APR 2016 ISLwemm DATt . 9/29/206 By: SCOTT FtNPEGA CONMENrS: CURRENT WELL BORE SCHEMATIC 4/2016 REv1s aN SCALE- a 1 I:ti Iko Bay #1 Sundry Subsequent Report04-27-2017.docx Page 13 of 38 RtA Re,.,,wpLL,i� A1ARSHCREEK RKS GROUND LEVEL Wl .1• /• 15' MD / TVD 10' MD / TVD ?40' MD / TVD 530' MD / TVD 10 r _ ". , DRILL.NG FLU O I1 FREEZE POINT 6'F OBSTRUCTIONS IN A NLLLS '! .' - �� -�• - NACL BRINE TO 9 6 PPG '/' •',�, - FLOW VISC PLUS POLYMER 720' MI) / TVD BASE OF PERMAFROST / i 7L9' MD / TVD - BARITE TO 14 PPG, [2.5 PPc 720 MD / 1 VD 790' MD / TVD FORMATION FLUID 910' MD / TVD r 915' MO ! TVD 4 SHOT -USING PUNCH !1 S NGLE P'-IASE ORIENTATION _ .•j - BROWN LINER HANGER J: R 7" 23# UKN GRADE (A.SUME C-95) R3 % D 6 366' D-D• 6.21.1' B: 5,000 Psi C: 2,500 Psi r 1,270' MD I TVD i �, ✓' 5.5' 20# J-55 R3 ID 4.788' D:D: L.653• : is B: 5,000 PS. C: 5,000 PSI r TOP- 1,212- MD / TVD ' • ' �!• •� BOTTOM: 1,950' MD / TVD ORANGE PEALED ON BO-TOM SLOTTED: 1,242'-1,271A 1,562'-1,648' 1,307'-1,370' 1.732-1,775' �. I,L69'-1,536' 1,905'-1,950' ;- 2.875' 6.5# J-55 R2 6 RIND :,�i 10. 2.445- DID: 2.30" �•. :~' !bit �•�� B; 5.000 Psi C-. 5,300 Psi t ~':r•rj CUT; 1,300' MD / TVD VERIFIED WITH CCL ; A. 11942' MD / TVD MD / TVD CUT 2-7/8' TUBING CEMENT - 1,135' FVGHT 90 BBL 12.5 PPG ARCTIC SET CEMEN - - TOP OF CEMENT NOT VISIBLE N THE ANNULLiS ON THE CBL. - CEMENT TAGGED hN TUO NG AT 9 E MD / TVD """" rrrrrrrr. LEGEND rrrr..rr •... r r r.. CEMENT wvvvvvvvvi rrrrrr DRLL1NG FLUW Q DIMIL Q 4 MVD/9.6 BRINE 12H 5 CEMENT F(wArm" FLUw OMTRJ IWB LAT. 71-10-17,181) N LONG: 156'10'26.276- W DATUM: NAD 83 US DEPARTMENT OF INTERIOR IKO BAY No. I API # 50 023 20007 00 00 PERMIT TO DRILL # 100-0360 1 � R S H C' R E E K EAST. 1,856,250 US FT NORTH: 6.281.360 US FT ZONE. ASP 6 SECT ON: 16 TOWNSHIP: 21 N RANGE. 16 W MERfDAN: UMIAT FWL: 2,500 FT FSL: 1,850 FT ELEV. 28 PT RKB. 12 FT SFUD DATE ICOHPLETION DATE STATUS DATE STATUS 0: FEB 1975 1 23 FEB 1975 1 20APR 2016 JSUWENDEO T9/29/2016 BY. SCOTT FINTEGA COMMENTS: URRENT WELL BORE SCHEMATIC FW-V'SION: I SCALE Rn:: we HiftWWKK INTER STRINGS ONLY 4/2016 ` KID Bay #1 Sundry Subsequent Report--04-27-2017.docx Page 14 of 38 111ARSHCREEK SIARSHCRHHK m--- Iko Bay #1 Rig: WA Spud: February 1, 1975 NPR - Alaska Meridian Township Ran a Section Created Umiat 21 N 16W 1 16 Current Wellbore SchematicF Toast Mod 04/14/2017 WID CASING AND TUBING DETAIL SIZE WT GRADE CONN ID MD TOP MD t3TM. 24" 18, 16"(Not Observes a sumo 759 N-80 16.124" 149' 10.75" 51# P-110 9.85" 119tr 7" 23# C-95 6.366' 1270' 56, 209 J-55 4.788" i 212' 1 950' 2 875" 6 5# J-55 2 441" Surface 1 300' M ppq = N1C19ms(Qlrgq Fbwvac Ps►Aw NO 114 ppp Cemat 125 ppp Fa Pufal nd;m rMD 913m MD .,r Tbg ill • LY31' ND Cement Retainers & Plugs Date Depth Item 04/10/2017 300' 24" Brico Wireline Retrievable Bridge Plug, Rated to 10,000 psi Product #10-049-0250 04/09/2017 -475' Thru Tubing Systems Cmt Retainer Pars No_ 2:1-,209 003 LO 2.09" OD 2-%" Cement Retainer Rated 10,000 psi 300 04/09/2017 415, Thru Tubing Systems Cmt Retalner Put No. 21,a 20B 003 Lo 2.09" OD 2-fie" Cement Retainer Rated 10,000 psi 300 Deg) 04/138/2017 590' Thru Tubing Systems Cmt Retainer Port Na. 21;13.20.003 La 2.09" OD 2-%" Cement Retainer Rated 10,000 psi 300 Deg.) 04/08/2017 620' ACT {"�""°" m"'"'"" "'"'l 2.160" OD Model BKR Premium Drillable Brld a S. Rating: 10,000 @325 Deg. 04,06/2017 g37' Thru Tubing Systems Cmt Retalner Pert No. zimm9.oa3 so 2.09" OO 2-%* Cement Retainer (Rated 10,000 psi 300 Deg.) 03/30/2017 900' 2-%" Brno Wireline Retrievable Bridge Plug, Rated to 10,000 psi Product #10-049.0250 Tubing Punches Gun s cations: 1 9118" OD 4 spfZero Dearee Phased Date Depth Number of Hoks Comments 04/06CO17 330' — 334' 13 Saw 30 psi pressure loss Q330, 04/0812017 335' — 338' 9 04/09/2017 35D' — 354' 10 D410912017 385' — 389' 10 04/10/17 Unable tD sting into retainer @3751. Aborted circulation attempt 04/09/2017 425' — 429' 13 Achieved no circulation between 425' & 330' — 338' 04108/2017 600' — 604, 10 Achieved no circulation between 600' & 330' — 338' 04/07/2017 790' — 794' 13 Achieved no circulation between 850' & 790' 04/06/2017 850' — 854' 13 04/07/17 Achieved no circulation between 850' & 330' r 2016 910' No Circulation or In ection r 2016 1 915' 1 No Circulation or Injection Iko Bay #1 Sundry Subsequent Report04-27-2017.docx Page 15 of 38 Mr..X.4 NIARSH CREEK HCREEK 3'!a', 5 000 psi flange Tree Cap x 1502 with nipple, gauge and bleeder Valve FMC OCT Tubing Head Top Flange 6" 5000 psi Btm Flange 10" 300D psi NOTE: rM Thp i4md h.a dnn Dmo * Ad f"d in not API C oftflt 2" 3k Rockwell Plug Valve Dynamic Balance Plug Valve Cameron 3k ball valve Gauge wl Bleeder valve �r 2" x 10" Threaded Nipple OD- 2,375" WT. 0.436" 10" 3,000 psi — NOTE: D=m6nwd."dn nef AA Cox 7' Ttweaded Bull Plug - OD 2.375" WT 0.218" Regan Csg head, 10" 3k x 16", 3k Machined to slip-on 1 Weld -on to 10 3W casing NOTE 17 3h i. D4roKYn4 a and h ml API cemplrK 1.856.250 us `WL: 2,500 FT FSL: 1.850 SPUD DATE ICOMPLETION DATE 01 FEB 1975 1 23 FE8 1975 I 3-i18", Model M 12D FE5,000 psi gate valve �FMC Installed in 2016 u FMC OCT Tubing Head Adapter. 6", 5k x 3118" 5k 2", 3K Rockwell Plug Valve Dynamic Balanoe Plug Valve Threaded Gauge w/ Bleeder valve Cameron 3k ball valve, Threaded - 2" x 10" Threaded Nipple OD: 2.375" WT: 0.436' F 112" Ball Valve - Should be covered with Cml "Casing 16" Casing (Not observed) 10 J" CASING 7' CASING 2 e TUBING US DEPARTMENT OF INTERIOR IKO BAY NO. 1 API * 50-023-20007-DO-00 PERMIT TO DRILL * 100-0360 ?k111LRS1IC REIX DATE1A MAV inn BT' s1CWTvI[t Iko Bay #1 Sundry Subsequent Report04-27-2017.docx Page 16 of 38 0 Daily Operations Report Well Name: Iko Bay #1 Operator: BLM 50.023-20007-00.00 Report #: 1 Report Date: 29-Mar-17 Contract #: L16PC00003 Weil Type: _ Gas Producer API #: Field: NPR -Alaska PTO #: 100-0360 Contacts - Weather Supervisor: P _ Site Manager: g /CiC BLM PI: Shane McGeehan Scott Finnegan phone #: phone #: (801) 556-0946 1907}350-9566 Gen. Conditions: Clear l n/a 5 MPH West -13 -26 Phase: Chad Thompson Phone #: Wind Speed: Wind Direction: temp. (Low, High): Rodney Brashear Phone #: _ Windchill Temp. low Hi h : TD: 21731 GL, ft: Well Status 28 Planned Days: 10 PBTD: gis RKB, ft: 12 Start Date: Operation Days- 1 Last Evac Drill: 29-Mar-17 1 3/2S/2017 Fluid in Well: Tbg: Diesel (7.0 ppg) Ann: 9.6 ppg NaCl brine, barite, cement OH ID, in: 7.625 Last BOP Test: n/a Last Safety M : 3/29/2017 C4 String OD (Inj I Depth Iftl Weight (#/ft) Integrity Issues Drive Pipe: 24 18 NA Conductor: 16 149 75 Surface: 10.75 1,190 51 Production: 7 1,270 23 Slotted Liner: 5.5 1,950 20 Tubing: 2.87S 1,300 6.5 Master valve leaks at 1500 psi Pump Parameters Pump # Type Model Rate (BPMj Pressure (psil 100508 Mud Pump TEE-165 Mud / Brine Properties Fluid Type Weight (ppg) Volume (bbls.) CaC12 (brine} 11.4 Not mixed yet Cummulative Volume (bbls): 0 Fluid Waste Fluids Personnel Personnel on Board: I32 _ft Company # People Company # People Company # Pea Ie Marsh Creek BLM AOGCC_ Pollard 25 1 _ 2 PRA UIC 1 Halliburton 1 Fairweather 1 1 MI-Swaco CH21-1ill ISchlumberger Operations Report I 1 24 Hour I Inspect wellhead, Stage tool conexes, Boiler, Accumulator, Power up equipment, Set in boom truck, Build work platform around well, Heat up I .Summary: wellhead, Spot Pollard wire line unit and equipment. F24 Hour Test Pollard wireline Lubricator, Make up Gauge ring, Run in hole to 915', Run Retrievable Bridge plug and set above perforations at 910', TestBridge plug, Make up Halliburton logging tools, Run In hole Log from 900'to surface, Set Retrievable bridge plug at 300' and test, Rig down recast: wireline HSE Summary: No accidents or spills to report, Safety Meeting topic Rig up safety, Muster Areas From To Hours Operational Details (6:00 - 6:00) Safety Meeting - Use spoter and proper hand signals when setting equipment Set in place three tool conexes, Boller, Accumalator, power up and heat up Build work platform around well, Set in circulating tank and test equipment Tarp in work area around well and heat up Check well for pressure, 400 psi on tubbing, 0 psi on casing, Fill boiler and build steam, Set Air compressor and heat up Set Pollard equipment in place and rig up 6:00 7:00 1:00 7:00 10:00 3:00 10:00 13:00 3:00 13:00 15:00 2:00 15:00 15:30 0:30 15:30 17:30 2:00 17:30 20:00 2:30 0:00 0.00 0:00 Total Hours: 14:00 Remarks: X \IANVII� Daily Operations Report Well Name: Iko Bay #1 Operator: API M PTO M BLM 50-023 20007-M CIO 100-0360 Report #: Re rt Date: Contract #- 2 30-Mar.17 L16PCOOD03 We11 Type: Gas Producer NPR -Alaska Field: Contacts Weather Supervisor. P Shane McGeehan S Fincott negan Phone #: Phone #: (801) 556 0946 en. Conditions: Haze n/a Southeast 3 8 -11 •2 24 13 Site Manager: (907) 350.9566 Phase: OA/CIC, Chad Thompson Phone #: Wind Direction: BLM PI: Rodney Brashear Phone #: Wind Gusts (mph): Temp. (tow, High): Wind-chill Temp. (Low, Hi Well Status TD: 2,731 GL, R: 28 12 Planned Days: 10 _ 29-Mar-17 2 PBTD: 915 RKS, ft: Start Date: Fluid in Well: Diesel OH ID, in: _ 7,625 Operation Days: Last BOP Test: n/a Last Saf Mt 3/30/2017 Last Evac Drill* 3125/2017 Strip 00 la Depth (ftj Wetkt.til/flij Integrity Issues Drive Pipe: 24 18 NA Master valve leaks at 15D0 psi Conductor; 16 149 75 Surface. 10.75 1,190 51 Production, 7 _ 1,270 23 Slatted Liner: 5.s 1,950 20 Tubing: j 2,875 1,300 6.5 Pump Parameters Type Model Rate [SPMj Pressure [psij Pump # 100508 Mud Pump TEE-165 Mud /ARrrine Properties Fluld Type Wei ht ppe) Volume [bbis.j Cumulative Volume bbls): 0 Waste Fluids Fluid Type I Wei&&htjl Daily Volume bbts.j Cumulative volume {bbls); _ 0.0 Personnel Personnel on Board: 34 Company # People Company # People Co # People Marsh Creek 22 PRA Halliburton MI-5waco 5chlumber er 1 1 1 1 Atlgun 1 UIC 1 Fairweather 1 CH2MHill 1 BLM 2 AOGCC Pollard 2 'Operation_sl Rep ort 24 Hour summary: Safety meeting regarding wellsite communications and working with explosives while running wireline. Tbg pressure was observed at 400 psi, 0 psi on csg. Attempted to bleed down well. Tbg bleed down from 400 psi to 100 psi, all gas. We were unsuccessful In bleeding the tbg down to 0 psi Make up lubricator, make up wireline tool string w/ 2.24" gauge ring. Test lubricator to 250 psi (low) & 2500 psi (high) for 15 minutes each, no bleed off was detected. RIM w/ gauge ring to 915', POH. While running the gauge ring the tbg pressure built back up to 400 psi. Make up WRP, RIH w/ WRP, set at 900'. Test WRP for 1500 psi for 30 minutes, no bleed off detected. 30 gallons of diesel displaced downhole to pressure up well to 1500 psi. -70 gallons of diesel was recovered during bleed -back Make up Halliburton temp log. Install decoder to Pollard wireline unit. 24 Hour Forecast: Run temperature log from 900' to surface at 0 psi. Run CBL from 900' to surface at 0 psi. Repeated CBL from 900'to surface at 1000 psi. RIH with second WRP to 300', test WRP to 1500 psi for 30 minutes. Replace leaky master valve. NU 4-1/16" SOPS. HSE Summary: No accidents or spills to report, safety meeting topic rig up safety & muster areas. Iko Bay #1 - Daily Operations Report (April 21, 2D17) From To Hours OperationalDetails 16:00-6:00) 6-00 7:00 1:00 Safety Meeting, Good communications with new people on location, working with explosives whale running wire line. Tubing pressure was observed at 400 psi, 0 psi on csg. Attempted to bleed down well, Tbg pressure bleed down from 400 psi to 100 psi, all gas, unsuccessful to bleed tbg pressure down to 0 psi, Make up lubricator, make up wireline tool string with 2.24" gauge ring. Test Lubricator to 250psi (15 minutes), 2500psi (15 minutes). No bleed off detected,. 7100 10:30 3.30 10.30 11:30 1,00 11,30 12:00 030 Run in hole with gauge ring to 915', pull out of hole. While running gauge ring tbg pressure built back up to 400 psi. 12:00 1430 2,30 Make up Wirellne Retrievable Plug (WRP) Run in hole w/ WRP, set at 900', Pull out of hole. 14,30 16:00 1:30 Test WRP to 1500 ps.i for 30 minutes, no bleed off detected- 16:00 18:00 2:00 30 gallons of diesel was displaced downhote to pressure up well to 1500 psi. `70 gallons of diesel was recovered during the bleed -back. 18:00 19200 1:00 Make up temperature log. Instal Haliburton decoder to pollard wireline unit. Total Hours: 13:00 Remarks- Iko Bay #1 - Dally Operations Report (April 12, 2017) ♦N�llt k� Daily Operations Report ' 11 ' w ! Well Name: Well Type: Field: _ Iko Bay #1 Operator: Gas Producer API #: BLM Report #: 3 31-Mar-17 L16PC00003 50-023-20007.00.00 Report Date: NPR -Alaska PTO #: IM0360 Contract #: Contacts Weather Supervisor: Shane McGeehan Scott Flnneltan Phone #: Phone #: {801) 556 094fi (907} 350 9566 Gen. Conditions: Phase: Overcast and partly cloudy East / North-east calm 8 -20 -2 36 -12 Site Manager. g QA/QC Chad Thompson Phone #: Wind Direction: BLM PI. Rodney Brashear Phone #: wind Gusts (mph): mp. (Low, High}: Ind -chill Temp. ELow Hi 28 1 Planned Days: 10 29-Mar-17 TO: _ 2,731 NEMEW.NILtatus Gl, k: PSTD: 915 RKB, ft, 12 Start Date: Fluid in Well: Diesel OH ID, in: 7.625 Operation Days: 3 n/a Last BOP Test: n/a Last Safety M : 3/31/2017 Last Evac Drill; . Csg String OD I in} Depth ft Wei ht #/ft Integrity Issues Drive Pipe. 24 18 NA 75 51 Master valve leaks at 1500psi Conductor. A 149 Surface: 1Q,75 1,190 Production; 7 1,270 23 Slotted Liner: 5.5 11950 _ 20 6.5 Tubinir. 2.875 1,300 Pump Parameters Pump # Type Model I Rate4BPMj j Pressurejpsi) 100508 Mud Pwnp TEE-165 Mud / Brine Properties fluid Type Wei ht } Volume jbblS.} Cumulative Volume bbls}: 0 Waste -Fluids Fluid Type Weight (ppgj Daily Volume }bbls.) Cumulative Volume {bbls}: 0 Personnel Personnel on Board: 34 Company # People ComganV # People Company # People Marsh Creek 22 PRA 1 Atlgun 1 BLM AOGCC Pollard 2 Halliburton 1 UIC_ 1 1 1 MI-Swaco 5chlumberger I _ 1 1 jCH2MHIII Fairweather 2 Ope"`"'rations Report 24 Hour Summary: Safety meeting regarding wellsite safety. RIH w/ temperature log. Log from surface to 900'. At 900' temperature was 34 F, at 200' temp was 19 F, fluid Interface was observed at -220'. Log second pass from 900'to surface. PU/MU CBL to wireline. RIH to 900', log to surface at 0 psi. Filled empty well column w/ diesel in 2-7/8" tubing. Repeat CBL run from 900' to surface while holding 1000 psi on tbg. The CBL tog struggled to find free pipe reference points and was decided to POOH and swap make up CBL back up tool. The pressure pass log is not valid. Repeat CBL from 900' to surface at 0 psi. The back up CBL produced the same results. Free pipe not detected. POOH lay down CBL. Make up Wireline Retrievable Plug (WRP) and set at 300', pressure test WRP to 1500 psi for 30 minutes,100 psi bleed off was detected. Nipple down new master valve and remove from wellhead. Nipple down and remove old {leaky} master valve and remove from wellhead. Tubing head adapter seal area in good shape. Nipple up new master valve back onto wellhead. 24 Hour Forecast: Pressure test new master valve. Nipple up BOPS. Pressure test BOPS. HSE Summary: No accidents or spills to report, safety meeting topic: wellsite safety & caution wh'-le running wireline unit. From To Hours Operational Details 16,00 - 6:00) 6:00 7:00 1:00 Safety Meeting regarding wellsite safety & using extra caution while running Pollard's wireline unit. AIH w/ Halliburton temp. log unit. Log from surface to 900' (main pass). At 900' temperature was 34 F, at 200' temp 7:00 8 00 1:00 was 19 F, fluid interface was observed at -220'. log second pass from 900' to surface. Pickup/ Makeup (PU/MU) Halliburton's CBL tool to Pollards wireline unit. RIH to 900', log to surface at O psi Fill 2.7/8" tbg w/ diesel to eliminate void column in tbg. Pressure up to 1000 psi. 85 gallons of diesel was pumped 8:00 9:30 1:30 �030 9:30 10:00 down the 2-7/8" tbg. Repeated CBL from 900' to surface while holding 1000 psi pressure on tbg. POOH, lay down Halliburton's CBL tool. 30:0 11:30 1:30 Struggled to find proper tool gate setups due to lack of free pipe. The pressure pass log Is not valid. Bleed back 30 gallons of diesel (lubricator volume). Well Is now full, can see fluid level In the well. PU/MU Halliburton's back-up CBL tool to verify Initial tool response. RIH w/ CBL calibrate to free pipe (pollard 11:30 12 30 i:DO lubricator). Run COL from 900' to surface at 0 psi. CBL produced same results as the first log, log results showed no free pipe in 12:30 13:00 0:30 the 2-7/8 x 7" annulus. Able to see a little bit of the character around 700' that was seen In last year's logs. 13:00 POOH. Lay down CBL tool. Make up wireline Retrievable Plug (WRP) to eilne. RIH to 300' and set WRP. 14:00 1:00 14:00 14:30 0:30 14:30 15:30 1:00 POOH. Laydown WRP setting tool. Rig up pressure testing equipment. 15:30 Ifi:30 1:00 Pressure test 2nd WRP to 25DO psi, maintained pressure for 30 minutes. 100 psi bleed off detected. 3 gallons of diesel to pressure up, gat back 3 gallons of diesel Nipple down new master valve and remove utilizing crane. Nipple down old (leaky) master valve. Remove old master 16:30 18:30 2:00 valve utilizing crane. Tubing head adapter seal area In good shape Nipple up new master valve onto tubing head _ adapter. 18:30 1900 0:30 Clean up wellsite area. Total Hours: 13:00 Remarks: Daily Operations Report Well Name: �e Ikon Say #1 Operator: BLM Report #: 4 Well Type: Gas Producer API #: 50 023-20007-00-00 Report Date; i-Apr-17 Field: NPR -Alaska PTD M 100.0360 Contract #: L16PC00003 Contacts 1W Weather Su ervisor: P Shane McGeehan Phone #; Phone #- (801) 556-0946 (907) 350-9566 Gen- Conditions! Phase; Direction: Wind Gusts (mph): Temp. (Low, High}: ind-chill Temp. Low Hi h [fear Northeast calm 10 -9 0 -27 -12 Site Manager: Scott Finnegan QA/QC. Chad Thompson RodneyBrashear Phone M.Wind BLM PI. --- Phone #: Wellrstatus TD: PBTD: 2,731 GL, ft: RKB, ft: OH 10, in, Last Safety Mt ! 28 12 Planned Days: _ Start Date: 10 29-Mar-17 915 Diesel 4/1/2017 Fluid in Well: 7-625 Operation Days. 4 2512017 Last BOP Test: 4/1/2017 Last Evac Drill: Csg String OD (in) Depth IN Welght [#/ft) Integrity Issues Drive Pipe: 24 _ i8 149 1,190 NA 75 51 23 20 6.5 _ Conductor is Surface: Production; Slotted Liner. Tubing- 10.75 7 1,270 5-5 2.975 1,950 2,300 Pump Par�ters Pump # Type Model Rate (BPM) Pressure Ipsi] 100508 j Mud Pump TEE-165 Mud / Brine Properties Fluid Type Weight (ppg) Volume (bbls.) Cumulative Volume (bbls): 0 Waste Fluids Fluid Type Wei fit Daily Volume (bbls.) Cumulative volume (bbls): 0 Personne_ Personnel on Board: 34 Company # People Company # People Company # People Marsh Creek 22 PRA 1 Atigun 1 UIC 1 Fairweather �_ 1 CH2MHill 1 BLM 2 Halliburton 1 AOGCC MI-Swaco 1 Pollard 2 iSchlumberger 1 6perdtions Report 24 Hour Summary: Safety meeting regarding wellsite safety, overhead loads and proper reflective equipment. Pressure test master valve to 250 psi (low) and 2000 psi (high) for 30 minutes each- NU 4-1/16" BOPS utilizing the crane. Rig up scaffolding around SOPs and enclose w/ tarps to heat wellhead and BOPS. Rig up choke manifold and hard line to mud -cross. Change out 1.9" pipe rams w/ 1.315" pipe rams Function test BOPS, Test Annular, Inside kill valve and inside choke valve to 250 psi (low) for 30 minutes, passed test. 24 Hour Forecast: Test BOPS: Annular, Inside kill valve and inside choke valve to 2500 psi (high) against the WRP set In the tbg. Test outs de kill valve and outside choke valve to 250 psi (low) and 2500 psi (high) against the WRP set in the tbg. Test choke manifold to 250 psi (low) and 2500 psi (high) against the WRP set in the tbg. Test floor valve to 250 psi (law) and 2500 psi (high) against the WRP set in the tbg. Drawdown test on accumulator. Build 10.4 CaCl2 brine, heat to 130 F. HSE Summary: No accidents or spills to report, safety meeting topic: wellsite safety, wearing the proper reflective gear and using caution while lifting overhead loads. From To Hours Operational Details (6:00 - 6:00) 6.00 7:00 1:00 7:00 9:30 2:30 9.30 11d70 1,30 11:00 13,30 2.30 13:30 15:00 1:30 15:00 17,00 2:00 17:00 19:00 2:00 Total Hours: 13:00 Remarks: :ty meeting regarding wellsite safety, wearing the proper reflective gear around the wellsite and using caution ie lifting heavy overhead loods. isure test master valve to 250 psi (low) and 2000 psi (high) for 30 minutes each. The first test at 2000 psifailed so e connections were checked and tightened. Second pressure test at 2000 psi had roughly 150 psi bleed off. Me up 4-1/16" BOPS (mud -cross, pipe rams & annular bag) while utilizing the crane. up scaffolding around BOPS and enclose w/ tarps to heat wellhead & BOPs. up choke manifold and hard line to mud -cross. _ nge out 1.9"pipe rams to 1.3" pipe rams ction test BOPS_ Test Annular, Inside kilvalve and inside choke valve to 250 psi (low) for 30 minutes, passed test. ' Daily Operations Repo _ •1 •Ntil1i NI 1 K Well Name: Iko Bay #1 Operator: BLM Report M 5 Well Type: Gas Producer API #: 50-023.20007-00-00 Report Date: 2-Apr-17 Field: NPR -Alaska PTD #: 100.0360 Contract #: _ L16PC00003 Contacts Weather Su Supervisor: P Shane McGeehan Phone #:- (801) 556.0946 Gen. Conditions: Phase: Wind Direction: Y Wind Gusts (mph): (Low, High): Windchill Temp. Low Hi h Clear / Foggy n/a East Calm 6 -20 -2 -25 -15 Site Manager. g Scott Finnegan Chad Thompson phone #: (907) 350 9566 CkA/QC' Phone #: BLM PI: Rod e y Rodney BrasTemp. Phone #: Well Status TO: 2,731 915 GL, ft: iRKB. ft. OH 10, In: last Safety Mt -. 28 12 7.625 4/2/2017 Planned Days: Start Date: Operation Days: Last Evac Drill: 10 29-Mar-17 5 3/25/2017 PBTD: Fluid In Well: Diesel 4/2/2017 Last BOP Test: CsS String OD (in) De th (ft] Weight i#{ft) Integrity Issues Drive Pipe; Conductor: 24 _ SB NA 75 16 149 Surface, 10.75 1,190 51 Production: 7 1,270 23 Slotted Liner: 5.5 2 875 1,950 _ _ 20 6.5 — Tubing, 1.300 Pump Parameters Pump # Type Model Rate (BPM) Pressure (psi) D3508 Mud Pump TEE-165 Mud / Brine Properties Fluid Type Weight (ppg) Volume (bbls.) Cumulative Volume (bbis): 0 Waste Fluids Fluid Type I Weight [ppg) Volume )bbls.] —Daily Cumulative Volume (bbis): p Personnel Personnel on Board: 32 - conwny # People Company # People CompanV # People Marsh Creek 20 PRA 2 Atigun 1 1 1 BLM 2 Halliburton 1 UIC AOGCC MI-Swaco 1 Fairweather. --- CH2MHIII Pollard 2 Schlumber er 1 1 Operations Report 24 Hour Summary: Safety meeting regarding welisite safety, proper equipment when handling CaCl2 brine and caution around eline equipment. Test BOPS (annular, Inside out outside kill vale & choke valve, choke manifold: 2 outside valves and 31nside valves, floor valve and pipe rams and drawdown test on accumulator). Rig up hardline to diverter tank. Rig up eline, pressure test PCE on eline. RIH w/ eline and retrieved WRP at 300'. 24 Hour Forecast: Build 10 4 ppg CaCI, brine, heat to 130 F. RIH w/ 1" WS Weight up to brine to 11.4 after Diesel has been displaced from the wellbore. Circulate wellbore w/ 11.4 CaCI, brine for 24 hours. HSE Summary: No accidents or spills to report Safety meeting topic. welisite safety, proper equipment while handling CaCI, brine and caution around eline equipment when pulling WRP set at 300'. From To Hours Operational Details (6:00 - 6:00) 6.00 7.00 1.00 Safety meeting regarding wellsite safety, proper equipment when handling CaCI, brine and rautiknn around eline equipment when pulling WRP set at 300'. Test annular BOP, inside choke valve and outside kill valve against WRP at 300' to 2500 psi. Hold pressure for 30 7:00 8:30 1:30 minutes. Passed test, Test annular BOP, outside choke valve and inside kill valve against WRP at 300' to 250 psi (low) and 2500 psi (high). 8,30 10:00 1:30 Hold pressure for 30 minutes_ Passed tests. Test the two outside valves on choke manifold against WRP at 300' to 250 psi (low) and 2500 psi )high). Hold 10:D0 11:30 1:30 pressure for 30 minutes. Passed tests. Test against three inside valves on choke manifold against WRP at 300' to 250 psi (low) and 2500 psi (high). Hold 1130 13:00 1:30 pressure for 30 minutes, Passed tests. Test floor valve and pipe rams against WRP set at 300' to 250 psi (low) and 2500 psi (high). Mold pressure for 30 1300 14:30 1'30 minutes. Passed tests. Drawdown test on accumulator: full charge = 2900 pst, close annular and pipe rams, pressure dropped to 2350 psi 14:30 15:00 0:30 (650 psi drawdown), Took 43 seconds to pressure up to 2900 psi. Pre -charged nitrogen bottles read 1000 psi Nipple up eline pressure control equipment. Pressure tested same to —250 psi {low) to —2500 psi (high) for 15 15 00 16:30 1:30 minutes each. Make-up pulling tool with stem and jars to retrieve WRP set at 300'. Rig up wireMe. Rig up hard line to diverter 16:30 17:30 1;00 tank. RIH w/ eline to WRP setting depth at -300'. Retrieved WRP and pulled out to surface. RO eline pressure control 17:30 21:00 3 30 equipment. Serviced BOP drilling spool valves. Total Hours: 15:00 Remarks: -�D Daily Operations Report i 11nN+11 k' �i Well Name: 9011 Type: Iko Bay #1 Operator: _ Gas Producer AN q; NPR Alaska PTO p: BLM 50-023.2OW7-00-00 100-0360 Re rt #: Report Date. Contract #: fi 3 Apr-17 L16PC00003 Field: Contacts Weather Supervisor: Shane McGeehan_ Phone #_ (801) 556-0946 (907) 350-9566 Gen. Conditions: Phase: Wind Direction: Clear to Hity n/a East 9 15 Site Manager: Scott Finnegan Phone #: OA/4C. [had Thompson Phone # BLM PI. Rodney Brashear Phone * Ind Gusts (mph). Temp. (Low, High); -20 0 Wind-chill Temp. Low, H h): -40 Will[ Status TD: 2,731 GL, ft. 28 Planned Days: 10 PBTD: 915 RKS, ft; 12 Start Date: 29-Mar-17 Fluid in Well: Diesel OH 10, in; Last Safe Mt 7.625 4/3/2017 Operation Days: 6 Last Evac Drill. 3/25/2017 Last BOP Test: 4/2/2017 Cs$String OD (in] Depth It) We1kcht 0/ftl Integrity Issues Drive Pipe: 24 16 ~10.75 r 1B NA Conductor: 149 75 Surface: 1,1o0 51 Production: 7 1,270 23 Slotted Liner: 5.5 2 875 1,950 1,300 20 6 5 Tubing: Pump Parameters Pump # Type Model Rate{BPM] Pressure(psi] 100SOB Mud Pump TEE-165 Mud / Brine Properties Fluid Type Weight Volume bbis.) Diasel CaCl2 brine 6.9 10.4 In well 5 Mixed in tank 30 Cumulative Volume (bbis): 0 Waste Fluids -- Fluid Type Weight Ippgl Daily Volume Ibbls.l Cumulative Volume (bbis): 0 Personnel Personnel on Board: 32 Company # People Company # Peollile Comisany # People Marsh Creek 20 PRA Halliburton MI-Swaco Schlumberger 1 Atigun 1 UIC 1 Fairweather 1 CH2MHIII 1 FILM 2 1 AOG[C 1 Pollard 2 1 Operations Report 24 Hour Summary: Safety meeting regarding mixing chemicals and caution while lifting overhead loads. R g up batch -mixer, build 30 bbis of 10 4 ppg CaCl2 brine. Rig up tbg handling equ'pment to handle 1" W5. Rig up flow line to diverter tanks (drums). RIH to 896'. Brake circulation w/ diesel to fluid pack wellbore. 24 Hour Forecast: Heat brine to 130 F Circulate 10 4 ppg Ca[I2 brine down 1" W5 and up 2-7/8" annulus. Displace "5 bbls of diesel left in hole. After one full wellbore circulation weigh brine up to 114 ppg CaCl2 Circulate brine for 24 hours. Log Wed morning HSE Summary: 'No accidents. There was a smai amount of trapped pressure from the eline work that sprayed a mist of diesel on ground when the well was opened up In praperatio n to run In hole w/ 1" W5. Estimated to be— 2 gals spill. Safety meeting topic: welisite safety, proper equipment while handling CaC12 brine and caution whi'e lifting overhead loads From To Hours Operational Details ]6:00-6:00) 6!00 7!00 1-D0 ISafety 9:00 2.00 1 meeting regarding mixing chemicals and caution while I,ft!ng overhead loads. Rig up batch -mixer. Build 30 bbis (70, 50# sacks) of 10-4 ppg CaCl2 brine in batch -mixer. 7:00 Ee W $'40 110 2'00 I IRIg up tubing handling equipment )false floor, flow pan & elevator) to handle V WS. Rig up flow line diverter tanks I (drums) to capture diesel displaced from tripping in. There was a small amount of trapped pressure from the eline work that sprayed a mist of diesel on ground when the MOD16 8D 5_00 well was opened up in preperation to run In hole w/ 1" WS_ Estimated to be "2 gals RIH w/ 1" WS to WRP setting depth of 896'. A total of 85,1" tubing jo;nts were run In hole, mule joint was run at bottom of WS, 15,0 I ISM I 2:00 I8roke circulation w/ diesel (40 ga,lons) down 1" WS and up 2 7/8" annulus. No pressure was seen on the surface gage. Clean up equipment around we.lsite- Total Hours: 12M Remarks: l� Dally'00etations Report Well Name: Iko Bay #1 Operator: BLM Report #; 7 Wall Type: Gas Producer API #: M-023-20D07-0040 Report Oate: 4-Apr-17 Field: NPR -Alaska PTO U. 100-0360 lContract #: L16PCODD03 Supervisor-. Site Manager: QA/QC: BLM PI. Contacts Shane McGeehan Phone #: (801} 556 0946 Gen. Conditions: 111ILW Clear n/a East 13 23 30 -19 Scott Finnegan Phone #: (907) 350-9566 Phase: Chad Thompson Phone #: Wind Direction: Rodney Bras_hear Phone #. Wind Gusts (mph): Temp. (Low, High): Wind-chill Temp. Low, Hiiih: _ W_ ell Status TD: 2,731 _ 915 G4ft., 28 Planned Days: 10 Start Date: 29-Mar-17 PBTD: RKB, ft: 12 Fluid in Well: Diesel OH ID, in: 7:625 Operation Days: 7 Last BOP Test: 4/2/2017 Last SafejV Mtr. 4 4/2017 Last Evac Drill: 413 2017 Csg String OD In Depth ft) Welight(4/114 Integrity Issues Drive Pipe: 24 i8 NA Conductor; 16 149 75 Surface; _ 10.75 1,190 51 Production- 7 1,270 23 Slotted Liner, 5.5 1,950 20 Tubing! 2.875 1,300 6.5 Ir Pump parameters Pump # Type Model Rate (BPM) Pressure (psi} 10 500 300SDB Mud Pump TE E.165 Mud / Brine Properties Fluid Type + Weight (ppg) Volume Ibbls.I CaCr2 11.4 30 Cumulative Volume (bbis): 30 Waste Fluids Flu[d Type Weight(ppg] Dailp Volume 4bbIs.j Diesel 5,943 5 Cumulative Volume (bbis)- 5 Personnel 4-1i Personnel CompanV on Board: 33 People .. Companv # People Companiii # People Marsh Creek 21 PRA HaMburton MI-Swaco 1 _ I Atigun I11C Fairweather CH2MHil1 1 T 1 + 1 1 T BLM 2 AOGCC 1 Pollard 2 Schlumbe er 1 Operations Report 24 Hour Summary: Safety meeting regarding wellsite safety. Heat brine to 130 F, rig up batch mixer and rig up hardline from mud cross to circulating tank. Circulate 10.4 ppg CaC12 brine to displace diesel In wellbore- Rig down hard line. Rig up line from mud cross to brine tank. While beginning to circulate brine, the triplex pump suction cup failed causing 10 4 CaC12 brine to spill on the ground. Began circulating 10.4 ppg CaCl2 brine at 130 F, weighed up to 11.4 at the beginning of circulation I4 Hour Forecast Continue circulating until 30 am Trip out. R g up Halliburton CBL / Temp. Log to eline. Log from 900'to surface. Laydown logging tools. Rig up eline to and pulling tools to retrieve WRP set at 900'. HSE Summary: No accidents. There was a spill of CaCl2 While beginning to circulate brine from the batch mixer through the triplex pump the suction cap failed causing CaCiz to spill out of the batch mixer lines and onto the ground It was estimated that -10 gallons of brine spilled on the ground. Safety meeting topic: wellsite safety, proper equipment while handling CaCl2 brine and caution while lifting overhead loads. From To Hours Operational Details (6:00- 6:00) 6:00 7'00 1:00 1:30 Safety meeting topic, wellsite safety, proper equipment while handling CaCIj brine and caution while lifting overhead loads - Heat brine to 130 F using steam line- Rig up batch mixer. Rig up hard line from mud cross (kill valve) to circulating tank to take diesel returns- 7:00 830 Circulate 10 4 CaCl2 brine at 130 F to displace diesel out of the wellbore. Once brine was seen, the triplex pump was shi 9 30 9N 0 30 in and the hardline was rigged down `5 bb6s of diesel {wel:boFe displacement vo'ume) was displaced to the circulating tank. Rigged up line from mud cross (kill valve) to brine rank. While beginning to circulate brine from the batch mixer through the triplex pump the suction cap failed causing CaClito 9 00 30 0:30 split out of the batch mixer lines and onto the ground. It was estimated that " 10 gallons of brine spilled on the ground. Began circulating 10.4 ppg CaCI= brine at 130 F to heat wellhore, Brine was we'ghed up to 11.4 ppg (40, S0M sacks) to g.3# 6 00 2030 serve as KWF in the well. The exothermic reaction fram weighing up brine to 114 brought the brine temperature to 17S F. Before circulation -28 bbls of brine was measured In the brine tank. After circulating and displacing the well with 11.4 CaCl2 brine, 23 bMs of brine was measured I i%the tank. See separate excel sheet for: circulating analytics. Total Hours,. Remarks: �J Daily Operations Report Well Name: Iko Bay #1 loperator BLM Report #: 8 Well Type: _ Gas Producer API #: 50-023.20007-00-00 Report Date: 5 Apr-17 Field: NPR -Alaska PTD q: 100-0360 Contract #: L16PC00003 Contacts Weather Supervisor: Shane phone #- (801) 556.0946 Gen. Conditions: Clear McGeehan Phase: n/a Site Manager. Scott Phone #; [907) 350 9566 Finnegan Chad. Phone #; QA/QC Wind Direction: East Thompson Rodney Phone #: BUM Ph Wind Gusts [mph): 16 21 Bra_sh_ea_r _ Temp. (Low, High): _ S_ 17 Wind-chill Temp. [Low, Hi hl: 15 1 _ Well Status To: 2,731 GL, ft: 28 Planned Days: 10 PBTo: 915 RKB, h: 12 Start Date; 29-Mar-17 ON ID, In: Fluid In Well: Diesel _ 7,625 Operation Days_: 8 Last BOP Test: 4/2/2017 Last Evac Drill: 413/2017 Last Safe Mt 4/ 2017 Csg String OD I in Depth 'ft Weight IN/ftj Integrity Issues Drive Pipe: 24 18 NA Csg not seen at surface. _ _ Conductor; 16 149 75 Surface: 20.75 1,190 51 23 _ 20 6 5 Production_ 7 Slotted Liner_ 5.S _1,270 1,950 Tubing: L875 1,300 .'Pump.Patameters pump # Type Model Rate GPM Pressure I psi) 100508 Mud Pump TEE-165 1.0 500 Mu(d '/ Brifie. Properties Fluid Type We ht Volume I bbls. 11.4 42 Cumulative Volume lbbls): 42 Waste Fluids Fluid Type Weight jppgj Daily Volume{bbls.) Diesel 69 5 Cumulative Volume lbbls): 5 Personnel ._ . Personnel on Board: 33 id k Co"Wriv I #People Co any #People Company #People Marsh Creek 21 PRA Halliburton 1 1 _ Atigun 1 1 BLM 2 LTC_ AOGCC MI-Swaco i _ Fairweather i Pollard 2 1 CH2MHI!l 1 Schiumbergu Operations Report Continued clrculat on w/ 11.4 ppg CaCl2 brine. Safety meeting regarding wellsite safety. Weighed up brine from 10.7 to 11.4 ppg. Circulation was stopped after 24 5 hours of circulation. Rigged down batch -mixer and steam line from boiler. Rigged up tbg handling equipment. Pulled out of 24 Hour hole. Rigged down tbg handling equipment and false floor. Rigged up ellne PCE and fubrcator. Make up COL tool to eline Pressure test ellne to Summary: 250 psi (low) and 2500 ps; (high), hold for 15 minutes each. Log from 900' to surface at 0 psi Repeat pass hold!ng 1000 psi. Lay down COL tool. Make up Temp. Tool. RIH w/ Temp. Tool attached to eiine. Log from 900' to surface Lay down Temp. Tool. Rig down ellne. Punch lower tbg punch at 850'. Run temperature log. Attempt to establish circulation Punch upper tubing punch at 330'. Attempt to establish Hour circulation. Set cement retainer 10' above lower punched holes Heat up well bore Attempt to establish circulation. If circu-ation Is established, Forecast: pump tracer to confirm volume Next lower perforation is at 600' No accidents or spills to report Safety meeting topic: wellsite safety, proper equipment while handling CaCI: brine and caution while using HSf Summary: explosives. From To Hours Operational Details (6.00-6.00) 0:00 6:00 6.00 Continue 24 hour circulation of 11.4 ppg CaQ b ri g e at 130 Of at a circulating rate of 1 OPM. EO G-00 7.00 1.00 Safety meeting regarding wellsite safety, caution while tripping out, pinch points and caution whCe using explosives. Continue 24 hour cirtubtion. At 07:00 mud weight was observed at 10.7 ppg, loss in weight was due to the steam We adding moisture to the brine tank. Began weight up at 09:00 to 11.4 ppg (40, 50# sacks were added). Circulation was 7:00 101100 3:00 stopped after 245 hours. 42 bbis of brine was measured in the tank_ Refer to separate Iko Bay #1 circulation sheet far circulation analytics. 10:00 10:30 0:30 Rig down batch mixer and steam line from boiler. Rig up tbg handling equipment to pull 1" WS. 10.30 13:30 3:00 Pull out of hole Rig down tbg handling equipment and false floor. Rig up pollard ellne Pressure Control Equipment (PCE) and Iubrlcatnr. 13:30 15:1S 3A5 Make up Hallburton's CBL tool to ellne unit- Pump 7 bbis of 11.4 ppg CaClr brine from batch -mixer to circulating tank. Blow down circulating lines from hatch mixer. 15:15 16:30 1:15 Pressure test Pollard's PCE to 2S0 psi (low) and 2500 psi(high) and hofd for 15 minutes each. RIH w/ Hallburton's CBL tool attached to ellne to 900'. Calibrated CBL tool. Logged from 900' to surface at 0 psi. Repeat pass from 900'to surface holding 1000 psi on the 2-7/8" tbg. Lay down CBLtool_ Make up Temp. Log to eline. RIH w/ Halliburton's Temp. Log to 900'. Log to surface at 0 psl- 16.30 18:30 2,00 18,30 19:00 0:30 29:00 20:15 1:15 2M15 22:00 OAS 21:00 22:30 0:30 Lay down Temp. Log. Rig down ellne. Rig up night cap on wellhead, Total Hours: 15,30 Remarks: ♦1.\NMlft RII;K Daily Operations Report Well Name: Iko Bay #1 Operator: BLM Report #: 9 Well Type: Gas Producer API #: 50.023-20007-00 00 I_ Field: NPR -Alaska PTD #: 1OD-0360 Contract #s Contacts Weather Supervisor: p Shane Phone #: (801) 556-0946 Gen. Conditions: Clear McGeehan Site Manager g Scott phone #: 1907j 350 9566 Phase: n}a _ Finnegan Chad Phone #: Wind Direction: QA/QC: East Thompson Rodney BLM PI: Brashear phone #: Wind Gusts (mph); 15 28 Temp. (Low, High): 1 15 Wind-chill Temp. - n 6-Apr 17 1.1613000003 IU: [,r31 GL,rt: 28 Planned Days: 10 29-Mar-17 9 4/6/2017 Pam: 915 RKB, ft: 12 Start Date: Operation Days! Last Evac Drill: Fluid in Weil: Last BOP Test: 12.4 CaCl2 brine 4/1/2017 OH ID, in: 7.625 Last Safety Mitg., 4/6/2017 Css String OD {in Depth Iftj Weight (ft) Integrity Issues Drive PI e 24 16 18 149 NA 75 Csg not seen at surface _ Conductor; Surface: 10.75 11190 51 Production: 7 1,270 23 Slotted Liner: 5,5 1,950 20 Tubing: 2.BT5_j 1,300 6.5 Pump Parmeters _ Pump # Type Model Rate e-P Pressure psi) 100508 Mud Pump TEE-165 1.0 504 Mud►/ Brine P{operties Fluid Type We t j Volume {bbls.) CaC6 11.4 42 Cumulative Volume (bbls): 1 42 6.9 1 5 Personnel an Board: 33 Company # People Company # People Company # People Marsh Creek 21 _ PRA i Atigun 1 BLM 2 _ Halliburton 1 UIC 1 AOGCC _ MI-Swaco _ 1 Fairweather 1 Pollard 2 Schlumberger 1 CH2MHill 1 Operations Report Safety meeting. Rig up perf gun to eline. Pressure up tbg to 500 psi, while maintaining pressure RIH and tie Into recently run COL Punch tbg at 850', no pressure response was seen. POOH w/ eline. Pressure up on 2-7/8" tbg to 2000 psi and attempt to establish circulation, no circulation was established and no pressure response was seen. Make up Halliburton's Temp Log, log from surface to 900', POOH. Rig up second perf gun to ellne. 2hour pressure up tbg to 500 psi, while maintaining pressure RIH and tie into recently run CBI_ Punch tbg at 330% a 30 psi bleed off was seen. POOH w/ Summary: :line. Pressure up on 2-7/8'tbg to 2000 psi and attempt to establish circulation, no circulation was established and `200 psi bleed off was seen on the tbg. Make up cement retainer to eline. RIH and set cement retainer at 837', POOH. R-g down eline and PCE. Rig up tbg handling equipment and false floor. RIH w/ cement stinger attached to 1" WS to 837'. Rig up batch -mixer and circulate 11.4 CaCI, brine overnight Continue circulation of 11,4 ppg,130 F CaCI= brine at a rate of 1 BPM overnight Stab Into retainer with stinger. Attempt to establish circulation Hour between perfs at 850' & 330'. If able to establish circulation then run tracer follower by cement job. If unable to establish circulation POH with 1" Forecast: work string, perforate at 790', RIH with 1' work string, st ng into retalne at 837, attempt to circulate between 8SO' and 790' perforations No accidents or spills to report. Safety meeting topic wellslte safety, caution while using explosives ad being mindful of trapped gas while punching H5E Summary: tbg N From To Hours Operational Details (6:00 - 6:00) Safety meeting regarding wellsite safety, caution while using explosives and being mindful of trapped gas while punching 6:00 7:00 1 1:00 IRIS tbg- 7:00 up Po'lard eline Makeup perf gun to eline unit. 8;00 1:00 Pressure up to 500 psi. While maintaining pressure RIH, tie into recently run Halliburton CBL run. Punch tbg at 850' wlth 8:00 8:30 0:30 a 4' gun 13 shots. No tbg pressure fall off was noted, 0 psl on 2-7/8" x 7" annulus. POOH w/ eline. Allshots fired Nipple up eline PCE night cap. Pressure up on 2-7/8" tbg to 2000 psi and attempt to establish circulation from 850' to 8-30 9:00 0:30 surface. No returns were seen at surface and no tbg pressure bleed off was noted, 0 psi on 2.7/8" x 7" annulus. Bleed off tbg pressure after 15 minutes. Make up Halliburton's Temp. Log to eline. RIH. Log from surface to 900'. POOH. Lay down temperature logging tool. 9.00 10:00 1:00 Lower well at'-36-44F upper well -32-36F Make up second perf gun to eline unit. Pressure up to 500 psi. While maintaining pressure, tie Into recently run 10:00 11.00 1,00 Halliburton CBL. Punch tbg at 330' with a 4' gun 13 shots. An initial 30 psi fal' off in tbg pressure was seen before quickly stabilizing pressure at (" 470 psi), 0 psi on 2-7/8' x 7" annulus- POOH w/ eline- All shots fired Nipple up eline PCE night cap. Pressure up on 2-7/8" tbg to 2000 psi and attempt to establish circulation from 330'to 21:00 11:30 0:30 surface. No returns were seen at surface. Tog pressure bleed off -'200 psi, 0 psi on 2-7/8" x 7" annulus. No returns were seen at surface, Bleed off tbg pressure after 15 minutes- 11!30 12:30 1:00 Make up 2 7/8" cement retainer to eline unit, RIH, Set cement retainer at 837'. POOH, Rig down ellne and PCE. Rig up tubing handling equipment and false floor. 12,30 13:30 1:00 13,30 16.30 3:00 RIH w/ stinger attached to 1" WS to just above retainer at 837% Circulate 11.4 ppg CaCl2 brine down I" tbg and taking returns up 2 7/8" tubing using test pump while rigging up triplex 16.30 18:00 100 pump and circulating lines from the batch tanks. Circulate 21.4 ppg CaCh brine,130 F (out), using the triplex at a rate of 18PM from the batch -mixer tank. We have 18:00 24-00:00 6,00 wrpped steams lines around the outside on the batch -mixer tank, the heat transfer may be'ess, will see If we are able to maintain 130F overnight. Total Hours: 18:00 Remarks •I1N 1 'YDaily Operations Report Well Name: Iko Bay #1 Operator: BLM Report #: 50 023<20007-0D Chi Report Date: 100-0360 lContract#. 10 7-Apr 17 LIGPCOD003 Well Type: Gas Producer API #: Field: NPR -Alaska PTO #: Contacts Weather Supervisor: Shane M_ cGeehan Phone #: (801) 556.0946 Gen. Conditions: Clear n/a East 14 31 1 15 1-28 1 Site Manager: _ Scott Finnegan phone #: Phone #: (907) 35D.9566 Phase: Wind Direction: QA/QC: Chad Thompson BLM PI: Rodney Brashear phone #: Wind Gusts (mph): iTemp. (Low, High): Wind-ddil Tlnlp. (Lew, High): Well Status TD: 2,731 GL, ft, 28 Planned Days: 10 PBTO: 915 RKB, ft: 12 Start Date: 29-Mar47 Fluid in Well: Last BOP Test- 22.4 CaClt brine T 4/2/2017 OH ID, in: 7.625 Operation Dayst 10 4/6/2017 Last Safety Mtg: 4/7/2017 last Evac Drill: Csj String OD jinj Depth [ft) Welght IN/ftj Integrity Issues Drive Pare: 24 i8 NA Conductor: lib _ IM75 149 75 Csg not seen at surface Surface{ 1,190 51 Production; 7 1,270 23 Slotted Liner. 5.5 2,950 20 6.5 Tubing: 2,875 1,300 Pump Parameters Pump # Type Model Rate j6PM) Pressure (psi) 100508 Mud Pump TEE 165 2.0 5DD Mud / Brine Pr`a_ perties Fluid Type _ CaCI, j 77 Weight [ppg] Volume (bbls.j 11.4 45 Cumulative Volume (obis): 45 Waste Fluids Fluid Type Weight j ppg) Daily Volume [bbls.j Diesel 65 5 Cumulative Volume (bbls): 5 Personnel Personnel on Board: 34 Company # People Company # People company # People Marsh Creek 22 BLM 2 _ _ _ AOGCC i Pollard 2 PRA 1 Atigun 1_ 1 1 1 Halliburton 1 UIC MI-Swaco 1 Fairweather CHZMHill 5chlumberger I _ 1 Operations Report 24 Hour Summary: Safety meeting. Weighted up CaCl2 brine to 11.4. Discontinued circulating Stab Into cement retainer w/ stinger. Attempted to circulate brine through the perforations at 850' and up the 2-7/8" x 7" annulus to 330'. Attempt to establ ish circulation was unsuccessful. Attempted to establish circulation down the 2-7/8" x 7" annulus, a small pressure bleed off was noted, circulation was unsucessful. Pull i" WS out of hole. Run Temperature Log from surface to 900' using eline. Punch tbg at 790' using ellne, all shots fired. RIH to `837' w/ stinger. Stab into cement retainer. Attempt to circulate from 850' to 790'. Pressure built to 2000 psi, tb p p g pressure bleed off was notice. Na pressure response was noticed on the csg and no returns were seen at surface. Picked up out of retainer and circulated 11.4 ppg CaC12 brine at 230 F at a rate of 1 BPM overnight to heat the wellbore. 24 Hour Forecast: Continue circulating overnight. POOH. punch tbg at 600', set cement retainer —1G' above. RIH w/ stinger, punch Into retainer and attempt to establish circulation between perfs at 600' & 330'. HSE Summary: No accidents or spills to report. Safety meeting topic: wellsite safety, caution while lifting overhead loads, caution around eline equipment and vehicle safe around camp From To Hours I Operational Details (6:00 - 6:00) N Safety meeting regarding we8site safety, caution while tifting overhead loads, caution around ellne equipment and 6:00 7:00 1'� vehicle safety around camp. Weight up CaCl2 brine to 11.4 ppg 115, SG# sxsj. Discontinue circulating 11.4 CaCI= brine, Temp out = 135 F. Temp In 7:00 8.30 1:30 133 F. Rig down batch•mbrer. Rig up tbg handling equipment to stab into cement retainer w/ stinger. Stab Into cement retainer at 837' w/ stinger. Pressured upon the 1" WS to 2000 psi In an attempt to circulate 11.4 ppg CaCl2 brine through the perforations at 850' and up the 2-7/8" x 7" annulus to 330% Attempt to establish circulation 8:30 9:OD 0:3D was unsuccessful, No returns were seen at surfacm. Csg pressure remained at 0 psi. 1" Work String pressure bleed 9:30 off from 2000 pis to 1500 psi in 15 min. Circulate bottoms up. 9:00 0:30 Rig up tbg handling equipment to pull 1" WS. POOH. Test 2.7/8" x 7" annulus to 2000 psi, moniter for 15 minutes. A 9:30 11:30 2:00 small pressure bleed off was noted. Rig down tbg handling equipment and false floor. Rig up ellne PCE. Make up Halliburton's Temp. tool to ellne. RIH RIH w/ Hal iiburton's Temp_ Log. Log from surface to 9W. POOH w/ ellne. Log run 5 hrs after a 14 hrs circulation 12:30 12:00 0:30 12:00 i2:30 COO Well temp is between -55-60 F the majority of the well Make up / Rig up pert, gun. RIH w/ pert. gun to 790', pressure up to 500 psl. While maintaining pressure, punch tbg at 12:30 13:30 1:00 790' with a 4' gun, 13 shots. No pressure bled off of 2 7/8" tbg. The 2.7/8" x 7" annulus pressure remained at 0 psi. POOH w/ eline. All shots fired. 13:30 14:30 1:00 Rig down PCE, lubricator, heat sock and ellne unit. Rig up tbg handling equipment and false floor. 14.30 17.00 2:30 RIH w/ stinger to cement retainer at -837'. 17.00 18.00 1:00 Worked 1" WS to stab stinger Into cement retainer. Stabbed in w/ 300 psi on tbg, Pressured up on 1" WS to 2000 psi In an attempt to circulate 11.4 ppg CaCl2 brine through the perforations at 8SO' and up the 2-7/8" x 7" annulus to 790'. Attempt to establish circulation was unsuccessful. No returns were seen at surface, 18 1900 1:00 tbg pressure bleed off to 1000 pis. Csg pressure remained at 0 psi. We made three attempts to circulate by bullding up to 2000 psi, each attempt bled off quickly before leveling out at 3000 psi. The in itial bleed off Is suspected due to air in the system. 1:00 1900 _ 20:00 Rig up batch mixer and bailerunit to heat brine to 130 F. 4,00 20 00 24'00:00 Pick up out of retainer, Circulate 22.4 ppg CaCi2 brine at 130 F at a rate of 1 BPM overnight to heat the wellbore. Total Hours: 18;00 Remarks: Daily Operations Report Well Name: Well Type: Field: Iko Bay #1 Gas Producer NPR-A'.aska Operator: BLM 50-023-20007-00-00 1DO.0360 Report #: 11 Report Date: B-A r-17 Contract #: L16PC00003 AN #: PTD #: Contacts Weather Supervisor. P Site Manager: g QA/QC: BLM Pl: Shane McGeehan Scott Finnegan Ckad— Thompson phone #: 180115560946 Gen. Conditions: Clear n/a Northeast 14 20 1 11 -18 -6 Phone N: 1907) 350 9566 Phase: Phone N: Wind Direction: Wind Gusts (mph): —Rodney Brashear Phone N: Temp. [Low, High}: Wind-chill Temp. 1 Low, High) : W061 7__ Well Status_ TD: 2,731 28 Planned days: 10 29-Mar-17 PBTD, 915 12 Start Date: Fluid in Well: 11,4 CaClz brine EL, :Njft� 7,625 4/8/2017 Operation Days: 11 Last BOP Test: 4/2/2017 Last Evac Drill: 4/8/2017 Csd Strip OD in D hIft] Integrkylssues Drive Pipe: 24 18 NA Csg not seen at surface _ Conductor. 16 149 75 Surface; 10.75 1,19L} 51 Production: 7 1,270 23 Slotted Liner: 5.5 1,950 1,300 20 TublnF 2.875 63 Pump Parameters Pump N Type Model Rate I BPM# Pressure € sl) 100S08 Mud Pump TEE-165 1.0 500 Mud / Brine Properties Fluid Type Weight g Volume (bbls.1 CaCl2 1 11.4 51 -- Cumulative Volume (bbls): 51 Waste Fluids Fluid Type Weight f ppRj Daily Volume Ibbis.M Diesel 5.9 5 Cumulative Volume [bbls): 5 Personnel AL _ Personnel on Board: 34 Company # People Company # Peak Company # People Marsh Creek 22 PRA 2 Halliburton MI-Swaco 1 Atigun 1 UIC I Fairweather 1 CH2MHIII 1 BLM 1 1 1 AOGCC Pollard 2 Schlumberger Operations Report - 24 Hour Summary: Continued circulating CaC12 brine at 130 F to heat the wellbore. Had safety meeting. Circulation was discontinued at 07:00, temperature properties were measured at 135 F (In) and 132 F (out), Weighted up brine from 11.3 to 11.4 ppg. POOH with stinger. RIH and set CIBP at 620'. Perforate at 600' and 335'. Set cement retainer at 590'. RIH w/ stinger to top of cement retainer. Stab Into cement retainer at 590' w/ stinger. Attempted to circulate CaClz brine through the perfs. at 6130' and up the 2-7/8' x 7'- annulus to 335'. Attempt was unsuccessful, tbg pressure bled off to 1100 psi after stabilizing. Csg pressure remained at 0 psi and no ret,rrns were se nn at surface. Pick up out of retainer. Rig up batch mixer. Circulate 12.4 CaCl2 brine at 130 F overnight. 24 Hour Forecast: Discontinue circulating. POOH. Perforate tbg at 430' and set cement retainer at 420' using eline. RIH to cement retainer, stab in and attempt to establish circulation. HSE Summary: No accidents or spills to report. Safety meeting top;cs: we'Isite safety, pinch points, scope changes, evac. drills and camp adequate. From To Hours 3 Operational Details (6!00 - 6:00) 0:00 _ 6:00 _ 6:00 7:00 _ 1:00 Continue circulating 11.4 ppg CaC12 brine at 130 F to heat wellbore. Safety meeting regarding wellsita safety, pinch points, scope changes, evac. driils and camp adequate. 6:00 1 N Measure brine properties. Temp in =135 F, Temp out :132 F. Weight up CaCii brine from 11.3 ppg to 11.4 ppg (25, 50q 7:00 7;30 0:30 sxs), Discontinue circulating11.4 CaC! brine. Rig down circulating equipment and tri triplex um PP$ i g 8P pump. 9:00 1,30 POOH the 1"work string w/ stinger. Make up Cast Iron Bridge Plug (ClBP) to ellne unit. Rig up ellne, PCE, lubricator and heat sock. RIH and set CIBP to 620'. RIH w/ ellne_ 9:00 10:00 1,00 10:00 10:30 0:30 Make up / Rig up perf. gun, RIH w/ perf. gun to 600', pressure up to 500 psi. While maintaining pressure, punch tbg at 10:30 11:00 030 600' with a 4' gun, 10 shots, No pressure bled off of 2-7/8"tbg. The 2-7/8" x 7" annulus pressure remained at 0 psi. POOH w/ ellne, All shots fired. Make up / Rig up perf, gun_ RIH w/ perf_ gun to 335', pressure up to 500 psi. Wh,le maintaining pressure, punch tbg at 11:00 1230 130 335' with a 3' gun, 9 shots. No pressure bled off of 2 7/8" tbg. The 2-7/8" x 7" annulus pressure remained at 0 psi. Wireline Sheave dropped after gun fired Indicating perf gun was pushed up hole. POOH w/ ellne- AN shots fired, 12:30 14!00 1:30 Make / Rig up cement retainer. RIH w/ eline. Set cement retainer at 590'_ POOH_ 14.00 15.00 V00 Rig down PCE, lubricator, heat sock and eline unit_ Rig up tbg handing equipment and false floor. RIH w/ stinger to top of cement retainer 1590'j. Worked i"WS to stab stinger into cement retainer. Stabbed in w/ 300 15:00 17;00 2;00 psi on tbg. Pressured up on 1" W5 to 2000 psi In an attempt to circulate 11.4 ppg CaC12 brine through the perforations at 600' and up the 2-7/8`x 7" annulus to 335'. Attempt to establish circulation was unsuccessful. No returns were seen at surface, 17.00 1730 030 tbg pressure bleed off to 1100 psi. Csg pressure remained at 0 psi. We made two attempts to circulate by building up to 2000 psi, each attempt bled off quickly before leveling out at 1100 psi, The initial bleed off is suspected due to air in the system. Rig up batch mixer and bailer unit to heat brine to 130 F. Pick up out of retainer_ Circulale 11.4 ppg CaCr= brine at 130 F at a rate of 1 BPM overnight to heat the wellbore. 1730 1830 100 18,30 24:00900 530 Total Hours: 0:00 Retrorks: 7-5 ,,.KY,,, k Daily Operations Report Well Name: iko Bay 11 operator: Well Type: Gas Producer API#: _ Field: NPR Alaska PTD N: _ BLM Report #: 50-023-213007- uV Report Date: 100-0360 Contract N: 12 9Apr-17 L16PC00003 Contacts Weather Supervisor: p Site Manager: _ Shane McGeehan Scott Finnegan phone #; Phone #; Phone #: Phone M (801) 556 0946 (907) 350 9566 Gen. Conditions Phase' Wind Direction: Wind Gusts (mph): Temp. (Low, High): Wind.chillTemp. low, HI h Hazy n/a East - Northeast 13 22 5 _ 12 -10 -4 QA/QC- Chad Thompson BLM Pi: ey B Rodney ar Well Status _ TD: PBTD: Fluid In Well. Last BOP Test: 2,731 GL, ft: RKB, f ! ON 10, in; _ Last Safety Mtg: 28 12 7.625 4/9/2017 Planned Days; 10 Start Date: 29-Mar-17 Operation Dayst 12 Last Evac Drill: 4/9/2017 915 11.4 CaCl2 brine 4/2/2017 5tri OD in ft h Wei ht N/ftj integrity issues Drive Pipe: 24 _ 16 _ 10.75 _ 7 _ 5.5 2.875 18 NA 75 51 23 20 6.5 Csg not seen at surface Conductor; 149 Surface, _1,290 _1,270__ 2,950 2,300 Production; Slotted Liner; Tubing: Pump Parameters Pump # Type Model I Rate4BPMI Pressure ( sl) 100508 Mud Pump TEE-165 1 1.0 500 Mud / Brine Properties Fluid Type Weight l a pg) Volume ( bbls.) CaCl2 11.4 45 Cumulative Volume (bhis): 45 Waste Fluids Fluid Type Weight ( ) Daily Volume (bbls.) Diesel 6.9 CaCi? 21.4 5 10 Cumulative Volume (bbis): 15 Personnel Personnel on Board: 34 Company # People Comparyt # People Company N People Marsh Creek 22 PRA 2 Haliiburton 1 MI-Swaco 1 SchiumberEer 1 Atigun _ 1 UIC 1 Fairweather _ 1 CH2MH111 1 BLM 2 AOGCC 2 Pollard Operations Report 24 Hour Summary. Continued circulating CaCI. brine at 230 F to heat the welibore. Had safety meeting. Circulation was discontinued at 07;00, temperature properties were measured at 138 F (in) and 133 F (out). POOH with stinger. Perforate at 425'. Set cement retainer at 415'- RIH w/ stinger to top of cement retainer. Stab into cement retainer at 415' w/ stinger. Attempted to circulate CaCI. brine through the perfs. at 425' and up the 2-7/8' x 7` annulus to 335'. Attempt was unsuccessful, tb pressure bled off to 17M psi. Cs p g p p g pressure remained at 0 psi and no returns were seen at surface. POOH. Perforate at 385' and 350'. Set cement retainer at 375' 24 Hour Forecast: Rig up eline and run Temperature Log. RIH w/ 1" work string attached to stinger. Discuss w/ town to see if circu`ation is necessary. If circulation is not necessary attempt to establish circulation between 385' - 350'. HSE Summary: No accidents or spills to report. Safety meeting topics: welis_te safety, mixing chem;cals and staying clear of explosive loading site. From To Hours Operational Details (6:00- 6:00) O:DO 6:00 6:00 6:00 Continue circulating 11.4 ppg CaClt brine at 130 F to heat wellbore. 6:30 0:30 afety meeting regarding wellsite safety, mixing chemicals and staying clear of explaslvt loading site, O n �- Measure brine properties. Temp in t 138 F, Temp out = 133 F. Discontinue circulating 12.4 ppg CaCl2 brine. Rig down 6.30 7.00 030 circulating equipment and triplex pump. POOH the 1" work string w/ stinger. 7:00 1 8:30 1:30 8:30 9:30 I:00 Rig down tbg handling equipment and false floor. Rig up ellne, PCE, lubricator and heat sock, Make up / Rig up perf- gun. RIH w/ perf, gun to 425', pressure up to S00 psi. While maintaining pressure, punch tbg at 9130 10.00 030 425' with a 4' gun,13 shots. No pressure bled off of 2-7/8" tbg. The 2-7/8" x 7" annulus pressure remained at 0 psi. POOH w/ eline. All. shots fired. 10:00 11A0 1:00 Make / Rig up cement retainer. RIH w/ ellne. Set cement retainer at 415'. POOH. 11:00 12-W 2:00 Rig down PCE, lubricator, heat sock and eline unit. Rig up tbg handling equipment and false floor. RIH w/ stinger to top of cement retainer (4151. Worked 1" W5 to stab stinger Into cement retainer. Stabbed in w/ 300 12:00 14:00 2:00 psi on tbg. Pressured up on 1" WS to 2000 psi in an attempt to circulate 11.4 ppg CaCl2 brine through the perforations at 425' and 14:00 24:30 0:30 up the 2-7/8" x 7" annulus to 335'. Attempt to establish circulation was unsuccessful. No returns were seen at surface, tbg pressure bleed off to 1700 psi. Csg pressure remained at 0 psi. POOH the 1" work string w/ stinger. 1430 15:30 1:00 15:30 16,30 1:00 _ Rig down false floor and tbg handling equipment, Rig up One, PCE, lubricator and heat sock. _ Make up / Rig up pert, gun. Test lubricator to 250 psi (low) and 25DOpsl (high for 15 minutes each. RIH w/ perf. gun to 16:30 17:30 1:00 385'. pressure up to SWpsi. While maintaining pressure, punchtbg at 385' with a 4'gun,10 shots. No pressure bled off of 2.7/8" tbg. The 2-7/8" x 7" annulus pressure remained at 0 psi- POOH w/ eline. AM shots fired. Make up I Rig up pert. gun. RIH w/ perf. gun to 350', pressure up to 500 psi. While maintaining pressure, punch tbg at 17:30 18:30 1:00 350' with a 4' gun,10shots. No pressure bled off of 2-7/8" tbg. The 2.7/8" x 7" annulus pressure remained at 0 psi. POOH w/ ellne. All shots fired_ Make up / Rig up cement retainer- RIH w/ eline and set cement retainer at 375'. RIH w/ el me. Set down lubricator and 1830 19:30 1:00 heat sock. Place night cap on for the night_ Total Hours: 1930 1 R Remarks: -10 bbls of CaCI, brine was pumped into 'Yellow' tank. Total volume of fluid In the tank =-40 bbls, void space remaining = -87 bbls. .,.'J. Daily Operations Report Well Name: Iko Bay #1 Operator: Gas Producer API #: I BLM Report M 50-023-20007-00.00 Report Date- 13 10-Apr-17 Well Type: Field: NPR -Alaska PTD #: 100-0360 lContract #: I L16PC00003 ;Contacts' Wea#he��`�'�"�� supervisor; P _ Site Manager: Shane McGeehan phone #: phone M. Phone #: phone #: {801) 5560946 Gen. Conditions: Phase: Wind Direction: Clear n/a East - Northeast 14 18 12 15 4 0 Scott Finnegan (907) 350.9566 M/QC. Chad Thompson Rodney Brashear BLM PI. _ Wind Gusts Imph): _ Temp. jLow, High): Wind-chill Temp. Low, Hi h 41- Well Status TO: PBTO: Fluid in Well: Last BOP Test: 2,731 _ 915 _ Oiesel 4/2/2017 GL, ft: RKB, ft: OH ID, in: Last Safe MIS: 28 12 7.625 4/10/2017 Planned Days: 10 Start Date: _ 29-Mar-17 Operation Days: 13 BOP Drill. 4/10/2017 Cs Strin 00 j inj Depth [ft Weight (#/ft] Integrity Issues Drive Pipe: _ 24_ 16 28 149 v 1,190 _ NA 75 51 _ 23 Csg not seen at surface _ Conductor, Surface: Production; Slatted Liner: Tubing: --I _ 10.75 7 5.5 1,270 1,950 2Q 6.5 2.875 2.300 Pump Parameters Pump # Type Model I Rate (BPM) Pressure (psi) 100508 Mud Pump TEE-165 1 1.0 500 Mud / Brine Properties Fluid Type We ht Volume bbls.) Cumulative Volume (bbls): 0 Waste Fluids Fluid Type Weight IPM Daily Volume Ibbls.1 _ Diesel _ 6 9 CaCl2 12.4 2 55 Cumulative Volume (bbls): 57 Personnel Personnel on Board: 34 company # People CompareV # People Company # People Marsh Creek 22 PRA 1 Atigun UIC Fairweather CH2MHill 1 1 ; ; Bt.M 2 Halliburton 1 AOGCC MI-Swaco ; Pollard 2 Schlumber er _ 1 '. �pperatid-hs Report 24 Maur Summary: Safety meeting. RIH with Halliburton's Temperature Log. Log from surface to 375'. Temperature in wellbore was —42F surface and —36F from 200' - 375'. RIH w/ work string attached to stinger. At BLM's request we are suspending well operations on fko Bay # 1. Circulate brine at 130 F to heat wellbore. Attempted to stab Into retainer at 375' but was unsuccessful. Displaced wellbore from 375' to surface with diesel to freeze protect the well. POOH with workstring. Set WRP at 300'. Tested to 2000 psi for 30 min Pumped brine from batch-m!xer tanks into'yellow' waste manifest tank (-45 bbis . Began rigging down wellsite equipment. 24 Hour Forecast: Continue rigging down wellsite equipment. Nipple down BOPS. MOB to S. Barrow #3 H5E Summary: No accidents or spills to report. Safety meeting topics: new snow covering trip hazards, blowing snow and good radio communication. From To Hours I Operational Details (6:00 - 6:00) 5 x 7:00 1:00 Safety meeting regarding new snow covering trip hazards, bowing snow and good radio communication. Discussed well control responsibilities with the well ops crew, conducted BOP drill 7:0D 8,00 8 OD 1 100 Rig up ellne, lubricator and heat sock. Make up Halliburton's Temp. Log. RIH w/ One. Log from surface to 375'. Temperature in wellbore was —42 V surface and —36 F from 200' - 375'. Rig down ellne, rubricator, heat sock, PCE and Temp. Lag tool. Rig up tbg handling equipment and false floor. 9,100 1.130 9:00 10:30 1:30 RIH w/ 1' workstring attached to stinger. At BLM's request we are suspending well operations on Iko Bay p 1. 10:30 11,30 1:00 Circulate 11.E ppg Cad, brine at 130 F (out) to heat wellbore. 11:30 12:30 1:00 Attempted to stab into cement retainer at 375'. Worked workstring for -I hour and was unable to stab into retainer. 12:30 14.00 1:3D Displace wellbore w/ diesel from 375'to surface (-3 bbls). 14:01) 15,30 1:3D POOH w/ 1" work string and stinger. Rim of the stinger was a bit worn but no significant visible damage 25:30 16,00 0:3D Rig down tbg handling equipment and false floor. Rig up dine PCE. 16:00 16,30 0:3D Pick up / make up WRP. RIH, set WRP at 300'. POOH w/ eline. 16:30 17:00 0:30 Test WRP to 2000 psi for 30 minutes, 0 psi bleed off. 17:00 1800 1:00 Rig down ellne unit, lubricator and PCE. i8A0 18,30 0:30 Pump brine from batch mixer into'yellow' waste manifest tank (45 bbis) total for the well ~ 55 bbis. Rig down hard line and tbg equipment (elevator & floor clamps). Total Hours: 12:30 Remarks: 11.�MVIi ■i'1' Daily Operations Report ELOM", Well Name: Iko Bay #1 Operator: BLM Report #: 14 well Type: Field: Gas Producer _ NPR Alaska API #: 50.023-20007-00-00 I Report Date: 11-Apr-17 PTD#: 100-0360 Contract#: L16PCOM03 Contacts Weather Supervisor: p Shane McGeehan Phone #: {901) 556 0946 Gen. Conditions: Phase: Wind Direction: Wind Gusts (mph: Temp. {Low, High): Wind-chill Temp. Low, High): Hazy n/a East 11 15 10 16 -6 5 Site Manager g Scott _ Finnegan phone#: 19071350.9566 QA/QC: Thom cnaa pson Phone #: BLM PI: Rodney Brashear Phone #: _ Well Status TO: PBTD: Fluid in Well, Last BOP Test: 2,731 _ GL, ft: RKB, ft: OH ID, In; last Safety Mtg: 28 12 Planned Days: Start Date: 10 29-Mar-17 14 4/10/2017 91$ Disel 7.625 Operation Days: 4/2/2017 4/11/2017 BOP Drill: Csj String OD [inl De th jft We4ht(#/ftj Integrity Issues Drive Plpe Conductor. i _ 24 18 NA Csg not seen at surface 16 149 75 Surface: 10,75 I,190 51 Production. 7 1,270 23 Slotted Liner: 5.5 1,956 20 Tubing:2-875 1,300 6-5 -2W Pump Parameters Pump # Type Model Rate jBPME Pressure [psi) 1 D0508 Mud Pump TEE. 165 Mud / Brine Properties Fluid Type WelahtIPPO I Volume jbbls.l Cumulative Volume (bbls): 0 Waste Fluids Fluid Ty pc Weight [PM 6.9 11.4 Daily Volume jbbls.} 2 55 Diesel CaCl2 Cumulative Volume jbblsj: 57 Personnel Personnel on Board: 35 Company # People Companv # People Company # People Marsh Creek 23 PRA 1 Atigun 1 1 1 1 BLIV 2 Halliburton 1 LIIC AOGCC Pollard 2 MI-Swaco 1 Fairweather Schlumber er 1 CH2MHA ~" Operations Report 24 Hour Summary: Safety meeting. Nlpple down BOPS Change current pipe rams to 1.9" pipe rams. Rig down wellsite equipment Nipple up tree cap and check surface gauges. Load connex s and mobi: ize equipment to S. Barrow #3- 24 Hour Forecast: Mobilize to 5 Barrow #3 Rig up wellsite equipment and Nipple up BOPS. HSE Summary:: No accidents or spills to report- Safety meeting topics de -mobilization, pinch points, overhead loads and wellsite c?ean up. From To Hours Operational Details (6,00-6:00) 6:00 7;00 7-00 1;00 Safety meeting regarding de -mobilization, pinch points, overhead loads and wellsite clean up Nipple down BOPS. Change pipe rams to 1.9" pipe rams for South Barrow #3 Rig down work platform around well head. _ Pump Brine from Cement unit and circulating tank to storage tank, Clean out tanks. Nipple up tree[ap an check surface pressure gauges. 0 psi on 2 7/8" Tubing and 2 7/8" x 7" annulus Remove va ve handles on master valve and annulus valves. 9;30 2,30 9:30 11:30 2:00 1130 13:00 1.30 13:00 14;00 1oDD Ee L01 14:00 I 18:00 1 4.00 Itaad Conex's and equipment onto trailers to mobilize to S. Barrow U. Release from Iko Bay # 1 well @ 18.00 Demob 1 service comaanv ooeratars. technicians and PRA engineer Total Hours: Remarks: R�..�.A�.t. NIARSHCREEK Pressureh 4"' Attempt 04107/2017 7901to Surface �._ ;�� • � ��.._ TLC 2"' Attempt 0410612017 330' to Surface x.. x - Y, k� 5"L Attempt 0410712017 850' to 790' --_—- a— _---r J3j z 7'" Attempt 04108/2017 600' to 335' W x 7" Annulus to 330' k 6'Sw" f 3'" Attempt 0410712017 850' to 330' '\.��•+,.-ram-. \Y. I 912017 42V to 335' Iko Bay #1 Sundry Subsequent Report 04-27-2017.docx Page 31 of 38 M4-� a .h..AWU, NIARSHCREEK I Oth Attempt 04/1012017 38V to 350' Could not stab Into the retainer fj 375' "1012017 Pressure Test WRP 300' t cA Iko Bay #1 Sundry Subsequent Report_04-27-2017.docx Page 32 of 38 �~ 0 �1 mp.—M-d-NIARSHCREEK BPM t up to 1L4 ppg from 10.4 ppg We ght Up ppg this morning after night of doting. low brine weighldue moisture BPM JDD I 132 Beginning to weight up to12.4ppg BPM 142114AIL2ppg BPM 145 1230 BPM 140 14p 114ppg. Volume In tonk was measured at Wis. Circulation was stopped after24.5 Ikn Bay #1- 24 Hour Circulation too ..-'- — — 1re ; ---' too t ISO 140 1m 320 — -� 110 1m r�,Vy -jb,1$,+f 40af 4-011 0,1f�,1�v�a�• �{s'�8 08 If 11 Id "- ,$ p ,P --'P4,0 in line was coiled around brine tank to heat . End of steam line was placed Intosaparete to helpmitlgate volume Salim while Noting Ole to achieve IMF (Temp In) method stated e. Steam line was placed back Intobdnen Nil need to be mindful of remaining salt no moving forward. 1135 1133 1Added 15, SOe u3 to weight up from steaming overnight. 1L3 ppg #1- 24 Hour Circuladon (Apdi g.7,2017)1 340 120 120 - --- - uo —T..eo.n lac — go .0 IT SD MOO 19:10 18:20 Ia4S MCI 11:50 20:00 20:SO 21:00 22:00 23A0 090 2A0 2A0 3:00 4.00 5Aa am 7m 7r.. lka NYZ4- 1BPM 1BPM 1 BPM BPM Added 15. SON 593 to weight up,113 ppg to 11 A ppg IS 0700 145 Iko Bay ##- 24 Hour Circulation {Ap-B7•azf117} 140 c135 --'-- I230 125 --' - --' - '--' —Temp Pit -1I0 •— +� lamp Out 115 '—'-- ------- -'-- ...- 110 ---' - - - -- MOD 20:00 22-00 22:00 23:00 0:00 LOO 2:00 3:00 4:00 � 5:00 6:00 7:00 Time Iko Bay#1 Sundry Subsequent Report 04-27-2017.docx Page 33 of 38 -00 �Rpt„a. AZARSHCREEK Iko Ba 24- Hour Cal lation (A ri108-09, 2017) Time lPumpPFessuie rum Nate Tem .In Tem Out 18:00 500 psi 18PM 115 8o 19:00 500 s! 18PM 120 95 20.00 SW psi 1 BPM 130 115 21:00 SW psi 19PM 13S 122 22 00 SWpsi 1 BPM 139 1128 23:00 500psi 1 GPM 137 130 Moo Soo si 1 GPM 135 130 1:00 500 psi 1 GPM 131 129 2:00 Soo psi 1 GPM 134 129 3:00 S00 psi 1 GPM 137 131 400 500 si IBPM 139 132 5 0D 500 psi 1 GPM 131 130 6.00 500 psi 1 GPM 130 129 7:00 ISM psi 1 GPM 138 1133 Weight 11.4 ppg Iko Bay #1- 24 Hour Circulation 145 - =TanyM �TemyOui lam 3l:m 30:m 21-00 2290 ISM 0-00 1:00 2A0 3:00 4'07 S:m SOD 7.00 IYM� Iko Bay #1 Sundry Subsequent Report04-27-2017.docx Page 34 of 38 MOW4 AIARSHCREEK I' : 1' �• i 1 Y r. J BOPE Test Report \I \N%II Contractor. New Contractor Rig No.: DATE: 4017 Rig Rep.: Shane McGeehan Rig Phone: 877-262 9765 Operator. Marsh Creek Op. Phone: 877-262-9765 Rep.. Shane McGeehan E-Mail shane.mcgeehanomar5ii,-reekllc.com Well Name* lko Bay $1 PTD # 1001}380. Sundry # 5002320007 Operation_ Drilling: Workover X Explor.: Test: Initial: Weekly: BI-Weekly: Test Pressure (psi): Rams: 250/2500 Annular. 250 / 2500 Valves: 250/2500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VP Test Result Test Result Quantity Location Gen P Well Sign NA Upper Kelly 0 Housekeeping P Rig NA Lower Kelly 0 PTD On Location P Hazard Sec. P Ball Type 1 mding Order Posted P Misc. NA Inside BOP 0 FSV Misc 0 BOP STACK: Quantity Size/Type Test Result Stripper 0 NA Annular Preventer I 4-11W P #1 Rams t 4-1116" P #2 Rams 0 NA #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 2 2-1116" P HCR Valves 0 NA Kill Line Valves 2 2-1/16" P Check Valve 0 NA BOP Misc 0 NA CHOKE MANIFOLD: Quantity Test Result No. Valves 5 P Manual Chokes 2 P Hydraulic Chokes 0 NA CH Misc 0 NA MUD SYSTEM: Visual Trip Tank NA Pit Level Indicators NA Flow Indicator NA Meth Gas Detector NA 1-12S Gas Detector NA MS MISC 0 Inside Reel valves ACCUMULATOR SYSTEM: T1melPressure System Pressure amo 2900 Pressure After Closure (psi) 23W 200 psi Attained (sec) 10 Full Pressure Attained (sec) 43 Blind Switch Covers: All stations Nitgn. Bottles # & psi (Avg.): 7 ACC Misc 0 Test Results Number of Failures: Q Test Time: LQ Hours Repair or replacement of equipment will be made within D days. 24 hr Notice Start Dat&Time: Inspection Date/iime By 4/2f2017 7.00 (der.) (dme) Witness Test Result NA Alarm NA Test Result Test Result Yes P Iko Bay #1 Sundry Subsequent Report 04-27-2017.docx Page 35 of 38 f� MARSHCRI E K BOP TEST 0410212017 Chart #1 04/02/2017 Chart 04/0212017 Chart Iko Bay #1 Sundry Subsequent Report04-27-2017.docx Page 36 of 38 C NIARSHCREEK #10) Well Operations Photos Well crew building scaffolding around the wellhead_ nti Pen` gun after setting perforations at 850 ft M� Alf, • a t f r , No Bay 91 Sundry Subsequent Report 04-27-2017.docx Page 37 of 38 Q NIARSHCREEK IKO Bay #1 Tree at time Iko Bay #1 Sundry Subsequent Report Q4-27-2d17.docx Page 38 of 38 • RECEIVED '` JAN 272017 AOGCC FORM APPROVED Form 3160-5 UNITED STATES OMB No.1004-0137 (June 2015) DEPARTMENT OF THE INTERIOR Expires:January 31,2018 BUREAU OF LAND MANAGEMENT 5.Lease Serial No. SUNDRY NOTICES AND REPORTS ON WELLS 6,If Indian,Allottee or Tribe Name Do not use this form for proposals to drill or to re-enter an abandoned well.Use Form 3160-3(APD)for such proposals. SUBMIT IN TRIPLICATE-Other instructions on page 2 7 If Unit of CA/Agotement Name and/or No. .Type of Well 3 Well Name and No. 2 El Oil Well Q Gas Well ©Other Iko Bay No. 1 \6 o 0 7( c, 2.Name of Operator Bureau of Land Management 9 API Well No.50-023-20007-00-00 "C 3a Address 222 West 7th Avenue,#13 Anchorage,AK 3b.Phone No.(include area code) 10.Field and Pool or Exploratory Area 99513 (907)271-4429 NPR-Alaska 4.Location of Well(Footage.Sec.,l:.R.,M...or Surrey Description) II Country or Parish,State Let:71.1702 N E 716,275 Sec.16,T.21 N,R.16W.M.Umiat Long:156.1670 North Slope Borough,Alaska 12.CHECK THE APPROPRIATE BOX(ES)TO INDICATE NATURE OF NOTICE,REPORT OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION Q Notice of Intent n Acidize ED Deepen n Production(Start/Resume) n Water Shut-Off Q Alter Casing 0 Hydraulic Fracturing ED Reclamation Ej Well Integrity Subsequent Report n Casing Repair 0 New Construction n Recomplete El Other n Change Plans Plug and Abandon n Temporarily Abandon , U Final Abandonment Notice n Convert to Injection n Plug Back n Water Disposal 13. Describe Proposed or Completed Operation.Clearly state all pertinent details,including estimated starting date of any proposed work and approximate duration thereof If the proposal is to deepen directionally or recomplete horizontally,give subsurface locations and measured and true vertical depths of all pertinent markers and zones.Attach the Bond under which the work will be performed or provide the Bond No on file with BLMiBIA Required subsequent reports must be filed within 30 days following completion of the involved operations.If the operation results in a multiple completion or recompletion in a new interval.a Form 3160-4 must be filed once testing has been completed.Final Abandonment Notices must be filed only after all requirements,including reclamation,have been completed and the operator has detennined that the site is ready for final inspection.) Final Well Plug and Abandonment. Please see attached document. RKB:12 ft.. Spud Date:1975. SCANNED FEB 0 8 2017, 14 I hereby certify that the foregoing is true and correct. Name(Printed Typed) K ,. M - L. CM M 0 r✓ Title w' f-_, L L C'e l.?,a 1 7 40 1...: S r'I f t.'/r/_ Signature , --- Al t �-C-''%.__ Date I / -5 // 7 E SPACE FOR FEDERAL OR STATE OFICE USE Apr ov d by 44. Ji/ / t ‘110Title 7 1 Date `/27/7 Conditi. . ap ovi ,II any.ar40 hod.Approval of this notice does not warrant or certify •applicant holds leg equitable title to those rights in the subject lease Office Of/' Sd which woi entitle the applicant to conduct operations thereon. Title 1$U.S.0 Section 1001 and Title 13 U.S.0 Section 1212,make it a crime for any person knowingly and willfully to make to any department or agency of the United States any false.fictitious or fraudulent statements or representations as to any matter within its jurisdiction. (Instructions on page 2) • • ` 441 GENERAL INSTRUCTIONS This form is designed for submitting proposals to perform certain well operations and reports of such operations when completed as indicated on Federal and Indian lands pursuant to applicable Federal law and regulations.Any necessary special instructions concerning the use of this form and the number of copies to be submitted,particularly with regard to local area or regional procedures and practices,are either shown below,will be issued by or may he obtained from the local Federal office. SPECIFIC INSTRUCTIONS • Item 4-Locations on Federal or Indian land should be described in accordance with Federal requirements.Consult the local Federal office for specific instructions. Item 13:Proposals to abandon a well and subsequent reports of abandonment should include such special information as is required by the local Federal office. In addition,such proposals and reports should include reasons for the abandonment;data on any former or present productive zones or other zones with present significant fluid contents not sealed off by cement or otherwise;depths(top and bottom)and method of placement of cement plugs;mud or other material placed below,between and above plugs;amount,size,method of parting of any casing,liner or tubing pulled and the depth to the top of any tubing left in the hole;method of closing top of well and date well site condi- tioned for final inspection looking for approval of the abandonment. If the proposal will involve hydraulic fracturing operations,you must comply with 43 CFR 3162.3-3,including providing information about the protection of usable water. Operators should provide the best available information about all formations containing water and their depths. This information could include data and interpretation of resis- tivity logs run on nearby wells. information may also be obtained from state or tribal regulatory agencies and from local BLM offices. NOTICES The privacy Act of 1974 and the regulation in 43 CFR 2.48(d)provide that you be furnished the following information in connection with information required by this application. AUTHORITY:30 U.S.C. 181 et seq.,351 et seq.,25 U.S.C.396;43 CFR 3160. PRINCIPAL PURPOSE:The information is used to:(1)Evaluate,when appropriate,approve applications,and report completion of subsequent well operations,on a Federal or Indian lease;and(2)document for administrative use,information for the management, disposal and use ofNational Resource lands and resources,such as:(a)evaluating the equipment and procedures to be used during a proposed subsequent well operation and reviewing the completed well operations for compliance with the approved plan;(b)requesting and granting approval to perform those actions covered by 43 CFR 3162.3-2,3162.3-3,and 3162.3-4;(c)reporting the beginning or resumption of production,as required by 43 CFR 3162.4-1(c)and(d)analyzing future applications to drill or modify operations in light of data obtained and methods used. ROUTINE USES:Information from the record and/or the record will be transferred to appropriate Federal,State,local or foreign agencies,when relevant to civil,criminal or regulatory investigations or prosecutions in connection with congressional inquiries or to consumer reporting agencies to facilitate collection of debts owed the Government. EFFECT OF NOT PROVIDING THE INFORMATION:Filing of this notice and report and disclosure of the information is mandatory for those subsequent well operations specified in 43 CFR 3162.3-2,3162.3-3,3162.3-4. The Paperwork Reduction Act of 1995 requires us to inform you that: The BLM collects this information to evaluate proposed and/or completed subsequent well operations on Federal or Indian oil and gas leases. Response to this request is mandatory. The BLM would like you to know that you do not have to respond to this or any other Federal agency-sponsored information collection unless it displays a currently valid OMB control number. BURDEN HOURS STATEMENT:Public reporting burden for this form is estimated to average 8 hours per response,including the time for reviewing instructions,gathering and maintaining data,and completing and reviewing the form.Direct comments regarding the burden estimate or any other aspect ofthis form to U.S.Department ofthe Interior,Bureau ofLand Management(1004-0137),Bureau Information Collection Clearance Officer(WO-630), 1849 C St.,N.W.,Mail Stop 401 LS,Washington,D.C.20240 (Form 3160-5,page 2) 1 Pa4014,4 4044144 116444 MARSHCREEK NPRA Legacy Well Remediation Iko Bay#1 Single Well Program Plug and Abandonment Procedure Prepared By/Date Nolan Youngman Petroleum Engineer _ 5' '7 Prepared By/Date Steve Tyler Workover/intervention Engineering Advisor At 1'Pc L 1 ! l,l ) 117 Agreed By/Date Marty Lemon P.E. Project Management Drillingand Well Operations r 7 P ,.� YrL l 1� � d � 0 Vitt ibr-if, ' . t14,44,44 Rtu.d.4.A1.414, M ARSHCREEK Overview During the fall of 2016 Marsh Creek had contacted Petroleum Resources of Alaska(PRA)to perform the successful abandonment of legacy wells drilled in the NPRA along with the remediation of the physical location. Work Objective The priorities of the attached Plug and Abandonment Procedure for lko Bay#1 are listed as follows: 1. Perform all work in a safe and efficient manner,without causing harm to people,environment,or equipment. 2. Remediate gas pressure to surface. 3. P&A lko Bay#1 to BLM 43 CFR 3160"Onshore Oil and Gas Order No.2, Drilling Operations"Standards. Current Well Information • Well was drilled in 1975 by the US Navy. • Well was a successful producer of natural gas. • In April 2016 a final P&A was attempted by SolstenXp and Marsh Creek. The final P&A was deemed unsuccessful. A high level summary of current well conditions are listed as follows: 1. The well is shut-in. 2. Tbg&annulus both registered 250 psi in August 2016. i. Annulus was blead to zero in 3 minutes,all gas was produced.Annulus pressure remained at zero. ii. Tbg was blead from 250 psi to 235 psi over a 10 min period. Recovered(1)gal.of foamed brine/diesel mixture. Tbg built to 255 psi. 3. TOC in tubing was tagged w/wireline at 915' RKB on April 29,2016. 4. CBL ran on April 22,2016 depicting multiple obstructions in 2.875" x 7" annulus from 75'to 915'. 5. Tbg was cut at 1,300'. Tbg punched at 910'and 915'. 6. The wellbore currently rests out of balance with diesel left in tbg and 9.6 ppg NaCl w/sagged barite in the tbg x csg annulus. 7. High probability of trapped gas in tbg x csg annulus. Sundry Procedure Pre-Rig Ops: Pre-Rig Ops: 1. Inspect wellhead,grease valves on tree.Address any integrity discrepancies as required. 2. Record shut-in tubing and annuli pressures.Check for gas. Note in Morn Rpt.Attempt to bled pressure to zero. 3. Stage Tool &Parts Connexes, Boiler,Scaffolding,Generators, Heaters. 4. Spot surface support equip and 30 Ton National Cab Mounted Boom Truck.Build brine. Preheat to 150°F. lko Bay#1—Final Sundry Page 2 of 8 Patoikligewma4A1444, MARSHCREEK 5. Nipple Up(NU) Pollard Blowout Preventer(BOP), Lubricator and heat sock. Pressure test Pressure Control Equipment(PCE)250 psi low and 2500 psi high.Run In Hole(RIH)w/-2.24" Gauge Ring(GR).Tag Effective Total Depth (ETD)@-915'.Pull Out of Hole(POOH). Note:tbg was left full of diesel during April P&A attempt. 6. RIH w/Wireline Retrievable Plug(WRP)on eline.Set same above existing tbg punched holes @ 910'. POOH. Pressure test WRP to 1500 psi for 30 min. Record fluid volume returned when tbg pressure is bled to zero. Note: Master valve leaks at 1500 psi. 7. RIH w/CBL/Temp. Log. Tie-in to Halliburton Radial Cement Bond Log dated 22-Apr-2016. Log from-900' to surface. Repeat logging run while holding 1000 psi on the 2/8"tbg. POOH L/D logging tools. Utilize log results to determine the following: Establish Base Log to represent initial well conditions. 8. RIH w/2°d WRP.Set same at 300'. Pressure test tbg to 1500 psi for 30 min. Note difference in fluid volume returned when tbg is bled to zero from first WRP test.Rig Down(RD)eline. Note: Master valve leaks at 1500 psi. 9. Nipple Down (ND)of tree. Remove leaky legacy Master valve and 3%8"5k FMC swab valve. Reattach 3 Ys" 5k FMC swab valve(Master Valve)onto wellhead adapter. Pressure test 3'Is"5k FMC master valve to 2000 psi for 30 min. Note: Max allowable Surface Pressure is 2000 psi on tbg and/or csg. 10. NU 41/16" BOPE onto wellhead. RU choke manifold, Kill line, return lines.Test same against WRP to 250/2500 psi for 30 min each. 11. RU wireline PCE.Pressure test same to 250/2500 psi. RIH latch retrieve WRP @"300'. POOH L/D WRP. RD wireline. Operations: 12. RU tbg handling equipment to run workstring(WS). 13. RIH w/workstring to WRP set depth.Circulate heated KWF brine down workstring while taking returns out WS x 2%8"annulus. 14. Continue to circulate well w/heated brine for 24 hours to thaw wellbore.Continuously monitor pressures on all annuli and returns temperature. POOH. 15. RU wireline PCE. Pressure test same to 250/2500 psi. RIH latch retrieve WRP. POOH Lay-Down (L/D)WRP. 16. Ensure tbg x csg annulus is open to take returns.Pressure up on 2%8"tbg. Max Allowable Surface Pressure is 2000 psi on tbq and/or csq. Note:If pressure is leaking off, attempt to establish injection rate and pressure. Cement squeeze will be performed. If returns are noted, attempt to establish a circulation rate&pressure. Will circulate cement surface 17. RIH with CBL/Temp log.Tie-in to Halliburton Base Log(step 7). Log from^'900'to surface. Repeat logging run while holding 1000 psi on 2/8"tbg. POOH L/D logging tools. Utilize log results to determine the following: Wellbore thawing progress and depths of annulus obstructions. Finalize tbg punch depths to accomplish annular cmt squeeze. Compare data to previous run Base Log(Step 7). 18. PU/MU 2'Is" CIBP. RIH,set same 5' below btm of anticipated tbg punch holes. POOH. 19. PU/MU tbg punch.While maintaining 500 psi tbg pressure, RIH tie-in to recently run CBL. Punch tbg at the evaluated predetermined depth(s). Note tbg pressure fall off and annulus pressure. POOH w/tbg punch. Note:Preliminary anticipated punch depths are between±715'and±335'. 20. Pressure up on 2/8"tbg.Attempt to establish injection and/or circulation with tbg x csg annulus. Max Allowable Surface Pressure is 2000 psi on tbq and/or csq. Note:In the event that circulation can be established in excess of 1 bpm proceed to step#25. Will circulate cement to surface lko Bay#1-Final Sundry Page 3 of 8 /71 • 111111 PatRAt 1t1RSHCREEK Note:In the event that injection can be established in excess of 1 bpm a bullhead. Cement squeeze will be performed. 21. PU/MU second tbg punch.Ensure tbg pressure is being maintained @ 500 psi, RIH tie-in to recently run CBL. Punch tbg. Note tbg pressure fall off and annulus pressure. POOH w/2°d tbg punch. Repeat Step#20 Note: Maintain vigilance on wellbore conditions.High probability of trapped gas in tbg x csg annulus. 22. RIH w/cmt retainer on Mine.Set same above lower tbg punched holes. POOH RD eline. 23. RIH w/stinger on 1"workstring.Stab into retainer. Establish circulation rates and pressures between 1"tbg and 2 78"x 7"annulus. Ensure rates>1 bpm. Note: If unable to establish sufficient rates. POOH. RU/RI w/eline. Tbg punch additional holes at alternative depths. Repeat Step#22. 24. Pump tracer around to confirm volume of cmt needed. Pickup out of retainer.Circulate wellbore clean. RI stab back into retainer. 25. Mix 14 ppg cement at predetermined volume from tracer results.Pump mud push, pre pad,cmt slurry and post pad. Note:Slurry Density: 14.00 lb/gal,Yield: 1.18 ft3/sk, Mix Fluid:5.251 gal/sk. 26. PU above retainer.Circulate Bottoms Up(CBU)with heated brine while WOC. POOH. 27. RU eline. RI w/CBL tool to retainer. POOH LID tool. Evaluate log to determine TOC in tbg x csg annulus. 28. RIH w/CIBP.Set above top tbg punch holes. POOH. RI punch tbg @"'50'. RD eline.Circulate wellbore though tbg punch. 29. RIH w/workstring.Spot/lay-in 15.7 ppg cement above CIBP to surface.Close annular. Open 7" csg valve. Continue to circulate cmt to surface. POOH. Note:Slurry Density: 15.80 lb/gal,Yield:0.93 ft3/sk, Mix Fluid: 3.544 gal/sk. 30. Cut Tubulars 5' below ground level,make sure all annulus are full of cement, 31. Weld on a marker plate on the 24 inch conductor that meets current regulations.Marker Plate,%" minimum thickness,to have the following information bead welded into it. U.S. NAVY PTD: 100-0360 !KO BAY #1 API: 50-023-20007-00-00 • Ensure a%"weep hole is drilled in center of plate. Iko Bay#1—Final Sundry Page 4 of 8 ,,\%.,:).7) 410 A tS.:t..t P,e,«. At"ks MARSHCREEK Attachments Current Wellbore Schematic Iko Ray#1 Rig: N/A Spud: February 1,1975 NPR- Meridian Township Range Section Created Alaska Umiat 21N 16W 16 4tRsttt,RE aMR Current Last Mod Wellbore 1/12/2017 )4...L...41mi64, Schematic CASING AND TUBING DETAIL ' ' %v'1,1111 11111',;.: '` ! SIZE WT GRADE CONN ID MD MD al Ill V 19'MC TOP BTM. 16" 75# N-80 15.124 : 149' 0.10.75" 51# P-110 9.85' 1,190' 4 ' Fi . j -- L asel 7" 234 C-95 6.366" s x. 1,270' 5.55' 204 1-55 ;_ 4.788" 1,212' 1,950` I 7 R75' 6.54 1-45 2:441" I Surface 1;3DD' <i I — Nom` a f i ..0„," petted Cement Retainers i " NO Depth 1D Item or 1 TBD 2.5" CIBP -IIE ill .. 2 TBD 2.5" CIBP .y • NaCIErre f9Fppgl ,s • Flaw a=_ceolymer Tubing Punches i.!_Jr.• to?,e(tl4 ppg) • cen Ct(12ePPg} Date Depth Comments • FarmatnnFifias Apr. 910' i rib 1190'YT.) 2016 i Apr. 915' 2016 270 `' Winter TBD Depths will be determined 2017 based of CDL. ;C.rx 1 v ,•1 11.4 ppg ailing mud I Firm" PBTD=915'MD TD=2731'MD Current Wellbore Schametic REVISED:1/1212017 DRAWN BY:Nolan Youngman Iko Bay#1—Final Sundry Page 5 of 8 • pin ,,(4) ,....„ pi a. MARSHCREEK Current Wellhead Configuration (7,r• 3 FLANGEWITHGt fh, 11-. N.‘, 5,000 P$1 X 1502 AND BLEEDER MARSHCREEK _ Ur4144 FMC 5,000 PSI GATE VALVE I i r9111 rRi t rF FF7 Ling 44 L611 tii LEil 3' LP THREAD 1 \\\ \_ -.1 -1------------ FMC OCT MODEL 20 3" 3000 PSI 3LP THREAD el rli A fll Inl 6" 5000 PSI . STUDDED OUTLE'SI FMC OCT TUBINGHEAD ff <--- TYPE A.1" 9" OD 2" ROCKWELL PLUG VALVE .— 2" ROCKWELL PLUG VALVE DYNAMIC BALANCE PLUG VALVE LIDLy IP 1[ \ DYNAMIC BALANCE PLUG VALVE CAMERON 3,000 PSI BALL VALVE - - C--- . . .... ... - CAMERON 3,000 FGI BALL VAL.E EXTRA STRONG OD: 2,375" WT: 0.436 ffb rdrIfIr-6 rl 2" X t)''' DOUBLE EXTRA STRONG ---r .,/--- OD: 2.375 WT: 0.436" 10' 3,000 PSI 31. STUDDED OUTLETS 10 1.1P 1441 ii ' 1- -I / 1/2" BALL VALVE - 2' BULL PLUG, EXTRA >Cr 1 _ 1 - SHOULD BE COVERED WITH CEMENT STRONG r, OD: 2.375' WT: 0.218- 1 REGAN WELLHEAD 0;" CAsiNG 16" 3000 PSI MACHINED TO .------, SLIP ON 10 i" CASING 7" CASING ...------. 1 ..te----. 2 i" TUBING LAT 7110'17.180'N LONG. 1561026.276 W DATUM: NAD 83 US DEPARTMENT OF INTERIOR EAST: 1.856.250 US FT NORTH: 6.281.360 us FT ZDNE: ASP 6 ;KO BAY No, 1 SECTION: .61TowNstrif, 21 NIRANGE 16 WIMEFICAAN, UMIAT FWL: 2.500 FTIFSL. i.850 ETIELEV. 28 8TfRK3- 12 FT API # 50-023-20007-00-00 SKID DATE COMPLETION DATE STATUS DATE STATUS PERMIT TO DRILL# 100-0360 01 FEB 1975 23 FEE 1975 29 MR 2016 SUSPENDED DATE: By COMMENTS: WELLHEAD REVSCALE 19 MAY 2016 LUCAS MINISTER !SION' 4 ' Iko Bay#1—Final Sundry Page 6 of 8 _' S ('' 'MI -)C,L)) p4 ,444 Rm....4,14 A1.4&4 MARSHCREEK Proposed Wellbore Schematic Ike Bay#1 Rig: NLA Spud: February 1, 1975 ,.; NPR- Meridian Township Range Section _ Created MIA Alaska Um tat 21N 16W 16 Vt.skS1Tt RrrK Proposed Last Mod Wellbore 114/2017 I4. n.--.- Schematic CutTubulurs5'below groundlerel CASING AND TUBING DETAIL '' _'' .' $` A'>r;�'' SIZE WT GRADE CONN ID MD MD aill .1"'''''' ■ I '49"ND TOP BTM. 1111 ' 2 1♦ 16" 75# N-80 15.124'M ��- 149' I 0.-"'"-4411 --'-- MU 10.75" 51# P-110 9.85" Vii. • t 1,190` 7" 6.366" W. 1,2705 e 5.5' 20# 1-55 4.788 1,212' 1,950' A 4.CemertRetaineQI 2.875" 6.54 155 2.441°" Surface 1,300' s, 1. AV t S Susasred I Cement Retainers&CIBP`s i_ ! .....'7 .,bar a cn� __---- ---. NO Depth Item Comments ME an�.`�OM s10"� 1 TBD CIBP Minimum set depth 150' `�1r4pp7CaCt,Bnn� 2 TBD Retainer May require multiple 3 TBD CIBP Wiil be above 910' • tla':IBine("5ppg) • Maw 4,,c Pointe : • I me CH 4 PPO • Dee Ent(12.5pp9) • Eennaton Fluids J i tgt' ID Tubing Punches ".i Date Depth Comments .1 1270 MD Apr.2016 910' ,,., 10 Apr.2016 915' Winter 2017 TBD Depths will be determined based of CBL 101 4 114 ppg ddlrug mud 2731 MD PEND.915'MD TO=2731'MD Proposed Wellbore Schematic REVISED:1/4/2017 DRAWN BY:Nolan Yoummmin lko Bay#1—Final Sundry Page 7 of 8 • pau,vdi,„iRt4.04a4A/A444MARSHCREEK BOP Configuration A P S 1111 Iko Bay#1—Final Sundry Page 8 of 8 • • Note to file: Follow-up from BLM pre-planning meeting Iko Bay#1 PTD 100-036 SGApit4E0 MAR 1 0 201 1/25/2017 7 Attended a pre-planning meeting for the 2nd attempt to P &A Iko Bay#1 at BLM office. AOGCC personnel received the proposed procedure to finish the plugging of the well. Our comments mainly concerned the use of jointed pipe as the workstring.The AOGCC strongly recommended using Coil tubing due to several reasons as listed below: Ability to wash frozen tubing ID with coil will be much faster/or mill cement in tubing. Time to trip in and out of hole with jointed pipe will allow well to freeze Ability to pump higher rates with coil equals more heat transfer to OA Coil could cement well immediately after thawing without tripping Well control with coil tubing provides benefits over jointed pipe. Personnel exposure for working platform required for jointed pipe However Marsh Creek stated that the coil units that were currently available (Schlumberger)were too heavy to transport using Stieger Tracters. However, it does not appear that Marsh creek or BLM considered outsourcing CT units from Canada or checking with Halliburton/ BJ etc. Ultimately the procedure as written was agreed to using jointed pipe/lift crane with some modifications ( leaving a Master valve on wellhead to facilitate wireline work) and adding a CBL baseline pass. Guy Schwartz Staff Engineer PE AOGCC • • • �NTOpTy United States Department of the Interior CrigNERQP$ts1 iv 21 BUREAU OF LAND MANAGEMENT klf �' Alaska State Office �j40CH 3 A 222 West Seventh Avenue,#13RECEIVED Anchorage, Alaska 99513-7504 http://www.blm.gov/ak JUN 13 2016 AOGCC In Reply Refer To: JUN 1C 2016 2361 (930) CERTIFIED MAIL RETURN RECEIPT REQUESTED Cathy P. Foerster Chair, Commissioner SCANNEDi�' `- Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Dear Commissioner Foerster: We have received your letter dated May 31, 2016, regarding work completed at Iko Bay#1 by the Bureau of Land Management's (BLM) contractor, Marsh Creek, LLC, and their former subcontractor, SolstenXP. On April 19, 2016, we received information from our on-site BLM inspector that the pressure test of the April 18, 2016, cement job of Iko Bay#1 failed. On April 20, 2016, BLM met with the Alaska Oil and Gas Conservation Commission (AOGCC), Marsh Creek, and their subcontractor, to gather information to identify the potential causes of the failed pressure test. At that time the subcontractor stated, contrary to their April 16, 2016 documentation, that the well had not been bled to zero pressure or monitored for static conditions prior to setting the cement plug as required by BLM's approved procedures. Subsequently, BLM coordinated with and received concurrence from AOGCC prior to approving the contractor's revised procedures to set a cement plug at approximately 900 feet. On April 27, 2016, BLM coordinated a meeting with AOGCC, Marsh Creek, and their subcontractors to discuss the variables that may be contributing to why the attempts to implement the revised procedures failed, and the appropriate path forward. Due to the lack of information to support making any additional attempts and the impending closure of the winter tundra travel season, BLM required Marsh Creek to shut-in the well for the season. • • • , At this time, BLM does not consider Iko Bay#1 to be plugged and abandoned in accordance with 43 CFR Part 3160, Onshore Oil and Gas Order No. 2. The BLM has been working with Marsh Creek to ensure that the company remedies the deficiencies which have contributed to these circumstances to ensure the successful plugging and completion of this work by the end of the period of performance for this task order (December 2017). The BLM will coordinate a meeting in late summer 2016 with AOGCC and Marsh Creek, after Marsh Creek has been able to bring a Senior Petroleum Engineer on staff, so all parties can discuss the next steps on Iko Bay #1. BLM will continue to work closely with AOGCC to coordinate procedures prior to approving modifications to the plugging and abandonment of Iko Bay#1 and all future wells. As SolstenXP will no longer be associated with this project, it is unnecessary to include them on future correspondence regarding legacy wells. Please feel free to contact me at 907-271-5080, or Nicole Hayes at 907-271-4354, should further information be requested. Sincerely, Bud C. Cribley State Director .1.4 of r4 4.1.-„ 1,7,,,-. THE STATE• III Alaska Oil and Gas g�,; 1 o e T Conservation Commission -,6,..„ fALAs�`:A StWI 333 West Seventh Avenue 1. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov May 31, 2016 CERTIFIED MAIL— RETURN RECEIPT REQUESTED 7015 1660 0000 1487 7135 Ms. Nicole Hayes Legacy Wells Project Coordinator BLM Alaska State Office 222 W. 7th Ave, #13 Anchorage, AK 99513 Re: Docket Number: OTH-16-014 Notice of Violation- Failure to follow approved procedure Well: Iko Bay#1 (PTD 100-036, Sundry 316-122) Dear Ms. Hayes: The Bureau of Land Management (BLM)—through its contractor SolstenXP —commenced plug and abandon operations on Iko Bay #1 on April 9, 2016. The Alaska Oil and Gas Conservation Commission (AOGCC) approved the plug and abandon operations in sundry approval 316-122. That approval required elimination of the well's ability to flow hydrocarbons to surface, isolation of all hydrocarbon zones, and surface abandonment of the well. SolstenXP placed the initial abandonment cement plug in Iko Bay #1 on April 18, 2016. On April 19, 2016, in a test witnessed by AOGCC, the cement plug failed to hold pressure. A meeting was held on April 20, 2016 to discuss the circumstances surrounding the failed cement plug. Details provided by SolstenXP and BLM during the meeting established that SolstenXP's work violated the approved sundry. Specifically, SolstenXP admitted that the well was not bled to zero pressure or monitored for static conditions. SolstenXP also conceded the well had not been completely circulated with kill weight fluid as required by the sundry. Additional details demonstrated the well was underbalanced, allowed the flow of well fluids to surface and ensured there would be no competent primary cement plug. No substantive change to an approved program may take place without AOGCC approval. The facts presented establish a failure of BLM and its contractor to follow approved permit conditions, a violation of AOGCC statutes and regulations. Iko Bay #1 does not meet the AOGCC regulations for permanent abandonment. BLM is required to perform the necessary remedial work to permanently abandon this well. This is the Docket Number:OTH-16-014• • May 31,2016 Page 2 of 2 third Notice of Violation issued to BLM for failing to follow approved procedures during the winter 2016 operations. Within 14 days of receipt of this letter, you are requested to provide the AOGCC with a written explanation of what has been or will be done in the future to prevent recurrence of this violation (failure to follow approved procedures). BLM must also describe what will be done to complete the abandonment of Iko Bay #1 in a manner consistent with AOGCC requirements, and when such work will be completed. Failure to comply with this request will be an additional violation per 20 AAC 25.300. The AOGCC reserves the right to pursue additional enforcement action in connection with this Notice of Violation for Iko Bay #1. Questions regarding this letter should be directed to Mike Quick at (907) 793-1231. Sincerely, Cathy . Foerster Chair, Commissioner cc: Jim Regg, AOGCC ADEC, Division of Spill Prevention and Response Steven Cohn, BLM Rob Brumbaugh, BLM Lucas Munisteri, SolstenXP Bryan Lund, Marsh Creek RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. U.S. Postal Servicery CERTIFIED MAIL° RECEIPT Ln Domestic Mail Only m For delivery information,visit our website at www.usps.com`°'. ra N Certified Mail Fee 143 $ Extra Services&Fees(check box,add fee as appropriate) 0 Return Receipt(hardcopy) $ Q 0 Return Receipt(electronic) $ Postmark Q ❑Certified Mail Restricted Delivery $ Here CI ❑Adult Signature Required $ Q 0 Adult Signature Restricted Delivery$ Q Postage Total Postage and Fees N $ LegacyMs. WellsicoleHayes Project Coordinator Sent To Bureau of Land Management 1-9 Street and Apt.No.,or PO soxfh Alaska State Office r` 222 W.7th Ave.,Ste.13 City,State,ZIP+46 .--. Anchorage,AK 99513 PS Form 3800,April 2015 PSN -...--•• - , f • s • • SENDER: COMPLETE THIS SECTION COMPLETE THIS SECTION ON DELIVERY ■ Complete items 1,2,and 3. A. igThyaf ■ Print your name and address on the reverse r ❑Agent so that we can return the card to you. X :ice/i. � 0 Addressee •�, ■ Attach this card to the back of the mailpiece, ' "? D e o .el' ery or on the front if space permits. ritta, �/� 1. °eiinic. D. Is delive ddre.ss diff-rent from item 1? L Yes Ms.Nicole Hayes If YES,enter delivery address below: 0 No Legacy Wells Project Coordinator • 2 Bureau of Land Management J U N 2016 Alaska State Office 222 W.7th Ave.,Ste. 13 Anchorage,AK 99513 I[I11 I I Il I II III 3. ServiceType 0 Priority Mail Express®111E1111 MI 11111111111111111 ID Adult Signature 1=1 Registered MaiITM ❑Adult Signature Restricted Delivery 0 Registered Mail Restricted VrCertified Mail® pelivery 9590 9403 0910 5223 5230 72 ❑Certified Mail Restricted Delivery td Return Receipt for 0 Collect on Delivery Merchandise 2. Article Number(Transfer from service label) 0 Collect on Delivery Restricted Delivery 0 Signature ConfirmationTM ed Mail 0 Signature Confirmation 7 015 1660 0000 1487 7135 ed Mail Restricted Delivery Restricted Delivery ,..: $500) PS Form 3811,July 2015 PSN 7530-02-000-9053 Domestic Return Receipt DAILY QUALITY CONTROL REPORT ENVIRONMENTAL QUALITY CONTROL/QUALITY ASSURANCE REPORT (ER 415-1-302) General Daily Remarks: Marsh Creek continued to support P&A activities for Iko Bay#1, including; equipment and camp maintenance, equipment fueling, water making/hauling activities, and trail maintenance (grooming). Drums of methanol and calcium chloride were mobilized to Barrow vis aircraft and brought overland to Iko Bay. Today SolstenXP completed the following: • Rigged up wireline and made the first run down the tube with the 2 1/4 star bit. The obstruction was tagged at a depth of 1918 feet. Efforts continued to dislodge the obstruction. • A second run down the tube was made with the 2 1/4 bailer thick fluid was encountered at 1,422 feet. Bailer was worked down to 1,916 feet and a fluid sample was collected. The sample was weighed at 11.7 ppg. A repeat run was performed and to tools were able to get to 1,918 feet and solid obstruction was encountered. • Tubing pressure was bleed from 450 psi to 250 psi pressures stabilized when fluid returned to surface. Casing pressure went form 280 psi to 225 psi. • Tubing pressure was bleed from 225 psi to 220 psi and casing pressure remained static. • Mixed 40 barrels of 11.4 ppg mud heated to 150 degrees. • Pumped and reverse circulated 18 barrels of mud while maintaining a tube pressure of 250 psi. Well annulus pressure ranged from 140 to 210 psi. Well returns were containerized in the slop tank. A return fluid sample weighed 10.4 ppg in the beginning and 10.8 ppg at the end. • Pumped and circulated 22 barrels of mud while maintaining a tube pressure of 250 psi. Well annulus pressure of 200 psi was held. Well returns were containerized in the slop tank. A return fluid sample weighed 10.8 ppg. The volume of fluid and fluid weight indicate the well tube and annulus are in communication with each other and the well has been fully killed. • Rigged up the wireline with the tubing cutter and cut the tube at a depth of 1300 feet. Additional detail of the day's activities and planned work activities for the next day are in the attached email correspondence. Contractor's Verification: On behalf of the Contractor,I certify that this report is complete and correct,and all materials and equipment used and work performed during this reporting period are in compliance with the plans and contract requirements,to the best of my knowledge,except as may be noted above. CQC System Manager Forrest Janukaltis Date 4/17/2016 (type) (sign) • • DAILY QUALITY CONTROL REPORT ENVIRONMENTAL QUALITY CONTROL/QUALITY ASSURANCE REPORT (ER 415-1-302) Ikroavik Lake Lake Sungovoak Unnamed Lake Gallons of Water(today) -- -- 4,410 Yards of Ice Chips(today) -- -- 0 Gallons of Water Total -- -- 152,880 Yards of Ice Chips Total -- -- 0 General Daily Remarks: Marsh Creek continued to support P&A activities for Iko Bay#1, including; equipment and camp maintenance, equipment fueling, water making/hauling activities, and trail maintenance (grooming). Marsh Creek trail crew loaded unneeded equipment and containers of project waste for transport back to Dead horse. Today SolstenXP completed the following: • Completed setting up hoses for mud and cement pumping activities. • Pumped 11.4 ppg kill mud from the batch plant to the ISO tank, rigged up lines to circulate mud in the tank and tested all lines. • Mixed 90.1 barrels of artic set cement. Collected three samples of cement and weighed in a mud balance. All three samples weight 12.6 ppg. Collected one sample (3 x cup volumes) of cement to demonstrate cement hardness. • Pump 76.8 barrels into the well through the well tube. Well casing psi ranged from 350 to 475. • Set the foam ball in the tube and displaced 5.2 barrels of 11.4 ppg kill mud. • Shit annulus and tubing. Cementing complete at 14:55. • Pumped remaining kill mud into the batch mixer tank. Disconnected and removed charge pump and ISO tank. Cleaned lines and batch mixer. Contractor's Verification: On behalf of the Contractor,I certify that this report is complete and correct,and all materials and equipment used and work performed during this reporting period are in compliance with the plans and contract requirements,to the best of my knowledge,except as may be noted above. CQC System Manager Forrest Janukaitis Date 4/19/2016 (type) (sign) • • DAILY QUALITY CONTROL REPORT ENVIRONMENTAL QUALITY CONTROL/QUALITY ASSURANCE REPORT (ER 415-1-302) General Daily Remarks: Iko Bay Marsh Creek continued to support P&A activities for Iko Bay#1, including; equipment and camp maintenance, equipment fueling, water making/hauling activities, and trail maintenance (grooming). Marsh Creek trail crew departed Iko Bay loaded with two D7 dozers, 5,000 Peak waste tank and overpacks of project waste for transport back to Deadhorse. Today SolstenXP completed the following: • Disassembled, inspected and cleaned the batch plant mud pump • Cleaned out both batch plant mix tanks • Disassembled and put away hard lines and moved choke manifold to trailer with unneeded well supplies • Consolidated, palletized, and staged unneeded well cement/brine/bar and placed on trailer for transport • Bled well annulus pressure from 130 psi to 0 psi and shut back in. Bled tubing pressure from 200 psi to 0 psi and shut back in. No pressure buildup was observed after 5 minutes. • Set up equipment and pumped .5 barrel of 11.4 ppg fluid into the well annulus and pressurized to 1,500 psi to perform pretest of yesterday's cement job. 1,500 psi was held for 15 seconds but then bled down to 500 psi, held for 6 seconds and then bled to 300 psi. Annulus pressure rose to 340 psi after 45 minutes and stayed there for the next 3 hours. Tubing pressure was at 0 psi after 4 hours. Results indicate additional time is needed for the cement to cure. Notified Marsh Creek and SolstenXP offices of results to allow for contingency planning. • Drained and rolled up pump hoses and put away test equipment. • Wrapped well heat and continued to heat. South Barrow#3 Marsh Creek began site activities at the South Barrow#3 well site. The following was completed today: • Mobilized the Denali cat train survival unit car from Iko Bay to South Barrow#3 to support site activities. • Began cutting wood piling that are sticking up out of the tundra around the well flush with the ground surface. 47 piling were cut and staged for offsite transport and disposal. Approximately 61 visible piling remain. Several feet of snow cover is making it challenging to locate and cut the piling. Crew to continue cutting activities tomorrow. • Began evaluating area around the well for suitable location to position camp and work lay down areas. Contractor's Verification: On behalf of the Contractor,I certify that this report is complete and correct,and all materials and equipment used and work performed during this reporting period are in compliance with the plans and contract requirements,to the best of my knowledge,except as may be noted above. CQC System Manager Forrest Janukaitis t" Date 4/20/2016 (type) (sign) • • DAILY QUALITY CONTROL REPORT ENVIRONMENTAL QUALITY CONTROL/QUALITY ASSURANCE REPORT (ER 415-1-302) General Daily Remarks: Iko Bay Marsh Creek continued to support P&A activities for Iko Bay#1, including; equipment and camp maintenance, equipment fueling, water making/hauling activities, and trail maintenance (grooming). Today SolstenXP completed the following: • Removed and containerized additional mud impacted snow from the 4/18 mud release that was under the charge pump foot print. Some additional material remains to be recovered alongside the batch plant once it is moved and there is sufficient access. • Rigged up wire line with 2 1/4 bailer with flapper. Ran down the tube and tagged cement at a depth of 915 feet. A fluid sample was recovered and it was mostly barite. • Bled well annulus pressure from 220 psi to 0 psi and shut back in. Tubing pressure was at 0 psi. • Set up equipment pressurized well annulus to 1,500 psi to perform test on well cement plug. The first test attempt did not hold pressure and eight more attempts were made. Between attempts two drips were tightened and air was bled from the well. With each test the annulus was able to maintain more pressure. Results for the last test were; 1,500 psi dropped to 1400 psi after 20 seconds, 1,400 psi dropped to 1,300 psi after 86 seconds, 1,300 psi dropped to 1,200 psi after 3 minutes and 20 seconds, 1,200 psi dropped to 1,100 psi in 5min 30 seconds. • Set up equipment on well tube to perform pressure testing. Pressure on well was 0 psi prior to test. Opened bleeder value and no pressure was present. Five attempts were made maintain well tube pressure at 1,500 psi for 30 minutes: o Pressurized tube to 1,500 psi and pressure dropped to 1,325 psi in five minutes but then stabilized. o Tube was pressure was pumped back up to 1,500 psi and pressure dropped to 1,450 psi in eight minutes. o Air was bled from the tubing and then the tubing was pressurized to1,525 psi and pressure dropped to 1,475 in 17 minutes o Pumped tube to 1,525 psi and pressure dropped to 1,470 in 30 minutes o Pumped tube to 1,550 psi and pressure dropped to 1,500 in 30 minutes • Drained and rolled up pump hoses and put away test equipment. South Barrow#3 Marsh Creek continued site activities at the South Barrow#3 well site and the following activities were conducted: • Continued cutting wood piling that are sticking up out of the tundra around the well flush with the ground surface. 20 piling were cut and staged for offsite transport and disposal. Approximately 41 visible piling remain. Both chainsaws onsite broke down and prevented further progress. Crew to continue cutting activities tomorrow. Contractor's Verification: On behalf of the Contractor,I certify that this report is complete and correct,and all materials and equipment used and work performed during this reporting period are in compliance with the plans and contract requirements,to the best of my knowledge,except as may be noted above. COC System Manager Forrest Janukaitis l Date 4/21/2016 (type) (sign) 10OFr I%y a THE STATE Alaska Oil and Gas °fALA S� Conservation Commission 333 West Seventh Avenue R, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ALAS Y' Main: 907,279.1433 Fax: 907.276 7542 www.aogcc.alaska.gov Lucas Munisteri Drilling Engineer Bureau of Land Management 222 West 7th Avenue, Suite 13 Anchorage,AK 99513 Re: NPRA Field, Exploratory Pool, Iko Bay#1 Permit to Drill Number: 100-036 Sundry Number:316-122 Dear Mr.Munisteri: Enclosed is the approved application for sundry approval relating to the above referenced well. Conditions of approval: I. BOPE to be tested to 1500 psi (MASP=950 psi ) 2. Contingency Plan#1 as proposed is not approved. Verbal approval is required to proceed with this alternative. 3. Daily workover report summary to be submitted to AOGCC by email. (to: Mike Quick/Guy Schwartz) 4. 9.6 ppg NaCI brine is approved for BOPE testing(non-compressible fluid) Variance Requests: Alternate BOPE equipment layout as proposed in Sundry application is approved per 20 AAC 25.285(h). Alternate gas detection equipment using handheld sensors is approved per 20 AAC 25.066(d)(3). The physical configuration of the rig reduces the likelihood of accumulation of methane gases. 1-12S gas is not present in the reservoir. As provided in AS 3 1.05.080, 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, t a' Daniel T. Seamount,Jr. Commissioner DATED this 0 day of April, 2016. . , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request. Abandon 0 Plug Perforations❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown Suspend ❑ Perforate 9 Other Stimulate ❑ Pull Tubing 9 Change Approved Program❑ Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Atter Casing❑ Other. 0 2.Operator Name: 4.Current Well Class: 5.Permit to Dell Number: Bureau of Land Management Exploratory 0. Development 9 100-0360 3.Address Stratigraphic ❑ Service ❑ 6.API Number: 222 West 7th Avenue.#13 Anchorage,AK 99513 50-023-20007-00-00 7 If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? Iko Bay No. 1 Will planned perforations require a spacing exception? Yes 0 No Lir 9.Property Designation(Lease Number): 10.Field/Pool(s): NPRA• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(%):,_Effective Depth MD: Effective Depth TVD MPSP(psi): Plugs(MD)_ Junk(MD): (11?-31' 273)' aoSzv bs' �o� � r'S` z..:3 • Casing Length Size MD TVD Burst Collapse Structural Conductor 24" Surface 137' 16"75#N-80 149' 149' Intermediate 1178' 10.75"51#P-110 1190' 1190' 5600 psi 2500 psi Production 1258' 7"23# 1270' 1270' 5000 psi 2500psi Liner 1938' 5.5"20#J-55 1950' 1950' 5000 psi 5000 psi Perforation Depth MD(ft): Perforation Depth ND(tt): Tubing Size Tubing Grade Tubing MD(ft). NA NA 2.875"6.5# J-55 1942' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): NA NA 12.Attachments: Proposal Summary 0 Wellbore schematic 9 13.Well Class after proposed work. Detailed Operations Program 0 BOP Sketch 9 Exploratory 0- Stratigraphic 0 Development 0 Service 0 14 Estimated Date for 2/28/2016 Diagnose 15.Well Status after proposed work: Commencing Operations: 3/26/2016 Abandon OIL 9 WINJ ❑ WDSPL 0 Suspended ❑ 16 Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0.• 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Lucas Munisten Email lucas,munisten•soistenxp.com Printed Name LUCAS MUNISTERI Title Drilling Engineer G-rimLD EiG,'..,:___44 ,__ /.5-//e-,/ 014' Signature Phone 907-264-6114 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number l--). ,4ls sc:. rm0,,�,.:N..41l,-f-r‘4- 31 Le. - \2.2 Plug Integrity BOP Test 5/ Mechanical Integrity Test 0 Location Clearance (ie Sit,n•-IL"- ZL..I c,. Other: .r111 /51 if) r 5, Z)P j'C.5>r'"--- .. J1" eit.dt, Vc t-,-1-4,_.,.,4j 2,4-Si1 1,6 £ 1.4.14,4(2‘.1 C A P Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes ❑ No Z Subsequent Form Required: /C) - 4/L) 7 HERO Y / I Approved by: COMMISSIONER THE COMMISSION Date: ' co et<8 40./lc h- 'N4' Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 m the from the date of approval Attachments in Duplicate ORIGINAL .. a c, kb MARSHCREEK NPRA LEGACY WELL REMEDIATION Iko Bay # 1 SINGLE WELL PROGRAM PLUG AND ABANDONMENT PROCEDURE Date Issued: Thursday, April 07, 2016 Anticipated Date: Thursday, April 07, 2016 Expected Rig Name: Gefco 30K Water Well Rig Prepared By/Date Lucas Munisteri Drilling Engineer Agreed BY/Date Jesse Mohrbacher Manager --- Approved By/Date Rob Brumbaugh Bureau of Land Management IKO BAY # 1 - PLUG AND ABANDONMENT PROCEDURE Information used to develop this program was gathered from all available public sources of information on this well.The current configuration of this well was determined to the best ability and interpretation of the information. Due the nature of this well and its history,there may be some inaccuracies in the current well configuration.This program covers the final abandonment of the well in its currently interpreted condition. Therefore,caution needs to be taken at all times during the operation and error on the side of caution. Contents Overview 2 Well Diagnostics 3 Abandonment Procedure 4 APPENDIX Accumulator Test Procedure BOP Test Procedure Wellhead and valve drawings Wellbore Schematics Piping and Instrumentation Diagram • •DE: Lucas Munisteri Date Issued:4/7/2016 M: Jesse Mohrbacher Anticipated Date:4/7/2016 BLM: Rob Brumbaugh Page 11 • • Overview Iko Bay# 1 -Plug and Abandonment Procedure OVERVIEW During the winter of 2015—2016 BLM has contracted Marsh Creek and SolstenXP Inc.to perform the successful abandonment of legacy wells drilled in NPRA along with the remediation of the location. OBJECTIVE 1. Perform all work without causing damage to the environment, harm to people or equipment. 2. Perform all work in a safe and efficient manner. 3. Perform the successful final abandonment of the legacy wellbores. WELL HISTORY The Navy drilled this well in 1975.The rig had an original RKB of 12 feet.The well was completed and flowed gas. When the well was no longer necessary, it was shut in at the master valve and a bull plug installed directly downstream of that.At some point, a leak was detected from the bull plug.As there is no way to check definitively for pressure between the valve and the bull plug special precautions are required to service the valve to make entry into the well possible. CURRENT WELL STATUS As of 9 March 2016, a backup valve was successfully installed on the well and the leaking has been stopped. Initial diagnostics indicate that the tubing and casing are in communication however based on the pressure responses seen there may be an obstruction within the wellhead that was unidentifiable at the time due to the equipment spread that was onsite. Further diagnostics are still required to identify possible obstruction. The 3,000-psi master valve is no longer in service and should not be functioned until removed from the wellhead.The old master valve has been superseded by a 5,000-psi master valve. The casing has two different valves on the outside.One side has a 2,160 psi rated plug valve, and the other side has a 3,600 psi rated plug valve. Neither valve was in very good condition and required significant servicing to get them to function.The existing valves will be backed up by a 3,000 psi ball valve upon rigging up equipment. Determined that the well has 920 psi on both the tubing and the casing. Date Issued:4/7/2016 DE: Lucas Munisteri Anticipated Date:4/7/2016 M: Jesse Mohrbacher 2 I P a g e BLM: Rob Brumbaugh • • Iko Bay# 1 -Plug and Abandonment Procedure WELL DIAGNOSTICS PRESSURE COMMUNICATION TESTING 1. Move in required equipment to test wellhead for the leak and combustible gasses. Keep all ignition sources away from well. 2. Tarp in existing structure and rig up gas monitoring equipment. 3. Begin heating wellhead area with an indirect fired heater positioned upwind. 4. Attach secondary backup valves on the existing casing x tubing annulus valves. 5. Pressure test connection between backup valves and original valves to 1,500 psi. Chart the results. 6. Check for pressure in the annulus.The pressure should be the same in the tubing,assuming the well is not plugged off downhole. 7. Rig and secure a 2-inch vent line to the ground and locate downwind 100 feet. a. Install a check valve between the pump and the well as close to the well as possible. b. Vent through the choke manifold. c. Vent line terminates into an open top tank that is setup to flare the gas. d. Maintain the flare with an open flame at the end. e. Minimize number of bends in the flare line 8. Install pressure gauge on the tubing x casing annulus. 9. Pressure test vent lines with air to 100 psi for 10 minutes. 10. Vent the well out the tubing for 15 to 30 minutes with the choke fully open. Monitor pressure on the tubing x casing annulus to confirm the tubing and annulus are in communication. 11. Record the pressure every minute on both annuli. 12. Shut the well in. 13. Record the pressure build up every minute,for the equivalent time,the well was allowed to flow. 14. Repeat test on the annulus. OBSTRUCTION TESTING - IF REQUIRED 1. Rig up wireline tools 2. Run in hole with lead impression block slowly to locate obstruction. 3. Pull up and release block to get impression. 4. Pull out of the hole with the impression block. 5. Identify the obstruction. 6. Determine plan forward with SolstenXP and BLM onsite personnel. DE: Lucas Munisteri Date Issued:4/7/2016 M: Jesse Mohrbacher Anticipated Date:4/7/2016 BLM: Rob Brumbaugh Page 13 • • Iko Bay# 1 - Plug and Abandonment Procedure ABANDONMENT PROCEDURE PRIMARY PLAN MOVE IN EQUIPMENT 1. Move in required equipment,piping, generators,air compressor,scaffolding,tarps, rig and other well site equipment. 2. Rig up pumping equipment and secure a 2-inch vent line to the ground and locate downwind 100 feet. a. Install a check valve between the pump and the well as close to the well as possible. b. Vent through the choke manifold. c. Vent line terminates into an open top tank that is setup to flare the gas. d. Maintain the flare with an open flame at the end. e. Minimize number of bends in the flare line 3. Install pressure gauge on the tubing x casing annulus. 4. Pressure test vent lines with brine to 100 psi for 10 minutes.Chart the results. KILL WELL This section of the P&A program assumes that the tubing and annulus are in communication,and the well can be circulated. It the well cannot be circulated,proceed to Contingency Plan 1. 1. Rig up circulating lines on the well to pump down the tubing and take returns out the tubing x casing annulus,through a choke and flare the gas. 2. Circulate non-freezing kill weight fluid or 11.4 ppg down the tubing taking returns through the casing valve. 3. Circulate additional volumes as necessary to kill the well. During this time pump a tracer and verify there is not a hole in the tubing. CUT TUBING 1. Rig up wireline tools 2. Run in hole with gauge ring to 1,300 feet RKB and pull gauge ring out of the well. 3. Run in the well with tubing cutter to 1,300 feet RKB and cut the tubing 4. Verify that the tubing has been cut. 5. Pull out of the hole with the tubing cutter. CEMENT OPEN HOLE INTERVAL 1. Establish injection rate pressure.Working up in 0.5 bpm increments until 1,500 psi or 4 bpm is achieved. 2. Line up pumps to mix and pump 90 bbl., 1,135 feet of 12.5 ppg Arctic Set across the formation. 3. Verify that the annulus casing valves are shut. 4. Take 4 samples of cement and weight in a mud balance and document the weight of the cement. 5. Bullhead 74 bbl.of cement,do not exceed 1,500 psi at the surface. If 1,500 psi is reached at the surface, then open up the casing annulus and pump an additional 9 bbl of cement and proceed to step 7. _r4,t4 n . 6. Then open up annulus valves and finish pumping cement. Date Issued:4/7/2016 DE: Lucas Munisteri Anticipated Date:4/7/2016 M: Jesse Mohrbacher 4 I P a g e BLM: Rob Brumbaugh • • Iko Bay#1 -Plug and Abandonment Procedure 7. Insert foam ball in the tubing and displace cement with 5.2 bbl.of 11.4 ppg NaCI brine. 8. Shut-in well and allow cement to set for 24 hours. �c , c . f 5 9. Open valves,bleed pressure, shut back in and monitor for'ressure. 10. Test downhole cement plug by applying 1,500 psi on the tubing x casing annulus and monitoring tubing pressure.Chart test for 1. nin. Notify onsite inspector to witness. Bleed pressure off annulus. 30 wa,- 11. Repeat the test inside the tubing. RIGGING UP BOPE This section of the P&A program assumes that the pressure test of the well held pressure and the reservoir section of the well is isolated. If the well was unable to hold pressure proceed to Contingency Plan 2. 1. Monitor the fluid level in the well and ensure that the level is static. 2. Verify tubing hanger lockdown screws are fully engaged with the hanger. 3. Remove the master valves and tubing bonnet from the wellhead. 4. Clean and prep 7 in flange 5. Nipple up 7 inch BOP stack on the well consisting of blind rams,pipe rams,and annular preventer. pc 4-; 4: 4 C TEST BOP PER FEDERAL ONSHORE ORDER#2 „ye ..ter !{ l+'' Max Anticipated Surface Pressure=920 psi.Tested on 9 March 2016 by SolstenXP and FMC during onsite well diagnostics. 1. Function test the BOP stack and test the Accumulator Per the attached Accumulator Function Test procedure. 2. Fill well and stack and perform the tests with non-freezing brine bk' (9.6 ppg NaCl Brine TCT point-6°F). 3. Pressure test the BOP per the attached BOP Testing procedure. RUN INTO WELL TO CUTTING TUBING -1Q p� 1. Rig up wireline tools { � I I -7 2. Run in well with gauge ring,toq T .and pull out of the well. PI t 3. Run into well to 300 feet RKB.(, 4. Fire explosive tubing cutter and pull out of well. 5. Pull tubing hangar from well and lay down. Maximum pull is 10,000 lbs. 6. Pull tubing out of the hole with rig. SET SURFACE PLUG 1. Rig up wireline tools 2. Run gauge ring in the well to 250 feet and pull out 3. Run in with wireline bridge plug to 250 feet and set bridge plug. 4. Pull wireline out of the hole and rig down. 5. Run in the hole with the 2"pipe and tag the bridge plug. 6. Pull up 5 feet. 7. Line up surface piping to allow cement returns to be taken in an open top waste tank. DE: Lucas Munisteri Date Issued:4/7/2016 DM: Jesse Mohrbacher Anticipated Spud:4/7/2016 Client: Rob Brumbaugh Page 15 • • Iko Bay# 1 -Plug and Abandonment Procedure 8. Mix sufficient Arctic-Set cement to fill the 7-inch casing from 245 feet RKB to surface,about 10 bbl 9. Take 4 samples of cement and weight in a mud balance and document the weight of the cement. 10. Pump Arctic set cement 11. Displace well to cement until clean densified cement is observed at the top of casing taking returns into an open top tank.Take a sample of the returns every 5 bbls,weight the sample in the mud balance and set sample aside. 12. Follow cement with 0.5 bbl of displacement. 13. Pull work string out of hole slowly at first to prevent damaging the cement plug. 14. Top off if required. 15. Wait on cement for a minimum 6 hours to verify the plug does not fall 16. Top off where necessary. WELL HEAD REMOVAL 4444- 1. 44G1. Excavate around the well to a minimum depth of 6 feet. KJ o i J 2. Cut off the well 5 feet below ground level,top off casing and annuli*ith cement as needed r". 3. Weld on a marker plate on the 24-inch conductor that meets current BLM regulations and contract requirements. k 4ac,cc� a. Leave a small weep hole in the weld of the flange. b. Weld the Section,Township and Range to the side of the casing if there is no room on the marker plate. 4. Backfill excavated hole and proceed with disposal of waste materials from the site. Mound the excavation with gravel or tundra organics to account for settling. 5. Return to the site the following summer for stick pick operations. CONTINGENCY PLAN 1 Only to be performed with approval from the BLM. BULL HEADING WELL 1. Rig up on both the casing and tubing to pump,if possible based on diagnostics. If not proceed to Lubricate and Bleed. 2. Pump 11.4-ppg kill weight fluid down the well,surface pressure not to exceed 1,500 psi. 3. Pump two tubing volumes down the well. 4. Pump two wellbore volumes down the well monitoring surface pressure. 5. Shut down and monitor wellbore pressure LUBRICATE AND BLEED 1. Rig up on the wellhead section that circulation can be established. 2. Lubricate and bleed the well with 11.4 ppg brine until there is no pressure at the surface. 3. If necessary,bleed pressure from the annulus/tubing that is not being used to kill the well. RIGGING UP BOPE 1. Rig up wireline tools 2. Run in well with gauge ring to 200 feet RKB and pull out. 3. Run in well with Wireline retrievable bridge plug and set at 200 feet. 4. Monitor the fluid level in the well and ensure that the level is static. Date Issued:4/7/2016 DE: Lucas Munisteri Anticipated Date:4/7/2016 M: Jesse Mohrbacher 6 ! Page BLM: Rob Brumbaugh • • Iko Bay# 1 -Plug and Abandonment Procedure 5. Verify tubing hanger lockdown screws are fully engaged with the hanger. 6. Remove the master valves and tubing bonnet from the wellhead. 7. Clean and prep 7-inch the flange. 8. Nipple up 7-inch BOP stack on the well consisting of blind rams, pipe rams,and annular preventer. TEST BOP PER FEDERAL ONSHORE ORDER#2 Max Anticipated Surface Pressure=920 psi. Tested on 9 March 2016 by SolstenXP and FMC during onsite well diagnostics. 1. Function test the BOP stack and test the Accumulator Per the attached Accumulator Function Test procedure. 2. Fill well and stack and perform the tests with non-freezing brine(9.6 ppg NaCl TCT point-6°F). 3. Pressure test the BOP per the attached BOP Testing procedure. RETRIEVE BRIDGE PLUG 1. Rig up wireline tools 2. Run in well to retrieve wireline retrievable bridge plug set at 200 feet. 3. Latch on to tool and bleed pressure. 4. Monitor the fluid level in the well and ensure that the level is static. 5. Unset tool and retrieve to surface. 6. Rig down wireline. PULLING TUBING 1. Pull tubing hangar from well and lay down. 2. Pull tubing out of the well and lay down SETTING BRIDGE PLUG 1. Rig up wireline tools. 2. Run a gauge ring to 1,200 feet RKB and pull out of the well. 3. Run in the well to 1,170 feet RKB and set cast iron bridge plug. 4. Set the bridge plug and pull wireline out of the hole. 5. Run in the well with 2"work string and tag the bridge plug 6. Pull up 5 feet. 7. Line up surface piping to allow 12.5 ppg Arctic Set cement to be pumped down work string. 8. Take 4 samples of cement and weight in a mud balance and document the weight of the cement. 9. Pump 10 bbl.,250 feet of cement on top of bridge plug. 10. Load foam ball in the string and displace work string to just above the top of the plug,3.2 bbl. 11. Pull work string up 350 feet and circulate clean SET SURFACE PLUG 1. Pull work string up to 200 feet RKB. 2. Line up surface piping to allow cement returns to be taken in an open top waste tank. 3. Set a viscous plug from 200 feet RKB to 180 feet RKB,about 1 bbl., in the 7-inch casing. 4. Pull up to 180 feet RKB. DE: Lucas Munisteri Date Issued:4/7/2016 } DM: Jesse Mohrbacher Anticipated Spud:4/7/2016 Client: Rob Brumbaugh Page 17 • • Iko Bay# 1 - Plug and Abandonment Procedure 5. Mix and pump sufficient Arctic-Set cement to fill the 7-inch casing from 180 feet RKB to the surface,about 7 bbl. 6. Take 4 samples of cement and weight in a mud balance and document the weight of the cement. 7. Displace well to cement until clean densified cement is observed at the top of casing taking returns into an open top tank.Take a sample of the returns every 5 bbls,weight the sample in the mud balance and set sample aside. 8. Pull work string out of hole slowly at first to prevent damaging the cement plug. 9. Top off if required. 10. Wait on cement for a minimum 6 hours to verify the plug does not fall 11. Weight test surface plug to 200 lb. 12. Top off where necessary. WELL HEAD REMOVAL 1. Excavate around the well to a minimum depth of 6 feet. 2. Cut off the well 5 feet below ground level,top off casing and annuli with cement as needed 3. Weld on a marker plate on the 24-inch conductor that meets current BLM regulations and contract requirements. a. Leave a small weep hole in the weld of the flange. b. Weld the Section,Township and Range to the side of the casing if there is no room on ,r e' the marker plate. I" f', w� 4. Backfill excavated hole and proceed with disposal of waste materials from the site. Mound the '" excavation with gravel or tundra organics to account for settling. 5. Return to the site the following summer for stick pick operations. [% CONTINGENCY PLAN 2 - 54 op r p Only to be performed with approval from the BLM. PERFORATE TUBING 1. Rig up wireline tools 2. Run in hole with gauge ring,tag to the top of cement and pull gauge ring out of the well. 3. Run in the well with tubing punch to 100 feet above the cement and fire punch. Perforating 4 holes in phase with a punching charge. 4. Pull out of the hole with the tubing punch. CEMENT OPEN HOLE INTERVAL 1. Line up pumps to mix and pump 10 bbl.,250 feet of 12.5 ppg Arctic Set down the tubing to seal off the well. 2. Take 4 samples of cement and weight in a mud balance and document the weight of the cement. 3. Pump 10 bbl.of cement. 4. Insert foam ball in the tubing and displace cement with enough brine to put the ball at the top of the cement plug. 5. Shut-in well and allow cement to set for 24 hours. 6. Open valves, bleed pressure,shut back in and monitor for pressure. 7. Test downhole cement plug by applying 1,500 psi on the tubing x casing annulus and monitoring tubing pressure.Chart test for 30 min. Notify onsite inspector to witness. Bleed pressure off annulus. Date Issued:4/7/2016 DE: Lucas Munisteri Anticipated Date:4/7/2016 M: Jesse Mohrbacher 8 I P a g e BLM: Rob Brumbaugh S Iko Bay# 1 -Plug and Abandonment Procedure 8. Repeat the test inside the tubing. Note:If this fails,repeat the process of perforating the tubing and cementing one more time and if unsuccessful,consult with BLM, SolstenXP,and AOGCC. RIGGING UP ROPE 1. Rig up wireline tools 2. Run in well with gauge ring to 200 feet RKB and pull out. 3. Run in well with Wireline retrievable bridge plug and set at 200 feet. 4. Monitor the fluid level in the well and ensure that the level is static. 5. Verify tubing hanger lockdown screws are fully engaged with the hanger. 6. Remove the master valves and tubing bonnet from the wellhead. 7. Clean and prep 7 in flange 8. Nipple up 7 inch BOP stack on the well consisting of blind rams, pipe rams,and annular preventer. TEST BOP PER FEDERAL ONSHORE ORDER#2 Max Anticipated Surface Pressure=920 psi.Tested on 9 March 2016 by SolstenXP and FMC during onsite well diagnostics. 1. Function test the BOP stack and test the Accumulator Per the attached Accumulator Function Test procedure. 2. Fill well and stack and perform the tests with non-freezing brine(9.6 ppg NaCI Cloud point-7°F). 3. Pressure test the BOP per the attached BOP Testing procedure. RETRIEVE BRIDGE PLUG 1. Rig up wireline tools 2. Run in well to retrieve wireline retrievable bridge plug set at 200 feet. 3. Latch on to tool and bleed pressure. 4. Monitor the fluid level in the well and ensure that the level is static. 5. Unset tool and retrieve to surface. 6. Rig down wireline. CUTTING TUBING 1. Rig up wireline unit. Run into well and tag top of cement plug. 2. Fire explosive tubing cutter and pull out of hole. 3. Pull tubing hangar from well and lay down. 4. Pull tubing out of the hole with rig. SET SURFACE PLUG 1. Rig up wireline tools 2. Run gauge ring in the well to 200 feet and pull out. 3. Run in with wireline bridge plug to 200 feet and set bridge plug. 4. Pull wireline out of the hole and rig down. 5. Run in the hole with the 2"pipe and tag the bridge plug. 6. Pullup5feet 7. Line up surface piping to allow cement returns to be taken in an open top waste tank. DE: Lucas Munisteri Date Issued:4/7/2016 DM: Jesse Mohrbacher Anticipated Spud:4/7/2016 Client: Rob Brumbaugh Page 19 • • Iko Bay# 1 -Plug and Abandonment Procedure 8, Mix and pump sufficient Arctic-Set cement to fill the 7-inch casing from 180 feet RKB to the surface. 9. Take 4 samples of cement and weight in a mud balance and document the weight of the cement. 10. Displace well to cement until clean densified cement is observed at the top of casing taking returns into an open top tank.Take a sample of the returns every 5 bbls,weight the sample in the mud balance and set sample aside. 11. Pull work string out of hole slowly at first to prevent damaging the cement plug. 12. Top off if required. 13. Wait on cement for a minimum 6 hours to verify the plug does not fall 14. Weight test surface plug to 200 lb. 15. Top off where necessary. WELL HEAD REMOVAL 1. Excavate around the well to a minimum depth of 6 feet. 2. Cut off the well 5 feet below ground level,top off casing and annuli with cement as needed 3. Weld on a marker plate on the 24-inch conductor that meets current BLM regulations and contract requirements. a. Leave a small weep hole in the weld of the flange. b. Weld the Section,Township and Range to the side of the casing if there is no room on the marker plate. 4. Backfill excavated hole and proceed with disposal of waste materials from the site. Mound the excavation with gravel or tundra organics to account for settling. 5. Return to the site the following summer for stick pick operations. Date Issued:4/7/2016 DE: Lucas Munisteri Anticipated Date:4/7/2016 M: Jesse Mohrbacher 10 ! Page BLM: Rob Brumbaugh • • , ./7",C) SQUARE TOP MA RS H CR E E K BULL PLUG POSSIBLE LEAK 3" x 2" REDUCER V 3" LP THREAD \ 1 ' r .r FMC OCT MODEL 20 1 1 ti— 3" 3000 PSI i —1 1 1 Afii�iflflflfff I 1 hi.ifii 3" LP THREAD 6" 5000 PSI J dfli STUDDED OUTLETS FMC OCT TUBINGHEAD TYPE "U" 2" NORDSTROM VALVE \;; 9" OD DYNAMIC BALANCE PLUG VALVE ' FIG. 2344 J 2" NORDSTROM VALVE DYNAMIC BALANCE PLUG VALVE :iiii__ = FIG. 2344 2" x 10" DOUBLE C �- EXTRA STRONG OD: 2.375" WT 0.436" rflfli 2" x 10" DOUBLE /�' EXTRA STRONG 10" 3,000 PSI OD: 2.375" WT: 0.436" STUDDED OUTLETS 1L1 Q IU 4 112" BALL VALVE - SHOULD BE COVERED WITH 2" BULL PLUG, EXTRA > • CEMENT STRONG -. OD: 2.375" WT 0.218" II, A 1I 10 4" CASING ./r\ t 7" CASING REGAN WELLHEAD ,,�.c 2 " TUBING 16" 3000 PSI MACHINED TO SLIP ON 10 4" CASING LAT: 71.1702 N LONG: 156.1670 W DATUM: NAD 83 US DEPARTMENT OF INTERIOR EAST: 716,275 us FT NORTH: 6,281,650 us FT ZoNE: UPM IKO BAY No. I SECTION: 16ITOWNSHIP: 21 NI RANGE: 16 WIMERIDIAN: UMIAT FWL: 2,500 FTIFSL: 1,850 FTIELEV: 28 FTIRKB: 12 FT API # 50-023-20007-00-00 SPUD DATE COMPLETION DATE STATUS DATE STATUS PERMIT TO DRILL # 100-0360 01 FEB 1975 23 FEB 1975 08 MAR 1975 LEAKING DATE: BY: i C = '` COMMENTS: WELLHEAD 6 JAN 2016 LUCAS MUNISTERI t„f 0 € a5 i . r''• P REVISION: L SCALE: No Sura 0 " • • RKB ..-"*J.7.:(4 -\ GROUND LEVELI }— ] --`30' MD / TVD • CEMENT 10 SURFACE 149' MD / TVD - 660 SKS PERMAFROST MARSHC REEK 24" OD CONDUCTOR —166' MD / TVD • CEMENT TO SURFACE SET @ 18' GL - 810 SKS PERMAFROST 22"'HOLE 166MD / TVD 16" 75# N 80 R3 B RND • CEMENT To SURFACE ID 15 124" DID 14 936" - 360 SKS PERMAFROST SET @ 149' MD / TVD • UNKNOWN WELLBORE FLUID 14.75' Y HOLE A"' 1.220' MD ' TVD NI 6111 � cc 1011. 10 75" 5I# P-110 R2 BTC ID 9 850" DID 9 694" - � B 5.600 PSI C 2 500 PSI -r1.1 -.6 _ �'� 1,190' MD I TVD —1,190' MD / TVD —1212' MD / TVD m'`� "• BROWN LINER HANGER Fr, OW 7" 23# UKN GRADE (AsuME C-95)R3 I I I 1.220' MD / TVD L ID 6 366"DID: 6 241" -L L 10- 3i'. B 5,000 PSI C 2.500 Psi I I 1,270' MD / TVD I� 1,270' MD / TVD I I A 4'. 1,300' MD / TVD BASE OF PERMAFROST �'� APPROX 1,300' MD / TVD I I I. III I I 5.5" 20# J-55 R3 7, I ICf` E" ID 4.788' DID 4 653' I a p ' r B 5.000 Ps1 C 5,000 Psl is °" a ToP 1.212' MD / TVD I BOTTOM 1,950' MD / TVD I I =T ORANGE PEALED ON BOTTOM • FLOW TESTED WITH 800 PSI SLOTTED 1 262'-1,274' 1.562'-I 648' 1,307'-1,370' 1 732'-1.775' ' 1,942' MD i TVD 1.469'-1,536' 1 905' 1.950 1,950' MD/ TVD 2 875' 6,5# J-55 R2 8 RHD 2.035" MD / TVD ID 2 441" DID 2 347" B: 5,000 PSI C. 5,300 PSI • CEMENT - 175' HEIGHT 1.942' MD / TVD -120 SKS CLASS G CMT 2.210' MD i TVD 9.625'HOLE 7 2.702' MD / TVD LEGEND • DRILLING MUD I i CEMENT - Ii 4 PPG -0 DRILLING FLUID 2 702' MD I TVD IJ DIESEL r- 7.625" CORE HOLE 1 Q BRINE 2,731' MD 7 TVD 2.731' MD / TVD = WATER Q PRODUCED FLUID ED FaL C=I OTHER LAT: 71.1702 N LONG: 156.1670 W DATUM: NAD 83 US DEPARTMENT OF INTERIOR EAST: 716,275 us FT NORTH: 6,281,650 us FT ZONE: UPM IKO BAY No. I SECTION: I6ITOWNSHIP: 21 NIRANGE: 16 WIMERIDIAN: UMIAT FWL: 2,500 FTIFSL: 1,850 FTIELEV: 28 FTIRKB: 12 FT API # 50-023-20007-00-00 SPUD DATE COMPLETION DATE STATUS DATE STATUS PERMIT TO DRILL # 100-0360 01 FEB 1975 23 FEB 1975 08 MAR 1975 I-GASDATE' BY: I P COMMENTS: CURRENT WELLBORE CONFIGURATION 14 OcT 2015 LUCAS MVNISTERI T i :t:T t V tor REVISION: SCALE: RELATIVE VERTICAL 2 RELATIVE HORIZONTAL • • CEMENT - 245' HEIGHT RKB-\ 7 MD / TVD - 10 BBL , JI ' GROUND LEVEL 1 r L-I-30 ' MD / TVD \,�,�/J / CEMENTTO SURFACE n149' MD / TVD 660 SKS PERMAFROST MARSHCRFFK / -166 MDI TVD 24. OD CONDUCTOR245MD / Tv0 SET @ 18' GL "'- 250' MD / TVD 22" HOLE 166' MD / TVD 16" 75# N-80 R3 8 RHO ID 15.124" DID 14 936" • CEMENT To SURFACE SET @ 149' MD / TVD - 360 SKS PERMAFROST CAST IRON BRIDGE PG • DRILLING FLUID LU 11 4 PPG I4 75' HOLE > 1 220' MD / TVD 10 75" 51# P-110 R2 BTC ;r ID 9 850" DID 9 694" 900' M0 TVD B 5,600 PS/ C2.500 FS4 • CEMENT To SURFACE 1,190' MD / TVD - 810 SKS PERMAFROST —1,190' MD I TVD -1212' MD I TVD BROWN LINER HANGER A IA-- 7" 23# LAN GRADE (ASUME C-95) R3-- ( I I —1.220' MD / TVD ,ti, e,,I30;V ID 6.366" DID 6 241' IA B 5,000 PSI C 2 500 Ps+ i '-- 1270' MD / TVD 1,270' MD / TVD BASE OF PERMAFROST 1,300' MD / TVD APPROX 1,300' MD I TVD I 5,5" 20# J-55 R3 --I► I I ID 4.788" DID 4.653' I I B. 5,000 PSI C 5,000 PSI ToP 1,212' MD I TVD BOTTOM 1,950' MD/ TVD I, • I CEMENT 1.135' HEIGHT ORANGE PEALED ON BOTTOM - 90 BBL SLOTTED 1242'-1,276' 1 562'-1,648' 1,307'-1.370' 1.732'-1,775' t 1469'-1.536' 1905'-1 950 ! 950' MD / TVD 2 875" 6.5# J-55 R2 8 RNo 2.035' MD / TVD ID 2 441"DID 2 347" B. 5,000 PSI C 5,300 PSI • CEMENT - 175' HEIGHT 1,942' MD / TVD -120 SKS CLASS G CMT 2,210' MD / TVD 9 625' HOLE s 2,702" MD / TVD LEGEND • DRILLING MUD I: CEMENT - 11.4 PPG I: DRILLING FLUID 2,702' MD ( TVD 0 DIESEL 7.625" CORE HOLE , 1 Q BRINE 2,731' MD / TVD 2,731' MD / TVD ED WATER ID PRODUCED FLUID =I FILL (:=3 OTHER LAT: 71.1702 N LONG: 156.1670 W DATUM: NAD 83 US DEPARTMENT OF INTERIOR EAST: 716,275 us FT NORTH: 6,281,650 US FT ZONE: 1PM IKO BAY NO. SECTION: 16ITOWNSHIP: 21 NIRANGE: 16 WIMERIDIAN: UMIAT FWL: 2,500 FTIFSL: 1,850 FTIELEV: 28 FTIRKB: 12 FT API # 50-023-20007-00-00 SPUD DATE COMPLETION DATE STATUS DATE STATUS PERMIT TO DRILL # 100-0360 01 FEB 1975 23 FEB 1975 08 MAR 1975 I-GAS r DATE: BY: r" > a -� I COMMENTS: PROPOSED ABANDONMENT CONFIGURATION 6 APR 2016 LUCAS MUNISTERI C € t I1>; P REVISION: SCALE: RELATIVE VER,C41 6 RELATIVE HORIIOMTAL S COMPANY LEASE& WELL NAME TEST DATE Accumulator Function Test 1) Start with the work string placed in the well above the blind shear rams 2) Place All Functioning Accumulator Valves In Open Position Allow Accumulator To Pressure Up Before Shutting Off All Of The Pumps 3) Close Annular& Record Time and Pressure Annular Initial Pressure Final Pressure Time 4) Close Pipe Rams & Record Time and Pressure Top Pipe Rams Initial Pressure Final Pressure Time 5) Close the Blind/Shear Rams& Record Time And Pressure Simulated Blind Initial Pressure Final Pressure Time 6) Close HCR (If Applicable)& Record Time And Pressure HCR Initial Pressure Final Pressure Time 7) On Three Ram Stack Close Bottom Pipe Rams & Record Time and Pressure Bottom Pipe Rams Initial Pressure Final Pressure Time When Done With the Recorded Times and Pressures There Should Be At Least 200 psi Over the Precharge Pressure in the Accumulator(1200 psi) Nitrogen Bottles - Bleed Off Test 1) Finish Bleeding Off Bottles Into Accumulator Tank/Reservoir. 2) Watch and Record Where Pressure Drops (Accumulator psi) Pressure Drop psi The Accumulator Pressure Should Drop At 1100 psi to 900 psi 2 Minute Time Test - Accumulator Pumps 1) Shut Valves to Nitrogen Bottles 2) Place HCR in Open Position (If Applicable) 3) Place Annular in the Closed Position 4) Turn On Pumps And Record Time To Pressure Up Manifold On Accumulator to At Least 200 psi Over Precharge.Within 2 Min or Less Record Time Minutes Seconds 5) Open Valve to Nitrogen Bottles And Pressure The Accumulator Back to Shut Off Point. Then Open All Pipe Rams And Annular Before Pulling Plug And Drill Pipe Out Of BOP. BOP Test Procedure • COMPANY LEASE& WELL NAME TEST DATE Test # Time Systems Being Tested Choke Manifold Valves(Offline) 5min n50psi R 10 min(a)15n0p‹ 2 IBOP(Offline) 5 min co 50 psi& 10 min @ 150 2 Annular 4 Frs+b 10 min @ 1500 pt, 3 Pipe Rams rn in 4 Pipe Rams,inner choke line and kill valves,BOP Connection, Casing Weld 5 min c(i)50 psi&30 ni nresstye drop 15r. 5 Pipe Rams,outer choke line valve,kill line check valve ceb 50 psi&30 rn: 1500 psi-Max prey drop 150 psi 6 Blind/Shear Rams, Hard line tsuu p•i ;`-.1vx piessure drop 155 psi Test time(hrs.) Pick up assembly 1) Connect pumps to the choke manifold and close the valves and test the manifold valves 2) Open the inner valves and drain the manifold. 3) Connect the TIW valve the test stump and test TIW. 8) Fill Stack 4) Close Blind /Shear rams 5) Run test joint into BOP 6) Close annular and pressure test annular 7) Close pipe rams and test 8) Open Blind/Shear Rams, Close inner valves on Choke and Kill lines 9) Pressure test stack 10) Open inner valves on choke and kill lines and close outer choke line valve 11) Pressure test stack 12) Close the Blind/Shear rams and pressure test them from the lower side. Comments: BOP Test Procedure • II J -J 11( d � Q 1110 d 0 W ` I (1HN o E " � z O •o Z o E J O U X LU �I — V./ 0- O no O D _ ,,, J•� ' OZ 00 # J • Z > N J Y U k A ' w m O p m N L12 I- p O O O (..) S 2 4 # H a d E Q ct w a W a z Q J a O CO a Z ~ CD o m O 'o w (3U) �O I r Cr a 0 z 0 a 410 ti w z N 6 W F-, N a Oi ^�- z V'V o z a LU p — 11_ CO I i Io, Dki W r.L] {/ ( • • J J _. 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L.1 : ; JZ - I W W ..,.!� s I� I.Io U Q 0 II __ ° NY (1}Z Uiii ry Z 7sC U Q J m OO 00J 1-OmwQ aj w = = O o coZ N N 0N Csi Ill /0 =N b fl u ill N cv ,1a 1L c c W 0 O --Ir• •1s.:V,1111i4''•s10 O W 111* - Q T 0 2 Z1 zZ I V N id- n W O Z a ¢ oo0ar I O N W W I- Cr 0 -N _ > 000_ 0 w cc W a1j0 O• ~ it2 > WZO O 2 0U • • LZ m a c F-Q O 11- d 0> w m w z O¢ cc 0 • • flINCTechnologies 10/14/2015 Draft Recommendation to access well for Iko Bay Well#1. 1. OEM or qualified technician on site to determine the positioning of the FMC model 20 gate valve. Identify and verify size, pressure rating and, if possible, assembly part number for the valve. The identification tag for the FMC valves are generally found riveted onto the body. 2. Positioning of the gate valve is determined by removal of the stem protector and operating the stem independently. If the valve stem travels through its complete stroke and the stop nut contacts the carrier body, the valve is either operational or is in the closed position. 3. If the stem does not completely retract per the attached position document, the gate can be assumed to be in a partially or complete open position. This can be verified via the "A" dimension detailed in the picture labeled V-2 and the accompanying chart. 3- 9/16"from the carrier face to the rear of the stop nut is completely open. Additional information can be gathered from the ''Turns to Close" Documentation as well. 4. If the gate is not closing independently, utilize the "Repairing Broken Stems" section of the FMC service manual, attempt to force the gate into the closed position. 5. Once the gate is in the "Closed" position, secure the hand wheel and stem. Access the Plastic Injection Port on the valve body and inject FMC approved valve sealant into the cavity. The plastic injection is designed to enfuse the downstream seat with plastic and facilitate a seal against the gate. 6. At this point, check for leakage via the observed leakpath. If there is no leak evident, slowly remove the buliplug from the upper threaded portion of the gate valve and add an additional gate valve to the tree assembly.. NOTE: No bleeder plug is evident in the bull plug, this renders this part of the procedure extremely dangerous Proceed with caution and consider remote removal of the bull plug 7. If the original gate valve is operational, open the valve and continue with well operations. At a proper place in the procedure, it is recommended that a full service be performed on the original gate valve. 8. If the original gate valve is not verified to be in the closed position, stop operations and consult with FMC engineering for remedial recommendations. These recommendations may include a hot tap operation to manually open the original gate valve, either through the well bore or into the rear of the valve body. These recommendations are drafts only and are designed to help develop a plan forward on this project. Additional information may change this draft at which time we would revisit these issues_..Please call with any items we can be of assistance with. Kevin Hite Operations Manager FMC Technologies, Inc Anchorage Alaska 99518 907-563-3990 Office 907-529-0106 Mobile • • . LJ ..VL.� Model 20 and Model 75 2,000 and 3,000 pst working pressure Stem protector • 7"---- � Handwheel ( ti's-' Drive screw Retainer ring Sten Lock screw anC Nylon plug �'� T,ip ���S 0111 �— infection screw Thrust bearings ,._ I<��Thrust-bearing 1, ---- Plastirnlect paekinq grease lifting !retlion porn 11 Istem packing; Bonnet nut i Caftifr retainer ring I. Gate :, r i 4 • Check valve IiStele packing T-siol __ __- Cliiii&_________________ Seat \\ ---"-- •::' ' 1111111*'4/440' , ,, el . , Plastic packing iniectiun port (downstream seat ontyl i'//'~v \\ Belleville spring At �-^ Andy / 1, Body grease ` rifting • 0 ______ �_ V. Adjusting Stop Nut t. - , All Models WARNING:The stop nut adjustment is extremely important. ' Improper adjustment will cause the gate to overdose or under- '"+w., :: ..'4iie4 ibir�ilip, •' close,allowing a leak path to develop.Follow the adjusting prose- --t w dure exactly. µ* Tools required:Adjustable wrench,Allen wrenches,ruler in inches ` �. "x. To adjust stop nut: 11-1 V 2 1. Open valve fully. Gate will bump the bonnet. 2. Remove stem protector(fig.V-1). 3. Use ruler to measure face-to-face distance between stop nut and �{ ,, i. carrier(fig.V-2). 4. Refer to Stop Nut Adjustment Chart for correct distance for the .: valve you are working on. -�: 5. If measured distance is not correct,loosen Allen-head lock screws on stop nut(fig.V-3). f r Alt-'=-- 6. 6. Move stop nut to correct distance by turning it. ' . CAUTION:Be sure stem does not rotate when you turn the stop nut. 7. Use ruler to recheck distance. S. Tighten Allen-head lock screws securely. V-3 Hi; With valve al tub-open position, set slop nut to"A"dimension___ PPM'I ifitilliiiii*- -11 w1 Wessomimonmor Stop Nut Adjustment Chart —� 'A'uDIMENSION—Working Pressure,psi M°dE27, Model 30 Nominal Bore 2,000 Size. Size. and inches inches 3,000 5,000 10,000 15.000 10,000 15,000 1 114. 116 Ph - _ 13/. 1131,. 2'6 23/4 2'4 2% 2'l: 231. 2 2'h. 2'6 2'6 2'6 236 2'6 23/. 2'4 29/a 3 3 3 3'/. 3 3'/. 3 3'/, 3'h. 33/4. 39/.. 3"h., Sola 3'/. 4 416 436 43/, 43/. — 43/. 5 5 514 513/, 5l3/, — — — — 6 6'/. 6"/,, 6"h. — — — — 6 636 736 736 — — — _ 6X7 7'4 7"h. 7"h. — — — 'lC • • Table 0—Plastic Packing Chart TABLE Ill—Turns To Open Model 20 and Model 30 All Models Plastic-Teflon packing for Model 20 and Model 30 valves may be Handwheel Revolutions(Full open to full close)—T' Revolution ( ) ordered using the following part numbers. Valve Working Pressure,pal Size,inches Nominal Bore Diameter Length Part Number Color Size, Size, 2,000 inches inches 3,000 5,000 10,000 15,000 20,000 S1„ 34 90-019-050 Purple 3/, 2 48-080673 Purple 13/. 1'3/., 12'l: 12'6 12'6 133/. 18'6 134 63/, 90-019-051 Purple 2 2'/,. 12'6 12'6 12'1, 133/. — 2'l: I'6 48-080-874 Purple 2'!, 29/,. 15 15 15 16'/. — 3 3'4. Model 75 314. 1731, 1731. 1734 19'/. 31 In Model 75 valves, arctic sealant replaces the plastic-Teflon 4 4'4, packing. 4'4. 23 23 23 20 — 5 5'4 29 283/. — -- Size,inches 6 6V. 334. 33'1. — — --- Diameter Length Part Number Color 654 654 363/. 3634 — -- — M. 4 90-419-083 Gray 7 7'4 38'1. 38'l. -- — — 3/, 2 90-419-084 Gray 134 6". 90.419-082 Gray 2'6 7'/, 90-419-081 Gray 10lbcan — 90-419-080 Gray Table IV—Trim Materials Model 20 and Model 30 When repairing any FMC gate valve,replace worn or used parts WARNING:Failure to trim properly during repair can result in with new parts of identical material. premature valve failure.Do not substitute parts or materials without the approval of Wellhead Equipment Division,Valve Engineering Refer to the following chart for proper trim data. Dept., Houston,Texas. Trim data for FMC gate valves Model 20 and Model 30 Valve body 2,3,5 Alloy steel castings Alloy 410 S S Alloy 410 S S 10 — Steel 410S S Steel 410 S S. 15 — Castings 410 S S Castings 410 SS 20 — Forgings 410 S.S forgings 410 SS. Bonnet 8 2,3,5 Rolled steel Rolled steel 410 S S Rolled Steel 410 S.S. bat.plug 10 -- Rolled steel 410 S.S Moly coated Rolled seed 410 S.S Moly coaled body 15 — Rolled steel 410 SS Rolled steel 410 SS 20 — Rolled steel 410 S.S. Rolled steel 410 S.S. Stem 8 2,3,5 4140 steel moly coated 410 S S 410 SS. 4105S. 410 SS. bal stern 10 — 410 S.S Moly coaled 410 S S Moly coated K-Mond Moly coaled K-Monet Moly coated 15 — 410S.S threads 410 S.S threads K-Mond threads K-Mond threads 20 — 410 S.S. 410 S.S. K-Monet K-Monet Seats 2,3,5 4140 steel rnoly coaled 410 SS 410 S.S 410 SS 410 SS 10 -- 410 SS Hardsurtace 410S S Hardsurtace 410 S.S Hardsurtace 410S S Hardsurtace 15 -- 410 S S Hardsurtace 410 S.S.Hardsurface 410 S S Hardsurface 410 S.S Hardsurface 20 — 410 SS Hardsurtace 410 SS.Hardsurface 410 S.S Hardsurface 410 S.S Hardsurtace Gate 2,3.5 Forged steel nickel plated 410 S S Moly coaled 410 S S Moly coated K-Monet K-Monet 10 -- 410 S S Hardsurface 410S 5 Hardsurlace 410S S.Hardsurtace 410S S Hardsurtace 15 — 410 S S Hardsurtace 410 S.S Hardsurface 410 S.S Hardsurtace 410 SS Hardsurtace 20 — 410S S Hardsurtace 410 S.S Hardsurtace 410 S.S Hardsurtace 410 S.S Hardsurtace Stem 2,3.5 Buna-N,duck.hycat,etc Buna-N.duck,Teflon',etc Buna-N.duck.Teflon'etc Buna-N,duck,Teflon'.etc Buna-N,duck,Teflon',etc packing w/plastic injection w/plastic injection wlplastic injection w/ptastic injection w/plastic injection 10 - Tetlon/Hycar Teilon/Hycar Teflon/Atlas Teflon/Atlas 15 — Tellor'Hycar Teflon/Hycar TetelonmAllas Te1Io/Atlas 20 — Teflon/Hycar Tetlon/Hycar Tetelon/Aflas Teflon/Atlas (1) Controlled hardness is 238 max B H N on steel and stainless steel,302 max 8 1-1N on K-Monet (2) Wateruood is Trim"S"except coated internally w/electroless nickel (3) Meets N.A C.E requirements for 11,5 service. 'Teflon impregnated Buna-N,cotton and nylon fabric Hellon is a du Pont trademark Trim to'Model 75 valves is similar but material packing and elastomers for cold temperature replace the standard parts • • o"1 FLOWSERVE Nordstrom Valves Steel Lubricated Plug Valves FCD NVENBR1004-02—01/11 Dynamic Balance Plug Valves 0 0 O Principal Features :-.01.0.,.0�0 • Turns easily every time,shuts off with O ' the proven dependability of a plug valve and eliminates the problems 0 1.:\ generally associated with conventional plug valves. • As shown in the photograph,balance 0 holes at the top and bottom of the plug maintain equal pressure above and below the plug and in the plug port so that line pressure cannot jam the plug t into the body taper.A stainless steel i.�r spring pre-loads the plug to prevent _ _ vibration and thermal cycling from wedging the plug in the taper.Loading the top of the plug in this way also compensates for the weight of the - plug when the valve is installed upside — down. • The Dynamic Balance design provides durable,metal-to-metal seats and a 1. Stem Head-is obround with two 5. Plug-is coated with permanently sealant system for bubble-tight shutoff wrench flats that align the wrench in bonded,low-friction coating. on hard-to-hold fluids and restoration the direction of the port opening,thus of damaged seats. becoming an easily visible position in- 6. Bottom Balance Hole(not shown) dicator.Square adapters are available -is an integral part of the Dynamic • The Dynamic Balance design also to allow operational flexibility where Balance system which maintains pres- offers the Protected Pressure Balanc- space is limited. sure equalization between the plug ing feature for increased reliability in port and the bottom of the plug. service where there is a possibility of 2. Stem-treated with low-friction PTFE foreign particles in the media.This de- coating to reduce overall valve torque. 7. Balance Hole with Ball Check(not sign ensures that the balancing holes Wrench-operated valve stems are shown)-ensures that pressure above are not exposed to the line media in made of 400 series stainless steel the plug is the same as or greater than the plug port,providing added security for corrosion protection(i.e.,tough in the plug port. compared with normal pressure bal- offshore applications). 8. Sealant Injection Fitting-permits ancing. 3. Stem Packing-specially designed restoration of damaged seats and • Standard carbon steel API-6D and by Flowserve Nordstrom Valves, drop-tight shutoff on hard-to-hold 816.34 valves are suitable for general manufactured from a combination of fluids. service at temperatures from-20°F to graphite and TFE,the stem packing +450°F Weatherseal-two different types are +450°F(-29°C to+232°C). is pressure-energized(no external found in Dynamic Balance valves.The • Sealant systems are incorporated adjustments necessary)and is inert to Y a wide range of fluids and gases. stem weatherseal is specially shaped in metal-seated plug valves as an and constructed to protect the stem integral part of the valve,and sealant 4. Plug-Balancing Spring-is designed and packing from hostile environ- is required to ensure proper valve to preload the plug to prevent vibra- ments that can lead to corrosion.The performance. 6 tion and thermal cycling from wedging cover weatherseal is an elastomeric the plug into the taper regardless of ring compressed between the body • Dynamic Balance plug valves with installed position. and cover to protect cover bolts from their metal-to-metal seats have been i corrosion. fire-tested in conformance with API Standards 607 and 6FA. • • FLOWSERVE Nordstrom Valves Steel Lubricated Plug Valves FC0 NVENBR1004-02-01/11 Dynamic Balance Plug Valves Regular Pattern �K ASME Class 900 i (PN 150) I l . Figure 2344.Sizes 2 to 4 E 7 / O-._-3 Inca shown) '-- i 0 0 0 Figure 2345..Sites 3 8 4 only Figure 234514.Sizes 3 8 4 only (rot shown) FLL_ .l 1 O O (not shown) 11 A88 y I.--M Figure 2345 Sizes 3 and 4 ASME Class 900 — Figure 2344, 2345, 2345' 2345' 1 NPs 2 sire , ON 58 18.50• 21.50• End-to-endwelding ends.Figure 2345', i. 470 546 Face-lo-lace.flanged(raised face) r, 1500 18,00 final '.;'raised lace).Figure 2345 381 457 15.12 18.12 End-to-end.Hanged(ring loin)) 384460 1850____ 21.50' Enda-end.Clanged by weld end.Fiqure 2345': 470 548 End-to-end.threaded ends.Figure 2344 10.04 11.47 255 291 Diameter al flange 9.50 11.50 241 292 Center to top olstem E C6 7.8 8.9 168 193 226 42 50 58 Center to bottom of body F 107 127 147 Width of stem flats 0.81 1.00 1.25 21 25 32 Diameter of seem 1.09 1 41 1.78 N 28 36 45 10 11 t4 Height of stein flats 1 25 28 36 47 6.2 8.7 Extreme wage of body M 119 157 221 Wrench size 00-2 08-3 D8-4 _ 43 104 152__... Weight(aPProx.I.Flom 2344 20 47 69 Weight laPPro:.).Figure 2315 Sr `is^ a---146 240 ... 1I . 66 109 Weight(approx.) figure 234514 _ `; 111 -__ 154 1 50 70 I Weight lapprox I Figure 234514 ,„' 128 197 _ 5s !9 tc 4arbP Secrion 6.3and is mvbedaccordingly. 30 • ALASKA LEGACY WELL Iko Bay Well#1 71.4556°N, 154.3328°W NOT TO SCALE Wellhead has broken gate valve nd is leaking KB 12' • Well was tested then left in current condition. Well was reported to have kicked with 11.4 ppg mud in hole. Ground level ` # L- Y ■■ ■3 . • ■�_,_1 joint 24"Conducter set @18' 149' - 16"75# N-80 set @149' Cemented w/660 sxs < . a iIuio weight in tubing and on backside not known. 1190' 10-3/4"51#P-110 casing set @ 1190' Cemented w/810 sxs • 1212' .11 Liner Hanger set @1212' 1270' =j J 7"23#J-55 casing set @1270' Cemented w/360 sxs,1"50 sxs to surface cap.>>>.2210cuft/ft .0393 bbl/ft Slotted Liner Perforations 1242-1274 1307-1370 1469-1536 1562-1648 1732-1775 1905-1950 1939' .< 61 joints,2-7/8 6.5#Hydrill CS Tubing set @ 1939' 1950' 5-1/2"20#J-55 Slotted Liner set @ 1950' PB 2035' ;' cap '''.1L4Scuftjh .0211 bblji 120 sxs cement plug tagged @2035' 2731'TD • • WELLBORE CLEANUP TOOLS MI SW gp--,,,. Wellbore Productivity •��•���+�" M-I L.L.C.A Schlumberger Company Customer focused,solutions-driven 6411 A Street,Anchorage Alaska,99518;Tel:907-273-1700 PREPARED FOR Lucas Munisteri PREPARED BY Michael Brzezinski (281)507-7220 CA- COPIES TO R. Figueroa,K.Haag r s CLASSIFIED A5 M 1 SWACO-SolstenXP J 4 r DATE January 5,2016fit,r. 0 j r LOCATION Alaska EXECUTIVE SUMMARY Lucas Munisteri, SolstenXP, has requested product information and mixing /breaking instructions for three upcoming abandonment wells in a remote area outside of Barrow,Alaska.Two of the wells propose minimal risk based on the data received from SolstenXP and will likely be permanently abandoned with cement plugs from surface to+/-250'.The third well,has the potential to be more complex in that it was a producer and exhibited pore pressures that would require an equivalent mud weight of 11.4 ppg to control.This well also has production tubing in place that will likely not be able to be pulled,or circulated through. M-I SWACO has been asked to provide chemical and mixing instructions to SolstenXP to permanently abandon these wells according to their own design. Chemicals to be provided include: CaC12(Calcium Chloride) FLOVIS Plus Barite Myacide GA25/Busan 1060 ECF-2396 SAFE-BREAK L f Caustic Soda Citric Acid • • Schlumberger Laboratory Cement Test Report 12.5 Solsten XP Plug Pilot- DRAFT EXTERNAL Fluid No :PAK 16pIg1006 Client Solsten XP Location/Rig :N/A Signatures Date Jan-25-2016 Well Name .X Field : Umiat f Daniel Himel Job Type 9 5/8" Depth 500.0 ft TVD 500.0 ft BHST 50 Starting Tem 90gF BHCT 65 degF BHP 500 psi g PdegF Time to Temp 00:20 hr:mn Heating Rate -0.31 degF/min Starting Pressure 200 psi Time to Pressure 00:20 hr:mn Schedule () Composition Slurry Density 12.50 lb/gal Yield 2.04 ft3/sk Mix Fluid 10.085 gal/sk Solid Vol. Fraction 33.787% Porosity 66.213% Slurry type Other Code Concentration Sack Reference Component Blend Density Lot Number 12.5 ppg Sols 108.6 lb of BLEND Blend 148.73 lb/ft3 D124 0.85 XP Blend Fresh water 9.824 gal/sk Base Fluid Rheology Tem.erature 80 de.F 65 des F (rpm) Up Down Average Up Down Average (deg) (deg) (deg) (deg) (deg) (deg) 300 8.0 8.0 8.0 96.0 96.0 96.0 200 6.0 7.0 6.5 86.0 83.0 84.5 100 4.0 5.0 4.5 75.0 67.0 71.0 60 3.0 4.0 3.5 64.0 58.0 61.0 30 2.0 4.0 3.0 46.0 43.0 44.5 6 2.0 3.0 2.5 16.0 19.0 17.5 3 2.0 2.0 2.0 11.0 12.0 11.5 10 sec Gel 6 deg-7 13 Ibf/100ft2 19 deg-22.57 Ibf/100ft2 10 min Gel 33 deg-39 19 Ibf/100ft2 19 deg -22.57 Ibf/100ft2 Rheo computed I Viscosity• 12.770 cP Yield Point:2.56 Ibf/100ft2 I Viscosity 94.107 cP Yield Point.56.89 lbf/100ft2 I Thickenin t Time Consistency Time 30 Bc 04:10 hr:mn 50 Bc 10:04 hr:mn 70 Bc 12:16 hr:mn 100 Bc 15:47 hr:mn Free Fluid 1.2 mU250mL in 2 hrs At 80 degF and 0 deg incl Sedimentation: None Note: This is a pilot test. Field blend may differ after testing. Please read field blend report carefully and compare to pilot report and load out. Contact the laboratory with any questions or concerns. Page 1 • WELLBORE CLEANUP TOOLS Mi SWACO Wellbore Productivity M-I L.L.C.A Schlumberger Company Customer-focused,solutions-driven Field Formulations FLUID TYPE AND 50 BBLs 11.1 PPG 50 BBLs 11.4 PPG WATER ADDITIONS PRODUCTS CACL2 BRINE CACL2 WBM w1TH-10°F TGT wrrH-10°F TCT WATER 43.4 bbls 42.5 bbls 1 bbl CALCIUM CHLORIDE 8,150 lbs 8,000 lbs 180 lbs FLOVis PLUS 49 lbs BARITE 900 lbs ECF-2396 As Needed for Foam As Needed for Foam As Needed for Foam MYACIDE GA25 OR 1 gallon 1 gallon 0.02 gallon BUSAN 1060 Discussion I estimate 300 bbl minimum requirement for the 3 wells at this concentration. A request by SolstenXP for 100% contingency anticipated barite will be formulated into the commercial estimate.The 300 bbl estimate does not include any safety factors.Please let us know what kind of contingency safety factor you would like included in the commercial proposal. Commercial Proposal Commercial Proposal update to follow. 02010 M-1 All rights reserved'Mark of M-1, CMC 2300 0907 R2(E) This information is supplied coley for informational purposes and M-1 SWACO makes no guarantees or warrantieseither expressed or implied wdh respect to the accuracy and use of this data AS product warranties and guarantees shat be governed by the Standard Terms of Sate Nothing in this document is legal advice or is a substitute!or competent legal advice ,/7 • ,---.' ‘t, 0 ___. '- --0 0.7--------,,,NN Tk le—Tr ND HISTORY ,� a.: HIR. a Pad Rogan 'Me • - — Memorial Airport '- IN' _ TA* /' / 8 IR "- urs r+ r , w __- owQE -U . , uox. 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I I _ i Zi.K „ • usobk 1 — — I !Om- - i ' II 1i EQUIPMENT LAYOUT FORL— --r-t-----1 T - IKO BAY WELL REMEDIATION i fa....k: 20' I 40' 0 PARTS CONEX (8'x 20') —•— O TOOL CONEX (8'x 20') i L_..___.__I I I O ISO TANKS (8'x 20') I I 0 ISO TANKS (8'x 20) ' OCEMENT UNIT (8'x35.5) Tov ELEVATION OF vAo• — I ! 95 5' / BOILER (8x20') 11 i.71r:r 1' j O BOP j i• 0$ RETURN TANK (3'x 6') 1 / 0 SCAFFOLDING 1, / / / 10 CHOKE MANIFOLD (4'x 4') '\ RAWP AT j 1 11 DIVERTER TANK (3'x6') , 1:6 SLOPE 1 /, 0 GENERATOR (4'x 6) ` 1 ;3. / 13 HEATER j oowx j // 14 HEATER ►, fJ O HEATER r/r ;1 16 LIGHT PLANT i,f OF PAW 11 ACCUMULATOR (8'x20`) TOE 18 COMPRESSOR (5'x 9') • 24' --,g 8'---- I r IIKEANED) '_._.Vim, TS IS 5 ZS j Feet 00 10 0 SCALE Plan North I Work Site Layout I P'"7"-C1') �� 1 .-1'4 may.,\ \-, iU., aa., I ter., won , — :.----- ,_,• • :., • ' .-...„. -"I .'• .•• -. • -,..',„--t1*•40.A..„ . . ....—..„„ --...-..-_,- .•.-,,. -"A*--0:---„ • ,..---.,:,.,-.'• . . .. .;,-.--.....;:.- :„ ..„,„ „.........„ .„ ,..,..-,.„.„.1„.„ ..„:,„...,.,,.....:.,-"„ti,4„,...,..,--....-,.,.,.y„,f1...i„„tvit4...,..4- 4.!0.0.4;;.".•'-'',7";,'"0' i -:•-• „ ..„... eX„„4;70,,f4:;t:e."',..-.s.;--',k,-.'...,:.4:44,- -,..i..,-„.'---4,,t.,1:??0i-- ..: .„ - -•4•"4-t:-.44,...... •.:•'•1:•","„'•,-;,•"...4,„0„0„.4,•;"-:"-"i.".'.i...,:::.•••••!., .• -7.4.1;14.4k,:';-•;!.,4•;,"••• ••,••:.,-:...F.•• -, S . . 4,„:-..cNIP,..-•„,..*oe .,."..„.•:.. • .1.-**,,„,„„1";,:.•„,•••;i-., • „„• ... i ,-."-,„„c1,..„.,.4e0" -" • ,"•-•,-,-,,--."--". :„.:: ' •'„,', ,, .4 ,.. ....,,.':,...,„::..,„„,,...„..-.,.. 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'••-• '''''.• ' ft....•'.--:-..;',:.,i".7.--.t.;-•'''."'.,it'.44.."'".. ..f.""7'.""-:';'"- '- - • • • Oko Bay#1 _PTD 100-036 Conditions of approval: 1. BOPE to be tested to 1500 psi (MASP=950 psi ) 2. Contingency Plan #1 as proposed is not approved. Verbal approval is required to proceed with this alternative. 3. Daily workover report summary to be submitted to AOGCC by email. (to: Mike Quick/Guy Schwartz) 4. 9.6 ppg NaCl brine is approved for BOPE testing(non-compressible fluid) Variance Requests: Alternate BOPE equipment layout as proposed in Sundry application is approved per 20 AAC 25.285(h). Alternate gas detection equipment using handheld sensors is approved per 20 AAC 25.066 (d)(3). The physical configuration of the rig reduces the likelihood of accumulation of methane gases. H2S gas is not present in the reservoir. MAY 10 ?LW WELL LOG TRANSMITTAL OC .,; To: Alaska Oil and Gas Conservation Comm. May 5, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, KBEENDEERR Alaska 99501 S i D1 g �i . RE: Radial Cement Bond Log& Temperature Log: Iko Bay#1 Run Date: 4/22/16-4/27/16 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Iko Bay#1 Data in LAS format, Digital Log Image files 1 CD Rom 50-023-20007-00 Radial Cement Bond Log& Temperature Log (Field Print) 1 Color Log, ea. 50-023-20007-00 Composite Log 1 Color Log 50-023-20007-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION ..: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. SCANNED Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: MetaLozokeit V OF Tist • e", //7,-4'e. THE STATE Alaska Oil and Gas �►����� °f Conservation Commission = S _= ALAS 115147:-SAC "_ 333 West Seventh Avenue 1. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OFALAS�� Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Lucas Munisteri Drilling Engineer Bureau of Land Management 222 West 7th Avenue, Suite 13 SCANNED APS Anchorage,AK 99513 $ ZQ�� Re: NPRA Field,Exploratory Pool, Iko Bay#1 Permit to Drill Number: 100-036 Sundry Number: 316-122 Dear Mr. Munisteri: Enclosed is the approved application for sundry approval relating to the above referenced well. Conditions of approval: 1. BOPE to be tested to 1500 psi (MASP=950 psi) 2. Contingency Plan#1 as proposed is not approved. Verbal approval is required to proceed with this alternative. 3. Daily workover report summary to be submitted to AOGCC by email. (to: Mike Quick/Guy Schwartz) 4. 9.6 ppg NaCI brine is approved for BOPE testing(non-compressible fluid) Variance Requests: Alternate BOPE equipment layout as proposed in Sundry application is approved per 20 AAC 25.285(h). Alternate gas detection equipment using handheld sensors is approved per 20 AAC 25.066(d)(3). The physical configuration of the rig reduces the likelihood of accumulation of methane gases.H2S gas is not present in the reservoir. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, .0 Daniel T. Seamount,Jr. Commissioner DATED this 0 day of April, 2016. RBDMS L}- APR 1 1 2016 • • RECEIVED STATE OF ALASKA FEB 16 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon L-1 Plug Perforations LJ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ill Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool El Re-enter Susp Well 0 Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Bureau of Land Management Exploratory Pi _ Development ❑ 100-0360" 3.Address. Stratigraphic LJ Service ❑ 6.API Number. 222 West 7th Avenue,#13 Anchorage,AK 99513 50-023-20007-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Iko Bay No. 1 Will planned perforations require a spacing exception? Yes ❑ No Li< ?b 9.Property Designation(Lease Number): 10.Field/Pool(s): NPRA 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): a 311 2? 40 4035 aoAs9 2-D r iz`3%c L�n3S Casing Length Size MD TVD Burst Collapse Structural Conductor 24" Surface 137' 16"75#N-80 149' 149' Intermediate 1178' 10.75"51#P-110 1190' 1190' 5600 psi 2500 psi Production 1258' i 7"23# 1270' 1270' 5000 psi 2500psi Liner 1938' 5.5"20#J-55 1950' 1950' 5000 psi 5000 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): NA NA 2.875"6.5# J-55 1942' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): NA NA 12.Attachments: Proposal Summary Q Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program D BOP Sketch ❑ Exploratory [_j- Stratigraphic 0 Development Service ❑ 14. Estimated Date for 2/28/2016 Diagnose 15.Well Status after proposed work: Commencing Operations: 3/26/2016 Abandon OIL ❑ WINJ ❑ WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned [E.- 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Lucas Munisteri Email lucas,munisteri@solstenxp.com Printed Name LUCAS MUNISTERI Title Drilling Engineer - —% "-- /S/-,aa« Signature Phone 907-264-6114 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. /---, �41sc sc� -r 3..t.:e t'L-r1-i+" 1-5 \Le - \2.'L Plug Integrity[I BOP Test[if Mechanical Integrity Test ❑ Location Clearance 52/ S'L erivra - Zc,/te Other: -, 15.76. p5 . 6b" �` S fA4to / a(„1.,....„.2,,,,k C4..s:,1 f,�..t--- w CA P Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /0 - 4/0 I- RBDMS LA- APR 1 1 2016 (C)1,#".- APPROVED BY 1 W 1 1 ti Approved by: COMMISSIONER THE COMMISSION Date: /��/�1)M 24 1 7:4( Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 m the from the date of approval Attachments in Duplicate ORIGINAL -- 40 c,Q %. • • til°11.11.111) SOLSTEN4, P MARSHCREEK NPRA LEGACY WELL REMEDIATION Iko Bay # 1 SINGLE WELL PROGRAM PLUG AND ABANDONMENT PROCEDURE Date Issued: Thursday, April 07, 2016 Anticipated Date: Thursday, April 07, 2016 Expected Rig Name: Gefco 30K Water Well Rig Prepared By/Date Lucas MunisteriDrilling Engineer Agreed BY/Date Jesse Mohrbacher Manager Approved By/Date Rob Brumbaugh Bureau of Land Management • I IKO BAY # 1 - PLUG AND ABANDONMENT PROCEDURE Information used to develop this program was gathered from all available public sources of information on this well.The current configuration of this well was determined to the best ability and interpretation of the information. Due the nature of this well and its history,there may be some inaccuracies in the current well configuration.This program covers the final abandonment of the well in its currently interpreted condition. Therefore, caution needs to be taken at all times during the operation and error on the side of caution. Contents Overview 2 Well Diagnostics 3 Abandonment Procedure 4 APPENDIX Accumulator Test Procedure BOP Test Procedure Wellhead and valve drawings Wellbore Schematics Piping and Instrumentation Diagram DE: Lucas Munisteri Date Issued: 4/7/2016 M: Jesse Mohrbacher Anticipated Date: 4/7/2016 BLM: Rob Brumbaugh Page 11 ! ! Overview Iko Bay# 1 - Plug and Abandonment Procedure OVERVIEW During the winter of 2015—2016 BLM has contracted Marsh Creek and SolstenXP Inc.to perform the successful abandonment of legacy wells drilled in NPRA along with the remediation of the location. OBJECTIVE 1. Perform all work without causing damage to the environment, harm to people or equipment. 2. Perform all work in a safe and efficient manner. 3. Perform the successful final abandonment of the legacy wellbores. WELL HISTORY The Navy drilled this well in 1975.The rig had an original RKB of 12 feet. The well was completed and flowed gas. When the well was no longer necessary, it was shut in at the master valve and a bull plug installed directly downstream of that. At some point, a leak was detected from the bull plug. As there is no way to check definitively for pressure between the valve and the bull plug special precautions are required to service the valve to make entry into the well possible. CURRENT WELL STATUS As of 9 March 2016, a backup valve was successfully installed on the well and the leaking has been stopped. Initial diagnostics indicate that the tubing and casing are in communication however based on •. the pressure responses seen there may be an obstruction within the wellhead that was unidentifiable at the time due to the equipment spread that was onsite. Further diagnostics are still required to identify possible obstruction. The 3,000-psi master valve is no longer in service and should not be functioned until removed from the wellhead. The old master valve has been superseded by a 5,000-psi master valve. The casing has two different valves on the outside. One side has a 2,160 psi rated plug valve, and the other side has a 3,600 psi rated plug valve. Neither valve was in very good condition and required significant servicing to get them to function. The existing valves will be backed up by a 3,000 psi ball valve upon rigging up equipment. Determined that the well has 920 psi on both the tubing and the casing. Date Issued:4/7/2016 DE: Lucas Munisteri Anticipated Date:4/7/2016 M: Jesse Mohrbacher 2 I P a g e BLM: Rob Brumbaugh • Iko Bay# 1 - Plug and Abandonment Procedure WELL DIAGNOSTICS PRESSURE COMMUNICATION TESTING 1. Move in required equipment to test wellhead for the leak and combustible gasses. Keep all ignition sources away from well. 2. Tarp in existing structure and rig up gas monitoring equipment. 3. Begin heating wellhead area with an indirect fired heater positioned upwind. 4. Attach secondary backup valves on the existing casing x tubing annulus valves. 5. Pressure test connection between backup valves and original valves to 1,500 psi. Chart the results. 6. Check for pressure in the annulus.The pressure should be the same in the tubing, assuming the well is not plugged off downhole. 7. Rig and secure a 2-inch vent line to the ground and locate downwind 100 feet. a. Install a check valve between the pump and the well as close to the well as possible. b. Vent through the choke manifold. c. Vent line terminates into an open top tank that is setup to flare the gas. d. Maintain the flare with an open flame at the end. e. Minimize number of bends in the flare line 8. Install pressure gauge on the tubing x casing annulus. 9. Pressure test vent lines with air to 100 psi for 10 minutes. 10. Vent the well out the tubing for 15 to 30 minutes with the choke fully open. Monitor pressure on the tubing x casing annulus to confirm the tubing and annulus are in communication. 11. Record the pressure every minute on both annuli. 12. Shut the well in. 13. Record the pressure build up every minute, for the equivalent time, the well was allowed to flow. 14. Repeat test on the annulus. OBSTRUCTION TESTING — IF REQUIRED 1. Rig up wireline tools 2. Run in hole with lead impression block slowly to locate obstruction. 3. Pull up and release block to get impression. 4. Pull out of the hole with the impression block. 5. Identify the obstruction. 6. Determine plan forward with SolstenXP and BLM onsite personnel. DE: Lucas Munisteri Date Issued:4/7/2016 M: Jesse Mohrbacher Anticipated Date:4/7/2016 BLM: Rob Brumbaugh Page 13 i • Iko Bay# 1 - Plug and Abandonment Procedure ABANDONMENT PROCEDURE PRIMARY PLAN MOVE IN EQUIPMENT 1. Move in required equipment, piping, generators, air compressor, scaffolding, tarps, rig and other well site equipment. 2. Rig up pumping equipment and secure a 2-inch vent line to the ground and locate downwind 100 feet. a. Install a check valve between the pump and the well as close to the well as possible. b. Vent through the choke manifold. c. Vent line terminates into an open top tank that is setup to flare the gas. d. Maintain the flare with an open flame at the end. e. Minimize number of bends in the flare line 3. Install pressure gauge on the tubing x casing annulus. 4. Pressure test vent lines with brine to 100 psi for 10 minutes. Chart the results. KILL WELL This section of the P&A program assumes that the tubing and annulus are in communication, and the well can be circulated. If the well cannot be circulated, proceed to Contingency Plan 1. 1. Rig up circulating lines on the well to pump down the tubing and take returns out the tubing x casing annulus, through a choke and flare the gas. 2. Circulate non-freezing kill weight fluid or 11.4 ppg down the tubing taking returns through the casing valve. 3. Circulate additional volumes as necessary to kill the well. During this time pump a tracer and verify there is not a hole in the tubing. CUT TUBING 1. Rig up wireline tools 2. Run in hole with gauge ring to 1,300 feet RKB and pull gauge ring out of the well. 3. Run in the well with tubing cutter to 1,300 feet RKB and cut the tubing 4. Verify that the tubing has been cut. 5. Pull out of the hole with the tubing cutter. CEMENT OPEN HOLE INTERVAL 1. Establish injection rate pressure. Working up in 0.5 bpm increments until 1,500 psi or 4 bpm is achieved. 2. Line up pumps to mix and pump 90 bbl., 1,135 feet of 12.5 ppg Arctic Set across the formation. 3. Verify that the annulus casing valves are shut. 4. Take 4 samples of cement and weight in a mud balance and document the weight of the cement. 5. Bullhead 74 bbl. of cement, do not exceed 1,500 psi at the surface. If 1,500 psi is reached at the surface, then open up the casing annulus and pump an additional 9 bbl of cement and proceed to step 7. L.i 7r4-,tia- *4w1414 6. Then open up annulus valves and finish pumping cement. Date Issued:4/7/2016 DE: Lucas Munisteri Anticipated Date:4/7/2016 M: Jesse Mohrbacher 4 ! Page BLM: Rob Brumbaugh • • Iko Bay# 1 - Plug and Abandonment Procedure 7. Insert foam ball in the tubing and displace cement with 5.2 bbl. of 11.4 ppg NaCI brine. 8. Shut-in well and allow cement to set for 24 hours. ( f s 9. Open valves, bleed pressure, shut back in and monitor for liressure. 10. Test downhole cement plug by applying 1,500 psi on the tubing x casing annulus and monitoring tubing pressure. Chart test for Wriiin. Notify onsite inspector to witness. Bleed pressure off annulus. 3o 11. Repeat the test inside the tubing. fsvvp��./30 RIGGING UP BOPE This section of the P&A program assumes that the pressure test of the well held pressure and the reservoir section of the well is isolated. If the well was unable to hold pressure proceed to Contingency Plan 2. 1. Monitor the fluid level in the well and ensure that the level is static. 2. Verify tubing hanger lockdown screws are fully engaged with the hanger. 3. Remove the master valves and tubing bonnet from the wellhead. 4. Clean and prep 7 in flange 5. Nipple up 7 inch BOP stack on the well consisting of blind rams, pipe rams, and annular preventer. c -; _7 4O6 C-(— TEST BOP PER FEDERAL ONSHORE ORDER # 2 [ h h.r !{� k rs. Max Anticipated Surface Pressure =920 psi. Tested on 9 March 2016 by SolstenXP and FMC during "‘4i� onsite well diagnostics. 1. Function test the BOP stack and test the Accumulator Per the attached Accumulator Function Test procedure. 2. Fill well and stack and perform the tests with non-freezing brine /. (9.6 ppg NaCI Brine TCT point-6°F). 3. Pressure test the BOP per the attached BOP Testing procedure. RUN INTO WELL TO CUTTING TUBING focl 1 (oe) 1. Rig up wireline tools i? 2. Run in well with gauge ring, taq TgC and pull out of the well. 3. Run into well to 300 feet RKB. 4. Fire explosive tubing cutter and pull out of well. 5. Pull tubing hangar from well and lay down. Maximum pull is 10,000 lbs. 6. Pull tubing out of the hole with rig. SET SURFACE PLUG 1. Rig up wireline tools 2. Run gauge ring in the well to 250 feet and pull out 3. Run in with wireline bridge plug to 250 feet and set bridge plug. 4. Pull wireline out of the hole and rig down. 5. Run in the hole with the 2"pipe and tag the bridge plug. 6. Pull up 5 feet. 7. Line up surface piping to allow cement returns to be taken in an open top waste tank. DE: Lucas Munisteri Date Issued: 4/7/2016 DM: Jesse Mohrbacher Anticipated Spud: 4/7/2016 Client: Rob Brumbaugh Page 15 • • Iko Bay# 1 - Plug and Abandonment Procedure 8. Mix sufficient Arctic-Set cement to fill the 7-inch casing from 245 feet RKB to surface, about 10 bbl 9. Take 4 samples of cement and weight in a mud balance and document the weight of the cement. 10. Pump Arctic set cement 11. Displace well to cement until clean densified cement is observed at the top of casing taking returns into an open top tank. Take a sample of the returns every 5 bbls, weight the sample in the mud balance and set sample aside. 12. Follow cement with 0.5 bbl of displacement. 13. Pull work string out of hole slowly at first to prevent damaging the cement plug. 14. Top off if required. 15. Wait on cement for a minimum 6 hours to verify the plug does not fall 16. Top off where necessary. WELL HEAD REMOVAL 4c4,44-4.- 1. Excavate around the well to a minimum depth of 6 feet. �T ywr�� .tea 2. Cut off the well 5 feet below ground level, top off casing and annuli vGith cement as needed k 3. Weld on a marker plate on the 24-inch conductor that meets current BLM regulations and contract requirements. 4-40t`ec-- a. Leave a small weep hole in the weld of the flange. b. Weld the Section, Township and Range to the side of the casing if there is no room on the marker plate. 4. Backfill excavated hole and proceed with disposal of waste materials from the site. Mound the excavation with gravel or tundra organics to account for settling. 5. Return to the site the following summer for stick pick operations. CONTINGENCY PLAN 1 ____= rt,'; e Only to be performed with approval from the BLM. BULL HEADING WELL 1. Rig up on both the casing and tubing to pump, if possible based on diagnostics. If not proceed to Lubricate and Bleed. 2. Pump 11.4-ppg kill weight fluid down the well, surface pressure not to exceed 1,500 psi. 3. Pump two tubing volumes down the well. 4. Pump two wellbore volumes down the well monitoring surface pressure. 5. Shut down and monitor wellbore pressure LUBRICATE AND BLEED 1. Rig up on the wellhead section that circulation can be established. 2. Lubricate and bleed the well with 11.4 ppg brine until there is no pressure at the surface. 3. If necessary, bleed pressure from the annulus/tubing that is not being used to kill the well. RIGGING UP BOPE 1. Rig up wireline tools 2. Run in well with gauge ring to 200 feet RKB and pull out. 3. Run in well with Wireline retrievable bridge plug and set at 200 feet. 4. Monitor the fluid level in the well and ensure that the level is static. Date Issued: 4/7/2016 DE: Lucas Munisteri Anticipated Date: 4/7/2016 M: Jesse Mohrbacher 6 ! Page BLM: Rob Brumbaugh • • Iko Bay# 1 - Plug and Abandonment Procedure 5. Verify tubing hanger lockdown screws are fully engaged with the hanger. 6. Remove the master valves and tubing bonnet from the wellhead. 7. Clean and prep 7-inch the flange. 8. Nipple up 7-inch BOP stack on the well consisting of blind rams, pipe rams, and annular preventer. TEST BOP PER FEDERAL ONSHORE ORDER # 2 Max Anticipated Surface Pressure =920 psi. Tested on 9 March 2016 by SolstenXP and FMC during onsite well diagnostics. 1. Function test the BOP stack and test the Accumulator Per the attached Accumulator Function Test procedure. 2. Fill well and stack and perform the tests with non-freezing brine (9.6 ppg NaCI TCT point-6°F). 3. Pressure test the BOP per the attached BOP Testing procedure. RETRIEVE BRIDGE PLUG 1. Rig up wireline tools 2. Run in well to retrieve wireline retrievable bridge plug set at 200 feet. 3. Latch on to tool and bleed pressure. 4. Monitor the fluid level in the well and ensure that the level is static. 5. Unset tool and retrieve to surface. 6. Rig down wireline. PULLING TUBING 1. Pull tubing hangar from well and lay down. 2. Pull tubing out of the well and lay down SETTING BRIDGE PLUG 1. Rig up wireline tools. 2. Run a gauge ring to 1,200 feet RKB and pull out of the well. 3. Run in the well to 1,170 feet RKB and set cast iron bridge plug. 4. Set the bridge plug and pull wireline out of the hole. 5. Run in the well with 2"work string and tag the bridge plug 6. Pull up 5 feet. 7. Line up surface piping to allow 12.5 ppg Arctic Set cement to be pumped down work string. 8. Take 4 samples of cement and weight in a mud balance and document the weight of the cement. 9. Pump 10 bbl., 250 feet of cement on top of bridge plug. 10. Load foam ball in the string and displace work string to just above the top of the plug, 3.2 bbl. 11. Pull work string up 350 feet and circulate clean SET SURFACE PLUG 1. Pull work string up to 200 feet RKB. 2. Line up surface piping to allow cement returns to be taken in an open top waste tank. 3. Set a viscous plug from 200 feet RKB to 180 feet RKB, about 1 bbl., in the 7-inch casing. 4. Pull up to 180 feet RKB. DE: Lucas Munisteri Date Issued: 4/7/2016 DM: Jesse Mohrbacher Anticipated Spud: 4/7/2016 Client: Rob Brumbaugh Page 17 Iko Bay# 1 - Plug and Abandonment Procedure 5. Mix and pump sufficient Arctic-Set cement to fill the 7-inch casing from 180 feet RKB to the surface, about 7 bbl. 6. Take 4 samples of cement and weight in a mud balance and document the weight of the cement. 7. Displace well to cement until clean densified cement is observed at the top of casing taking returns into an open top tank. Take a sample of the returns every 5 bbls, weight the sample in the mud balance and set sample aside. 8. Pull work string out of hole slowly at first to prevent damaging the cement plug. 9. Top off if required. 10. Wait on cement for a minimum 6 hours to verify the plug does not fall 11. Weight test surface plug to 200 lb. 12. Top off where necessary. WELL HEAD REMOVAL 1. Excavate around the well to a minimum depth of 6 feet. 2. Cut off the well 5 feet below ground level, top off casing and annuli with cement as needed 3. Weld on a marker plate on the 24-inch conductor that meets current BLM regulations and contract requirements. a. Leave a small weep hole in the weld of the flange. b. Weld the Section, Township and Range to the side of the casing if there is no room on I (f'" the marker plate. ei„ c 4. Backfill excavated hole and proceed with disposal of waste materials from the site. Mound the � � excavation with gravel or tundra organics to account for settling. 5. Return to the site the following summer for stick pick operations. 1J CONTINGENCY PLAN 2 — s S+ Oro- t p d. Only to be performed with approval from the BLM. PERFORATE TUBING 1. Rig up wireline tools 2. Run in hole with gauge ring, tag to the top of cement and pull gauge ring out of the well. 3. Run in the well with tubing punch to 100 feet above the cement and fire punch. Perforating 4 holes in phase with a punching charge. 4. Pull out of the hole with the tubing punch. CEMENT OPEN HOLE INTERVAL 1. Line up pumps to mix and pump 10 bbl., 250 feet of 12.5 ppg Arctic Set down the tubing to seal off the well. 2. Take 4 samples of cement and weight in a mud balance and document the weight of the cement. 3. Pump 10 bbl. of cement. 4. Insert foam ball in the tubing and displace cement with enough brine to put the ball at the top of the cement plug. 5. Shut-in well and allow cement to set for 24 hours. 6. Open valves, bleed pressure, shut back in and monitor for pressure. 7. Test downhole cement plug by applying 1,500 psi on the tubing x casing annulus and monitoring tubing pressure. Chart test for 30 min. Notify onsite inspector to witness. Bleed pressure off annulus. Date Issued: 4/7/2016 DE: Lucas Munisteri Anticipated Date: 4/7/2016 M: Jesse Mohrbacher 8 I [ BLM: Rob Brumbaugh • Iko Bay# 1 - Plug and Abandonment Procedure 8. Repeat the test inside the tubing. Note:If this fails, repeat the process of perforating the tubing and cementing one more time and if unsuccessful, consult with BLM, SolstenXP, and AOGCC. RIGGING UP BOPE 1. Rig up wireline tools 2. Run in well with gauge ring to 200 feet RKB and pull out. 3. Run in well with Wireline retrievable bridge plug and set at 200 feet. 4. Monitor the fluid level in the well and ensure that the level is static. 5. Verify tubing hanger lockdown screws are fully engaged with the hanger. 6. Remove the master valves and tubing bonnet from the wellhead. 7. Clean and prep 7 in flange 8. Nipple up 7 inch BOP stack on the well consisting of blind rams, pipe rams, and annular preventer. TEST BOP PER FEDERAL ONSHORE ORDER #2 Max Anticipated Surface Pressure =920 psi. Tested on 9 March 2016 by SolstenXP and FMC during onsite well diagnostics. 1. Function test the BOP stack and test the Accumulator Per the attached Accumulator Function Test procedure. 2. Fill well and stack and perform the tests with non-freezing brine (9.6 ppg NaCI Cloud point-7°F). 3. Pressure test the BOP per the attached BOP Testing procedure. RETRIEVE BRIDGE PLUG 1. Rig up wireline tools 2. Run in well to retrieve wireline retrievable bridge plug set at 200 feet. 3. Latch on to tool and bleed pressure. 4. Monitor the fluid level in the well and ensure that the level is static. 5. Unset tool and retrieve to surface. 6. Rig down wireline. CUTTING TUBING 1. Rig up wireline unit. Run into well and tag top of cement plug. 2. Fire explosive tubing cutter and pull out of hole. 3. Pull tubing hangar from well and lay down. 4. Pull tubing out of the hole with rig. SET SURFACE PLUG 1. Rig up wireline tools 2. Run gauge ring in the well to 200 feet and pull out. 3. Run in with wireline bridge plug to 200 feet and set bridge plug. 4. Pull wireline out of the hole and rig down. 5. Run in the hole with the 2"pipe and tag the bridge plug. 6. Pull up 5 feet 7. Line up surface piping to allow cement returns to be taken in an open top waste tank. DE: Lucas Munisteri Date Issued:4/7/2016 DM: Jesse Mohrbacher Anticipated Spud:4/7/2016 Client: Rob Brumbaugh Page 19 • 1111 Iko Bay# 1 - Plug and Abandonment Procedure 8. Mix and pump sufficient Arctic-Set cement to fill the 7-inch casing from 180 feet RKB to the surface. 9. Take 4 samples of cement and weight in a mud balance and document the weight of the cement. 10. Displace well to cement until clean densified cement is observed at the top of casing taking returns into an open top tank. Take a sample of the returns every 5 bbls, weight the sample in the mud balance and set sample aside. 11. Pull work string out of hole slowly at first to prevent damaging the cement plug. 12. Top off if required. 13. Wait on cement for a minimum 6 hours to verify the plug does not fall 14. Weight test surface plug to 200 lb. 15. Top off where necessary. WELL HEAD REMOVAL 1. Excavate around the well to a minimum depth of 6 feet. 2. Cut off the well 5 feet below ground level, top off casing and annuli with cement as needed 3. Weld on a marker plate on the 24-inch conductor that meets current BLM regulations and contract requirements. a. Leave a small weep hole in the weld of the flange. b. Weld the Section, Township and Range to the side of the casing if there is no room on the marker plate. 4. Backfill excavated hole and proceed with disposal of waste materials from the site. Mound the excavation with gravel or tundra organics to account for settling. 5. Return to the site the following summer for stick pick operations. Date Issued:4/7/2016 DE: Lucas Munisteri Anticipated Date:4/7/2016 M: Jesse Mohrbacher 10 ! Page BLM: Rob Brumbaugh • • ..)•\ SQUARE TOP MARSHCREEK BULL PLUG I, POSSIBLE LEAK 3" x 2" REDUCER -3" LP THREAD I \�— E _ - F - - FMC OCT MODEL 20 -- —I3" 3000 PSI 1 3" LP THREAD rfli r11iii ifii 6" 5000 PSI 11m STUDDED OUTLETS ♦✓ —1—AGE FMC OCT TUBINGHEAD TYPE "U" 2" NORDSTROM VALVE m\\\\\\ u 9" OD DYNAMIC BALANCE PLUG VALVE /1-14 4 \ FIG. 2344 2" NORDSTROM VALVE �__ """""°""""""' DYNAMIC BALANCE PLUG VALVE F FIG. 2344 2" x 10" DOUBLE— ,.-, EXTRA STRONG OD: 2.375" WT: 0.436" rfh I1 2" x 10" DOUBLE EXTRA STRONG OD: 2.375" WT: 0.436" 10" 3,000 PSI STUDDED OUTLETS 1-141LP1-14It ( 7 111 I 1/2" BALL VALVE SHOULD BE COVERED WITH 2" BULL PLUG, EXTRA >CCEMENT STRONG [_1 -1--" I OD: 2.375" WT: 0.218" '1 •A 10 in CASING r,� 7" CASING BEGAN WELLHEAD 2 a" TUBING 16" 3000 PSI MACHINED TO SLIP ON 10 4" CASING LAT: 71.1702 N LONG: 156.1670 W DATUM: NAD 83 US DEPARTMENT OF INTERIOR EAST: 716,275 US FT NORTH: 6,281,650 US FT ZONE: UPM IKo BAY No. I nSECTION: 16 TOWNSHIP: 21 N RANGE: 16 W MERIDIAN: UMIAT FWL: 2,500 FT FSL: 1,850 FT ELEV: 28 FT RKB: 12 FT API # 50-023-20007-00-00 SPUD DATE COMPLETION DATE STATUS DATE STATUS _ PERMIT TO DRILL # 100-0360 01 FEB 1975 23 FEB 1975 08 MAR 1975 LEAKING DATE: BY: COMMENTS: WELLHEAD 6 JAN 2016 LUCAS MUNISTERI S//��V LST E NP i , REVISION: 4 SCALE: NO SCALE i • / . j/,•�IJ RKB-N4 '' !:` ` 11 GROUND LEVEL-"" 30' MD / TVD �• CEMENT TO SURFACE MARS HCR E E K / /% 149' MD / TVD 660 SKS PERMAFROST -166' MD / TVD 24" OD CONDUCTOR • CEMENT TO SURFACE SET @ 18' GL - 810 SKS PERMAFROST 22" HOLE — • CEMENT TO SURFACE 166' MD / TVD 16" 75# N-80 R3 8 RND- - 360 SKS PERMAFROST ID: 15.124" DID: 14.936" SET @ 149' MD / TVD UNKNOWN WELLBORE FLUID 3"LP THREAD .11%14.75" HOLE > FMC OC 1,220' MD / TVD MODEL 2c ■IE1I1 .pi, --3 LP THREAD 10.75" 5I# P-I10 R2 BTC 7 ID: 9.850" DID: 9.694" B: 5,600 PSI C: 2,500 PSI 6 rail �� 1,190' MD / TVD 2"NORDSTROM —1,190' MD / TVD VALVE r__ 111- -1,212' MD / TVD .'1 BROWN LINER HANGER A.__ _ _ 1011-' � 2"x 10"DOUBLE - -!- 7• a ��� EXTRA STRONG ' I 7" 23# UKN GRADE (ASUME C-95) R3 I I I1,220' MD / TVD ID: 6.366" DID: 6.241" `-- 10 3 �� B: 5,000 PSI C: 2,500 PSI I I 1,270' MD / TVD 1,270' MD / TVD I I E"BULL TRONG 1 �4" I EXTRA STRONG BASE OF PERMAFROST 1,300' MD / TVD APPROX 1,300' MD / TVD I I ii ii II i 1111II I I 1 5.5" 20# J-55 R3 y- I I REG3N WELLHEAD 16"3000 751 ' ID: 4.788" DID: 4.653" I I MACHINED TO SLIP B: 5,000 PSI C: 5,000 PSI ON Io i"CASINGill TOP: 1,212' MD / TVD BOTTOM: 1,950' MD / TVD I I ORANGE PEALED ON BOTTOM • FLOW TESTED WITH 800 PSI SLOTTED: 1,242'-1,274' 1,562'-1,648' 1,307'-1,370' 1,732'-1,775' -1,942' MD / TVD 1,469'-1,536' 1,905'-1,950' 1,950' MD / TVD 2.875" 6.5# J-55 R2 8 RND 2,035' MD / TVD ID: 2.441" DID: 2.347" B: 5,000 PSI C: 5,300 PSI • CEMENT - 175' HEIGHT 1,942' MD / TVD -120 SKS CLASS G CMT > v v 2,210' MD / TVD 9.625" HOLE V v v c v v v 2,702' MD / TVD V v v'2 VVV VVVV 5-vvv LEGEND •_. DRILLING MUD FI CEMENT C V V V - 11.4 PPG DRILLING FLUID V V V .7 a a V DIESEL V v v 2,702' MD / TVD 7.625" CORE HOLE I I I-I BRINE 2,731' MD / TVD 2,731' MD / TVD I—I WATER I-I PRODUCED FLUID O FILL OTHER LAT: 71.1702 N LONG: 156.1670 W DATUM: NAD 83 US DEPARTMENT OF INTERIOR EAST: 716,275 US FT NORTH: 6,281,650 US FT ZONE: UPM IKO BAY NO. SECTION: 16ITOWNSHIP: 21 N RANGE: 16 W MERIDIAN: UMIAT \ FWL: 2,500 FT FSL: 1,850 FT ELEV: 28 FT RKB: 12 FT API # 50-023-20007-00-00 SPUD DATE COMPLETION DATE STATUS DATE STATUS PERMIT TO DRILL # 100-0360 01 FEB 1975 23 FEB 1975 08 MAR 1975 GASBv �P COMMENTS: CURRENT WELLBORE CONFIGURATION DATE 4 OCT 2015 . LUCAS MUNISTERI SO L S T E N REVISION: SCALE: RELATIVE VERTICAL 2 RELATIVE HORIZONTAL • ID )-. (°� RKB-� CEMENT - 245' HEIGHT 17' MD / TVD - 0 BBL GROUND LEVEL—/ ' MD / TVD.. : L130 CEMENT TO SURFACE 49' MD / TVD - MARSHCREEK r '�_... —1166' MD / TVD 660 SKS PERMAFROST 24" OD CONDUCTOR245' MD / TVD SET @18' GL /alli250' MD / TVD 22" HOLE 166' MD / TVD 16" 75# N-80 R3 8 RND CEMENT TO SURFACE ID: 15.124" DID: 14.936" SET @ 149' MD / TVD - 360 SKS PERMAFROST CAST IRON BRIDGE PLUG - DRILLING FLUID - 11.4 PPG 14.75" HOLE 7- 1,220' MD / TVD I 10.75" 51# P-I10 R2 BTC i ID: 9.850" DID: 9.694" —900' MD / TVD B: 5,600 PSI C: 2,500 PSI , ----------- CEMENT TO SURFACE 1,190' MD / TVD - 810 SKS PERMAFROST —1,190' MD / TVD —1,212' MD / TVD BROWN LINER HANGER 7" 23# UKN GRADE (AsuME C-95) R3 A]A 1 I9` I-1,220' MD / TVD ��y �',f30z ID: 6.366" DID: 6.241" _..._,1,.. 1 1, L1,270' MD / TVD B: 5,000 PSI C: 2,500 PSI I 1,270' MD / TVD BASE OF PERMAFROST 1,300' MD / TVD APPROX 1,300' MD / TVD 1 1 5.5" 20# J-55 R3 + I I ID: 4.788" DID: 4.653" I B: 5,000 PSI C: 5,000 PSI ToP: 1,212' MD / TVD BOTTOM: 1,950' MD / TVD I. I— CEMENT - 1,135' HEIGHT ORANGE PEALED ON BOTTOM - 90 BBL SLOTTED: 1,242'-1,274' 1,562'-1,648' 1,307'-1,370' 1,732'-1,775' I 1,469'-1,536' 1,905'-1,950' I1 —1,950' MD / TVD 2.875" 6.5# J-55 R2 8 RND MD / TVD ID: 2.441" DID: 2.347" B: 5,000 PSI C: 5,300 PSI 0 CEMENT - 175' HEIGHT 1,942' MD / TVD ;,�;> -120 SKS CLASS G CMT x' 2,210' MD / TVD ,vvv,; 9.625" HOLEV V V V VVVV 2,702' MD / TVD V V V V ' vvv': 'VVV • VVV ' LEGEND S- DRILLING MUD I—I CEMENT V V V - 11.4 PPG n DRILLING FLUID S7vvc w V F-2,702' MD / TVD En DIESEL •7.625" CORE HOLE Z .,vv 11-7 BRINE 2,731' MD / TVD 2,731' MD / TVD 0 WATER n PRODUCED FLUID EJ FILL OTHER LAT: 71.1702 N LONG: 156.1670 W DATUM: NAD 83 US DEPARTMENT OF INTERIOR EAST: 716,275 US FT NORTH: 6,281,650 us FT ZONE: UPM IKO BAY No. I /�� SECTION: 16 TOWNSHIP: 21 N RANGE: 16 WIMERIDIAN: UMIAT '': A► FWL: 2,500 FT FSL: 1,850 FT ELEV: 28 FT RKB: 12 FT API # 50-023-20007-00-00 SPUD DATE COMPLETION DATE STATUS DATE STATUS _ PERMIT TO DRILL # 100-0360 01 FEB 1975 23 FEB 1975 08 MAR 1975 I-GAs DATE: By: COMMENTS: PROPOSED ABANDONMENT CONFIGURATION 6 APR 2016 LUCAS MUNISTERI SO LST E N/(P REVISION: SCALE: RELATIVE VERTICAL 6 RELATIVE HORIZONTAL • • ! COMPANY LEASE& WELL NAME TEST DATE Accumulator Function Test 1) Start with the work string placed in the well above the blind shear rams 2) Place All Functioning Accumulator Valves In Open Position Allow Accumulator To Pressure Up Before Shutting Off All Of The Pumps 3) Close Annular& Record Time and Pressure Annular Initial Pressure Final Pressure Time 4) Close Pipe Rams & Record Time and Pressure Top Pipe Rams Initial Pressure Final Pressure Time 5) Close the Blind/Shear Rams & Record Time And Pressure Simulated Blind Initial Pressure Final Pressure Time 6) Close HCR (If Applicable) & Record Time And Pressure HCR Initial Pressure Final Pressure Time 7) On Three Ram Stack Close Bottom Pipe Rams & Record Time and Pressure Bottom Pipe Rams Initial Pressure Final Pressure Time When Done With the Recorded Times and Pressures There Should Be At Least 200 psi Over the Precharge Pressure in the Accumulator (1200 psi) Nitrogen Bottles - Bleed Off Test 1) Finish Bleeding Off Bottles Into Accumulator Tank/Reservoir. 2) Watch and Record Where Pressure Drops (Accumulator psi) Pressure Drop psi The Accumulator Pressure Should Drop At 1100 psi to 900 psi 2 Minute Time Test - Accumulator Pumps 1) Shut Valves to Nitrogen Bottles 2) Place HCR in Open Position (If Applicable) 3) Place Annular in the Closed Position 4) Turn On Pumps And Record Time To Pressure Up Manifold On Accumulator to At Least 200 psi Over Precharge. Within 2 Min or Less Record Time Minutes Seconds 5) Open Valve to Nitrogen Bottles And Pressure The Accumulator Back to Shut Off Point. Then Open All Pipe Rams And Annular Before Pulling Plug And Drill Pipe Out Of BOP. BOP Test Procedure • • COMPANY LEASE& WELL NAME TEST DATE Test# Time Systems Being Tested 1 Choke Manifold Valves(Offline) 5min L50psi&10min @1500psi 2 IBOP(Offline) 5min @50 psi&10 min @ 1500 psi 2 Annular 5min @50 psi&10 min @ 1500 psi 3 Pipe Rams @ 50 psi&10 min @ 1500 psi 4 Pipe Rams, inner choke line and kill valves, BOP Connection, Casing Weld 5 min @ 50 psi&30 min© 1500 psi. Max pressu : :p 150 psi. 5 Pipe Rams,outer choke line valve, kill line check valve 5 min @ 50 psi&30 min @ 1500 psi ividA piesswe drop 150 psi. 6 Blind/Shear Rams, Hard line 5 min @ 50 psi&30 min @ 1500 psi. Max pressure drop 150 psi. Test time(hrs.) Pick up assembly 1) Connect pumps to the choke manifold and close the valves and test the manifold valves 2) Open the inner valves and drain the manifold. 3) Connect the TIW valve the test stump and test TIW. 8) Fill Stack 4) Close Blind/Shear rams 5) Run test joint into BOP 6) Close annular and pressure test annular 7) Close pipe rams and test 8) Open Blind/Shear Rams, Close inner valves on Choke and Kill lines 9) Pressure test stack 10) Open inner valves on choke and kill lines and close outer choke line valve 11) Pressure test stack 12) Close the Blind /Shear rams and pressure test them from the lower side. Comments: BOP Test Procedure • • �a f 144 z , nw ,,,,,i- ` J 0 I II Q tA Z (9 —H I Q E 1_ O o ws -III ~ 9 O o a O 'D z sO D � � o O Z q ^ 0 O N IX v J O U W O O u ``W'i' � O O O J W ` .„ Z O # J N ' ~ r ' J Y U :1 ' w Q N c] (n �x% y CO O 0 ,O I C p p O O (.) # LLJ Q Q 0 Q a_ O W0 =nom Q H _ %iuPP D Q W . Z CD C a Z • Q UJ CD Lu 0 O U 0 z 0 Z O Q 0 ~ W ZN - W O n M 0 CC d' N Z cs(�ra O //��// Z �1A7 CLLI t Q — Z o O Nr Nr M I w _ _11_ _ _ • • • r • 11VV „ • w • �� .• vQ.C;-- k1 vJ s • C D ]7 =O z ar co m m c -' Z? 1 n CO 0 n K O 0Zm* /.\ Z _ -iO Cn 0 (n C 2 CH -I 33pa� mm 0zr— m z N N ZCOCn 37 - o —•Omv > Im N K - m Z T. - 0 � Z 2 ■ 0 m m I 'N, i ..- fz <TA eVO <m N N IQ it 3L MNII G NN � JJO NN N m mW -0 3700 Z7 3]00 DJ li (n Ori m I ,(� W r --1 mFD= O mo m Z 0 N o o OZ _< Oo Z 7 mm5 - — -11- C a 0 03 33 o a N D - m N m m m CO D 00"' ---I EOC miv m �O< mWv z O (71 1 O I N< 71• 0v NC OW� 17 Z Oct o,•- , 000 Ow m c 3] D3 r7J a'0 C° S 1-00 0 CJ J HO 2N° Z I m(n -' mF mcn z< L7 � cn amx D �� oDF m nJ - ma m " DD x ; / 1 I -. i u in1:� iuj '� =cncncnocnncn 09 ni , W __ D ------u - KK /7_ (I)37 -0131313171313131313 J. 073 0(d/CD ncncncncn(/)cncn J. J. �O 0°000000°00�OOOOOOZ OO * ZzzzzzZzz rriO = < n__ -- 111i10DO00000000nn DO*__ — _ i ��r�lI` m �� II1111JII13jimmmmmmmmm1rnii1" pj ° mm =•= -- 4k == CD__, i_i-A-A-A-Am-A1 r• *m mCnmmmmmmCnmm - r. cn cn_4cncncncncncn_Acncn ,^! yk H -I -1-1-1-i-1-1 -I-1 Co m — m i p W N N N N co), 4,0 S CO r 0 DocomN3rncnDaw X c cn z I r r- 41FMC Technologies 10/14/2015 Draft Recommendation to access well for Iko Bay Well #1. 1. OEM or qualified technician on site to determine the positioning of the FMC model 20 gate valve. Identify and verify size, pressure rating and, if possible, assembly part number for the valve. The identification tag for the FMC valves are generally found riveted onto the body. 2. Positioning of the gate valve is determined by removal of the stem protector and operating the stem independently. If the valve stem travels through its complete stroke and the stop nut contacts the carrier body, the valve is either operational or is in the closed position. 3. If the stem does not completely retract per the attached position document, the gate can be assumed to be in a partially or complete open position. This can be verified via the "A" dimension detailed in the picture labeled V-2 and the accompanying chart. 3- 9/16" from the carrier face to the rear of the stop nut is completely open. Additional information can be gathered from the "Turns to Close" Documentation as well. 4. If the gate is not closing independently, utilize the "Repairing Broken Stems" section of the FMC service manual, attempt to force the gate into the closed position. 5. Once the gate is in the "Closed" position, secure the hand wheel and stem. Access the Plastic Injection Port on the valve body and inject FMC approved valve sealant into the cavity. The plastic injection is designed to enfuse the downstream seat with plastic and facilitate a seal against the gate. 6. At this point, check for leakage via the observed leakpath. If there is no leak evident, slowly remove the bullplug from the upper threaded portion of the gate valve and add an additional gate valve to the tree assembly.. NOTE: No bleeder plug is evident in the bull plug, this renders this part of the procedure extremely dangerous. Proceed with caution and consider remote removal of the bull plug. 7. If the original gate valve is operational, open the valve and continue with well operations. At a proper place in the procedure, it is recommended that a full service be performed on the original gate valve. 8. If the original gate valve is not verified to be in the closed position, stop operations and consult with FMC engineering for remedial recommendations. These recommendations may include a hot tap operation to manually open the original gate valve, either through the well bore or into the rear of the valve body. These recommendations are drafts only and are designed to help develop a plan forward on this project. Additional information may change this draft at which time we would revisit these issues...Please call with any items we can be of assistance with. Kevin Hite Operations Manager FMC Technologies, Inc Anchorage Alaska 99518 907-563-3990 Office 907-529-0106 Mobile • • • • MON aseoa6Apog • Apug Bulids eUlaatias (Ajuc teas weansu*op) Nod uolpa(uI !looped alseid max, teas r .y lois-1 flopped wets aelea liaaq3 owe U EuI� ifulsLW 1.0183 tna Peng popped u�aolpel AWMI es" Supped sltsei� - > 6ul�es4 ls+udl - sbopeaqIII GSnr41 Mass uoltaa(ul kid uolAtl Mals pot Malss>iso1 6ui�iaulstoy 4,3;, Moxas aaWp Iaaq*QYeH iopatwd MILS a,4nssa zdYuz y torn zsd 000'8 Pup 000'0 SL leP°W Pun OL IePoW V. Adjusting Stop Nut ; '00,0 rP All Models " (/ WARNING:The stop nut adjustment is extremely important. ' '' ' a Improper adjustment will cause the gate to overdose or under- """"*'- j ,. •'' ""• ''"""' • close, allowing a leak path to develop.Follow the adjusting proce- dure exactly. '� ...', Tools required:Adjustable wrench,Allen wrenches,ruler in inches < To adjust stop nut: V-1 V-2 1. Open valve fully. Gate will hump the bonnet. 2. Remove stem protector(fig.V-1). 3. Use ruler to measure face-to-face distance between stop nut and , j (fig. carrier V-2). ��� � � x� 4. Refer to Stop Nut Adjustment Chart for correct distance for the valve you are working on. 5. If measured distance is not correct,loosen Allen-head lock a� screws on stop nut(fig.V-3). 6. Move stop nut to correct distance by turning it. CAUTION:Be sure stem does not rotate when you turn the stop nut. / 7. Use ruler to recheck distance. 8. Tighten Allen-head lock screws securely. V-3 With valve at Lull-open position, )..............„.\ set stop nut to"A"dimension. 1.-#71111111#i ,° I Stop Nut Adjustment Chart "A"DIMENSION—Working Pressure,psi Model 20 Model 30 Nominal Bore 2,000 Size, Size, and inches inches 3,000 5,000 10,000 15,000 10,000 15,000 1 1'/,e 1'h 1'/: — — — — 13/e 113/v 21/, 2'h 23/4 25h 21/: 29/4 2 2M 2'h 2V, 2'/, 23/4 2'h 23/4 2'h Me 3 3 3 31/e 3 31/e 3 3% 39/,e 3911. 33/4. 311/4 39/, 31h 4 41/. 45h 43/. 43/, — 43/4 5 5 5'/e 5t Ms 573he — — — — 6 61 611h 6"he — — — — 6 63/4 73/4 73/4 — — — — 6X7 714 71 the 71'As — — — .2c • • Table 11--Plastic Packing Chart TABLE III--Turns To Open Model20 and Model 30 All Models Plastic-Teflon packing for Model 20 and Model 30 valves may be Handwheel Revolutions(Full open to full close)--* '/z Revolution r '4 ordered using the following part numbers. Valve Working Pressure,psi Size,inches Nominal Bore Diameter Length Part Number Color Size, Size, 2,000 inches inches 3,000 5,000 10,000 15,000 20,000 5 a 3, 90-019-050 Purple 3/. 2 48-080-673 Purple 134 113/,e 121/2 121/2 121!2 133/. 18212 134 63/. 90-019-051 Purple 2 21/,e 122/2 121/2 121/2 133/. — 21/2 772 48-080-674 Purple 2 Vz 29/,. 15 15 15 162/. — 3 314, Model 75 311,1 173/, 173/. 173/. 191/. 31 In Model 75 valves, arctic sealant replaces the plastic-Teflon 4 4'12, packing. 4'b8 23 23 23 20 -- 5 51/e 29 283/. — — Size,inches 6 614 33V. 331/8 — -- Diameter Length Part Number Color 65/e 65/e 363/+ 3631. — — — sl,e 4 90-419-083 Gray 7 71/e 381/. 38'/. — — — 3r. 2 90-419-084 Gray 138 63/. 90-419-082 Gray 21/2 71/2 90-419-081 Gray 10 lb can — 90-419-080 Gray Table IV—Trim Materials Model 20 and Model 30 ' When repairing any FMC gate valve, replace worn or used parts WARNING:Failure to trim properly during repair can result in with new parts of identical material, premature valve failure.Do not substitute parts or materials without the approval of Wellhead Equipment Division,Valve Engineering Refer to the following chart for proper trim data. Dept., Houston,Texas. Trim data for FMC gate valves Model 20 and Model 30 Valve body 2,3,5 Alloy steel castings Alloy 410 S.S. Alloy 410 SS. 10 — Steel 410 S.S Steel 410 SS. 15 — Castings 410 S.S. Castings 410 S S 20 — Forgings 410 S.S. Forgings 410 S.S. Bonnet& 2,3,5 Rolled steel Rolled steel 410 S S Rolled Steel 410 S.S. bal.plug 10 — Roiled sleet 410 S.S. Moly coated Rolled steel 410 S.S. Moly coated body 15 — Rolled steel 410 S.S Rolled steel 410 S S. 20 — Rolled steel 410 S.S. Rolled steel 410 S.S. Stem& 2,3,5 4140 steel moly coated 410 S.S. 410 S.S. 410 S.S. 410 S.S. bal stem 10 — 410 S.S. Moly coated 410 S.S. Moly coated K-Monet Moly coated K-Monet Moly coated 15 — 410 S.S. threads 410 S.S. threads K-Monet threads K-Monet threads 20 — 410 S.S. 410 S.S. K-Monet K-Monet Seats 2,3,5 4140 steel moly coated 410 S.S. 410 S.S 410 S.S. 410 S.S. 10 — 410 S.S.Hardsurtace 410 S.S.Hardsudace 410 S.S.Hardsurface 410 S S.Hardsurtace 15 --- 410 S.S.Hardsurface 410 S.S.Hardsurface 410 S.S Hardsurface 410 S.S.Hardsurface 20 — 410 S.S.Hardsurface 410 S.S.Hardsurface 410 S.S.Hardsurface 410 S.S.Hardsurface Gate 2,3,5 Forged steel nickel plated 410 S.S Moly coated 410 S.S.Moly coated K-Monet K-Monet 10 -- 410 SS.Hardsurface 410 S.S.Hardsurface 410 5.S.Hardsurface 410 S.S.Hardsurface 15 — 410 S S Hardsurface 410 S.S.Hardsurface 410 S.S.Hardsurface 410 S.S.Hardsurface 20 — 410 S.S.Hardsurface 410 S.S.Hardsurface 410 S.S.Hardsurface 410 S.S.Hardsurface Stem 2,3,5 Buna-N,duck,hycar,etc. Buna-N,duck,Teflon',etc Buna-N,duck,Teflon',etc Buna-N,duck,Teflon',etc. Buna-N,duck,Teflon',etc packing w/plastic injection wlpiastic injection w/plastic injection w/plastic injection w/plastic injection 10 — Tetton/Hycar Tetton/Hycar Teflon/Atlas Tetion/Aflas 15 — Teflon/Hycar Tefion/Hycar Tetelon/Alfas Teflon/Aflas i 20 — Teflon/Hycar Tetlon/Hycar Tefelon/Atlas Teflon/Atlas (1) Controlled hardness is 238 max.B H N.on steel and stainless steel,302 max B.H.N.on K-Monet. (2) Waterflood is Trim"S"except coated internally wietectroless nickel. (3) Meets N.A C.E.requirements for H1S service. 'Teflon impregnated Buna-N,cotton and nylon fabric tTefton is a du Pont trademark Trim for Model 75 valves is similar but material,packing and elastomers for cold temperature replace the standard parts III 1111 FLOWSERVE Nordstrom Valves Steel Lubricated Plug Valves FCD NVENBR1004-02—01/11 Dynamic Balance Plug Valves . 0 0 Principal Features r 0 • Turns easily every time,shuts off with 0 the proven dependability of a plug valve and eliminates the problems 0 X\\ generally associated with conventional plug valves. ``` • As shown in the photograph,balance 0 holes at the top and bottom of the plug maintain equal pressure above and below the plug and in the plug port so that line pressure cannot jam the plug into the body taper.A stainless steel spring pre-loads the plug to prevent vibration and thermal cycling from wedging the plug in the taper. Loading the top of the plug in this way also compensates for the weight of the plug when the valve is installed upside down. • The Dynamic Balance design provides durable,metal-to-metal seats and a 1. Stem Head—is obround with two 5. Plug—is coated with permanently sealant system for bubble-tight shutoff wrench flats that align the wrench in bonded,low-friction coating. on hard-to-hold fluids and restoration the direction of the port opening,thus of damaged seats. becoming an easily visible position in- 6. Bottom Balance Hole(not shown) dicator.Square adapters are available —is an integral part of the Dynamic • The Dynamic Balance design also to allow operational flexibility where Balance system which maintains pres- offers the Protected Pressure Balanc- space is limited. sure equalization between the plug ing feature for increased reliability in port and the bottom of the plug. service where there is a possibility of 2. Stem—treated with low-friction PTFE foreign particles in the media.This de- coating to reduce overall valve torque. 7. Balance Hole with Ball Check(not sign ensures that the balancing holes Wrench-operated valve stems are shown)—ensures that pressure above are not exposed to the line media in made of 400 series stainless steel the plug is the same as or greater than the plug port,providing added security for corrosion protection(i.e.,tough in the plug port. compared with normal pressure bal- offshore applications). 8. Sealant Injection Fitting—permits ancing. 3. Stem Packing—specially designed restoration of damaged seats and • Standard carbon steel API-6D and by Flowserve Nordstrom Valves, drop-tight shutoff on hard-to-hold B16.34 valves are suitable for general manufactured from a combination of fluids. service at temperatures from-20°F to graphite and TFE,the stem packing +450°F Weatherseal—two different types are +450°F(-29°C to+232°C). is pressure-energized(no external found in Dynamic Balance valves.The • Sealant systems are incorporated adjustments necessary)and is inert to stem weatherseal is specially shaped in metal-seated plug valves as an a wide range of fluids and gases. and constructed to protect the stem integral part of the valve,and sealant 4. Plug-Balancing Spring—is designed and packing from hostile environ- is required to ensure proper valve to preload the plug to prevent vibra- ments that can lead to corrosion.The performance. 6 tion and thermal cycling from wedging cover weatherseal is an elastomeric the plug into the taper regardless of ring compressed between the body • Dynamic Balance plug valves with installed position. and cover to protect cover bolts from their metal-to-metal seats have been corrosion. fire-tested in conformance with API Standards 607 and 6FA. • • .....1 FLOWSERVE Nordstrom Valves Steel Lubricated Plug Valves FCD NVENBR1004-02—01/11 `.... Dynamic Balance Plug Valves Regular Pattern - K J ASME Class 900 (PN 150) If:I_TL Figure 2344,Sizes 2 to 4 E O O (not shown) OO Figure 2345,Sizes 3&4 only r� Figure 23451:,Sizes 3&4 only U o ® O (not shown) F Figure 2345%,Size 3&4 only ,.O 0,r (not shown) A&8 1.—M—.. Figure 2345,Sizes 3 and 4 ASME Class 900 — Figure 2344, 2345, 23451/2, 23451/4 21.50' Endo-end,welding ends,Figure 2345% A 470 546 Face-to-face,flanged(raised face) 15.00 18.00 (incl.1"raised face),Figure 2345 B 381 457 15.12 18.12 End-to-end,flanged(ring Joint) - 384 460 18.50' 21.50' End-to-end,flanged by weld end,Figure 2345%. 470 546 7.75 10.04 11.47 End-to-end,threaded ends,Figure 2344 19/ 255 291 Diameter of flange C 9.50 11.50 241 292 6.6 7.6 8.9 Center to top of stem E 168 193 226 4.2 5.0 5.8 Center to bottom of body F 107 127 147 Width of stem flats J 0'81 1.00 125 21 25 32 1.09 t41 1.78 Diameter of stem K 28 36 45 1.0 1.1 1.4 Height of stein flats L 25 28 36 4.7 6.2 8.7 Extreme width of body M _ 119 157 221 Wrench size - DB-2 DB-3 DB-4 Weight(approx.),Figure 2344 43 104 152 20 47 69 Weight(approx.),Figure 2345 146 240 66 109 Weight(approx.),Figure 2345% 111 154 50 70 Weight(approx.),Figure 2345% 128 197 58 89 'Conforms to API 6D,Section 6.3 and is marked accordingly. 30 • • ALASKA LEGACY WELL Iko Bay Well#1 71.4556°N, 154.3328°W NOT TO SCALE Wellhead has broken gate valve and is leaking KB 12' 1 ` • Well was tested then left in current condition. 4,-.-, Well was reported to have kicked with 11.4 ppg mud in hole. Ir _ I� Ground level ��� 1 • 1 1 joint 24"Conducter set @18' 149' I 16"75# N-80 set @149' Cemented w/660 sxs . < Fluid weight in tubing and on backside not known. 1190' i 10-3/4"51#P-110 casing set @ 1190' Cemented w/810 sxs , 1212' 4 Liner Hanger set @1212' 1270' 7"23#1-55 casing set @1270' Cemented w/360 sxs,1"50 sxs to surface cap.>>>.2210cuft/ft .0393 bbl/ft Slotted Liner Perforations 1242-1274 1 1307-1370 1469-1536 1562-1648 1732-1775 1905-1950 1 1J J 1939' 61 joints,2-7/8 6.5#Hydrill CS Tubing set @ 1939' 1950' 5-1/2"20#J-55 Slotted Liner set @ 1950' PB 2035' , cap.>>>.1245cuft/ft .0221 bbl/ft 120 sxs cementlu p g tagged @2035' 2731'TD WELLBORE CLEANUP TOOLS MI SWACy/ Wellbore Productivity --- ..� — M-I L.L.C.A Schlumberger Company Customer focused,solutions-driven 6411 A Street,Anchorage Alaska,99518;Tel:907-273-1700 PREPARED FOR Lucas Munisteri PREPARED BY Michael Brzezinski(281)507-7220 C.L.gP COPIES TO R. Figueroa,K.Haag c+y�-�",,,,� CLASSIFIED AS M-I SWACO-SolstenXP 5jS -" ' • DATE January 5,2016 fro r I `O j LOCATION Alaska EXECUTIVE SUMMARY Lucas Munisteri, SolstenXP, has requested product information and mixing /breaking instructions for three upcoming abandonment wells in a remote area outside of Barrow,Alaska.Two of the wells propose minimal risk based on the data received from SolstenXP and will likely be permanently abandoned with cement plugs from surface to+/-250'.The third well,has the potential to be more complex in that it was a producer and exhibited pore pressures that would require an equivalent mud weight of 11.4 ppg to control.This well also has production tubing in place that will likely not be able to be pulled,or circulated through. M-I SWACO has been asked to provide chemical and mixing instructions to SolstenXP to permanently abandon these wells according to their own design. • Chemicals to be provided include: CaC12(Calcium Chloride) FLOVIS Plus Barite Myacide GA25/Busan 1060 ECF-2396 SAFE-BREAK L Caustic Soda Citric Acid • r • WELLBORE CLEANUP TOOLS Mi SWA O Wellbore Productivity M-I L.L.C.A Schlumberger Company Customer focused,solutions-driven TECHNICAL RESPONSE As salt is dissolved in water, it lowers the freezing point of the solution until the eutectic point is reach. The eutectic temperature represents the lowest temperature on the saltwater phase diagram. Increasing the salt concentration beyond the eutectic raises the crystallization point. The concentration at which the solution is saturated is a function of its temperature.This crystallization point is the primary reason salt is required for this fluid.The eutectic point for Calcium Chloride brine occurs at 10.8 ppg and-51°F. For the two simple wells,the fluid density should be maintained between 10.0 ppg and 11.1 ppg to maintain the TCT less than-7°F which will help prevent freezing or crystallization of the fluid in the tanks and lines. For the more difficult well,an 11.4 ppg fluid may be required for well control.To minimize the amount of solids and disposal costs, Calcium Chloride salt is recommended for several reasons. First, Calcium Chloride can achieve densities of up to 11.1 ppg with a-10°F crystallization point. Second,soluble Calcium Chloride salt will minimize the amount of barite that will be needed to increase density,if required.Third,Calcium Choride reacts exothermically,it generates its own heat,with water. This will save you significant time during your "melting" operations and heat/steam costs.Fourth,a higher density fluid can be built that can take in any melted water and still give you the TCT range that is optimum to reduce the chances of crystallization. Finally, Calcium Chloride will also significantly reduce your tank cleaning and injection costs. There will be less solids/sludge in the tank bottoms that will have to be liquefied and require confined space entry to shovel out. To build a fluid with density greater than 11.1 ppg, planning and technique will be required. An appropriate amount of water will need to be added to the pits(depends on pit size),one-half to three-quarters of the required • Calcium Chloride should be added to the water.Doing this will generate a significant amount of heat,the fluid should be allowed to cool to -150°F and 1 lb/bbl FLOVIS PLUS should be added(number of bbls is based on planned final volume mixed,volume will increase with salt additions). If the fluid is not allowed to cool to less than-150°F the polymer may be denatured and rendered ineffective with the high temperatures. Once all of the polymer has been added,the rest of the Calcium Chloride should be added at a rate such that the circulating fluid temperature does not exceed 175°F. You now have your water, FLOVIS Plus polymer and Calcium Chloride in an 11.1 ppg viscous fluid.Barite will need to be added to increase the density the remaining 0.3 ppg,or as needed for well control. As Calcium Chloride and FLOVIS Plus are mixed,there will be some foaming. ECF-2396 defoamer will need to } be utilized to control any foaming issues. Polymer based fluids are subject to bacterial degradation.For this reason,bactericides must be added to the fluid system.Myacide GA25 and/or Busan 1060 bactericides will be provided to be maintained in the system. A breaker for the viscous fluid may be required after the complex well is completed. For this purpose, SAFE- BREAK L and Caustic Soda will be provided. SAFE-BREAK L is a dry lithium based bleach which will oxidize the polymer causing it to denature or break and allowing any solids in the fluid to settle out. SAFE-BREAK L is utilized at concentrations of 3-4 lb/bbl.This breaker may need to be supplemented with 0.2 lb/bbl increments of Caustic Soda to minimize the time required to completely break the system. If the SAFE-BREAK L and/or Caustic Soda are utilized,the pH of the remaining liquid will need to be reduced back to the 9.0 to 10.5 range with citric acid before it is reused.This is the ideal range for the bactericides to work • efficiently. ©2010 M-I All rights reserved.*Mark of M-I«.. .0907.R2(E) This information is supplied solely for informational purposes and M-1 SWACO makes no CMC.2300 guarantees or warranties,either expressed or implied,with respect to the accuracy and use of this data.All product warranties and guarantees shall be governed by the Standard Terms of Sale.Nothing in this document is legal advice or is a substitute for competent legal advice. 4110 . • 0 Schlumberger 0 Laboratory Cement Test Report 12.5 Solsten XP Plug Pilot- DRAFT EXTERNAL Signatures Fluid No : PAK 16plg1006 Client : Solsten XP Location/Rig : N/A Date :Jan-25-2016 Well Name X Field : Umiat Daniel Himel Job Type 9 5/8" Depth 500.0 ft TVD 500.0 ft BHST 50 degF BHCT 65 degF BHP 500 psi Starting Temp. 90 degF Time to Temp 00:20 hr:mn Heating Rate -0.31 degF/min Starting Pressure 200 psi Time to Pressure 00:20 hr:mn Schedule () Composition Slurry Density 12.50 lb/gal Yield 2.04 ft3/sk Mix Fluid 10.085 gal/sk Solid Vol. Fraction 33.787% Porosity 66.213% Slurry type Other Code Concentration Sack Reference Component Blend Density Lot Number 12.5 ppg Sols 108.6 lb of BLEND Blend 148.73 lb/ft3 D124 0.85 XP Blend Fresh water 9.824 gal/sk Base Fluid Rheology Tem.erature 80 de.F 65 de.F (rpm) Up Down Average Up Down Average (deg) (deg) (deg) (deg) (deg) (deg) 300 8.0 8.0 8.0 96.0 96.0 96.0 200 6.0 7.0 6.5 86.0 83.0 84.5 100 4.0 5.0 4.5 75.0 67.0 71.0 60 3.0 4.0 3.5 64.0 58.0 61.0 30 2.0 4.0 3.0 46.0 43.0 44.5 6 2.0 3.0 2.5 16.0 19.0 17.5 S 3 2.0 2.0 2.0 11.0 12.0 11.5 10 sec Gel 6 deg-7.13 lbf/100ft2 19 deg-22.57 Ibf/100ft2 10 min Gel 33 deg-39.19 Ibf/100ft2 I 19 deg -22.57 Ibf/100ft2 Rheo.computed I Viscosity: 12.770 cP Yield Point:2.56 Ibf/100ft2 I Viscosity: 94.107 cP Yield Point:56.89 Ibf/100ft2 Thickenin. Time Consistency Time 30 Bc 04:10 hr:mn 50 Bc 10:04 hr:mn 70 Bc 12:16 hr:mn 100 Bc 15:47 hr:mn Free Fluid 1.2 mL/250mL in 2 hrs At 80 degF and 0 deg incl Sedimentation : None Note: This is a pilot test. Field blend may differ after testing. Please read field blend report carefully and compare to pilot report and load out. Contact the laboratory with any questions or concerns. • Page 1 • 0 • • WELLBORE CLEANUP TOOLS MI SWACO Wellbore Productivity M-I L.L.C.A Schlumberger Company Customer focused,solutions-driven Field Formulations FLUID TYPE AND 50 BBLS 11.1 PPG 50 BBLS 11.4 PPG WATER ADDITIONS PRODUCTS CACL2 BRINE CACLZ WBM WITH-10°F TCT wim-10°F TCT _ WATER 43.4 bbls 42.5 bbls 1 bbl CALCIUM CHLORIDE 8,150 lbs 8,000 lbs 180 lbs FLoVis PLus 49 lbs BARITE --- 900 lbs ECF-2396 As Needed for Foam As Needed for Foam As Needed for Foam MYACIDE GA25 OR 1 gallon 1 gallon 0.02 gallon BUSAN 1060 Discussion I estimate 300 bbl minimum requirement for the 3 wells at this concentration. A request by SolstenXP for 100% contingency anticipated barite will be formulated into the commercial estimate.The 300 bbl estimate does not include any safety factors.Please let us know what kind of contingency safety factor you would like included in the commercial proposal. Commercial Proposal Commercial Proposal update to follow. S ©2010 M-1 Lc.All rights reserved.*Mark of M-1 LLC This information is supplied solelyfor informational CMC.2300.0907.R2(E) PP purposes and M-1 SWACO makes no guarantees or warranties,either expressed or implied,with respect to the accuracy and use of this data.All product warranties and guarantees shall be governed by the Standard Terms of Sale.Nothing in this document is legal advice or is a substitute for competent legal advice. • WELLBORE CLEANUP TOOLS Mi SWAC_� Wellbore Productivity M-I L.L.C.A Schlumberger Company Customer focused,solutions-driven • This page intentionally left blank. • 41/1 ©2010 M-1 All rights reserved.*Mark of M-1 Lc. This information is supplied solely for informational purposes and M-I SWACO makes no CMC.2300.0907.R2(E) guarantees or warranties,either expressed or implied,with respect to the accuracy and use of this data.All product warranties and guarantees shall be governed by the Standard Terms 11110 of Sale.Nothing in this document is legal advice or is a substitute for competent legal advice. J . E. ' 1!./ 0 Off....di _.,..7„..,..,; 4111 1:;'4 44. "Pr= Memairport , 011111P1 numell ', ta,li 4:: !:1 ----. II. ""'' 4#0, II BO�f?. AR1A4Uia AIRfs ?Dot ' ,. I) " � � A r ' 4' iTA, 20' 37.5''' 1 4. ' a r } 0 2 -.--\\ II /..... ,� 11:1 1:: \1:T1MNEN •'� j 12• 1?TI 1:1 1 e' ;.r! „ aulDfeAD fAUHF,w +,-e FT.HE,BH1 - - _ \ /� .../.0 Ff.mew YA:LL by i3 Ff.IIsi a `� o IN + — t1) co co crl cn5500 gal MIMI MINIM Wi 0 -- -1--IA- _ _ 1 EQUIPMENT LAYOUT FOR I I _____ i 1 IKO BAY WELL REMEDIATION L rl 1 : 20' I i 4' 1 PARTS CONEX (8'x 20) y- —.- 0 TOOL CONEX (8'x 20') i L.._._J I I O ISO TANKS (8'x 20') O ISO TANKS (8'x 20) I I OCEMENT UNIT (8'x 35.5') TOP aEVArN OF PAO - I 95 5' © BOILER (8'x 20') fl 1:11:1 t % Q BOP 1}� --4.-jJ % ® RETURN TANK (3'x 6') t r / 0 SCAFFOLDING 1 ! / / 10 CHOKE MANIFOLD (4'x 4') 11 RAMP AT t! l 1:6 SLOPE 11 DIVERTER TANK (3'x 6) 1 41/ 90. 1j?. GENERATOR (4'x 6) j lkf;% 13 HEATER j ooi w j % 14 HEATER 1 J% O HEATER 1 Ii 1 jj 16 LIGHT PLANT I QF RAW 117 ACCUMULATOR (8'x 20') TOE 24' ___.8,_____ 18 COMPRESSOR (5'x 9') • PADh70NA610N @F l 25 15 5 25 f Feet 20 10 0 SCALE I PrC1 IWork Site Layoutfor I • Orn Raw I anar.v Wall • , • 111 1411‘ • - •••• -"" „4( 4,‘ .41111 6 ., • • Oko Bay#1 _PTD 100-036 Conditions of approval: 1. BOPE to be tested to 1500 psi (MASP=950 psi ) 2. Contingency Plan#1 as proposed is not approved. Verbal approval is required to proceed with this alternative. 3. Daily workover report summary to be submitted to AOGCC by email. (to: Mike Quick/Guy Schwartz) 4. 9.6 ppg NaC1 brine is approved for BOPE testing(non-compressible fluid) Variance Requests: Alternate BOPE equipment layout as proposed in Sundry application is approved per 20 AAC 25.285(h). Alternate gas detection equipment using handheld sensors is approved per 20 AAC 25.066 (d)(3). The physical configuration of the rig reduces the likelihood of accumulation of methane gases. H2S gas is not present in the reservoir. 1...4 .,..• ...., , 4. a , off':-,- ... r - .; , *IF . . .. ,...., ,...:;:.... ,,,, .. .„„ , .„,. . ,, 4 ,. ... , -.: I , - ' . • ::,,,, 1•,". 1p%1 . ,"!N° ,,, it lit \ t, „., . _ .,. ,.......: ._ , ,... , ..... , , . I. 40 vior , .. . . , . 4 ' 411>I11.11111111° 440r lik. .- '''" • 41110114 Asir ,.,. \ . • , . ' - • .,4 4b \ , \ . •-,, 4 . . N . . t ,r, P :, 0 i/. v 7 'f ,. CO 1 I o M (:.-1 p J /'" 4 H N J Ie •... N fti � j t m ° 1 " Oj N - ? 8 Q„J m V w Y T W jic y U 1 r z CC I y < 0 0 6 a A o w Ci - - o 2 p < EC D CR a g4 a' Z r Z N O 0 Q vl CO N CC A .d O O < W Z L p t Oto CL p j Q LL < tt I– .. 2 Z z cJ Y = co ! ie • , O H z Z N N >nE 3 J ._ i,4 _ 1- U) N o -- r t ._- 2 U ; C N Y Z C7 QHz 'F, - - O a) 1c' H >Q O 1 m M - J Q ki bE • cc Lo o W 6) Cn (n pi l _ —j : r ,. meg ° � `n Q Q O a sE t � Cr > O O _ F (,e � �� U 01 CO Z 9 I 4« - i _ 0m Z f ..d• e s .7' ' i , - -, .- 1 t ' c 1 - - . , ct �.. t tco a .\ ., 4s .' ,' if, 4- i 'fir` ' �- ,- _. 5 :':' ".‘,.. y _ o _. _ `. ..- IA. J2 g m ' •ter S v-TC — _ •E ‘1S• a• W z. Ja "F Lu �0t ;0^ O O o 0 • z Z �& �0 �-- y a• z CO o `' ' K Q W W N 3 Q O U Q K N Li u_ 01 . • LA Q U >" 0 v+ •i O N 00 co 00 c-.1 `'i 00 H Lri to to C. _ O LT ri C(1-19 L.70— L CL Z 2 ao u1 O1 N LO i0 Q N N LO Ln H_a c 4 o 'Cr c�.1 .`r'1 v c ro Z m o NCNI Th 2 v N o0 0 a ao in it) uO Q 1 in c A mm LD M N 0 m N O1 N Ln O O1 e-.1 4 Ol ri N m a1 ri %--i (-4 Z Z LA N N N Lv r-i O r-I Ln 'a 01 u1 O 01 3 ri r I r-I O :I'. 0 0 0 0 r-1 ri e-I ri C\ N N N C -1 ZZZZ 0 CO c U 0 O = = = = J a. a 0) a aJ 7 'U X333 ll CU ai a; - CD CU 0 0 a a a a L _O U U U U N > 3 .O w C N a. O N •V NO a O 00 as ' co cLo cLa o c c c c `n llO LnitCO MO N W d J Ln N a N CO Q c O O Ln Oi if; V m O Gl r N r-I N C7 W Q W Q 2 m m _ O U Q O N La 01 NCN J J W Z• O d' N N Ln _rn = 00 N r-1 O LA 00 O 2 Ll i • 4. in COO 000 CO000 Ln a to m to Q .-i ,-is r-i r-i a c ri W CJ O O Q 4 +, ' U 'cr, 0 a m N 0 L.O 0cis 1 + =m ifsl X _ Ol Cr) c Q w 4 00 01 O Z a U 0o N X ,= m W ri Cf) Ln Ln 0 E 0� O_ M Z C� M M 0 O 0= ri O O N 0 Q O . O1 r-I 00 O _ 0: U s-i Ln a Z a N M oM N N "a a i_ 41 4 an r-I - Za � cc T — a m Le LD L,� LD m >. Ln E a c Q YO >, c so a 0A ( �` O Q m L U ll1 a O CLO M a -p +, N -0 O . inO c r_ O Ln Q N0 NI _ v tt 4# r +a+ +' E Ln "a j il 7 m CO 0 O +., Y m CO m a Q &i O a 41 >.co t UinQ00t C 3 ' Uw Qj ~ Q 30 0 a N n U + - a N +� c 4 .�.+ C 0 C11 as oo • • AOGCC Coordinate Conversion for BLM 23 October 2017 INPUT OUTPUT Geographic,NAD83 State Plane,NAD27 5006-Alaska 6,U.S.Feet Accuracies of conversions from NAD 83 to NAD 27 are typically 12 to 18 cm. Iko 1 1/1 Latitude: 71 10 17.17993 Northing/Y: 6281672.405 Longitude: 156 10 26.27656 Easting/X: 716246.288 Convergence: 1 43 53.95464 Scale Factor: 0.999953114 Datum Shift(m.): Delta Lat.=45.815,Delta Lon=-124.419 Remark: Corpscon v6.0.1,U.S.Army Corps of Engineers • AOGCC Coordinate Conversion for BLM 23 October 2017 INPUT OUTPUT Geographic,NAD83 Geographic,NAD27 Accuracies of conversions from NAD 83 to NAD 27 are typically 12 to 18 cm. Iko 1 1/1 Latitude: 71 10 17.17993 Latitude: 71.171849485 Longitude: 156 10 26.27656 Longitude: 156.170512981 Datum Shift(m.): Delta Lat.=45.815,Delta Lon=-124.419 Remark: Corpscon v6.0.1,U.S.Army Corps of Engineers • . Davies, Stephen F (DOA) From: Chmielowski, Jessie <jchmielowski©blm.gov> Sent: Tuesday, October 17, 2017 3:50 PM To: Davies, Stephen F (DOA) Cc: Link, Liz M (DOA) Subject: Re: FW:Well Completion Reports for S. Barrow Test#3,Avak#1, Barrow Core Rig Test# 2 Attachments: 30025.15_Barrow Wells.pdf Steve, Thank you very much for offering to convert the coordinates. I just received the NAD83 coordinates for the 2017 Legacy Wells from the contractor which I have attached as a PDF. For the 2018 wells, I already have the coordinates in NAD27 format. Jessie On Thu, Oct 5, 2017 at 10:44 AM, Davies, Stephen F (DOA) <steve.davies@alaska.gov>wrote: Jessie, Please provide surveyor's plats, or correct lat/long coordinates (with the geodetic reference datum),for Barrow Core Rig Test#2 (PTD 100-020), S. Barrow Test#3 (PTD 100-025), and Avak#1 (PTD 100-027), and I will calculate the State Base Plane NAD 27 coordinates for the AOGCC Well Completion Reports. Thanks for your help, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 1 • • From: Chmielowski,Jessie [mailto:jchmielowski@blm.gov] Sent: Wednesday, September 20, 2017 11:52 AM To:AOGCC Reporting (DOA sponsored) <aogcc.reportingPalaska.gov> Subject: Re: Well Completion Reports for S. Barrow Test#3,Avak#1, Barrow Core Rig Test#2 Hi Liz, Several months ago I tried to use the online coordinate converter(from the site recommended by AOGCC), but the file on the website was corrupted. I am unable to install the coordinate converter software onto my computer due to government rules. Since similar 407's have been accepted by AOGCC in the past, I didn't pursue it further. Thanks,Jessie On Wed, Sep 20, 2017 at 10:02 AM, AOGCC Reporting (DOA sponsored)<aogcc.reporting@alaska.gov>wrote: Hello Jesse, I wanted to follow up and find out if you were able to obtain the correct format for the location data of the wells listed below. Thanks in advance, Liz Link Statistical Technician II Alaska Oil and Gas Conservation Commission(AOGCC) 907.793.1241 2 • • liz.link@,alaska.gov From: Link, Liz M (DOA) Sent:Wednesday,June 28, 2017 10:19 AM To: 'jchmielowski@blm.gov' <jchmielowski@blm.gov> Cc:AOGCC Reporting (DOA sponsored) <aogcc.reporting@alaska.gov> Subject:Well Completion Reports for S. Barrow Test#3, Avak#1, Barrow Core Rig Test#2 Hello Jesse, I was hoping you could resubmit the front page of the Well Completion Reports (10-407's)with the location data (boxes 4a and 4b) in the correct format (PLSS for 4a; State Base Plane Coordinates NAD 27 for 4b) for the following wells: • S. Barrow Test#3 (PTD 100-025) • Avak#1 (PTD 100-027) • Barrow Core Rig Test#2 (PTD 100-020) Email is an adequate means to transmit the revised front pages. Please let me know if you have any questions. Thanks in advance, Liz Link Statistical Technician II Alaska Oil and Gas Conservation Commission(AOGCC) 907.793.1241 liz.linkAalaska.gov 3 �� �� �� Jessie Chmielowski, P.E. SrPetroleum Engineer Bureau of Land Management 222 W. 7th Ave., #13 Anchorage, AK8Q513 Office (907) 271-4190 CeU (QO7) 23O'Q82S Jessie Chmielowski, P.E. Sc Petroleum Engineer Bureau of Land Management 222VV. 7th Ave, #13 Anchorage, AK 99513 Office (907) 271-4190 Cell (907) 230-9826 4 o>r r • THE STATE Department of Environmental 011-1LASKL'1 GOVERNOR SEAN PARNELL RECEIVED FEB 0 7 2014 February 4, 2014 A0GCC Certified Mail, Return Receipt Requested Article No.: 7012 2210 0002 1216 2391 Wayne Svejnoha BLM — Division of Resources 222 W 7th Ave, #13 Anchorage, Alaska 99513 Conservation Division of Spill Prevention and Response Contaminated Sites Program File: 320.38.010 SCANNED 0 2 2014 Re: Potentiall Responsible Party Notice Letter and Information Request NPRA Legacy Wells - General Hazard ID: 26125 Ledger Code: 14339387 Dear Mr. Svejnoha: 610 University Ave. Fairbanks, Alaska 99709-3643 Main: 907.451.2181 Fax: 907.451.5105 This letter is to advise you that the Alaska Department of Environmental Conservation (ADEC) has identified the 136 legacy wells within the National Petroleum Reserve in Alaska (NPRA) as potential contaminated sites. Some of these wells require extensive cleanup of oil and other hazardous substances released to the environment. Since you are identified as a current or past owner and/or operator of these sites, please be advised you may be financially responsible or liable for the investigation and /or cleanup of any hazardous substance contamination that might be present. Alaska Statute 46.03.822 establishes who is liable for contamination. Records available to the ADEC indicate that you meet one or more of the following criteria: » owned or controlled the hazardous substance at the time of its release; » own(ed) or operate(d) the property or facility from which the release occurred; » owned or operated property at which the hazardous substance came to be located; and » arranged for transport, disposal or treatment of hazardous substances that were released. Site History From 1944 through 1982 the US Government drilled 136 wells to explore for oil and gas resources in the NPRA. It is our understanding that other federal agencies and some private companies may have operated or managed these sites in the past. We have also been informed that 23 of these well have been conveyed to public and private entities. The ADEC currently lists 14 of the 136 legacy wells on our database of contaminated sites. The Bureau of Land Management (BLM) is identified as the responsible party for the following sites. Wayne Svejnoha 0 2 February 4, 2014 • BLM Cape Halkett Drill Site (File # 300.38.108) • BLM East Simpson #2 (File # 300.38.109) • BLM East Teshekpuk Drill Site (File # 300.38.110) The U.S. Army Corps of Engineers, under the Formerly Used Defense Sites program, is working with ADEC under the Defense States Memorandum of Agreement on cleanup actions at the 11 Umiat test well sites. BLM is identified as the landowner in our records, and as such is identified as a potentially responsible party in addition to the Department of Defense: C Umiat Test Wells 1-11 (File # 335.38.001) The information contained in these files is part of the public record. Our databases are accessible on the Internet at: http://dec.alaska.gov/spar/csp/db_search.httn Additional Actions Needed ADEC sent a letter on July 11, 2013, identifying an additional 15 legacy well sites with confirmed releases (enclosed). As stated in the letter, ADEC recommends that BLM develop a plan to address known, suspected, and unknown releases at the legacy well sites, in coordination with the appropriate regulatory agencies. We expected a response to this letter before now. Please respond to this letter within 30 days. After we receive and review your response we will determine what additional actions will be taken regarding each site with known or suspected contamination. In addition, with your response, please complete and return the enclosed questionnaire requesting more information about past operators. In accordance with Alaska Statute Title 46, ADEC is authorized to provide regulatory oversight for any contamination response efforts initiated by the responsible party. However, if response actions by the responsible party are not satisfactory to ADEC, we may then assume the lead role in the investigation and cleanup efforts. In the event that State response actions are necessary, the responsible parties may be held financially liable for any response actions taken by the State. Alaska Statutes 46.04.010 and 46.08.070 establish cost recovery procedures for certain costs, including oversight activities, incurred by the State in responding to pollution incidents. If you are determined to be a responsible or liable party, ADEC may bill you at a later date for our expenditures associated with this pollution incident. Expenses for which we may seek reimbursement include: Staff time associated with general or technical assistance; work plan review; project oversight; general project management; legal services; interest; travel; equipment and supplies; and any contracting costs. Pursuant to Alaska Statute 46.08.075, the State may also file liens against all property owned by a person who is responsible or liable for State expenditures. Please respond in writing within thirty (30) days from the date of this letter addressing your intended actions with respect to this pollution incident. If you believe someone else is responsible for this pollution incident (e.g., a past owner or operation of the site) or if you have any questions concerning this matter, please contact Mr. Fred Vreeman at (907) 451-2181. The attached "ADEC Information Request" describes the minimum information expected in your response. Additional information may needed to evaluate the risks and responses required at each legacy well site. Sincerely, Fred Vreeman Environmental Program Manager G:\SPAR\CS\Contaminated Site Files (38)\320 National Petro Reserve Area\320.38.010 NPRA Legacy Wells General\2-2-2014 Letter\PRP Letter All Wells.docx Wayne Sveinoha Enclosure: 0 3 • ADEC Information Request Concerning Contaminated Sites BLM Legacy Wells Dispute letter date July 11, 2013 February 4, 2014 cc: Bud Cribley, Director, Bureau of Land Management Steven Cohn, Deputy Director, Bureau of Land Management Jolie Pollet, Branch Chief, Bureau of Land Management Robert Brumbaugh, Geologist, Bureau of Land Management Michael McCrum, Environmental Engineer, Bureau of Land Management Larry Hartig, Commissioner, Alaska Department of Environmental Conservation Lynn Kent, Deputy Commissioner, Alaska Department of Environmental Conservation Kristen Ryan, Director, Alaska Department of Environmental Conservation Lori Aldrich, Program Manager, Alaska Department of Environmental Conservation Steve Bainbridge, Program Manager, Alaska Department of Environmental Conservation Jennifer Roberts, Program Manager, Alaska Department of Environmental Conservation ADEC Response Fund Administration GASPAR\CS\Contarr nmted Site Files (38)\320 National Petro Reserve Area\320.38.010 NPRA Legacy Wells General\2-2-2014 Letter\PRP Letter All Wells.docx 0 0 ADEC INFORMATION REQUEST Concerning a contaminated site(s) Re: Legacy Well Sites in and near the National Petroleum Reserve, Alaska (NPRA) Please precede each answer with the number of the question to which it corresponds. Please direct any questions concerning this information request to Fred Vreeman, Contaminated Sites Program, 610 University Avenue, Fairbanks, AK 99709; Phone: 907-451-2181. Thank you for your cooperation. 1. Provide name and company affiliation of the person answering the questionnaire. 2. Provide copies of all studies, reports, and supporting information (including preaquisition assessments and work done on behalf of other parties) which you have knowledge of which address past and/or present environmental conditions at the site. Identify the name, title, address, and phone number of the party(s) who are responsible for preparing the studies or information. Information which has been previously submitted to ADEC need not be submitted again (unless specifically requested in a subsequent communication) if you can provide the name of the office (and name and title of the DEC officer if known) to whom the report was previously provided. 3. Provide a description of any ongoing or planned investigations or cleanup work at the site. Identify the names, titles and phone numbers of the individuals responsible for preparing the studies or information. 4. Provide a description of known releases at the site (date of occurrence, quantity released, type of substance released, etc.) and a description of corrective measures that were taken. Provide information on any suspected releases which may have or are occurring. 5. Describe the nature of past and present operations at the site. In particular, any actions that may have caused the release or threat of release at the site. Describe the physical characteristics of the site including major structures, water wells, fuel or waste storage systems, drainage or septic systems, etc. 6. Provide a list of any permits issued by the Department which relate to activities at the site and a list of RCRA identification numbers (U.S. EPA identification numbers) which may be held. 7. Identify persons to whom you leased all or a portion of the property and describe the nature of their operations. 8. Identify the person(s) who used the site for disposal of substances deposited there, if any. 9. Provide copies of manifests for any hazardous waste and/or petroleum contaminated materials taken to or from the site. 10. Provide a list of persons and their phone numbers and addresses of persons who have knowledge about the use of hazardous substances at the site. 11. Provide information regarding the existence of insurance coverage for damages resulting from releases of hazardous substances and copies of all such insurance policies, both currently in effect and in effect during the periods of activity in question. 12. Describe the acts or omissions of any person, other than your employees, agents, or those persons with whom you had a contractual relationship, that may have caused the release or threat of release of hazardous substances at the site. a. In addition, describe all precautions that you took against foreseeable acts or omissions of any such third parties. 13. Describe the care you exercised with respect to the hazardous substances found at the site. 14. Describe the physical characteristics of the site including structures, wells, drainage systems, etc. THE STATE July 11, 2013 'ALASKA GOVERNOR SEAN PARNELL Wayne Svejnoha Supervisory Minerals & Energy Specialist 222 W 7th Avenue, #13 Anchorage, Alaska 99513 Re: BLM Legacy Wells Dispute Dear Mr. Svejnoha: Department of Environmental Conservation Division of Spill Prevention and Response Contaminated Sites Program 610 University Ave. Fairbanks, Alaska 99709-3643 Main: 907.451.2181 Fax: 907.451.2155 The Alaska Department of Environmental Conservation (ADEC) — Contaminated Sites has reviewed the National Petroleum Reserve in Alaska: 2013 Legacy Wells Summary Report dated February 2013, containing updated information on the status of the 136 Legacy Wells located in the National Petroleum Reserve — Alaska (NPR -A), and the draft National Petroleum Reserve in Alaslm. 2013 Legacy Weiss Strategic Plan dated May 2013. ADEC has also reviewed the response by the Alaska Oil and Gas Conservation Commission (AOGC). We concur with the response by ACIGC and have no further comment regarding the priorities. We do have comments about the investigation and cleanup plans presented in the report. With this letter we arc outlining regulatory requirements related to the environmental work that is proposed and required as part of these cleanups. ADEC is concerned that the 2013 Legacy Wells Strategic Plan prepared by the BLM does not include either assessment of the contingency for assessment of known, likely, or unknown but possible contaminant releases. In addition, BLM plans for surface cleanup of these wells should be made clear in the plan. At least one of these legacy wells has extensive PCB contamination and has resulted in a multi-year cleanup totaling tens of millions of dollars. At others, solid waste disposal practices have resulted in releases to the environment with estimated cleanup costs in the hundreds of millions. Known releases documented in the records we reviewed include crude oil, gasses, refined oil and fuel, drilling fluids that include various organics, metals, and other chemicals, and unknown contaminants from drums and other containers observed to be damaged and abandoned at the various well sites. There are 13 legacy well sites with known releases currently on the DEC contaminated sites list. Many of these are in the process of being addressed, cleaned up, and closed. From our Waited records review there are 15 additional legacy well sites with confirmed releases. These should be prioritized for initial records reviews and then added to the BLM contaminated sites list under our cooperative agreement. Suspected releases include fuel releases from operations, storage, and fuel spills at the sites, impacts to various surface water bodies from spilled fluids during drilling and breaches of containment at reserve and flare pits, continued surface runoff from drilling fluids uncontained at several sites, and down -hole substances that were ejected from the holes over time or during blowouts or drilling operations. 1 Wayne Sve noha ? July 11, 2013 Y The.BLN-1 plan to address these known, suspected, and unknown releases at legacy well sites is notably absent from the documents presented to date. The three primary regulatory agencies that need to be involved in the plan are ADEC — Contaminated Sites, Alaska Oil & Gas Conservation Commission, and ADEC — EH/Solid Waste. Other agencies will need to be consulted. as well. Below we provide recommendations for a coordinated plan using the Uniform Federal Policy for Quality Assurance Project Plans (UFP-QAPP) that will involve all of the regulatory agencies in one coordinated manner. This will allow BLM to address these sites in a consistent and coordinated project which fulfills all of the regulatory requirements so that the sites do not need to be re -visited in the fu=e xvhen they are closed after this project. Attached are our comments on each specific well. The acronyms used on the list include terms that are typically used in a CERCLA type investigation however they are also suitable for investigations conducted under the State of Alaska cleanup rules. These include the following; Historical Records Review (HRR) 'chis is recommended for almost all of the well sites. Much of the information required for these reviews is already contained in various reports and appendices or in BLM files. The Historical Records Review should document the type of releases that might have occurred from drilling operations as well as historical use of the site, and should capture all available information on the drilling fluids used and any product produced or released. Preliminary Assessment (PA) This is recommended for almost all of the well sites. A Preliminary Assessment is a limited scope investigation that provides an assessment of information about a site and its surrounding area to distinguish between sites that pose little or no threat to human health or the environment and sites that require further investigation. The PA is a CERCLA defined document and typically does not require sampling. Site Inspection (SI) If the PA recommends further investigation, then an SI is necessary. The SI is a CERCLA defined document, and it is analogous to an initial report of contamination under state cleanup rules. On some legacy well drillings sites it is evident now that an Sl is required just from a review of the reports. An SI investigation typically includes the collection of samples to determine what contaminants are present at the site and whether they are being released into the environment. An approved site specific workplan is required under both CERCL-A and 18 AAC 75 prior to SI sampling. The SI typically is not intended to develop a full site characterization, but is limited to determining the presence or absence of a release. If contamination is found after completion of the HRR, PA, and SI then a RI/FS under CERCLA, or a Site Characte-rizatiowlteportandcleanup-Alas,under-l-fi-AAC7iis`required. -- ----- - -- — --------- - DEC recommends that BLM incorporate into the strategic pian the processes outlined in this letter. A team of agencies composed of AOGC, DEC -CS, EPA as required, and DEC -EH should address regulatory and technical requirements for these well closures. By cooperating and working together with the regulatory agencies BLM will save time and expense, and regulatory uncertainties will be avoided. The strategic plan should reference a project to prepare a generic workplan. DEC suggests that BLM utilize the generic UFP-QAPP workplan format for the required environmental work. If properly prepared, the workplan could encompass most of the investigations and cleanups required at these sites over multiple years. At other multi -site projects we have found this to be an effective way to reduce uncertainties and risk in these types of investigations. A very small site specific FSP could then be developed as BLM approaches each drilling site. Regulatory decisions made during workplan development would provide more certainty in the planning process for cleanups. G:\SPAR\CS\federal F2cilitie3\Ci%ih2n 1-cdcrrt Agr=ics\DOl\B[.nl\1'roiens\lxgAey Wells\7 11 13 Luter to KIN on lxbxy wells.doex Wayne Svejnoha 3 0 July 11, 2013 Please review the attached list of specific sites. If you have any questions, please do not hesitate to call me at 907-451-2181 or by email at fred.vreeman@alaska.gov. I look forward to working with you as the Federal Government fulfills its requirement to clean up these well drilling sites in Alaska. Sincerely, y' Fred Vreeman Environmental Program Manager Enclosure: SPAR Response with Legacy Wells cc: Bud Cribley, State Director, Bureau of Land Management Steven Cohn, Deputy State Director for Resources, Bureau of Land Management Jolie Pollet, Branch Chief, Bureau of Land Management Robert Brumbaugh, Geologist, Bureau of Land Management Michael McCrum, Environmental Engineer, Bureau of Land Management Cathy Foerster, Commissioner, Alaska Oil and Gas Conservation Commission Larry Hartig, Commissioner, Alaska Department of Environmental Conservation Kristen Ryan, Director, ADEC Division of Spill Prevention and Response Steve Bainbridge, Program Manager, ADEC Contaminated Sites Program Jennifer Roberts, Program Manager, ADEC Contaminated Sites Program GASI'AR\CS\Fedcrrl Fo61ibLy\Gvi6n Falctul AgcnnCs\DOI\BI.N1\Proitcts\lA'6.1' q W03\7 11 1314tur to Aim\I on Ug2cy Wclls.doex Well Name operator I RP I Land Simpson Core Test #5 1! Na 1 BLM Simpson Core Test #6 US Na I BLM Simpson Core Test #7 us Na 1 Bl. M Sin son Core Test 98 US Navy 113LM Si son Core Test #9 U5 Na I BLM Sinwson Core Test #1f) U.S Navy! BLM Core Test #11 AOGCC Subsurlaca I BLM Core Test #12 FUSNa a I BLM Core Test #16 a 18LM Core Test #17 US Na 1 BLM Core Test 018 US Na I BLM Core Test #19 US Na 1 BLM t Core Test #20 US Navy 1 BLM i Gore Test #21 2S Na 1 BLM I Core Test #22 US Na 111•LM I Core Test dnlf fluids left in hole i BLM Core Test �#2vy I BLhA n CareTest #25 US Na Y I BLM K Core #1 US Navy i BLM 1 -t- *1 SPAR Response with Legacy Wells Lisl.xlsx 2013 Risk Ity CSP Status I Fito tllHazid Rolea5e7 Nnne None IYOMWil Low RNooe ane Nona Unused, Unused. I None Unused, i None Uncased, None None None None (None Unknown Unknown Page 1 of 14 •I AOGCC Subsurlaca AOGCC Surface SPAR W arkgroup Notes Status Status Need HRR, PA, S1 no data no data Need HRR. PA. SI no data no data Need PA ind drill fluid assessnsenl & workplan drillin 11uids left in hole no data Need PA ind drill fluid assessment & work an drilling fluids left in hole no data Need PA incl drill Ifusd assessment & work Ian dnlf fluids left in hole no data Need PA nc drill fluid assessmcnf &work Ian dnllxs fluids left rn hale no data well skc-lch provided by Need PA ind drill fluid BLM not consistent with assessment & work Ian AOGCC or BLM data no data Need PA ind drill fluid assessment & work Ian dnflin fluids left in hole no data Need PA and 51 ind 13611 fluid assessment. workplan rid sampling stressed debfis, partially as blowout and fire rove elated site areas Need PA incl drill fluid assessment & workplan dn lling fluids left in hole no data geed PA ind drill fluid assessment & wOTk Ian drij I ing fluids teff in hole no data Need PA incl dfifl nutd assessment & work Ian drillin fluids left m holo no data Need PA incl drill fluid assessment & work Ian drillin ituids left in hole no data Need HRR. PA, SI no data no data Need PA incl drill fluid assessment & work Ian drillin fluids felt in hole ria data Need PA incl dnll fluid assessment & work larx drillin fluids left in hole no data Need PA incl drill fluid assessment & work Ian drillin fluids Teff in hole no data Need PA ind dnll fluid drflfing fluids and ball assessment & work len peen hammer left in hole no data overshot, drill collar, rock revegelated —131 Need HRR, PA bit, and N -reds left in hole can't find it Review Report as PA. No evidence of sheen, stressed veg, or drilling Not abandoned, waste on surface. Veg ----_— , ,raw,, plunaed to surface site not cleared •I SPAR Response with Legacy Wells LisLxlsx Page 2 of 14 is • vi nce o BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator I RP I Land Mgr Priority CSP Status file #IHazid Release? SPAR Workgroup Notes Status Status plugging operations inadequate and Wellhead tell as Umiat 43 US Navy I BLM I FUDS None pending dos 335.38.00113092 Yes. see file 'Plugged by BLM in 2004 incomplete historic site? plugging operations inadequate and Wellhead left as Umiat #4 US Navy I BLM / FUDS None pending dos 335.38.001!3079 Yes, see file Plugged by BLM in 2004 incomplete historic site? plugging operations inadequate and Wellhead left as Umial 98 US NaMy I BLM I FUDS None pendinq dos 335.38.001/3D81 'Yes, see_ _file Plugged BLM in 2004 incomplete historic sile? plugging operations inadequate and Wellhead left as Umiat #1'0 US Navyj BLM_I FUDS None pendingdos 335.38.00113082 Yes, see fila Plu ed by BLM in 2004 incomplete historic site? Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Plugged to 7868'. Drilling Cleanup. Photos - evidence mud and diesel to Awuna #1 USGS I BLM Medium None None Yes of erosion into lake surface. > 100 _Pylons Need HRR, PA, SI with sampling. Drilling mud Wood , metal, assessment. Surface Plugged to 2039'. Diesel plastic debris. Fast Simpson #1 USGS I BLM Low None None Yes Cleanup. to surface. >10D Pylons Need HRR, PA, SI with Wood and metal Drilling mud assessment debris. Pylons - Photos straw areas of no Plugged to 2047'. Diesel Tankage for lk ' #1 USGS / 8LM Low None None Yes ve elation. to surface. flammable fluids Need HRR. PA, SI wdh sampling. Drilling mud assessment. Surface Plugged to 1400'. Drilling Wood and metal Koluktak #1 USGS I BLM Low None None LYes Cleanup. mud & diesel to surface debris Pylons Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Plugged to 1894'. Diesel Wood and metal Ku am 91 USGS I BLM Low None None Unknown Cleanup. to surface debris. Pylons Need HRR, PA, Sl with sampling_ Drilling mud assessment_ Surface Plugged to 4464'. Drilling Wood & metal Kuyanak #1 USGS I BLM Low None None Yes Clean mud & diesel to surface debris. Pylons Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Photos show Plugged to 1840'. Diesel Plastic and metal Lisburne 41 USGS I BLM Low None None Yes stained soil to surface debris. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Plugged to 8192'. Drilling Wood and metal North Iii ok $1 USGS I BLM Low None INone Yes Cleanup. mud & diesel to surface debris - Page 2 of 14 is • Well Name Peard South Meade #1 1 RP 1 Land 1BLM BLM #1 4USGS ! BLM SPAR Response with Legacy Wells Usl.xlsx ;013 Risk &W CSP Status File XlHazkl T Page 3 of 14 AOGCC Subsurface AOGCC Surface WAR Workgroup Notes Status r Status � deed HERR, PA SI with iampling. Dining mud rssessment- Surface ;leanup. Site photos show areas of stressed iegetalion. No issues Plugged to 2232'. Diesel Wood and metal soled in USGS re ort. to surface debris. Pylons Need HRR, PA, SI with sampling_ Drilling mud assessment Surface Plugged to 2026'. Diesel Wood and metal Cleanup. to surface debris. P Ions Add to She list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Od reported bubbling to the surface within reserve pit in 1982. Oily residue and sheen observed adjacent to east side of reserve pil, down hole material at the Plugged to 1875. Diesel Wood and metal surface to surface debris. P ons Add to Site list. Need HRR, PA, S) with sampl'uig. Drilling mud assessment - Surface Cleanup. Reserve pit berm had breaches anowirrg water to exit. Oil - stained sediment was observed above the Plugged to 1478'. Diesel Wood and metal waterline of the I. to surface debris. Site photos may show hydrocarbon sheen on Plugged to 2600'. Drilling Wood and metal water in well cellar mud & diesel to surface debris. Pylons Add to Site list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Berms have been breached an allow water to flow out of reserve piUllare pit. Rising bubbles of ail observed in Hare pit 1484. Photos Show Plugged to 1825'. Diesel Metal debris. ra.. v-1 v.nnnralinn to Surface ... 0 •I SPAR Response with Legacy Wells Lisl.xlsx Page 4 of 114 0 0 vi encs o BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator 1 RP f Land Mgr Priority CSP Status File #fHazld Release? SPAR Workgroup Motes Status Status Need HRR, PA, Sl wrlh sampling. Drilling mud assessment Surface Cleanup. Breaches in bemi allow water to flow into and out of reserve pit, sheen on Plugged to 2700' Diesel Wood and metal West Dease #1 USGS l BLM Low Nona None Yes surface water in well cellar to surface debns. Pylons Add to Site list. Need HRR,. PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Water flows into the pits through breaches on the eastern berm and out of the pits through breaches on the northern and western berms. Downhole material Plugged to 228'9'. Drilling Wood and metal South Harrison Bay #1 USGS f BLAB Low None None es Present at surface mud & diesel to surface debris. Add to Site list. Need HRR, PA, SI with sampliing. Drilling mud assessment. Surface Cleanup. Stressed vegetation noted and apparent in site pholos. Plugged to 2443'. Drilling West Fish Creek #1 USGS 1 BLM Low None None Yes Drilling mud around well mud & diesel to surface Pylons Need HRR, PA, SI with sampling. Drilling mud assessment, Surface Cleanup. High TPH Plugged to 1977'_ Drilling wellhead sticking concentrations underneath mud under plugs. Diesel up. Wood debris. Fast Simpson #2 USGS 1 BLM I Low _ Active 300.38.10912691 Yes, see file the rig inundation to surface Pylons South Barrow 94 US NavyiNorth Slope Bono None None None Unknown Need Surface Status completed gas well - no data South Barrow #5 USAF - BLM Unknown None None None. Unknown Need Surface Status completed gas well no data South Barrow #& US Na /Norlh Sto Burg None None None Unknown Need HRR, PA, St no data no data South Barrow #9 US NavyfNarih Slop2 Boro None None None Unknown Need HRR, PA, Sl no data no data _ South Barrow #10 US Navyfflorlh Sto Bora None None None Unknown Need Surface Status com ted gas well no data South Barrow It12 US Na /North Slope Baro None None None Unknown Need HRR, PA. Sl no data no data BLM well skMh not consistent with AOGCC South Barrow #14 US NavyMorth Sloe Boro None None one Unknown Nsed HRR. PA, St data no data Need PA ind drill fluid well left filled with drilling South Barrow #16 US NavyiNotih Slope Bora None None None Unknown assessment & workplan mud and diesel no data Need PA incl drill !turd tubing in well. no perfs, Soulh Barrow 017 US Na /North Sloe 13ora None None None jUnknown assessment & work fan I unknown fluid, I no data Page 4 of 114 0 0 SPAR Response with Legacy Wells Lisl.xisx Page 5 of 14 •I E CYfuu .v v AOGCC Subsurface A Surlaco TEHILM T013 Risk CSP Stilus File #IHaaid Historic Rekeasa7 SFAR YUnrkgroup Nates 5latus at US $1<ntus Well Name flperatar f RP f Land Mgriority Unknown Need Surface Status corn feted as well no data 5aulh Barrow #18 US Na INorlh Slo a Bora None None None Unknown Need HRR, PA, St no data no data Walak a #1 USGS! Unknown None None None rsg 890`. Multiple cement plugs of unknown volume. Shallowest None None Unknown _ Need HRR, PA, SI SOD' no dada Gubik #1 US Na d Ur#cnown Low Add to Site list. Need HRR. PA. SI with sampling. csg Q SOD' Well blowout Drilling mud assessment. from zone al 1SOT during Surface Cleanup. Photos plugging operations show disturbed/ slashed Plugging never completed after blowout. no data Gub* #2 US Na ! Unknown Low None Nora es areas two downhole Dement plugs of unknown depth Mone None Unknown Need MR. PA. Sl and volume no data Grandstand #1 US Navy 1 Unknown None Add to Site list. Need HRR. PA, SI with sampling. Dnliing mud assessment. Surface Cleanup Sediment from the reserve pit was excavated and spread over the pad to drill a 2nd well at this location, Upon completion of the 2nd well. the sediment was pushed back into ft reserve pit.. Area does not appear to be revegetaling. perhaps from the presence property plugged but no of drilling mud at the data on abandonment None None Yes surface status no data W 7 Foran #1 " USGS I Unknown Low on Site list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Slressed vegetation, photos show plugged, but not open csg; metal & Active 306.3$.108f2689 Yes. see file site underwater abandoned at surface corwsele debris under 5' of water, Cape Halken #1 " US Na (Unknown Low None Unknown !Need HRR, PA. SI es to 27' open C_s Min a Veloei #1 U5 Na f t3LM one None csg @ 31" 280' of drill pipe, drill collar, and Core Unknown Need HRR. PA, SL barrel left rn hole. rove etaled Ournalik Core #i US Na / BLM None -No obsery None !None Page 5 of 14 •I E SPAR Response with Legacy Wells Lisi.xlsx Page 6 of 14 • • WI F3nCe Q BLM 2013 Risk Historic AOGCC Subsurface ADGCC Surface Well Name Operator t RP I Land Mgr Priority CSP Status File #IHazid Release? SPAR Workgroup Notes Status Status Need HRR, PA, Workplan for St with Sampling. Drilling Mud Assessment. Surface Cleanup. Photos show debris, stressed No csg. 15' of drift pipe Oumalik Caro #2 US Navy 1 ULM Low None None yes ve elation and rock hit left in hole. no data Need HRR, PA, Workplan for Si with Sampling open csg & other Drillip) Mud Assessment. piping sticking out Surface Cleanup_ Reports of ground; wood, of debris, drilling muds on melat, conciele Oumalik Core 011 US Navy 1 BLM Low None None Yes surface (__q to 9', debris open csg sticking out of ground; wood & metal 0umalik Core #12 US Navy I BLM Low None None No Need HRR, PA, SI no data —__—debris _„ debris buried by landslide. Need HRR, PA, St, Well not no dala on Sentinel Hill #1 US Navy 1 BLM Low None None Unknown ap panent in site Rholos Csq to 3t1'. underwater status Need IQR, PA, SI. No evidence of sheen, open crag slightly stressed veg, or drilling above ground waste on surface. Veg 37' of csg, drilling fluids level; wood and S imp son Core Test #1 US Navy 1 BLM Low None None No appears healthy lett in hole metal debris Need HRR, PA, St. No evidence of sheen, stressed veg, or drilling waste on surface_ Veg 76'01 Csg, drilling fluids Simpson Core Test #2 US Navy I BLM Low None None No appears healthy left in hate no data Need HRR, PA, Sl. No evidence of sheen, stressed veg, or drilling waste an surface. Veg 61' of csg, drilling fluids Sim sun Core Test #3 US Navy I BLM Low None None No appears healthy left in hole no data Need HRR, PA, St. No evidence of sheen, stressed veg, ordrilling waste on surface. Veg --60' of crag, drilling fluids Sim eson Core Test #4 US Nayy t BLM Low Norse None No apecars healthy left in hole no data Need HRR, PA, St. No evidence of sheen, stressed veg, or drilling waste on surface. Veg csg cemented @25% open csg sticking Songsoncore Test #13 US Na 1 BLM Low None None No appears health dritin fluids IeR in hole_ out of round Need HRR, PA, SI. Vegetated, no evidence of crag cemented @2D'; open csg sticking Simpson Core Test #14 US Navy ! BLM Low None None No release. drillin fluids left in hole out of ground Page 6 of 14 • • SPAR Response with Legacy Wells Lisl.xlsx ism son Core Fest #26 t=vrdence or Medium AOGCC Subsur(aen ADGGC Surface 13LM 2013 Risk CSP Status File WHazid Historic Retease7 SPAR Wwkgroup Notes Status Status Well Name operator r RP 1 Land Mgr Priority Unko Need HRR, PA. SL US Na ! $LM open casing None Nave Vegetated. no ev4dence of cog set shallow; drilling slicking nut of Low No release- fluids left in hole round Simpson Core Teri #14a US Na !BLM Low None None & weilhead slick Need HRR. PA, SI crude nil left in hole open casing Need HIR, PA, Workplan Vegetated, no e+wdence of csg cemented 12181; slicking out of openregd ng No release. drillingfluid left in hole round Simoson Care Tesl #15 US Na !BLM Low None None d wooden Oellar, Need HRR, PP, SL Sate a9 r�110'. dolling fluids wood 8 metal ism son Core Fest #26 US Na ! BLM Medium None None res Sim sen Core Test 027 US Na J 13LM IJone None None Unko Sim son Gore Test #28 US Na ! $LM Low None Nave Yes clmnnnn Core Tesl #29 US Navy! BLM Low Norte No No Simpson Core Test 030 US Na 1 !BLM Core Test #30a JUS,Navy 1 BLM Low `None Prone n Gore Test #31 JUS Navy/ BLM None Page 7o(14 photos appear to show oil at surface, from a natural csg Q 350'. Completed in oil seep, seep, also drilling mud in oil well Open perfs. At 1welhead sticking sacks on the tundra one lime capable of up_ metal debris PI u ed b BLM in 2004. unassisled flow. and rustingbarrels 'Need HRR, PA, St. Site photos appear to show Oil csg cemented at surface, from a natural @i02;dnllutg fluids nn oily ground; csg seep- Plugged by BLM in including diesel and & weilhead slick vin 20014 crude nil left in hole out of ground Need HIR, PA, Workplan for Sl with Sampling- openregd ng ❑rilling Mud Assessment . out grouunnd in Surface Cleanup. Site d wooden Oellar, photos appear to show a p le of drilling mud about a9 r�110'. dolling fluids wood 8 metal 160 feel tram the welt tell in hole debris. Solid waste Need HRR, PA, Sl_ No evidence of sheen, stressed veg, or dri" waste on surface. Veg csg cemented at 1S2'; open csg. Wood a ears healthy dnknq fluids lett in hole and metal debris Need HRR, PA, SI. frilling mud at surface. but well is also in the middle of a large in oil seep; Open oil seep and surrounded by cog sticking up; pooled oil. Plugged by BLNI csg cemented A150'; wood & metal ser Holes in 20514- drillin fluids left in hole detail on oily ground; tog Need HRR. PA, Sl. Well is wellhead slick in the middle of a large oil seep and surrounded by csg cemented at 100% out of ground. pooled oil. Plugged by 131. dulling mud left in hole. wellhead leaking see noses in 2004 gas blowout at 423' gas Need HRR, PA, St. Leaky valve replaced in 2001, little evidence of contamination following valva on city ground; reg replacement- Plugged by csg cemented at 100'; & wellhead stick see notes BLM in 20174 iddifing fluids, left in hole out o1 round SPAR Response with Legacy Wells List.xlsx Page 8 of 14 • • yr enco o BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator f RP f Land Mgr Priority CSP Status File glHasid Release? SPAR Workgroup Notes Status Status Need HRR PA, Workplan csg Cemente=d al for Sl with Sampling. 1028', cement plugs a1 Drilling Mud Assessment. 6387' and 5520'. Fish in Surface Cleanup. Drilling hole, drilling fluids Iefs in No data. Open Simpson Test Welt #1 ak US Navy1 BLM Low None INone yes muds near wellhead hale casing Need HRR, PA, Workplan for Sl with Sampling. Dolling Mud Assessment. Surface Cleanup Also Wellhead sticking evidence of a natural seep- above ground, Tar sheens in the summer ST from 2552 to 3018. wood, melel, and months. BLM is concerned csg @2915. Slotted liner concrete debris. Fish Creek #1 US Navy I BLM Medium None None Yes about exposure to wildlife to TO. Completed oil well Rusting barrels Need HRR, PA, Workplan for SI with Sampling. rasing cemented at 48; Drilling Mud Assessment. gas 0mv and explosion Surface Cleanup. Small gas while drilling at 863'; hole leak in wellhead flange, will Filled with fresh water to Wolf Creek 91 US Navy f BLM Low None Nano No flow if the valve iso en 330' No data. csg cemented a[ 53';hole left tilted with fresh water, Wolf Creek 02 US Navy 1 BLM Low Noire Nona No Need HRR. PA. Sl. fish in hole csg cemented at 107'; No data bridge plugs from 1447 to 1735 and from 554 to Wolf Creek #3 US Nayy I BLM Low None None No Meed HRR, PA, SI. 661, No data Add to Site list. Need HRR, PA, SI with sampling. csg slicking out of Drilling mud assessment ground with wood Surface Cleanup. Sheen on plug on top; solid surface water in well cellar, csg cemented at 30'; drill waste; wood hundreds of drums indicate pipe, drilling mud and debris; about 200 Skull Cliff Core iesl #1 US NaMy I BLM High None None Yes polential for cornlamrna[ion diesel left in hole nisling barrels Need HRR, PA, SI. Two open csg, wood drums are floating on a building; pylons; pond near the well. csg cemented at 1000', wood & metal Kaolak 01 US Navy 1 BLM t ow None jNone lNo Potential for hurried landfill. fdriltingluidsieftin hole debris Page 8 of 14 • • SPAR Response with Legacy Wells Lisl.xlsx 181-11119013 Risk Well Name Operator f RP ! land Mgr Priorlty CSP Status File 1NHazid #1 1 U Navy 19LM #1 JUS Navy/ umatik Ill US Na I BLM Low None None as[ Oumalik #i US Na !BLM Low None None #1 N East Topagoruk #1 USN l BLM Kniteblade #1 US Navy l BLM Page 9 of 14 Subsurface `AOGCC Surface SPAR Workgroup Notes Status Add to Site list. Need HRR, PA, SI with sampling. open flange Q Drilling mud assessment. Surface Cleanup. Drilling Gas well. Open ports. ground level. Mud pile overgrown with Drilling fluids and Metal & wood v , etallon and lichen tubulars lett in hole debris Need HRR, PA, SI. No evidence of sheen, stressed veg, or drilling csg cemented at 502'; open casing slicking out of waste on surface. Veg plug at 3470 to 3511'; ground. Wood appears heall drilling nuids left in hole debris. Open casing below Add to Site list. Need HRR, ground level. PA, SI with sampling- Revegetated. Drilling mud assessment. Numerous metal Surface Cleanup. Debris csg partially cemented at I support structures and drilling muds. Stressed 2762'. Plug at 2543% slicking up. vegetation Dridin mud left in hole Concrete debris, plate welded to pipe: l' of pipe rsg cemented at 1100'. sticking up - Need HRR. PA. SI. Drig fluids left in hole Wooden debris. Add to Site list. Need HRR, PA, SI with sampling. Driving mud assessment. open csg broken Surface Cleanup. Downhole material present csg cemented at 6073'. off and sticking up: at surface, area mostly original hole drilled to wood, metal, revegetated. Diesel still 7154'& junk len; concrete and other occupies the ground sidetrack hole left wilh debris. rusting dreulatioir lines. drillina fluids barrel Add to Site list. Need HRR, PA, SI with sampling. Dolling mud assessment. Surface Cleanup. Pile of tsg 10 1100'; pkig al open casing drilling muds is next to the 1049% drilling mud below sticking up. Wood, teller. No offical reserve pit plug: unknown fluids in metal, and glass noted o en hole debris. open casing Need HRR, PA, SI. BLM sticking up. Wood, stales that there was no metal, and glass debris at this site in 2012. csg cemented at 420% debris - •I 0 SPAR Response with Legacy Welts Lisl.xlsx Paye 10 of 14 0 0 w once a BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator I RP f Land Mgr Priority CSP Status File #IHazid Release? SPAR Workgroup Notes Status v F Status open casing sticking up. Wood, metal, & concrete debris rusting Need NRR, PA, SI. Reports barrels. One indicate solid waste csg cemented to 45';fish marked flammable Knileblade #2 US Navy I BLM Low None None No drums in hole hazard. open casing slicking up; metal & Krideblade #2a US Navy 1 BLM Low None None No Need HRR, PA, SI. csq cemented at 38% concrete debris Need HRR, PA, SI including learning assessment. Site partially No wellhead. submerged intermittently csg cemented at 80; Metal. Solid waste North Simpson Test Wel 4 US N2n I BLM Low None None No during the summer dri0ing fluids left in hole ? No dala crude wellhead. Need HRR, PA, St. Surface csg cemented at 685'; Wood and metal Umiat 01 US Navy J BLM I FUDS Medium Cleanup co 335.38.00113090 Yes, see file Cleanup drillinq fluids left in bole debris No wellhead. Gravel pad partially csg cemented a1486; revegelaled wood Need HRR, PA, SI. Surface cement plug from 440 to debris and pipe Umiat #i t US Na I BLM I FURS Low pending dos 335.38.00113083 Yes, see file Clea 490'; sticking u csg cemented at 7206'; vVefNwad- Gravel various plugs from 8250' pad revegetaled 7 South Sirnpson 01 US Navy I BLM Low None None Yes Need HRR, PA, SI. to surface No data Add to Site list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Large quantifies of ferrous oxide, zinc oxide, zinc carbonate, and barium sulfate were added to drilling muds. Stains apparent in photos. BLM field camp an site. Walls between the reserve and Pare pits have eroded. Wellhead and Water flows into surface gravel pad. ? No Wook #1 USGS I BLM Low lNone Name Yes water during break22L no data data Paye 10 of 14 0 0 SPAR Response with Legacy Wells Lrsl.xlsx BLM 2x13 Risk Well Name 10porator I RP I Land Mgr Priority CSP Status I File #IHazid Arca- Barrow Cure #1 US Na l til.M Avak 01 US Navy I BLM Barrow Bi R' #1 US Na I BLM Barrow Cafe Rig Test 91 US Na I BLM #2 I US Navy I BLM #1JUS N,a I BLM H' h NOr1e None Test Well #1 US Test Well #2 US Barrow Test Wetl #31115 Na IN©r1h Slo c Bora IAedium None None Unknown Page 11 of 14 Subsurface -FAOGCC Surface SPAR IWorkgfoup Notes Status _ ___ araiu5 Need HRR, PA, SI. Surface Cleanup, Photo CIMG0218 csg cemented at 53` shows area of disturbed tubing hung to 708': hole open casing vegetation that should be heft filled with drilling mud slicking up; wood & investi algid durin Sf and diesel metal debris open casing Need HRR. PA, St. Surface csg cemeoled at BIF. sticking up; wood & Cleanu-. lu set at 1348' metal debris Not abandoned, site not cleared, Need HRR, PA, SI. Surface open easing 7? No Cleanup no data data Not abandoned, site not eteared, Need HRR. PA, SI. 'Surface open casing 77 No Cteanu no data data Need HRR, PA, St with sampling. trilling mud assessment. Surface Cleanup. Drilling Muds on Not abandoned, site -slowly revegelatmg site not igred, More information on drilling open casing 7? No mud specifics rs being researched no data data Need 1lRR, PA, SI wdh sampling. Drilling mud wellhead leaking assessment. Surface cemented Csg to gas!? Wood & Cleanup- Cellar does not 1270;slotted liner to metal debris. Area retain water 1956': tbg to 1939 affected 50'x50' Need HRR, PA. SI. Drilling Csg cemented at mud assessment. Surface 441'.hole Iell willed with open pipe; metal & Cleanup- On mads stem water concmie debris Need HRR, PA, Sl. Drilling Csg cemented al 2260'; mud assessment- Surface periorated liner to TD. wood, metal & Cleariu . fln road s stem lin Completed well. Conerete debris Need HRR, PA, SI with sampling and workplan. Drilling mud assessment. Surface Cleanup. Drilling +csg cemented at 10461: open c5g slinking mud at surface. Sheen on hole left filled with drilling up; wood & metal surface wafer in well cell larQuids and wafer. de" 0 SPAR Response with Legacy Wells Lisl.xlsx Well Flame Operator I RP I Land Mgr BLM 201$ Risk Priority CSP Status File #ltiazid yr once oF— Historic Release? SPAR Workgroup Notes AOGCC Subsurface Salus g AOGCC Surface Status no data. Likely revegetaled. Removed from our list of wells of concern in < 50', no csg, no API#, October, 2012 Oumalik Foundation Tess A US Navy I BLM None-uncased hc None None lUnknown Need HRR, PA. not in AOGCC database Monlht Meeting no data. Likely revegetated. Removed from our fist of wells of concern in < 50', no csg, no API#, October, 2012 Cumalik Foundalion Test b US Navy I BLM None-uncased hC None jNane Unknown Need HRR. PA, not in AOGCC database Monthly Meeting no data. Likely revegetated. Removed From our irsl of wells of Concern In < 50', no csg. no API#, October, 2012 Oumalik Foundation Test A US Navy I BLM None-uncased hc None lNone Unknown Need HRR. PA, not m AOGCC database Monthly Meeting no data. Likely revegetated. Removed from our list of wells of concern in < 50', no c5g. no APF#. Odubut. 2012 Oumalik Foundation Test A US Navy I BLM None-uncased ht Nune lNone Unknown Need HRR, PA, nal in AOGCC database Monthiv Meetin no data. Likely revegetaled. Removed from our Ilst of wells of con cam in < 501, no csg, no APi#. October, 2012 Oumatik Foundation Test 0 US NavyI BLM None-uncased hc None None Unknown Need HRR. PA, not in AOGCC database Moral Meeting no data. Likely revegetaled. Removed from our list of wells of concern in < 50', no csg. no API#, October, 2012 Ournalik Foundation Test 4US Navy I BLM None4xwased h_j None None Unknown I Need HRR. PA, not in AOGCC database Month Meetin Page 12 of 14 0 Page 13 of 14 SPAR Response with Legacy Wells LrsLxisx Well Name BLM 2013 Risk Operator f RP I Land Mgr Priority Historic CSP Status Fife #IHazld Rslease7 AOGCC subsurface Status �__ - -_-�� . A013CC Surface Status no dala. Likely SPAR 1Norkgroup Nates revegelaled. Removed from our list of wells of concern in < 50'. no csg, no AP IN, October, 2012 Oumalik Foundation Test US Na!q BLM None -encased h None None Unknown Need HRR. PA. not w AOGCC database MonthlyMeetin no data. Likely revegelated. Removed from our list of wells of concern in < 501. no csg, no API#, October, 2012 Oumalik Foundalion rest U5 Na I BLM None -encased h None None Unknown Need HRR, PA, not in AOGCC database Monihl lAeeli no data. Likely revegetaled. Removed from aur fist of wells of concern in 0urn alik Foundation Test US Na 18 LM None -encased fi None None ilnknown Need HRR. PA, < 50', no csg. no API#, not in AOGCC database October, 2012 Month! Meetin no data. Likely revegetated. Removed from our list of wells of concern In < 50', no csg, no API#, October, 2012 Oumalik Foundat'Gon Test US Na I BLM None encased h Nome None Unknown Need HRR, PA, not m AOGCC database Month! Meeting property abandoned per then -applicable South Banow #7 US NEILM 2LI None None Unknown Need HRR. PA, ro erl lu ed re s no data to support proper Um -Qt 02 US N Noire Pendin Clo 335.30.001/3078 Yes, see file Plu d to surface abandonment no data to support proper Uncal #5 Ummt #9 Urrval A66 Umial #T Atiaaru Point#1 U5 US US Na I BL M US Na I BLM USGS/BLM None Pendin Hi h -PCB cleanu Active None Pendia None tPendi Mane Clo 3L5 313.00113079 335.38.00113093 Cao 335.3$.00113080 Clo 335 38 001I3091 None Yes, see file Yes, see file Yes, see file Yes. see lite No Plu ed E4 surface property plugged and abandoned pfupedy plugged and abandoned property plugged and abandoned Need HRR. PA,Plugged by properly plugged and BLM in 2009. abandoned abandonment suriaoe site rcmediated surface site remediated suriacx V le remediated surface site re medialed Page 13 of 14 SPAR Response with Legacy Wells LrsLxlsx Page 14 of 14 0 vrcTon`ce o BLM 2813 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator i RP 1 Land Mgr Priority CSP Status File #fFlaxid Releases SPAR Workgroup Notes Status Status Add to Site list. Need HRR, PA. SI with workplan and sampling. Chilling mud assessment. Surface Cleanup. Two large breaches on the south side of the berm allow water out of the reserve pit. Plugged properly plugged and surface site Drew Point #1 USGS 1 BLM None None None Yes by BLM in 2410. abandoned remedialed On Site list Need HRR, PA, 51 with workplan and sampling. [frilling mud assessment. Surface Cleanup. In 1976 the reserve pit berm failed and dolling muds/cutlings were released onlo the Poe of Teshekpuk Lake. Plugged by BLM in 2008. Solid waste from camp aril drilling operations buried on northern portion of pad. Erosion has exposed solid properly plugged and surface site East Teshek uk #1 US Navy 1 BLM None Active - waits 3Q0.38.11012652 Ycs, see file waste. abandoned remediated Threatened by erosion. properly plugged and surface site J. W. Dalton $P USGS f BLM None None None No Plu ed b BLM in 20fl5. abandoned rernediated properly plugged and surface site South Barrow #8 USAF 1 BLM None None None Unknown Need HRR, PA, abandoned remediated properly plugged and surface sile South Bartow 911 US Na INorih Slope Bono None None None Unknown Need HRR, PA, abandoned remedialed properly plugged and surface site South Barrow 013 US Na lNerlh Slope Boro None None None Unknown Need HHR, PA, abandoned remedialed properly plugged and surface site South Barrow #15 US Na !North Sloe Boro None None None Unknown Need HRR, PA, abandoned remediated properly plugged and surface site South Barrow #19 US Na 1Nrarlh Sloe Baro None Nana None Unknown Need HRR. PA, abandoned remediated Properly plugged and surface site South Barrow 1x20 US Na Worth Slope Bora None None None Unknown Need HRR, PA, abandoned remedialed Need HRR, PA, dolling mud assessment, containment assessment, possible releases. Breaches allow wafer to flow into and aul of property plugged and surface site Watakpa #2 USGSI BLM None None lNone lyes I reserve and flare pits. labandoned irernediated Page 14 of 14 0 - — -._.w4 . �- —_. 4F3 \I 1/7_.-- r THE STATE _.....' iwa r l k,i 1_7,1i-..J.,V :" L1. e Bal i Conservation 4.,• 1■1.-: ._''%.^.'''' .,...-'1''.7" r'A OfA LA S''"s'''} ! --" Division of Spill Prevention and Response -1-=_-,.e Contaminated Sites Program '"� GOVERNOR SEAN PARNELL ®�, p. 610 University Ave. ALAST' Fairbanks,Alaska 99709-3643 Main:907.451.2181 Fax:907.451.2155 July 11, 2013 . Wayne Svejnoha Supervisory Minerals & Energy Specialist 222 W 7th Avenue, #13 SCANNED MAR 1 12014 Anchorage,Alaska 99513 Re: BLM Legacy Wells Dispute Dear Mr. Svejnoha: The Alaska Department of Environmental Conservation (ADEC) —Contaminated Sites has reviewed the National Petroleum Reserve in Alaska: 2013 Legacy Wells Summary Report dated February 2013, containing updated information on the status of the 136 Legacy Wells located in the National Petroleum Reserve— Alaska (NPR-A), and the draft National Petroleum Reserve in Alaska: 2013 Legacy Wells Strategic Plan dated May 2013. ADEC has also reviewed the response by the Alaska Oil and Gas Conservation Commission (AOGC). We concur with the response by AOGC and have no further comment regarding the priorities. We do have comments about the investigation and cleanup plans presented in the report. With this letter we are outlining regulatory requirements related to the environmental work that is proposed and required as part of these cleanups. ADEC is concerned that the 2013 Legacy Wells Strategic Plan prepared by the BLM does not include either assessment or the contingency for assessment of known,likely, or unknown but possible contaminant releases. In addition,BLM plans for surface cleanup of these wells should be made clear in the plan. At least one of these legacy wells has extensive PCB contamination and has resulted in a multi-year cleanup totaling tens of millions of dollars. At others, solid waste disposal practices have resulted in releases to the environment with estimated cleanup costs in the hundreds of millions. Known releases documented in the records we reviewed include crude oil,gasses,refined oil and fuel, drilling fluids that include various organics,metals,and other chemicals, and unknown contaminants from drums and other containers observed to be damaged and abandoned at the various well sites. There are 13 legacy well sites with known releases currently on the DEC contaminated sites list. Many of these are in the process of being addressed, deaned up, and closed. From our limited records review there are 15 additional legacy well sites with confirmed releases. These should be prioritized for initial records reviews and then added to the BLM contaminated sites list under our cooperative agreement. Suspected releases include fuel releases from operations, storage, and fuel spills at the sites,impacts to various surface water bodies from spilled fluids during drilling and breaches of containment at reserve and flare pits, continued surface runoff from drilling fluids uncontained at several sites, and down-hole substances that were ejected from the holes over time or during blowouts or drilling operations. Wayne Svejnoha 2 July 11, 2013 The BLM plan to address these known, suspected, and unknown releases at legacy well sites is notably absent from the documents presented to date. The three primary regulatory agencies that need to be involved in the plan are ADEC —Contaminated Sites,Alaska Oil& Gas Conservation Commission, and ADEC —EH/Solid Waste. Other agencies will need to be consulted as well. Below we provide recommendations for a coordinated plan using the Uniform Federal Policy for Quality Assurance Project Plans (UFP-QAPP) that will involve all of the regulatory agencies in one coordinated manner. This will allow BLM to address these sites in a consistent and coordinated project which fulfills all of the regulatory requirements so that the sites do not need to be re-visited in the future when they are closed after this project. Attached are our comments on each specific well. The acronyms used on the list include terms that are typically used in a CERCLA type investigation however they are also suitable for investigations conducted under the State of Alaska cleanup rules. These include the following; Historical Records Review (HRR) This is recommended for almost all of the well sites. Much of the information required for these reviews is already contained in various reports and appendices or in BLM files. The Historical Records Review should document the type of releases that might have occurred from drilling operations as well as historical use of the site, and should capture all available information on the drilling fluids used and any product produced or released. Preliminary Assessment (PA) This is recommended for almost all of the well sites. A Preliminary Assessment is a limited scope investigation that provides an assessment of information about a site and its surrounding area to distinguish between sites that pose little or no threat to human health or the environment and sites that require further investigation. The PA is a CERCLA defined document and typically does not require sampling. Site Inspection (SI) If the PA recommends further investigation, then an SI is necessary. The SI is a CERCLA defined document, and it is analogous to an initial report of contamination under state cleanup rules. On some legacy well drillings sites it is evident now that an SI is required just from a review of the reports. An SI investigation typically includes the collection of samples to determine what contaminants are present at the site and whether they are being released into the environment. An approved site specific workplan is required under both CERCLA and 18 AAC 75 prior to SI sampling. The SI typically is not intended to develop a full site characterization,but is limited to determining the presence or absence of a release. If contamination is found after completion of the HRR,PA, and SI then a RI/FS under CERCLA, or a Site Characterization Report and cleanup plan under 18 AAC 75 is required. DEC recommends that BLM incorporate into the strategic plan the processes outlined in this letter. A team of agencies composed of AOGC, DEC-CS, EPA as required, and DEC-EH should address regulatory and technical requirements for these well closures. By cooperating and working together with the regulatory agencies BLM will save time and expense,and regulatory uncertainties will be avoided. The strategic plan should reference a project to prepare a generic workplan. DEC suggests that BLM utilize the generic UFP-QAPP workplan format for the required environmental work. If properly prepared, the workplan could encompass most of the investigations and cleanups required at these sites over multiple years. At other multi-site projects we have found this to be an effective way to reduce uncertainties and risk in these types of investigations. A very small site specific FSP could then be developed as BLM approaches each drilling site. Regulatory decisions made during workplan development would provide more certainty in the planning process for cleanups. !_•\CAAA\ro\FPAA,31 Fn.•;1;r;Pc\r;..a;0.,FP,iP.01 AoPT,P;PS\T1C1T\BT.M\Projects\Leeaev Wells\711 13 Letter to BLM on Legacy Wells.docx Wayne Svejnoha 3 Tuly 11. 2013 Please review the attached list of specific sites. If you have any questions, please do not hesitate to call me at 907-451-2181 or by email at fred.vreeman @alaska.gov. I look forward to working with you as the Federal Government fulfills its requirement to clean up these well drilling sites in Alaska. Sincerely, Fred Vreeman Environmental Program Manager Enclosure: SPAR Response with Legacy Wells cc: Bud Cribley, State Director, Bureau of Land Management Steven Cohn, Deputy State Director for Resources, Bureau of Land Management Jolie Pollet, Branch Chief, Bureau of Land Management Robert Brumbaugh, Geologist, Bureau of Land Management Michael McCrum, Environmental Engineer,Bureau of Land Management Cathy Foerster, Commissioner, Alaska Oil and Gas Conservation Commission Larry Hartig, Commissioner,Alaska Department of Environmental Conservation Kristen Ryan, Director,ADEC Division of Spill Prevention and Response Steve Bainbridge, Program Manager,ADEC Contaminated Sites Program Jennifer Roberts, Program Manager,ADEC Contaminated Sites Program G'\SPAR\CS\Federal Farilitiec\Civilian Federal Aoenriec\fC)1\RT.M\Prnierta\I.eoary Wellc\7 11 11 Letter to RLM nn T.eDacv Wells.docx Q 2 U J 0 m >,,-a m t iii N i 0) N 7 a Um m m m m m m m a co co co m co m m m CO (0 c m o N (-1 .F. 43 -23 i m m CO CO m CO m "' 0) m m CO co m cc m co m o)w m O a a a a a a _a m a a a a s a a a a a) 0 0 0 0 0 0 0 0 a� 0 0 0 0 0 0 0 0 0 > o < CO C C C C C C C C a C C C C C_ C C C C U Z W N N a) a) a) >,-C N U) a) a) a) a) U) N p U O I 0 L L L t "Cl i m 13 O O O O O O O — L O C To C L L L L L L L C C C C -Op C -0 C C C C C C C C L U 7 O U= > N a a U) O m N U) a) m U O .N J N a) a) N o o N C U N `` A U) N N N 0- C CO N N N N N N N N U — O N p 0 L ° a o a a a a a a E -0 0 O 5 5 7 0 U O O 0 5 O 'j '5 'c 'm '7 O E -z U N :° m c a) 0 0 3 c m o a CO CO a -o -`0 3 co Q o 0) 0 0 c o• o 0 o a 0 n C c N, m 0 m - o. 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G EO LOG ICAL SU RVEY National Petroleum Reserve in Alaska 2525 'c' Street - Suite 400 Anchorage, Alaska 99503 UNITED STATES DEPARTMENT OF THE INTERIOR May 11, 1979 Mr. William Van Alen Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Bill: I am transmitting to you, for the State files, a collection of ditch cuttings and core chips from wells drilled on the National Petroleum Reserve in Alaska. The logs, histories, samples, and cores of the seven (7) wells drilled by the U. S. Navy have been released to the public. The logs, samples, and cores from wells drilled by ONPRA will be made available to the public in the near future. Please hold the samples and core chips for these wells confidential until you receive a written release from George Gryc, Chief of ONPRA. The sample and core materials are listed below. U. S. Navy Wells Atigaru Point III Core chips, cores 1 & 2 i) II'" /' \ ,... '.. ", <. f/ l'~. " Ii' u "¿j Iko Bay 111 ft ( , 4/., "'-,~/.. 4,~ .... {¡'I ¢ Gft;¡ ""'¡{' . / '1(.;;. "':', Iv/,. .'f 'fC/& 4'(fl'l r,/~~, "'ell Core chips, cores 1-3 South Barrow 115 Core chips, core 1 South Barrow 1113 Ditch samples, 200' - 2535' Core chips, cores 1-6 South Barrow 1114 Ditch samples, 53' - 2250' South Harrison Bay III Core chips, cores 1 & 2 1 box 3 boxes 1 box 2 boxes 4 boxes 2 boxes 1 box ". .. ; .,-" , ~'.. r ¡. ï ¡ , fæ- ~ JI".,.,.,..,...., .....,. Ç"'qF t:. ~. . ¡. 7d.i.~-~"''''''' ........:/... ~'š"~~?""""f'¡¡'p' 'M "'~- .:"'" _J . . y.J- page_2 - 11 May 79 William Van Alen USGS-ONPRA Wells Drew Point Test Well #1 Ditch samples, 80' -7946 ' Core chips, cores 1-15 East Simpson Test Well 111 Ditch samples, 100'-7739' Core chips, cores 1, 4-10 Note: Cores 2&3 had no recovery. Because of special processing, chips from part of core 8 will be transmitted at a later date. Ikpikpuk Test Hell III (suspended) Ditch samples, 100'-14,210' Core chips, cores 1-12 Kugrua Test Well #1 Ditch samples, 90'-12,594' Core chips, cores 1-3 North Kalikpik Test Well #1 Ditch samples, 80'-7390' Core chips, cores 1-17 Peard Test Well #1 Ditch samples, 88'-10,225' Core chips, cores 1-12 South Barrow Hell 1116 Ditch samples, 200'-2399' Core chips, core 1 (included with ditch samples) South Barrow Well #17 Ditch samples, 100' -2382' . Core chips, cores 1-4 4 boxes 7 boxes ~\ ' 4 boxes 3 boxes 12 boxes 4 boxes ...... ~........1>".~ - ! I 6 boxes 1 box t· !. / f 3 boxes 12 boxes ~. ~ ~. ¡,"; ¡ ~ i:-_. ! ; t . . t· '.' r . ~~~j ~?~~: t~.-'¡' .- ...~.--'..;.. .."":. "", 1·,,·01.. . .' ,,", ~ '. .~.;; ; , 13 boxes 3 boxes 2 boxes 2 boxes 3 boxes '" -#, . . .v ~Page~3 - 11 May 79 William Van Alen Ditch samples, 100 '-2300 ' Core chips, cores 1-5 2 boxes 3 boxes I ~ VSGS-ONPRA Wells (Cont'd) South Barrow Well #19 South Meade Test Well #1 Ditch samples, 95'-9943' Core chips, cores 1-6, 8-10 Note: Core 7 had no recovery. 8 boxes 3 boxes Total..... 109 boxes f', I think we will have another smaller collection for you in the near future. ø-;/. tJ-'d/!¿;~ .~ ~ .. ,"'.." .... '·:t' , ¡ t Sincerely, W. L. Adkison Geologist cc: ONPRA Operations ONPRA Exploration Strategy I'¥f r~ I.r'" Jt,;:-£. I , t ," ~4 I . ¡'t_~" ; - f ;'. . k:~··)';ì:'· ~II:"";'~ ,..... :'~. , .."t!.~:.. r;;.' ~ ~~~...t;~_ ... . . -.' W ce mQw UNITED STATES Section i6 DEPARTMENT OF THE INTERIOR 21N T. GEOLOGICAL SURVEY CONSERVATION DIVISION R. 16W -- --- - - -- »-Umiat INDIVIDUAL WELL RECORD Her. PATENTED LAND January 30, 1979 API S0-023-20007 STATE LAND Date __»___ ___�____ _» _ Reference No. -_ - Lessee or owner U.S. Government Operator U. S. .Navy Wel No. Iko Al Subdivision NEsw Location 1850'N, 2500'E fr SW cor sec 16 21N -16W (straight hole) Drilling ap proved '19-- Well elevation 28'_ GL, 40' FCB feet State Alaska County North Slope Borough Field _.._ Exploratory District Alaska Onshore Drillingcommenced Feb. 1 --p 19 75 Total depth »»__.____2731 ^ feet Drilling ceased »__ ___�__ _ __» » , 19 Initial production Completed for production March 8, 19 75 Gravity A.P.I. Abandonment approved _______ ,19 Geologic Formations Surface Lowest tested Name WELL STATUS Initial R.P. Productive Horizons Depths Contents Yeas JAx. Fss. XA& Ars. KAY Jvxe IJuLy Avg SM. OCT. Nov. Dec. 1975 _»- ----------- spud dri----- drlg --Z'1- --------- ---- ------ ----------- - ---- -- ---- ------- ----------- ----------- ---------- -------- REMAM- ---«Casing»Record P�> >:, _�ni<of3t81s------ Avail ry @ ----- l149'x_660sx»_»».-».»SjQttrd_jjBerfrr�-_DIL_DI 211V-21961 �_»« 10 3/4" 1270', 360�x_______w_».»__.»«.__.»_____�__nENSI�C�Gi�...«_Z.2T321_-. (over) NIT s( sun IN DUrWC:•':r.• U�il t �G S ; ATtS �=.Nr...A. I, s (Srrethrrl11- e+lAetOwranY lto. ss•.ti8sfa. DEPARTMENT OF THE 1 NTER10 �^�«� -^ b RAR►sscA lorox A" !�+ scAIAL ... re.erae "a`) l�' e GEOI-OGICAL SURVEY avais Vama-e, xn COMPTION OR RZECOMPLETlON REPORT AND LOG* W, --.,'.LLE * 'r 1NPIAM. ALLor:L'a OR TAIYS i.AISa .L N,/A- I& : 1.. :•• Wi;LL. ut,. GARf;, wsLL 13wi:I.L ❑ Dar ❑ Other 1. vn r AaAmutim RAMS IL TYi S OF COMPLETIONS - N/A ' RSK WORKetr- rr.ru nt►r. WLLI. OTsa ❑ Petr- ❑ DACK ❑ RENVIL ❑' " Other K PARIS Oa &CASs NAISS, '— N/A z. NAeta ur orrmATOa Director, Naval Petroleum and Oil Shale Reserves D. we" ND. Iko l 1 " Awes►a or. orsAAToa Rm 550, Crystal Plaza No. 6, ; Washington, DC.- 20360* IL FISLO AND !0044 OR W&LPCAT '. Wildcat " 4. L cArwx or a•imi, (Report location dearly sad in aeeord49A= toil say 94990 requiremeAls)• Ataar:ae. 2500 ft FWL, 1850 ft FSL, Sect. 16, .-T21N, R16W 110 W-T:.r—K. asSLOCKASP WavEr UPM x=716,275,- y=6,281,650:.' ; '°"`ARTS At top prod• !•terra! reported .doer t , Sect. -.16, T2111; Itlid Straight hole �' . :, Umiat At total deptlt 14. TSAUXT No. VATS Issuse, •Com OR I& STATS N/A i. .N/A = %•. Alaska 15. DArs sroDOze /L DArs T.D. StACUSD Ii. PATS -,,Pi. IRtedy to Pr ld. Ze •TATJQX6 (Dr. SOLD. at. 614 DiC.)A 1 • LLCT• CAAtKOYiAD OI FEB 75 123 FEB ?5 108 MAR 75 I GR=28' MSL KB-40'MS 30. TOTAL Unit. ;LD A TVD 2i. rwo. iAGK rA am A To 1 23 Ir urLTiPLi COxrI. ; . IKTLRVALS aorAltT TOOLS CAbLx TOOLS 1212 KB HOW HAKTO DRiLLSO ST 2731' XB 2035' KB ee Diagram 100% • : j 0v . 14. PRODUCING INTFATAL(S). Or THIS courucTists—•Tor, NOTTOY. NARIS (YD AND Two) ' � `. � + .�', WAS DIaXIMONAL ,, See Diagram soars:, acus l Ytss �... ................. .........o..� ..,.�� ,._.. .\.Dia, :X3VA.CIIViC %j; =U1ItC 'Yes DIL; Dipmeter, Neutron, Gamma Rav, Sonic', Proximity/Microlog 0 0 7' 23 1270' KB 9 sx permafrost cmt 4.R CASING RECORD (Report all 0trisp0 099 in welt) eAAtxa Sins wsicsr. LD./rr. Dzmt ssz• (SID) note smz • .� csilsrarlKo sscoaD AitOOaT i,ai4sa 14" 75 149' KB TUBING RECORD 22" 1660 t-- -.r SLO PRODZ'iCTION PATS FIRST riOW.;CTjPX t'"U-IOU UCTROD (rloloina, Fa =+ft,. s—aiaa--ua!nd type at sump) WZLL 4TAT as (rrOd-ime ar :v/A Shut in DAT^. Or Tan 110cas TSSriD CROSS SUB FROD'D. TOR 011.-8111. OAST -ACF. WAW —SGU ""AL iATM I TSST )PSatOS ' rLOW. TLr.I\o NWAS. CAsiKO rAfsiiaf CALCI'LATRD OIL -88L. GAa—XCr. MATSS—•Sit. OIL ORAVITT-AM (CORA• 3$ IG -noon 10 P ( -- 0 639 MCFD ( 0 N. ourosalox or C." (Sold, used for Jast, vented, am) � Tsar wrsl+sasss by - Au. W:T OJ ATTACU349STS . Location diagram, completion profile I& I Lereby cert:iy that the torerola: and - tae ed Informapoa to eomyiete and Correct as determlaed troal &UavaAa T31.1-3. officer in Charge 'DA 17 KAY 75 "(See'Ineructions end Speces for Accitionol Drou on Reverse Sitio) 1074" ��� 1190' KB permafrost cmt -14-/,," .1810 :sx permafrost cmt 1360 0 0 7' 23 1270' KB 9 sx permafrost cmt •0.. 20. LITER RECORD E0. TUBING RECORD sus rot (UP) sorra= (XV) "Ctrs czuzxTa SCAzzn (NO) •reit D"M am (Sty we=ts ser (me) 7' 1212 KB 1950 KB •0 ee DlaQ. 2 / " 1939 KB NA ill. FTAro"TION isca" ilatervel, flat Umber) See diagram . .: . - . 4444.... ..- 4444..... � �.�.... •--"- .. » ' ACID, SHOT. FRACTURE, CEMENT SQV=E. r, -G, DSPM .3. RTAL ($D) AISOQMTKIND Or ISATsatAL Lata None . SLO PRODZ'iCTION PATS FIRST riOW.;CTjPX t'"U-IOU UCTROD (rloloina, Fa =+ft,. s—aiaa--ua!nd type at sump) WZLL 4TAT as (rrOd-ime ar :v/A Shut in DAT^. Or Tan 110cas TSSriD CROSS SUB FROD'D. TOR 011.-8111. OAST -ACF. WAW —SGU ""AL iATM I TSST )PSatOS ' rLOW. TLr.I\o NWAS. CAsiKO rAfsiiaf CALCI'LATRD OIL -88L. GAa—XCr. MATSS—•Sit. OIL ORAVITT-AM (CORA• 3$ IG -noon 10 P ( -- 0 639 MCFD ( 0 N. ourosalox or C." (Sold, used for Jast, vented, am) � Tsar wrsl+sasss by - Au. W:T OJ ATTACU349STS . Location diagram, completion profile I& I Lereby cert:iy that the torerola: and - tae ed Informapoa to eomyiete and Correct as determlaed troal &UavaAa T31.1-3. officer in Charge 'DA 17 KAY 75 "(See'Ineructions end Speces for Accitionol Drou on Reverse Sitio) hole with bit #3 from 13 �FEB 75 Froin 0001 to 2400 drilled -q%" 1220' to 17751.' One hour down time {circ. samples). Drilled last 24 hours 555'. 14 FEB 75 0001 to 0230 drilled 95/e" hole with bit #3 from 1775'. to 1823'. From 0230 to 0630 circulated and conditioned mud. Repaired drum. chain. From 0630 to 0900 tripped out. ..Well kicked. One stand of drill pipe and bottom hole assembly still in role. From 0900 to' 630 picked up inside blowout preventer. Tripped in, circulated out gas cut mud, 6 to 8 stand intervals. From 1630 to 1830 circulated and conditioned mud.' From 1830 to 2200 tripped. for bit. From 2200 to 2300 rearded and washed to bottom. From 2300 to 2400 drilled 95/&" hole with bit #4 from 1823' to 1842'. Drilled last 24 hours 671. 15 FEB 75 From 0001 to 2400, drilled 9% "'hole with bit #4 from 1842' to 20821. Two hours down time. One and one half hours circulated for samples. One half hour repaired pump.. Mud weight was lowered from 11.7 lb/gal to 10.9 lb/gal.. Well flowed under static conditions. Mud weight was increased to 11.5 lb/gal. Drilled last 24 hours 2401. 16 FEB 75 From 0001 to 0130,.drilled 95/e" hole with bit #4. From 0130 to 0315 packed swivel. From 0315 to 0630 drilled with bit 704. From 0630 to 1300, tripped for bit. There were no gas kicks while tripping with 11.4 lb/gal mud. From 1300 to 2400, drilled 9 /8" hole with bit #5 from 2121' to 22051. Drilled last 24 hours 123'. 17 FEB 75 From 0001 to 1800, drilled 9%" hole with bit #5 from 2205' to 2320'. Two hours down time. One hour spent repairing rig. One hour, circ. samples. From 1800 to 2000, tripped out for core barrel. From 2000 to 2230 picked up core barrel and welded flow line. From 2230 to 2400 tripped in with core barrel. There were no gas kicks while tripping with.11.4 lb/gal mud. Drilled last 24 hours 105'. 18 FEB 75 From 0001 to 0130 tripped in. From 0130 to 1430 cut 7%" x 31/2" core #1 with 60' Christensen core barrel and Navy owned diamond core head, from 2320' to 23801. From 1430 to 1730 tripped out -(SLM). From 1750 to 1900 dumped core and dressed core barrel. From .1900 to 2000 tripped in with bit 4V6. Well kicked with mud weight of 11.0 lb/gal. From 2000 to 2100 circulated and conditioned mud at 12001. From 2100 to 2200, tripped in. From 2200 to 2400, reamed 7%" to 9%" hole with bit A6, from 2337' to 2357'. SLM correction 17'.. Depth of core #1 - 2337' to 23961. Cut 59' of core. Recovered 50.51. Drilled last 24 hours 761. (Includes 17' isram) corrections) f DRi L L I NG AND C 0 M P L E T 1 0 H REPORT I.K0 TEST WELL N0. 1 NAVAL PETROLEUM RESERVE NO. 4 BARROW, ALASKA .99723 17 MAY 1975 A �� qc-1 W LLIAM JAC_�' %T RICHARD V.. SHAFERi' P.E. ARCTIC OILFIELD SPECIALIST LCDR, CEC, USN OFFICER INCHARGE d •% Q �•f••ff•foi�llf• 0*000f006 - PAO , • HM•M • ' w V t c• c, TABLE OF CONTENTS 1. INTRODUCTION ANM SCOPE .2. WELL DATA 2.1 Data Summary 2.2 Wellhead Diagram , 2.3 Wellbore Completion Profile 2.4 Location Map 3. DRILLING JOURNAL 4. DRILLING CREW 5. PERMITS AND REPORTS 5.1 Department of Interior Permit Application - 5.2 State of Alaska Permit Application .5.3-Department of Interior Completion Report 5.4 State of Alaska Completion Report r b. LAGS AND TESTS 6.1 Production Test 7. GEOLOGICAL CONSIDERATIONS 7.1 Lithology i Z. WL DATA '. 2.1 DATA SUMMARY rIELD: Iko Gas Field PROPERTY: Naval Petroleum Reserve No. 4 (U. S. Government) WELL NO. Gas Well'No. 1 LOCATION:. 2500 -ft. FWL, 1850 ft.. FSL, Sec. 16 T21N, R16W, UPM; W 716,275, y 6,281,650 ELEVATION: Ground Elevation = 28 ft YISL (approx.) DATUM: All depth measurements are referenced to kelly bushing top -(KB). KB is'12 ft. above ground level. DATE OF REPORT: 17 May 1975 DRILLED WITH: Navy owned Cardwell Model H drilling rig No.. 3 DATE CO3MLAINSENCED DRILLING: PRODUCTION DATA: Calculated absolute open flow potential 639 MCF/day. (See details in Section 6.1 of this report. PRODUCING IIv% 14ATION:. Unnamed sandy shales. TOTAL DEPTH: . 2731 ft, plugged back to 2035 ft. CASING AND CEMENTING PROGRAM: 24 -in OD Conductor Piper l joint, cemented at `18 " t: KB. 16 -in OD Casing: 4 joints, N-801 75 lb/ft. range 3, 8 Rnd TQC. Cemented at 149 KB with 660 sacks permafrost cement. LINER: TUBING: 109/4 -in OD Casing: 37 Joints, P-11.0, 51 lb/ft Range 2, Buttress T&C, topped with 1 joint N-80, 51 lb/ft Range 3, 8 Rnd, T&C. Cemented at 1190 ft KB with 810 sacks of permafrost cement. 7 -in OD Casing: 32 points, Extremeline 23 1b/ft Range 3, f ush joint. Cemented at 1270 ft with 360 sacks of permafrost cement. 51/27in Liner, 20 joints, J-55, 20 lb/ft, Range 3. Bottom joint orange -peeled and spaded. Slotted over the following intervals (KB): 1242 to 1274 1307 to 1370 1469 to 1536 1562 to 1648 1732 to 1775 ' -1905 to 1950 27/9 -in Hyd rill CS Tubing, 61 joints, J-55, 6.5 'lb/ft, range 2, 8-Rnd, T&C. Tubing bottom at ..1942 ft. KB. WELLHEAD: REGAN 109/4 -in Well head, OCT Tubing.Head, Type "U" 9 -in OD, 10 -in 30002V X 6-ih 5000# Studded Outlets MASTER VALVE: OCT Model 20, 3-in*3000# x 3 -in L.P.. SURVEYS: Schlumberger Dual Induction Laterolog Four Arm High Resolution Continuous Dipmeter Compensated Neutron Formation Density Compensated Formation Density Log (Ga ua-Gamma) Borehole Compensated Sonic Log Proximity Log-Microlog (with Caliper) Cement BondLoq Saraband _. Borehole Geo=metry Log Petro-Tech mud L g Bureau of Mines Gas sample analysis (Halliburton Successful drill stem testswire made at 2534-2729 ft. d 2.2 We L L H E A D 'D I-AGRANi L - -2" x 10" Doub l e 10� 3 00c 6 - 000 6 14000 Extra Strong 21! Nordstrom t Valve, Fig. 2344 ! ` 2"• caul I Plug, _ Extra Strong —.. Rogan WolIhoad 16" 3000" al chined to.sl ip on 103/4': casing 1. i LP Thread C.- T.' Mode 1 20 . LP Thread x 10" -Doub I•e tra Strong Nordstrom ' Ive, Fig. 2344 2" Nordstrom Valv©, Fig. 2344 - i01K," Casing 51 Ib/ft 7" Casing 23 lb/ft — 27/i" Hydri I 1 CS Tubing 2.50 Ib/ft WELLHEAD IKO WELL N0. 1 10� 3 00c 10 •- 300 LP Thread C.- T.' Mode 1 20 . LP Thread x 10" -Doub I•e tra Strong Nordstrom ' Ive, Fig. 2344 2" Nordstrom Valv©, Fig. 2344 - i01K," Casing 51 Ib/ft 7" Casing 23 lb/ft — 27/i" Hydri I 1 CS Tubing 2.50 Ib/ft WELLHEAD IKO WELL N0. 1 r 2.3 IK0 N0, 1 WELLBORE COMPLETION PROFILE Depths KB 'tiJ j t :• �.• _'' v/�� (feet) •"' 1• 24" Conductor Pipe, 1 it. 22" Hole l 16" N-80 Casing: 4 its, 75lb/ft Range.3, 8 Rnd T b C . 149 _"�"•"- '-•-.',� - - . • ' 166 t43/411 Hole 103/41" P-110 Csg: 37 its, 51lb/ft, R-2 Buttress TbC, Topped w/) it. 1031,," N-80 Csg: 511b/ft, R-3, 8 Rnd T&C " 27/8" Hydritl CS Tubing; 61 its, 6.51/ft R 1190 -'-- 1212 ?- BROWN Liner Hanger . 1228 --'-" �,--- 711 ExtremeIine Casing, 32 its, 231/ft Range 3, Flush joint 1270 Extremeline Casing: 32 its, 231/ft Range 3, flush joint. Slotted over the. following intervals: 1242 to 1274 1562 to 1648. 1307 to 1370 1732 to 1775 1469 to 1536 t905 to 1950 1939 1950 - ?035 : , • • ; .v- Cement plug 2210 95/011 hole 2702 71/." core ho I e 2731:.• 1. INTRODUCTION AND SCOPE This report describes work done in drilling and completion of 1ko Test Well No. 1 near Iko Bay on the Arctic coastal plain in the north central portion of Naval Petroleum Reserve No. 4, This exploratory well was drilled under the supervision of the.Officer in Charge, Naval Petroleum Reserve No. 4 by ITT/Arctic Services, Inc. for the Director, Naval Petroleum and Oil -Shale Reserves. The purpose of this well was to test for the presence of oil.or gas productive formations within an anticlinal structure east of the Barrow High Structure. Limited gas productivity was found in the sandy shale formations in the upper part of the well. Shows of oil but no productive potential was found in the Triassic formations just above "basement" (Argillite). The lower sections were plugged back and an open hole gas well completion was made in the upper part of the well. 29 28 27 ,(25 35 3P 33 34 . 36 TZPIY T2IN ..... - r."o"o o /2 8 7 ro C l7 Yaoo� /6 /5 14 Ae /7 20 2/ 22 23 2f t /9 20 -IK0 Vo, l WELL LOCATION scales 1: 63,360 ;5-G 7"1bliioe2'4J C y 3." D R I L L'I N G. J O U R N A L 20 JAN 75 From 0600 to 1800 repaired rig and equipment. 21 JAN 75 From 0600 to 1800 continued to repair rig and equipment. 22 JAN 75 From 0600 to 1800 repaired rig and equipment. 23'JAN 75 From 0600 to 1800 repaired rig and equipment. 24 JAN 75 From 0600 to 1000 skidded rig over hole. From 1000 to 1800 started rigging up. 25 JAN 75 From 0600 to 1800, continued to rig up. 26 JAN 75 From 0600 to 1800, worked on equipment. High winds and drifting snow prevented crews from going to well site. 27 JAN 75 Continued working on equipment as weather prevented crews 'from. going �to well site. 28 JAN 75 Continued working on equipment as weather prevented -crews from going to well site. 29 JAN 75 From 0600 to 1800 continued rigging up. 30 JAN 75 From 0600 to 1800 continued rigging up. 31 JAN 75From 0001 to 2400 continued rigging up. Broke tour. 01 FEB 75 rom 0001 to 1200 rigged up. From 1200 to 2350 continued to rig up and mixed CaCl2. Spudded at 2850 With bit 92, 241/4 "• 02 FEB 75 From 0001 to 0100, drilled 141/4* hole with bit #1. From 0100 to 0800 repaired mud and steam lines; worked on boiler. From 0800 to 0900 picked up drill collars. From 0900 to 1500 drilled 143/4" hole from 18' to 1661. From 1500 to 2400 opened hole from 143/4" to 22" from 18' to 75' with rerun pilot hole opener. Depth 1661. Total drilled last 24 hours was 1581. 03 FEB 75 From 0001 to 1100 opened hole from 143/4" to 22" from 75' to 1661. From 110-0 to 1500 conditioned hole. Pulled 22" hole opener. Laid down bottom hole assembly: From 1500 to 1830 ran 4 joints (1491) of 16" N80, range 3 casing, and 41/Z" drill pipe inner string equipped with Halliburton latch sub. From 1830 to 2400 cemented casing with 660' sacks of permafrost cement. Cement in place at 2400 hours. 04 FEB 75 From 0001 to 2400 hours, waited on cenent. 05 FEB 75 From 0001 to -00630 waited on cement. 'rippled up. From 0630 to 0900 drilled out float collar, cement and shoe. From 0900 to 1430 drilled 143/411 hole with bit *l. From. 1430 to 1645, waited on water. Circulated and conditioned mud. From 1645 to 1800 drilled. From 1800 to 1845 re - ]paired drum chain. From 1845 to 2045 drilled. From 2045 to 2400 waited on water. Total depth 4821. Drilled last 24 hours 316'.. 06 FEB 75 From 0001 to 124.5 waited on water. From 1245 to 1800 drilled 143/4" hole with bit #1. -From 1800 to 1900 un- plugged flow line. From 1900 to. 2130 drilled. From 2130 to 2230 unplugged flow line. From 2230 to 2300 drilled. From 2300 to 2330 unplugged flow line. From 2330 to 2400 drilled. Total depth 7681. Dri.1led last 24 hours 2861. 07 FEB 75 From 0001 to 0200 drilled 143/4" hole with bit n. From 0200 to 0230 cleaned. flow line. From 0200 to 0615 drilled `with bit #1 from 768' to 8571. From 0615 to 1130, tripped ..for bit. From 1130 to 1730 drilled with bit `:2. From 1730 to 1845 cleaned shaker tank. From 1845 to 2400 drilled. Total depth 10371. Drilled last 24 hours 2691. 08 FEB 75 From 0001 to 1430, drilled 143/4" hole with bit ;2. From 1430 to 1900 conditioned hole for logs. From 1900 'to 2230. tripped out. From 2230 to 2400 ran Schlumberger logs. Total depth 12201. Drilled last 24 hours 183'. 09 FEB 75 From 0001 to 0400 ran Schlumberger borehole. Compensated Sonic Log (with caliper). From 0400 to*1700 ran 37 joints 103/4" 51 lb/ft P-110, Range 2 buttress T&C casing. Topped •� with l.jt. 103/40, 51-lb/ft,.N80, Range 3,. 8 Rnd T&C casing equipped with Halliburton guide shoe and float collar 61.5 feet above shoe. Four centralizers were used. Cemented. From 1700 to 2400 cemented with 810 sacks of permafrost cement, preceded by 10 bbls. caustic soda solution (100 lbs. caustic soda). 10 FEB 75 From 0001 to, 0130 squeezed cement. Bumped plug w/500 PSI. Cement in place at 0130. From 0130 to 2400 WOC. 11 FEB 75 From 0001 to 2400, waited on cement. Welded on 103/4." head. Nippled up. 12 FEB 75 From 0001 to 1200 TIOC. Nippled up. Tested blowout pre- venters. From 1200 to 1430 drilled cement. From 1430 to 1600 tripped out for cement bond log. From 1600 to 2100 ran cement bond log, cleaned pits and mixed mud. From 2100 to 2400 tripped in with bit #3. Displaced CaC11 solution with gel base mud. ' 19 IZB 75 From 0301 to 0430, rea..red 75/$" to 95/0" with -bit 16 from 2357 to 2396. From 0430 to 0730, drilled 95/8" hole from 2396' to 24101. From 0700 to 1000 circulated and condi tioned mud for tripping weight 11.4 lb/gal. From 1000 to 1230 tripped out for core barrel. From 1230 to 1330 re- paired rotary clutch. Picked up core barrel. From 1330 to 1545 tripped in with core barrel. From 1545 to 2400 cut core #2, from 24101 to 24441. Drilled last 24 hours 481. There were no gas kicks while tripping. 20 FEB.75 From 0001 to 0645, cut core #2 from 2444' to 24701. From 0645 to 0715, • pulled out of 75/8" rat hole (2 stands) . From 0715 to 0900, mixed and conditioned mud for trip. 'Mud weight 11.8 lb/gal. From 0900 to 1230, tripped out. From 1230 to 1330 dumped core and dressed core barrel. Made full recovery on core 42. From 1330 to 1550 tripped in with bit V. From 1500 to 2030 reamed 75/4" to 9'/8" hole, from 2410' to 24701. From 2030 to 2400, drilled 95/A" hole with bit #7 from 2470' to 24921. No gas kicks while tripping. Drilled last 24 hours 481. 21 FEB 75 From 0001 to 0900, drilled 95/8" hole with bit #7 from 2492' to 25331. From 0900 to 1130 circulated and conditioned mud for trip wt. 11.6 lb/gal. From 1130 to 1430 tripped for bit. From 1430 to 2330, drilled 95/8" hole with bit 48 from 2533' to 257.21. One half hour down time (circ. samples). No gas kicks tripping with 11.6 lb/gal mud. Drilled last 24 hours 801. 22 :'EB 7S From 0001 to 0430, tripped for bit. From 0430 to 0800, drilled 95/8" hole with bit #9. From 0800 to 0830 tight- ened brakes. From 0830 to 1000 drilled. From 1000 to 1200 checked BOP, cleaned shaker tank and repaired shale shaker. From 1200 to 2400 drilled 2572' to 2678'. ro gas kicks while tripping with 11.6 lb/gal mud. Drilled last 24 hours 1061. 23 FEB 75 From 0001 to 0400 drilled 95/8" hole with bit #2, from .2678' to 27021. From 0400 to 1200, tripped for core barrel. From 1200 to 2400 cut core #3 from 2702' to 27311. No gas kicks while tripping with 11.4 lb/gal mud. Drilled last 24 hours 531. 4 FEB 75 From 0001 to 0300.pulled core 43. From 0300 to 0400 laid down core barrel. From 0400 to 1200 tripped in with rerun bit #6. Conditioned hole for Schlumberger logs. From 1330 to 2400 ran logs. 5 FEB 75 From 0001 to 2400, ran Schlumberger logs. 26 FEB 75 From 0001 to 0230 ran Schlumberger logs. From 0230 to 0900 tripped in with bit #10, 5/y" rerun. Conditioned, hole for DS-- From 0900 to 1200 tripped out for DST. From 1200 to 2000 picked up test tools and tripped in for DST. From 2000 to 2300 tested. From 2300 to 2400 tripped out with s. 27 FEB 75 From 0001 to 0300, tripped out with test tools. From 0300 to 1400 laid down test tools - 75/4" drill collars. From 1400 to 1600 tripped in with open ended 31/2" drill pipe to plug back*(SLM).' From 1600 to.2100 circulated and conditioned hole. From 2100•to 2400 plugged back with 120 sacks of Class G cement., Plugged from 2000 to 2210. Cement in place at 2300. 28 FEB 75 From 0001 to 2400, waited on cement./(tripped to -pick up bit) ; O1 MAR 75 From 0001 to 1400 waited on cement. From 1400 to 1430 polished cement plug. Top of plug at 20351. From 1430 to 1530 -tripped out. From 1530 to 2000 ran 32 jts. (1270') of 7" 23 lb/ft, Range 3, Extremeline casing. From 2000 to 2300 cemented with 360 sacks of permafrost cement. Cement in place at 2300. From 2300 to 2400 WOC. s. 02 .vAR 75 From 0001 to 1200 WOC. From 1200 to 2100 cemented through 1" pipe from surface to 160' with 50 sacks of permafrost cement. From 2100 to 2400 cut off 7" casing. Nippled up. - 03 MAR 75 From 0001 to 2400 WOC. Tripped in with bit #10 - 57/a"- 04 MAR 75 From 0001 to 0100, tested BOP. From 0100 to 0530, drilled out baffle collar, cement and shoe. From 0520 to 0930 circulated and conditioned mud. From 0930 to 1200 laid down 31/2" drill pipe. From 1200 to 1600 well kicked. Circulated and conditioned mud. From 1800 to 1900 laid down 31/2" drill pipe. From 1900 to 2100 changed rams in Shaffer BOP. From 2100 to 2400 picked up 2'/a" tubing.. Well kicked with 11.4 lb/gal mud. 05 MAR 75 From 0001 to 0130 picked up tubing. From 0130 to 1600 rigged up swab. From 1600 to 2230 swabbed. From 2230 , to 2400 flared well. 06 INIAR 75 From 0001 to 0300, tested well. From 0300 to 1200 killed well. Mixed mud and conditioned hole for 51/2" liner. From 1200 to 1400 tripped out. At 1400 picked up and ran 51/z" liner. 07 IMAR 75 From 0001 to 0500 worked liner to bottom. Tong die dropped in hole on top of liner hanger. At 0500 pulled tubing in two. At 0730 set liner hanger at 1212' after retrieving fish. From 0730 to 1300 -circulated and con- ditioned mud. From 1300 to 1730 tripped out, laid down hanger setting tools, drill collars, and kelly. From 1730 to 2230'tripped in and hung tubing. From 2230 to 2400 laid down BOP. 08 MAR 75 From 0001 to 0600 nippled up well head. From 0600 to 0800 rigged up swab. From 0800 to 2100 swabbed. From 2100 to 2400 flared well. 09'MAR 75 From 0001 to 2400 rigged down. 10 MAR 75 From 0630 to 1830 rigged down, using one crew 12 hours. 11 MAR 75 From 0630 to 1830 continued to rig down. 12 MAR 75 From 0630 to 1830 finished rigging down and started to move equipment. 13 MAR 75 From 0630 to 1830 continued to move equipment. 14 MAR 75 From 0630 to 1830 continued to move equipment. 15 MAR 75 From 0630 to 1830 moved rig. 16 MAR 75 Finished moving equip4ment from 0630 to 1830. 1015-1030 Poor recovery. 1030-1050 Clay: medium to dark gray, earthy occasionally, silty, occasionally hard brown siltstone laminae. Poor sample: 1050-1110 As above. 1110-1140 As above, grading to very fine-grained loose sd, traces fine disseminated pyrite. 1140-1170 Clay, as above, interbedded with eight gray fine-grained sandstone.. 1170-1220 Clay: medium gray, with fine-grained sandstone laminae, some friable -loose. 1220-1270 Clay and sand: as 1170-1220. 1270-1275 Siltstone: light gray to tan. 1275-1290 Sandstone: dark gray, very fine-grained, moderately carbonaceous, pyritic. Poor sample. �1 A-0 a.. %_/ i+ L V A: i 10475 Sample Description: U.S. Navy #1 iKO BAY .�. Depth " 190-280 Clay: gray, occasionally silty, earthy, spongy texture, sticky, traces fine-grained loose sand, trace gilsonite from cement. Poor samples. 280-420 Clay: gray, as above. 420-480 Clay: gray, as above, occasional interbeds of sandstone, fine- grained, quartzose with trace yellow fluorescence. Poor samples. 480-580 Clay: medium gray, more firm than above when dry, less.spongy " texture. Poor sample. ` 580-640 Clay: clay shale: dark gray occasionally sandy with minor yellow fluorescence and cut fluorescence. Poor samples. 640-680 Ciay:� dark gray, sandy and clay dark gray, slightly silty,.minor yellow fluorescence. Poor sample. 680-780.. Clay: light to medium gray, earthy, silty in part, slightly micaceous in part. -Poor sample. 780-1015 Clay: and silty clay: sticky, earthy, soft, plastic, occasionally sandy. Poor sample. 1015-1030 Poor recovery. 1030-1050 Clay: medium to dark gray, earthy occasionally, silty, occasionally hard brown siltstone laminae. Poor sample: 1050-1110 As above. 1110-1140 As above, grading to very fine-grained loose sd, traces fine disseminated pyrite. 1140-1170 Clay, as above, interbedded with eight gray fine-grained sandstone.. 1170-1220 Clay: medium gray, with fine-grained sandstone laminae, some friable -loose. 1220-1270 Clay and sand: as 1170-1220. 1270-1275 Siltstone: light gray to tan. 1275-1290 Sandstone: dark gray, very fine-grained, moderately carbonaceous, pyritic. Poor sample. 1290-1325 Sandstone: as above, very poor sample,. trace weak silver blue fluorescence, no cut, does not appear mineral. 1325-1345 Siltstone; as above, and sandstone, medium gray fine to medium grained, loose to moderately consolidated, carbonaceous, well - sorted, subrounded, slightly calcareous. 1345-1415 Sandstone: as above, with occasional trace glauc, interbedded with siltstone as above. 1415-1450 Claystone: medium gray, silty, with sandstone medium gray mottled . black with carbonaceous fragiments, very fine-grained, dull gold fluorescence and streaming cut fluorescence, calcareous, tite. 1450-1495 Claystone: medium gray silty with interbedded sandstone, as above, some silty occasionally carbonaceous minor dull gold fluorescence. 1495-1520 No samples. 1520-1535 Shale: medium -gray, massive, chert granules to 3.0 mm tan, it. gray to light yellow gray, cryptocrystalline trace very fine sand- stone with dull gold fluorescence, carbonaceous, traces -black vitreous. solid hydrocarbons (probably giisonitefrom cement) traces pyrite, disseminated and fine crystalline clusters, slight silver blue fluorescence, no cut. 1535-1615 Siltstone: gray to medium gray, carbonaceous with traces limestone tan, fine crystalline, some cryptocrystalline, chert granules common 1535-1550. 1615-1620 Siltstone: as above, with light gray to tan cryptocrystalline limestone. 1620-1655 Siltstone, as above. 1655-1690 Siltstone and silty shale: medium to dark gray, carboneceous, slightly calcareous, with occasional calcite grains. Quartz grains at 1670 + 3MM. 1690-1710 Siltstone and silty shale: medium to dark gray, carbonaceous, slightly calcareous, with occasional limestone, tan, crypto- crystalline. Chert and quartz granules, sub rounded, scattered pyrite, minor yellow fluorescence, coarse calcite 1705-1710. 1710-1745 Shale &•siltstone: as above, occasional claystone, green, sub vitreous, subwaxy to waxy, plastic, abundant pyrite. Sandstone, clear, medium to coarse grained. Less limestone than above. Mineral fluorescence only. 1745-1750 Siltstone: as above, slight increase in fine- to very fine- grained sand. 1750-1780. Siltstone: as above, increase in limestone, probably thin stringers or calcareous nodules. Thin interbedded sandstones, mottled gray, fine- to very fine-grained, carbonaceous, silty. 1780-1820 1820-1845 Siltstone & shale: as above, dark gray, micaceous, very fine sand, quartz pebbles, pyrite, carbonaceous. Shale: dark.gray, massive, carbonaceous, and silty shale, medium gray. Siltstone, light gray, very slightly sandy, pyritized plant fragments apparently with thin interbeds sandstone, medium. gray salt and pepper, very fine- to medium -grained, predominantly, very fine to fine, calcareous, carbonaceous, rounded clear grains. 1845-1865 Shale: dark gray, some silty, carbonaceous, probably massive abund, pyrite or marcasite, some floating. quartz, medium- to coarse-grained, clear, well rounded. 1865-1870 As above: chert pebbles common. 1870-1890 Shale: dark gray, with traces chert and pyrite, bentonitic` samples poor, hole booting.and clays balling. 1890-1920 As above. 1920-1925 Sandstone: light gray to clear, medium- to coarse-grained, angular to sub angular, loose, weak yellow fluorescence, faint cut fluorescence. 1925-1930 Shale: as above, trace limestone, tan, extremely argillaceous. 1930-1975 Claystone: probably water sensitive shales, light to medium gray, soft, sticky, bentonitic?, slightly carbonaceous, occasionally calcareous. 1975-2000 Shale and claystone as above. 2000-2035 Claystone: as above. 2035-2050 Claystone and sandstone: salt & upper, very fine-grained talc., tate, possible cavings. 2050-2100. Claystone: probably water sensitive shales, as above. 2100-2130 Shale: light to medium gray,. slightly silty, micaceous, fissile. 2130-2140 Shale: light gray as above, trace salt & pepper, very fine-grained sandstone, with -yellow fluorescence, cut fluorescence. 2140-2205 Shale: light gray slightly silty, slightly calcareous, sands sabove ou,onaceous in part, occasional scattered salt and pepper 2205-2250 Shale: light to medium gray, slightly silty, micaceous, some black carbonaceous, fissile, occasional limestone fragment, tan argilla ceous, occasional floating fine- to medium -grained rounded quartz. 2250-2260 Shale: as above, more sandy, calcareous. a M 2260-2290 Shale: as 2205-225-0, occasional pyrite. 2290-2331 Sandstone: light gray, vary fine-grained to fine-grained, sub- angular to sub -rounded, quartzose, slightly carbonaceous pyritic . in part, argillaceous, questionable slight stain, probably thin interbeds with shale as'above. 2231-2396 See core description 01. 2396-2410 Sandstone: medium gray to tan, very fine-grained to fine-grained, angular to subangular fair to well sorted, slight salt and pepper, poor.porosity, probably low permeability, friable, weak brown oil stain, good fluorescence and cut fluorescence on crush. 2410-2470 See core description 02. 2470-2540 Sandstone: as above, shale as'above and interbedded siltstone, medium gray, massive, siliceous, hard some slightly micaceous, slightly sandy, pyritic. 2450-2590 Sandstone: medium gray to tan, very fine-grained to fine-grained rarely medium, argillaceous, fair sorting, weak tan oil stain, dull gold fluorescence, fair to good cut & cut fluorescence, probably interbedded. 2590-2600, Siltstone: medium to dark gray and red brown limonitic, calcareous in part, slightly sandy, very fine-grained, argillaceous, pseudo oolites, ? siderite, some hematite stain. 2000-2650 Sandstone: light gray green, very fine-grained to fine-grained subangular to sub -rounded, salt and pepper, poor to fair sorting loose to moderately consolidated, very calcareous in part, traces limestone: gray fine crystalline to earthy argillaceous. 2650-2680 Siltstone light gray green, some sandy very fine-grained, non - calcareous. Claystone, light green to moderate green, waxy, plastic, may be of volcanic origin. 2680-2700 Sandstone, siltstone and interbedded claystone: as above, white crystalline calcite at 2700. 2700-2733 See core description #3. IU. S. N. IKO BAY #1 CORED INTERVALS CORE #1 2337'-2396' CUT 59' REC 50.5' CORING TIME 12, 8,18,18,12, 12,16,12,12,12, 12,10,12,10,14, 10,10,10,12,12, MINUTES/FOOT 10, ?,15,22,12, 14,16,12,16,12 16,12,12,10,12, 14,12,14,12, ?, Coring time destroyed or not recorded after 39'. Averaged 12- 14 minutes/foot. DEPTH 2337-38 Siltstone: and gry, s/carb, sl mic,,hrd, v. sl sdy; vfg, tr. min. fluor f 2338-39 Sandstone: and gry, . sli S&P, vfg, sr -r, sl carb, hrd, tite, no show. 2339-44.5 Siltstone: and gry, sdy, vfg, carb, argil, hrd, tite, no show. 2344.5-45 Sandstone: and gry, vfg, slty, carb hrd tite, no show 2345-45.5 Siltstone: as in 2339-44.5 2345.5-48.25 Sandstone: It-md gry, vfg sl, S&P sr -r, sl carb, hrd, tite, sl porosity, no show. 2348.25-51.7 Sandstone: It-md gry, vfg, sity, sl S&P, carb, sr-sa, sl mic, tr grn vitreous min. predom tite, occ spotty porosity no perm 2351.7-55 Sandstone: It-md gry, vfg, slty, ? ashy, sr -r, well sorted, sl carb hrd, tite, no show. 2355-56.75 Siltstone: It gry, argil scattered dr.k mineral tr, of x-talline pyrite in filmy elongated aggregates, hrd, tite, no show, some carb laminae, occ v. sl mic. 2356.75-57.5' Siltstone: vfg ss, It gry, v siliceous, extr hrd, dns subcon- choidal frac, appears to be sl carb, tits, no show. 2357.5-60.1 Sandstone: and gry, vfg, occ fg, r-sa, scattered fn drk cht, scat carb, v. sli talc, mod friable, carb laminae, sl P & P 2360.0-68.0 Siltstone: .It gry-med gry wet, ass w/ibd thin v.f.g. ss. stringers and carb laminae hard, tite no show, dips up to•15°, may or may not be reliable. 2368.0-71.7 Sandstone: It-med gry vfg, sty, carb, sa-r foss (pelcy, gastro?), lig w/plant frags partially replaced by pyrite, bleeding oil at 2371, tite. CORE i2 - 2410' - 2470' CUT & REC 60' CORING TIME 5,5,6,6,69 697,7,6,59 525,63,5,69 524,49495, 6,5,5,6,8, 8,10,8,8,9, 7,8,5,5,? ?,?,7,8,8, 8+7.7,8,7, 7,9,7,8,9, 8,8,8,898, 8,7,897,7, 2410-2435 Sandstone: It-med gry, drk gry & carb intervals vfg, slty, carb, sr -r, fair sorting, well cmtd, sil cmt, vfg, disspyrite,. some pyrite replace..►ent, carb frag, hrd, tite, sl fossiliferous,- frag unident, bleeding oil & gas, dull gold fluor 30-70% good cut & cut fluor and alt ste, It-med gry, sdy, vfg, occ, sl show (10-20% fluor), and comprising approx 30% of this interval. 2435-2437. Siltstone: 1t-med gry, carb, sl sdy, sl mic, argil, spotted yel fluor, in part no fluor, hrd, Lite. 2437-2439 Shale: drk gry-blk fissile, sl carb, occ disseminated pyrite, app dip flat -3 2439-2470 Shale: med-drk gry, slty, massive, sl carb, sl mic, fossi-liferous, frag of pelecypods, gastopods, 7 low spired type, occ woody frag, coaiified - sub bit coal replaced by pryte, large pyritized frag 2441.17 silicified; 2463.0 lignite fragmental gastropods. CORE #3 2702-2733 CUT 31' REC 29' COPRING TINE 10,15,16,14,3, 22,24,20,22,20, 28,22,24,20,189 16,20,20,20,22 18,22,22,22,20, 26,22,18,22,20,44. Core badly fractured. Jammed at 2732-33. Argillite: med to drk gray. Occ. grz & calcite veinlets discordant w/major fracture cleavage; fracture cleavage 45 to 600, talcy fracture surface. Occasionally near phyllitic, trace chlorite, trace pyritized carb. matter, mod brn oil stn & free oil on fractures. dull to mod yellow fluorescence occasional sdy laminae parallel to 300 off long axis of core. Veinlets abunt 2702-03, small veinlets 2705, 2706.5, 2712.7, 2720.1. & 2722. General t 'TI�L t S1 „1-i.ECr m0 Cas Well No. 1 was completed and blown free of mud, it was shut vellhead pressure blas 820 psig. Cls- 15 N,arci�c 1975 hsIY5;D MAR 221975 on Vareh 8 and, after the. well was. flared in. Rrproximate]y 12 hours later static 0z I�',arch 9, an attempt was made to co iauet a ,. ti -point bac:: pressure test to determine the calculated absolute open floe potential of the well through use of a 2" critical flow prover using orifice sizes of 1/16", 3/32", 1/8"' and 3/16". Although field test data are attached for informational purposes, the test failed due to the need for further cls anirg of the well. In 'addition a Pitot tube test proved impossible when drilling mud clogged the 1" f1.04911IDi barral of the instrument. (However, gas samples were taken and forwarded to the Bureau of Mines through LCDR R. V. Shafer, officer-:n-(r�;e, Pet -It. LCDR R, V. Shafer initiated a procedure for cleaning the well by allowing vell- head pressure to build up sufficiently for several hours followed by periodic blowdo��ns. Then, on March 11, after �:ellhead pressure statalzed at 810 psig, anotrer effort was made to test the m -ell. Field test data for the second test are attached, and application of the results, thougrc of some significance, provided inconclusive results, It should be noted that during the ?a tier part of the last test with the flc.•i prover the gas, .$hich had been beset , ltIa a moisture problem (causing hydrates, was clean and dry indicating ideal conditions for a Pitot tube test, which followed. Pitot iabe Test General I. The t=bb provides the following Inforaation: wTake ?,.tot tube reading and dete:nr ine open floc•, potential from tables. Use the nearest value found in the tables. Do not i'rterpolate for other pressures. If the correct diameter is not found in the tables, multiply the value for 1 -inch opening by the square of the actual diameter. Dote: In testing net; or unfamiliar wells, take first reading of Pitot tube after well has been bloom for 10 minutes. Five minutes later take another reading. If the second reacting, ohedks mith the first, it should be accepted as the correct test. If it is Issas than the first reading, continue taking readings at 5 minute intervals until no appreciable decline is noted." 7.. Open flow in M cubic feet per day as noted by the tables is bgsed on, -gauge pressure' a specific gravity of 0.6, a temperature base of 60 sand a p. assure base of 3i4.7 psis. A if "• and third orifices for a back.. pressure t st, omen oroper3y extended, indicated an absrit.t© epee f iow potential of appro ria telt' 558 XCID. See logarithrrai.•c paper. 2; Pitot Tu*Oe Test he test gauge was forwarded to Ahcho3rage by 'Mr.•James Spickaer, Dz!32 3 Superintendent,. ITT, for a calibration trot::, especially in the range of 6 to 12 psig, even though a calibration check at the gas plant., proved correct at 25 psig, the lowest check point .for the dead weigh tester. 'R. The specific gravity figure of .571 was taken from the gas aral3mis, Gas .Tell No. 12, fast miy correction resulting from the gas analysis of Iko C -as Wall NTo. 3 should be minor. C. Clean, dry gas prevailed throughout the test (the instrument was thoroughly steam -cleaned and dried the previous day. of the test after encountering 'a • =d -clogging condition during the test March,9). 3:.•Since a good Pitot tuba test was accomplished and the second back pressure test tended to confirm the results, lko Gas Well No. 1 has an ACP of about 600 MED. Andrea F. Crane _ Foreman Nat. Gas Operations IT"Z .Arciic Services Inc. :s t Dasa Results 1, Although the' well was produced for seven hours through small orifices of 'Erie fl &I prover, it was allowed to flow through the Pitot tube anstranent for 10 minutes. • Impact . Time Pressure 17115 nowing1755 ' 757 . B-3/4 ppsig 1758 9 psig 1802 9 Minus prig Tables:. 548 M= at 9 psig Z. Corroction Factors 4 Flow.Rate* rx'rD (Open Flow Potential pt 1.o49"ID• (1.049)2 M 1.100!: Ft R 30OF o 420 ) y r 1.0302 F # g ( )(}'� Divided by 1 .. 1.3234 1.0251 Pb l�� 1.=4 sed on specific gravity of gas, Gas 1•,61.1 No. 12,' until gas samples analyzed, Where: pt ID of instr=ent barrel. Ft Flowing gas temperature. gg Specific gravity of gasp flowing. . Pb Pressure base. r 4 (548) (1,Zbo4l) (1,0302) (1.0251) (1.00311) Q 639 VILM � ernsiors 3. ; zc c Pre ,sure Test - Using -data fron -Gas Well ;to. 12 until the ,gas samples are analy; ed i th o second bac'lc pressure test proved inconclusive. Data Bron the fi c t tested ;ailed.. However, two points established for t1W second -:,d last orifices Tentative - Multi -point Badc Pmssure Test #2 Iko 170. 1 Cenaral . Data for the gas analysis of Ro Das Well Plo. 1 was taken from Gas tdel l :va. 12; it is rot believed fiat the analysis of the gas samples . recently taken from Iko Gas Well Mo. 1 will affect the calculations materially. i'•on&L.ti on' s Shut in (Static) Wellhead Pressure: 810 psig Barwretric Pressure: 15 psia )eight of column of gas (Calculated):.42 psi Bottom Hole Pressure: 867 Asia 14.65 psia Base Pressure: 600E- Base Temperature: Psuedo-critical Temperature: 33308. •Psuedo-critical Pressure: 652 psia. Specific Gravity: .5T1 'Formals Flow Rate: Q (Fp) {ri:f) (Fg) (Fpv) (Pm) -Zhere: Q r Lcra ;ate (at 14.65 psia, 600F),9 NdC'rM (thousand cu/ft/day) Fp Basic orifice factor (at 11.65 psia., 600F.,.and 1.00 sp. gr.) Ftf - Flo7,ring temperature factor (520 divided by flowing gas terug.0R)X IF Specific gravity factor (1 divided by aowirg gas sp. gr -)i FPy « Supercompressibilityfactor ' (1 divided.by- compressibility factor) • (1 divided by Z) Pm Static pressure on critical flow prover, psia. P� . P8 Di « fferences of squares of formation pressures Pf.and pressure at the sand face$ Ps, Test 1 - 1/'7.6" Orifice Stabilization Pressure: (800 + 15) " 815 Psia Back Pressure: (800 + 15)« $15 psia Flowing Gas Temperatures .+3502"*. . j. •c F - .66569 P Ft± . 1.0249 Fg 1.3234 P - 8151652 - 1.25 r i• a 495/333 « 1.1;67 z • .872 Continued Q a (.2716) (1.03021 (1.3234) (1.055) (645) ' 252 2'�'FB P12 - Ps2 •• (825 + 49)2 - (645 + 42 )2 - 279,,720 ;t h - 3/'16" Orifi ca S I,abilizati on Prete si:: e : (315 + i5} '' 330 Asia (305 + 15)� 330 psia Back Pressure: Fl,,,Ing Gas Tem. erature : 34 F. F�o ..623? Fzf 1.026 F 1.3234 P„ .. a 33o/652 ' .506 Tr' - 494/333 ' 1.4834 z - .946 _ rpv .1.02$ P- NI 330 G, m' (.6237)'(1.026) (1.3234) (1.028) (330) ' 287.3 YlCFD �A (8�5 + 42)2 _ (330 + 42)2 ' 613,3 ps2 Conthi; lieu F " - 1.07 D4 , P - 815 Q - (.05569) (1.0249) (1.32311) (1.07) (815) - 77.7 P 2 _ P 2 - (825 +42)2* - (815 + 42 )2 - 17,240 S $ -st 2 - 3/52" orifice ---- Stabilization Pressure: (715 + i5) -730 Asia Back' Pressure: (7]5+ + 15) - 730 Asia Flowing Gas Tempe nature : 43°F. j F - .111116 i p ' Ft3' = 1-0168 7g. 1.3234 , Pr = 730/652 - 3,1196 ' Tr. _ 5o3/333 - 1.51o5 - .896 Fpv 1.057 P - 730 m " (,1.446) (1,0168) (1.32311) (1.057) (730) - 15° Mn - p f2 _ pet - ' (825+42) 2 - (730 + 42 )2 .. 1/$n Orifice at 3 (bio 15) - Stabilization Pressure: + 645 nsia Back Pressure: (630+ * 15)- 645 psia Flowing Gas Temperarures .300F. F - .2716 gti = 11.0302 Fg 1.32311 pr - 645/652 - •98926 1r - 490/333 - 1.47 = 95 w 3..056 end Tis tBackessure Test, Tco Gas ;:'ell tlo. 1 Field Test Data 'gest ibte: 11 March 1975 TeRi-ad by: A. Crnno D. Barnett Static shut-in Pressure: 810 psig Test 1 - 1/16n Orifice t rw.,:: ctirn : Annulus Tim Starved: 10111 hours L Pack Pressure, nsig 1*:1iient Temp: IO°F. :t;nd: Westerly 5 Knots narvmetric: 14.9 psia '�.cter Pressure, psi g Gas Tenor. OF. l M S Flooring 785- _ _.N______!__.. +45 1620 ---- ------- ------- ..__ A. +37 1030 ---------------- 800 ----------------- 800-_____ +33 1035 ---------- ------------------------- 80a ----------- . +35 1037 Plugged orifice through hydrates., remnvedt cleaned IMI F1Awi ng I i �_______—_w______r____r____ :A5 ------------------------------------- 800 +34.5 1050 800 +35 -800 800 ---------- - +35 i1rX�t�E.37atzatiarl --- ----------------- 800.._.. --- +35 T,y--t 2 - 3/32" orifice_ 1103 Flooring 785- _ _.N______!__.. +45 --.,...--------770 ------------------ 770.-- +47 tPn1c doteeted at nipple, below union at wellhead. Shut in. ;FS.xed. .1-5 r Lozring 785 ---- -------- 785 +118 ------------------------- 778 _______N__.--- +47.5 770 +46 i �_______—_w______r____r____ 7�L. 45�,J �1_♦w.__N_M_�N_N_MN—MN__..wN____.�— 750 +lt/ 740 +IL3.5 728 +43 - K ---- N---- -------- -.._N 725 ---------- - A2.5 720 - -- +40 ' •'t� +40 _ ��.%� ryj _.. Ire 0 +39 5 .5N_------- ^\, 23 +39 +1 2 ______.._______.. +41.5 715 +43 --_----!_ 718--------�...:...� +-43 ,05_ --_-------�_�--------- 1.31 5 715 ----------------- 715 ------N------- +43 +43.5 1390 _,...__._____..__....___....----------------.. 13�5_N_____NN___N_______.N___r____-....- 715 +43 1330 ..r.... --- ______-_r_____-__...._,.______NN 715 ..-..------------ + 43 1335 St++hilization --- 7151+-------------- -715 -- —+43 Kota: Since s qni- k shut-o"f was affoxded thra use o: Textream 1/it turn nlug valva., ;.:invite build un pressure was taken; .'715 to 716-719 psig ? os.!;.urs Test Continued I -rest 4 - 3/16" Or i:ftce 71 me BacI4 Pressure, ns:.g 1',eter Pressure, nsig Gas ienm. OF. iI LMring zt------- ------------ -------------------- 550 +23 3.r?5--------------------------------------- 500 +21 1.r37 ------•---------------------------------- L60 ----------- +20 15);p ..._______..�__----------------------- i440 ------- +20 ►.51 ,5 00 -------- ._ +19 — 55 +;.9 ----_� � ------------------��.� 405 --------_--_ 16)o5 --------------------------------------- 375---------------- +19.5 itj p 360 _______—..__-__ +119 1625 •.-------------------------------------- 330 ---------------• +iq ?63p 320 +119 - IA3K__-_----__--------------------------- 310 _�+ 0 - ------------- 295 -------------- 300 +18 �ASL5-------- ------------------------ . --- 290 X7.5 ; IA50 _.._:__—_____-------- _ 1-655 -----:..----------- ------- ------------ — 280 —._,----_..__.. +3.7 17n0-----_------------------------------- 270 ---------- 26n ---------- +37 +'��.5 1710. --------------------------------------- "11.5 ------------------------------------------- 25fl --—_--.__—� + 5 "775 --------------------------------------- 250 -----------_..__ +15 1730 ----------------------------------------- 215 --------------- +15 1735 ------------------------------------------ 240 +15 174n----------------------------------------- 235 - ----- _ +15 '-7h5 -------------------------------------- 230 +15 j-'/50 -_.._--_ _----------------------------- 230 ,•7r55 -----_ _-_------- 230-.._..____�.�.... +15.5 X55 Stabilization ------- 227 ----------- --- 230 +i5 M ►tete : on the first two tests neLma:-^.ler there. were considerable hydrates built up on the plate behind khe orrice port. Gas appeared dirty with some degree of noisture throughout the test. ►itot Tube lest IA1.2 Flowing A:ater flowing for about five minutes the bar. -el of the instr%imnt became c?.ogged with drilling iced, 'lb_ protect the gauges an impact pressure reading was not taken. .:r ;i -Les-61Baer. Pressure Test, 33 -co Gas Well No.. 1 Field Test Hata Test Date: 9 :jamb 1975 Tested by: A. Crano D. Barnett Static Shut. -in Pressure: 820 psig • Ambient Temp: -12°F, Time Starved: 1055 hours Mind: F.aster3y 5 Knots Tcst 1 - 1116" Orifice' Barometric : 14.9 Asia 'Oro*3u ction : Annulus Tine Bad -c Pressure, nsip t:etePressure, psis; . Gas Tr:mpe Oris. 105Flowing 11j.0 of.,'1 ce Plugged (Hvd:ates)'. 7R5 ----------- 785 --- +15 1120 Fl.owing 785 ---- 785 .._....._ +15 1130 780 ......___--__ 780 - +15 1135 775 ------ +18 J.1�0---l--......__._____---------__._.__.._:._ 770 _.._...�� +22 1150---------------------------------------�--- 770 ---------_ +24 1.155 Stabilization -- --- 775 ----- 770 ------ +26 Test 2- - 3/32" Orifice. 3.200 Flmfing 1205 .--_---- ___-----------------------....- 755 +M 121.5 ------------------------- 745+ - ----- 750 +3h 12%' ------------------------- ---------------- -- 7hO--------- +33 �.225------------------------------------------------ 735 ----_----_ +33.5 ,.230 -----------------------------=---------------- 730 -- --- +35 V35----- ------------------------ ------------ -- 720 --------- +34 12L0------------------------------------------------ 720 -------_--- +34 12L5 720.- +33.5 1250 Stabilization720+-------------- 720 ----------- +33 Note: Prover barrel with film of mud: removed, cleaned Tom t 3 - 1/83= Orifice using Herngn Nelson,. water, wire brush. 1300 Flo-Ang__ __ _ ._ 700 --..__----_ +34310 ._-_.._� _.�.. 680 ----- - +35 .,�._ -__--------- ul5675 +Y� 1390 ----.________-. -------------------------..-- 665 +39 3�5_----------_._-...�---------------------..-.._ 660 -------- +39.5 .330 ..--__----..__.__,_--.__-__--------------------- 650 -----_____ 13 5 615 ---------_ +40 +40 3t10----------.��.-----------------._-____ 610 ----� +W 635 +40 �i-____------_. _.__...____------------_--- -- 630 --------__ +40 1355 _-__------------------------------------ 620 --------- +40 1.405 _..__-_.-__..--------------------------- 610 _�....�.... +j�0 I.IJ10------------------- ---- 610- -------- -__ 608 ---------- +40 11N0---------------�__-___-_-_�.—_M._____----..__ 600 ----.------ --------- 590 ---- +hO +37 1137 �.j�jx3_.___-_-_._.---------=------------------------- 590 - _--- +32 -------------------------------------: -595 --____-_-- +25 .017_--- 1+9----_--_.._.��.------------------------------ 590 _. +24 x. 53 -----------_-..-_---------------------------- 590 +24 - - --------- --- 590 +2.4i178 i500 Stanilizatios -------- ---- 590 ---------_ +24 s firiet 'Pressure Test Continued Test 3 - 1/8" Orifice TIT.,* Hack Pressure, nsi!g, eter Pressure; psig Gas Trrtp. OF. 130 Flooring 131;5 -------N-------------------------------- 705 ._.—._+4 3.50 -------_-_.._..._----- bt�o------------------ 682 ------------ +)t7 - � ltt70 --- NN_---------------------------- - G7o--_-_--__- +45.5lit �.5--------------------------------------- . --- 642 ------ +10. tt25-------M-------------------------------- 6ho-----�..�N +31,.5 1. h3o _-- --__---.w..---------------------------- 630 +32.5 3 110---_..N_-_.._.._________w_____-__,r_______— 630 - +31 '..1th5 Stabilization ------ 630+--M____N_NNN 630 .._N»__-_- +30 '"extxeam valvie, located abnut 301 i.nostream of prover was shut in a�ad build up pressure in one ninutes auflrnxirrated 32 psig. Althnuj#1 orifice plate port a neared free of hydrates, barrel had a film of hyirates. Prover removed and cleared of hydrates thru use of Herman Eelsmix. Test it - 3%16" Orifice 1W. Flowing - 570� +34 1535 __---------------------------------------- 5110 ._----_-__- +33 3.5ho--..—.�------------- ------------------ ------------- 33 -sq.L5 N--_-----------------------------------____-- 475 ---------___ +33 • •• �K� " -- - -----N-- ------------ --N....__.._...... h6o -----N-..mow +32 �,. 43,5 ------- .� +3� ------------------------------------------ =. ----�—"-- 370 _____------.. +34 _...�N----------------------- -::,l.n -- -- ----------------------------- 340 ---- �__ + - i �..5 +3' . , f -,,----------- ------ 320 ---------_------------------- 315 ------------ +A.5 II 0 . V�►I�'I--_�'-_••_••--'�•r_� _NNw_-N____wN_wNN-_'� � NN_N�__w 1'j �--------------------N..__.� ?735 ------------ j30 ------------ +34 1720 Z �5 N_w_N—__.._...._____....wN_N..w., NMM.�•-•• 3`i5r + j -'•� 315+34 730__NMN___.'_N�.'_N-___________•.___.�N_..._�r �--_r- 'i?35 Stabilization ------ 315----------N__N_N 315 ------------- +34 S1 at, in. Aiirnite pressure 'wild up J. 30j35 lbs in 1 minute. Note: At 1610 hours, gas stream was clear, co-nipletely free of moisture foreign matter. Pitot tube test was stared a' M--5 hours. ?rote: Upon commetion of Pitot tulle test, gauge next to Textream valve Time Impact Pressure increased from a zero Presmir rondin -�•�• 9- vsig to 2.80 psig in 30 seconds, thon. to 1.157 8-3A psig 290 psig in the fo33owinp, 30 seconds 1758 9 .0si.g 1.802 9 ?!irus psi ?;c+�. ;?oto, Open i•1n<a potential: 'S•:S 'R1;�•`J iunrorrocted�. €1 ft AMtT !. Iii:: Jf:AT9 Hilo t0 ;.O 1 (OtLn .nsirwtions aft nrera► side) 3tiK. ! • )• 71 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MAW -17, TO DRILL OR 34. TTrs air woau x::211 L D::PZ.N ❑ D. TrTra or vr" OILOa! a ai;CL: Q MI't.TMi WiM, tJ 'VrLL oTAS1 Exploratory s NAME OF OPZ"TOR Director, Naval Petroleum and Oil Shale Reserve: X ADDRU S 07 OPs."7rJR Rm. 550, Crvsta_1 Plaza No. 61 Washinaton, OC 201. +. LOCATION OF WE' L At-r"ce X=716.275: Y=6,281,650 2500 ft.rVL, 1850 ft. FSL Sec. 16 T21N R16W UPS! At PraPsaed Pros. tone Same 11100.1 IK0 1 Ser: Naval Petroleum Resery NA ). UNIT FARMOR� N^.%jE NA a. WELL NO. Iko *1 * la. nELO AND POOL. OR WILDCAT Wildcat It. SEC.. T.. R.. I -L. tDOTTOSt HOLE ORJZ=Vt1 Sect. 16 T 7 1 N- IDI CTAT TT—.9 ..a. 'n we !J, DISTA.\CE IN UILES AND DIRECTION FROM N&AREST TUK•N OR POST OFFICE- � � LL 16 mi 120° N. MOND INFOKMATION. TYPE NA sur tv andiar No. Affmast is. DISTANCE FRUA9 PROPOSED' 11. NO. OF ACRES IN LLASZ IT. NO. ACRES ASSIGNED LOCATION TO NEAREST TO THIS WELL, PROPERTY OR LEASE LiNX FT. 8 Mi. NA NA 1^1010 to hearth dtig. unit. It any) , Ia. DISTANCE FROM PROros= LOCATION. TONEAREST WELL DRILLING. COAtPLETLD. is. PROPOSED DEPTH as. ROTARY OR CARLC TOOLS OR APPLIED TOR. TT. 31,249 3,100 ft. + Rotary .:. EI.r%rATiONS 15A0w whether DF. RT. GR. eta.1 $ APPROX. DATE WORK WILL START - Ground Elevation = 28 ft (approx) 01 FEB 75 ..i PROPOSED CASING AND CEMr-NTING PROGRAM S:Z£ OT HOLM 1 SIZE OF CASING I WEICIIT PER FOOT / GRAD£ sr SI1G n -,7-.H quantity of cement 51 IN 80 23 IN 80 The Director,. Naval Petroleum and Oil Shale Reserves will drill this exploratory well as part of a program to evaluate the petroleum and natural gas resources. -in Naval Petroleum Reserve No. 4. The well is being drilled by ITT/Arctic Services, Inc., under the supervi-sion of the Officer in Charge,•Naval Petroleum Reserve No. 4. Shaffer double .gate and-Hydril blowout preventers are to be used. *Direct inquiries to: Officer in Charge, Naval Petroleum Reserve No. 4, Barrow, AK 99723 IH ASOVZ SPACZ MZSCIISE PROPOS PROGRAM: It Proposal is W deepen give Ota on Ptlsetr! Preda"I" MM am rMpowd Mer Ptrlducttve 1011. li_pmnOsal Is to. ani or deepen airectlonasty. sive Panihant G&W on r4omrtace la"w" wA m"mrsa and Uve vertica) depths.. Ghia bi.wotTi Pray.ltter Program XL I beret y caruty that Lb- rare vo k is True an* Carron %t ''-.- 1' It = Aterzz-..s S S,G+zafi:t1�ShRfd:LCDRiEC.USN DATE ;'S i Tats space for state oalre uses coKnm, oxS OF APPROL'AL. IF ANY: SAA:.^L'i s AND COR's CHIPS RE UIRI;* 1411D 3.00 onwt Rs'1gVilt�:L�Yi: (] YL3 13 NO 13 YES 13 NO DIRECTIONAL SURVEY RZQUM= A?S. NVb=UCAL CODs C) Yas p xo P.7L1tT: NO APPROVAL DAT. APP:tOY� L•• .:..:. VA= 1 'S.. -'Q Lim ocaon:1Rea ::ew.ina S:Ga .~: .'. . . Page -L of ,.. £' WELL NAME: Iko Bay No.1 ITEM . TYPE LOG SCALE BASE .; t;...., i)'r RUN DATE LOG INTERVAL COP I ES ..f.(CQUESfEß l. OIL 5 F 1 2-08-75 0152'-1220' F'P , 2 2-24-75 1190'-2723' I 2. OIL 2 F 1 2-08-75 0152'-1220' :t: 2 2-24-75 1190'-2723' 3. BHC 5 F 1 2-09-75 0151'-1221' 2 2-24-75 1190 I -2725 ' 4. BHC 2 F 1 2-09-75 0151'-1221 ' F P f 2 2-24-75 1190' -2725 ' f t 5. '. FOC-GG 5 F 1 2-24-75 1190' -2726 ' F P f I 6. CNL-FOC 5 F 1 2-24-75 1190' -2726' T 7. CBL 2 F 1 2-12-75 0150' -1185 ' F P 8. m~-Arrow Plot 5 V 1 2-24-75 1199'-2729' F~P 9. Mud 2 V 2-06-75 0190'-2731' F~P f ì 10. Saraband 5 F 2 2-08-75 1200'-2710' t,pl 1l. Fd 5 F 12\ 2-24-75 1190' -2726 ' F P 12. MPL 5 F 1 2-24-75 1190'-2726' Ffp 13. MPL 2 F 1 2-24-75 1190 I -2726 ' F~P I 14. Geophysical 1 F 1 2-09-75 0151 '-1221' I FrS,P 2 2-24-75 1190' -2725' 0--- r{ c C t'- ' V ¡: D'. I L _ if L, MN< 2 8 D:vision OJ . .. . UNITED STATES . DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Office of National Petroleum Reserve in Alaska 345 Middlefield Road Menlo Park, California 94025 II.. Y ~.f\P @tfJ TM ---- March 23, 1978 ~ f i.\ ,.-': {;, t 9(M v ~ ¡; Mr. Harry W. Kugler Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Kugler: We are sending you, under separate cover, sepia and blue line prints of logs on the following wells from NPRA: cap: Ri~.~t~ ~o. 1 ~IKO Bay No. 1 ~ Sou h lmpson No. 1 W. T. Foran No.1 Lists of the logs for each well are attached and those we are sending to you are enclosed within the red outline. The letters."S" and "P" indicate "sepia" and "print". These logs are not to be released to the public until their avaiÞbility is announced by the Environmental Data Service of NOAA in Boulder, Colorado. NOAA will be the primary distribution agency and their release of the data will be authorized by the Office of National Petroleum Reserve in Alaska at the proper time. Please acknowledge receipt of the logs and your under- standing of the release procedure by signing the attached copy of this letter and returning it in the self-addressed envelope. ~,tCEIVED f,lN~ 2 4 1976 Very truly yours, /f:¿:9-rftfff (j;) t:ÁA~ tiV:2!Cr. Cr on t!, GGî3 G';:¡~~rv:;¡~!, , .~ Robert D. Carter () f) ~.#_ . ~~~. :r-r/ ... CúNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Office of National Petroleum Reserve in 345 Middlefield Road Menlo Park, California 94025 Mr. Harry W. Kugler Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Kugler: . ,\,) V!/ì Alaska L 11 ~/ \ ' ~// // /. December 15, 1977 In accordance with your letter of August 29, 1977, to Irv Tailleur, we are sending you, under separate cover, well log sepias which we had on hand. Two lists of these are attached; please acknowledge receipt of the sepias on one of these and return in the attached envelope. The remaining sepias and blue line prints of all logs will be sent to you when we receive them from Houston. A purchase order for this work is presently being prepared. Very truly yours, ') .--..-- ed':'1~ f;) t'0vl1-v Robert D. Carter Attachment f) r r -. il. ;' ~- r ." .- \ I,. 1 "i, ,) j, \ 1...., ....'- '~.' ¿ '.) L~ ~..~ o í' '-; C / f D¡v¡~!';!1 cf r:n n-_~ n;~V,:J i ion K --,'11\\ J r ~ l\ ~ Ý'M fW Q.-.. ~~v'--' _. ------~ ¡;;..-.... . ~...,.,-#"'. ~~"". ~ ,.r;- ~.. . - ~ ",,' ;.... ~'~:'" "'~. .~'--;..-,;..;.. 11'. .... ~.: ~.. - ~..' 'r ... . . ¡.. (!..... t . ,ol. ~"""""" ;,.:..."",./ '-.- r::~ .': ~... ì&....... . ~~~~;, -- ~ C:''f'_:'':t:,~.:.:'~.'-.~~,; ~~'_r~_·:,;;,;:,:~::,\",',,:~:.:. :...c:;;.;¡;."."-...",.__,".~.::zr~,,,., ~~ r . ,. ,. . . Sepias Atigaru Point #1 (Saraband J Cori band t/ Dual Induction - Laterlog East Teshekpuk #1 v Dual Induction - Laterlog v Borehole Compensated Sonic Log Cape Halkett 16N-2W-l vDual Induction - Laterlog ~Temperature Log v Ca 1 i per Log I Compensated Neutron - Formation Density \/ Cori band ..I Compensated Formation Density Log J Borehole Compensated Sonic Log v Borehole Compensated Sonic Log Borehole Compensated Sonic Log ~ Borehole Compensated Sonic Log \ Dual Induction - Laterlog J Cement Bond Log r/ Cement Bond Log · Cement Bond Log ~ Cement Bond Log ./ Mud Log / Stri p Log VContinuous Dipmeter v Borehole Compensated Sonic Log / Compensated Formation Dens i ty Log ¡Dual Induction - Laterlog V Borehole Compensated Sonic Log v Proximity Log - Microlog v Dual Induction - Laterlog Proximity Log - Microlog Cement Bond Log FD Log Compensated Neutron - Formation Density J Mud Log South Barrow No. 12 Dual Induction - Laterlog Cement Bond Log Borehole Geometry Log Formation Density Log Compensated Neutron - Formation Density Proximity Log - Microlog Saraband Dual Induction - Laterlog Borehole Compensated Sonic Log Borehole Compensated Sonic Log n r C f- . \ r r' f) "... ,... ¡ " .'. ; 1\, l.... ,L, \/ L '.. r' [" f' ~'- c'. If, _.1 'I' _, C_*_) I) íj ; ',} . < Dlv\~~!')n .f" ( n 5" 5" 2" ti ~ 5" 5" - 2" 2" 5" 5" 5" 5" 5" 2" 2" 5" 5" 5" 5" 5" 5" 211 2" ~.:..~~ h,'-' . ~j, ~; ..... ;,> . ~'" ",.' ~. ...,. .. ir.v ~ . c..f~~7"· ~~o:r ~'; 5" 2/1 5" 5" 5" 5" 2/1 2" 2" 5" 5" 2" ~~.:;,<:: ~,. . , . >-t ..~¡.'. ""'~"'. r--- ~~.. I''-J' '" 2" 2" 2" 5" 5" 5/1 5" 5" 5" 2" ..I, ..,¿;' ...~ ~ , ~.,.c- ". r,.."..~, ~: ~ ,~ ... "'i:'::; ~ ~····¥·~-.......L"";:"'-..:·j,-'é·þ1:~;'·"-""-'~7~~'~·"";"'~'A.;" ...~.::J~-:....~-"'_-::"<~, _..:;..... ~,,,,-~,,,,,';~""'.,í.\ 't...·_~·~.l ..,:, . :L~_"'"",:">'~~", .' . ".. ..~...... ....;;:,..."'-r;......'.~,c".~_'..' '.. ......, .....~... .,.....~ .'!I';"'..'~..!t";::t":.' ;.. .....,..'. '~.'''' .. '"...,,~ ~.,.,..'~.~', . '.. .. ~."'í' \""..... ... ;rr"",~', ~.....~.. :...""'.....~ ". .~,...-, ';...,~.. .... ,"-.' "-. ..'fl'.'. ~.,..'.:r~..'.."'. _ . .~""-,"'y_.,.~-.~........~c_,;;,£;,~.'.,.,..i'._ .,"'......._~~;~'v"!'''''''''-.,·I.:~~".,. .,. "~'.JoLc",,,,~":·I"; ...,'7~""'...:"'?\.'. ~ .. ,,......~.. ~-..t1(.¡¡,:~;'Ç..'7 :"'......~,~,~"........,_;,J.~_,¿Uþ....:.....,-----,~ ;~t~........,.".... ....q_ .'... ß.""" .Jf:;..... ~~'!>t<.. ~ '. ;';~" :".;._. ·. '" . Vellum South Harrison Bay #1 2", 2 runs Dipmeter Arrow Plot vv'" ¡' .....,., South Simpson #1 Dipmeter Arrow Plot 2", 2 runs v/ ,'.If - Atigaru Point #1 Dipmeter Arrow Plot 2", 2 runs '/ L,/ Wt Foran Dipmeter Arrow Plot 2", 2 runs ¿ v~ ~ West Fish Creek #1 Dipmeter Arrow Plot 2", 2 runs Vi/ ..-. ¡ ,,,, Above material has been received and will be held in a confidential (proprietary) status until announcement of release by the Environmental Data Service, National Oceanic and Atmospheric Administration, Boulder, Colorado. ~~~ , . ~ ~~:;t ~ n e~r ,> , /, ,. t/ ',:-) '-..,> ç / I - 1/ /7 ..." ....--. '; I ~, ~- - r I"' ro' ¡~1 r , . '"' ,. ¡-I [' ~ 'j. r' Divfr;"fì r;{ (' n,,^ ;';"..,:, :1/:; ~, 1;....,... ,,~, i.;,';¡ ~~~~ ~~ I - ,........., I í1 C '~ n ¡ ..'-.--------.-.-.-. .,.. .¡;;.;;~ff..J.?!1f~?~q,;~f('~::...;~:.:::~£~·f" .,'~~;..h~~...........'!....T~1Ii~ ... Depth 190-280 280-420 420-480 480-580 580-640 640-680 680-780 780-1015 @t ~ .. ........ V ......i L 'rJ ..w...... p I .~. 1 1975 Sample Description: u.S. Navy #1 IKO BAY -'0' Clay: gray, occasionally 'silty, earthy, spongy texture, sticky, traces fine-grained loose sand, trace gilsonite from cement. Poor samples. Clay: gray, as above. Clay: gray, as above, occasional interbeds of sandstone, fine- grained, quartzose with trace yellow fluorescence. Poor samples. Clay: medium gray, more firm than above when dry, less spongy texture. Poor sample. Clay: clay shale: dark gray occasionally sandy with minor yellow fluorescence and cut fluorescence. Poor samples. Clay: dark gray, sandy and clay dark gray, slightly silty, minor yellow fluorescence. Poor sample. Clay: light to medium gray, earthy, silty in part, slightly micaceous in part. ' Poor sample. Clay: sandy. and silty clay: Poor sample. sticky, earthy, soft, plastic, occasionally 1015-1030 Poor recovery. 1030-1050 Clay: medium to dark gray, earthy occasionally, silty, occasionally hard brown siltstone laminae. Poor sample. 1050-1110 As above. 1110-1140 As above, grading to very fine-grained loose sd, traces fine disseminated pyrite. 1140-1170 Clay, as above, interbedded with eight gray fine-grained sandstone. 1170-1220 Clay: medium gray, with fine-grained sandstone laminae, some friable-loose. 1220-1270 Clay and sand: as 1170-1220. 1270-1275 Siltstone: light gray to tan. 1275-1290 Sandstone: dark gray, very fine-grained, moderately carbonaceous, pyritic. Poor sample. leD -octo ~ , 1290-1325 Sandstone: as above, very poor sample, trace weak silver blue fluorescence, no cut, does not appear mineral. 1325-1345 Siltstone; as above, and sandstone, medium gray fine to medium grained, loose to moderätely consolidated, carbonaceous, well sorted, subrounded, slightly calcareous. 1345-1415 Sandstone: as above, with occasional trace glauc, interbedded with siltstone as above. 1415-1450 Claystone: medium gray, silty, with sandstone medium gray mottled black with carbonaceous fragments, very fine-grained, dull gold fluorescence and streaming cut fluorescence, calcareous, tite. 1450-1495 Claystone: medium gray silty with interbedded sandstone, as above, some silty occasionally carbonaceous minor dull gold fluorescence. 1495-1520 No samples. 1520-1535 Shale: medium-gray, massive, chert granules to 3~0 mm tan, It. gray to light yellow gray, cryptocrystalline trace very fine sand- stone with dull gold fluorescence, carbonaceous, traces black vitreous solid hydrocarbons (probably gilsonite from cement) traces pyrite, disseminated and fine crystalline clusters, slight silver blue fluorescence, no cut. 1535-1615 Siltstone: gray to medium gray, carbonaceous with traces limestone tan, fine crystalline, some cryptocrystalline, chert granules common 1535-1550. 1615-1620 Siltstone: as above, with light gray to tan cryptocrystalline limestone. 1620-1655 Siltstone, as above. 1655-1690 Siltstone and silty shale: medium to dark gray, carboneceous, slightly calcareous, with occasional calcite grains. Quartz grains at 1670 + 3MM. 1690-1710 Siltstone and silty shale: medium to dark gray, carbonaceous, slightly calcareous, with occasional limestone, tan, crypto- crystalline. Chert and quartz granules, sub rounded, scattered pyrite, minor yellow fluorescence, coarse calcite 1705-1710. 1710-1745 Shale & siltstone: as above, occasional claystone, green, sub- vitreous, subwaxy to waxy, plastic, abundant pyrite. Sandstone, clear, medium to coarse grained. Less limestone than above. Mineral fluorescence only. 1745-1750 Siltstone: as above, slight increase in fine- to very fine- grained sand. 1750-1780 Siltstone: as above, increase in limestone, probably thin stringers or calcareous nodules. Thin interbedded sandstones, mottled gray, fine- to very fine-grained, carbonaceous, silty. ~ , 1780-1820 Siltstone & shale: as above, dark gray, micaceous, very fine sand, quartz pebbles, pyrite, carbonaceous. 1820-1845 Shale: dark gray, massive, carbonaceous, and silty shale, medium gray. Siltstone, light gray, very slightly sandy, pyritized plant fragments apparently with thin interbeds sandstone, medium gray salt and pepper, very fine- to medium-grained, predominantly, very fine to fine, calcareous, carbonaceous, rounded clear grains. 1845-1865 Shale: dark gray, some silty, carbonaceous, probably massive abund. pyrite or marcasite, some floating quartz, medium- to coar~e-grained, clear, well rounded. 1855-1870 As above: chert pebbles co~mon. 1870-1890 Shale: dark gray, with traces chert and pyrite, bentonitic, samples poor, hole booting and clays balling. 1890-1920 As above. 1920-1925 Sandstone: light gray to clear, medium- to coarse-grained, angular to sub angular, loose, weak yellow fluorescence, faint cut fluorescence. 1925-1930 Shale: as above, trace limestone, tan, extremely argillaceous. 1930-1975 Claystone: probably water sensitive shales, light to medium gray, soft, sticky, bentonitic?, slightly carbonaceous, occasionally calcareous. 1975-2000 Shale and claystone as above. 2000-2035 Claystone: as above. 2035-2050 Claystone and sandstone: salt & pepper, very fine-grained calc., tite, possible cavings. 2050-2100 Claystone: probably water sensitive shales, as above. 2100-2130 Shale: light to medium gray, slightly silty, micaceous, fissile. 2130-2140 Shale: light gray as above, trace salt & pepper, very fine-grained sandstone, with yellow fluorescence, cut fluorescence. 2140-2205 Shale: light gray slightly silty, slightly calcareous, carbonaceous in part, occasional scattered salt and pepper sands as above. 2205-2250 Shale: light to medium gray, slightly silty, micaceous, some black carbonaceous, fissile, occasional limestone fragment, tan argillà- ceous, occasional floating fine- to medium-grained rounded quartz. 2250-2260 Shale: as above, more sandy, calcareous. ~ , 2260-2290 Shale: as 2205-2250, occasional pyrite. 2290-2331 Sandstone: light gray, very fine-grained to fine-grained, sub- angular to sub-rounded, quartzose, slightly carbonaceous pyritic in part, argillaceous, questionable slight stain, probably thin interbeds with shale as above. 2231-2396 See core description #1. 2396-2410 Sandstone: medium gray to tan, very fine-grained to fine-grained, angular to subangular fair to well sorted, slight salt and pepper, poor porosity, probably low permeability, friable, weak brown oil stain, good fluorescence and cut fluorescence on crush. 2410-2470 See core description #2. 2470-2540 Sandstone: as above, shale as above and interbedded siltstone, medium gray, massive, siliceous, hard some slightly micaceous, slightly sandy, pyritic. 2450-2590 Sandstone: medium gray to tan, very fine-grained to fine-grained rarely medium, argillaceous, fair sorting, weak tan oil stain, dull ~old fluorescence, fair to good cut & cut fluorescence, probably interbedded. 2590-2600 Siltstone: medium to dark gray and red brown limonitic, calcareous in part, slightly sandy, very fine-grained, argillaceous, pseudo oolites, ? siderite, some hematite stain. 2600-2650 Sandstone: light gray green, very fine-grained to fine-grained subangu1ar to sub-rounded, salt and pepper, poor to fair sorting loose to moderately consolidated, very calcareous in part, traces limestone: gray fine 'crystalline to earthy argillaceous. 2650-2680 Siltstone light gray green, some sandy very fine-grained, non- calcareous. Claystone, light green to moderate green, waxy, plastic, may be of volcanic origin. 2680-2700 Sandstone, siltstone and interbedded claystone: as above, white crystalline calcite at 2700. 2700-2733 See core description #3. CORE #1 CORING TI~1E ~iINUTES/FOOT DEPTH 2337-38 2338-39 2339-44.5 2344.5-45 2345-45.5 , ~ U. S. N. IKO BAY #1 CORED INTERVALS 23371-23961 CUT 591 REC 50.51 12, 8,18,18,12, 12,16,12,12,12, 12,10,12,10,14, 10, ?,15,22,12, 14,16,12,16,12 16,12,12,10,12, Coring time destroyed or not recorded after 391. 14 minutes/foot. 10,10,10,12,12, 14,12,14,12, ?, Averaged 12- Siltstone: md gry, s/carb, sl mic, hrd, v. sl sdy; vfg, tr. min. fluor Sandstone: md gry, sli s&p, vfg, sr-r, sl carb, hrd, tite, no show. Siltstone: md gry, sdy, vfg, carb, a rg i 1 , h rd, t i te , no shm..¡. Sandstone: md gry, vfg, s 1 ty , carb hrd tite, no show Sìl tstone: as in 2339-44.5 2345.5-48.25 Sandstone: It-md gry, vfg sl, s&p sr-r, sl carb, hrd, tite, sl porosity, no show. 2348.25-51.7 Sandstone: 1t-md gry, vfg, slty, sl s&p, carb, sr-sa, sl mic, tr grn vitreous min. predom tite, occ spotty porosity no perm 2351.7-55 Sandstone: 1t-md gry, vfg, slty, ? ashy, sr-r, well sorted, sl carb hrd, tite, no show. 2355-56.75 Siltstone: lt gry, argil scattered drk mineral tr, vf x-talline pyrite in filmy elongated aggregates, hrd, tite, no show, some carb laminae, occ v. sl mic. 2356.75-57.51 Siltstone: vfg ss, lt gry, v siliceous, extr hrd, dns subcon- choida1 frac, appears to be sl carb, tite, no show. 2357.5-60.1 Sandstone: md gry, vfg, occ fg, r-sa, scattered fn drk cht, scat carb, v. sli calc, mod friable, carb laminae, sl P & p 2360.0-68.0 Siltstone: lt gry-med gry wet, ass \'Ilibd thin v.f.g. ss. stringers and carb laminae hard, tite no show, dips up to 150 mayor may not be reliable. / 2368.0-71.7 Sandstone: 1t-med gry vfg, sty, carb, sa-r foss (pelcy, gastro?), lig wi plant frags partially replaced by pyrite, bleeding oil at 2371, tite. , . ( CORE #2 - 2410' - 24701 CUT & REC 601 CORING TH'iE 2410-2435 2435-2437 2437-2439 2439-2470 5,5,6,6,6, 8,10,8,8,9, 8,8,8,8,8, 5,5,6,5,6, ?,?,7,8,8, 5,4,4,4,5, 8,7,7,8,7. 6,5,5,6,8, 7,9,7,8,9, 6,7,7,6,5, 7,8,5,5,? 8,7,8,7,7, Sandstone: It-med gry, drk gry & carb intervals vfg, slty, carb, sr-r, fair sorting, well cmtd, sil cmt, vfg, disspyrite, some pyrite replacement, carb frag, hrd, tite, sl fossiliferous, frag unident, bleeding oil & gas, dull gold fluor 30-70% good cut & cut fluor and alt ste, It-med gry, sdy, vfg. occ, 51 show (10-20% fluor), and comprising approx 30% of this interval. Siltstone: It-med gry, carb, sl sdy, sl mic, argil, spotted yel fluor, in part no fluor, hrd, tite. Shale: drk gró-blk fissile, sl carb, occ disseminated pyrite, app dip flat-3 Shale: med-drk gry, slty, massive, sl carb, sl mic, fossiliferous, frag of pelecypods, gastopods, ? low spired type, occ woody frag, coalified - sub bit coal replaced by pryte, large pyritized frag 2441.17 silicified; 2463.0 lignite fragmental gastropods. CORE #3 2702-2733 CUT 031 ' REC 29 ' CORING TIME 10,15,16,140, 22,24,20,22,20, 28,22,24,20,18, 16,20,20,20,22 18,22,22,22,20, 26,22,18,22,20,44. Core badly fractured. jamimed at 2732-33. Argillite: med to drk gray. Occ. grz & calcite veinlets discordant w/major 0 fracture cleavage; fracture cleavage 45 to 60 , talcy fracture surface. Occasionally near phyllitic, trace chlorite, trace pyritized carb. matter, mod brn oil An & free oil on fractures dull to mod yellow fluorescence occasional sdy laminae parallel to 300 off long axis of core. Veinlets abunt 2702-03, small veinlets 2705, 2706.5, 2712.7, 2720.7, & 2722. ~ ~ ;~ }; "~ V1' ::~. '1 ',?1, ¡~~ . -Š?~ "1 I I I I i ~ '.\~~ .:~ \::'i ~r -.. ~-.-" ".c_:,.. ;Z.~ ,.'1 .: 1 t,:"J i '"'j ! , ~ . , \!~ ~j .:-...: 'I . '7--; . . ~ / - 23 -:,' ,c, ~ ENVIRONMENTAL IMPACT ASSESSMENT IKO NO. 1 WELL 1. Project Description Iko #1 Well is proposed as an exploratory gas well to increase the gas reserves for the use of the Federal activ- ities in the area of Barrow, Alaska and the Village of Barrow. . The use of gas is specifically authorized by Title 10 of the united States Code. The well will be located about 20 miles ESE of Barrow and is located in the same environment as described in the CEIS for the Continuing Exploration and Evaluation of NPR-4 Alaska, Dec 1974 Zone A.- By reference, that CEIS is made a part of this assess- ment. The well will be less thån 4,000' and be supervised by the arc NPR-4. '\ 2. Probable Environmental Impact of the Proposed Action. During the actual drilling operation men and equipment will move to and from the drilling site. The route of travel will be largely over a sea ice road on Elson Lagoon and Iko Bay. Only about one mile of the road will be over tundra, and this will be over frozen tundra protected by snow cover. No permanent effect on the tundra surface is anticipated. The contractor will take measures to avoid oil spill at the drilling site. If oil is spilled it will bE~ ccntained in a preconstructed system of snow berms after which it will be skimmed and/or flared. Any residue will be picked up by sorbents. No long term disruption of wild- life in the area is anticipated. No effect is anticipated on the fish in the waters of the area. Upon completion of the well all refuse from the operation will be cleaned up and removed. If the well is successful it will be capped with a wellhead and provided with a small well house. If the well is unsuccessful in locating gas or oil it will be cemented off and the well casing sealed with a blank flange. 3. Any probable Adverse Environmental Effects which Cannot Be Avoided Should the Proposal be Implemented The proposed project will result in no increase in air or water pollution in the area. If gas is discovered it will help prevent air pollution in the future since gas is inher- ently a cleaner burning fuel thém coal or other fossil fuels vlhich may be used in the area if no future reserves of gas are discovered. The only adverse effect which may arise are some damage to the tundra~ Since traffic on the tundra will ... " () e'" " . f ENVIRONMENTAL IMPACT ASSESSMENT (Continued) Iko No. I Well only be during frozen periods the tundra mat will not be destroyed and damage will not be of a permanent nature. The presence of men and equipment may cause some disrup- tion in the wildlife population of the area, but care will be used to avoid frightening the animals and it is expected that any disruption would be only of a temporary nature. The impacts of the proposed actions, both positive and neg- ative, are to a lesser extent the same as those discussed in the CEIS for Zone A. 4. Alternatives to Proposed Action Alternatives are not readily available since the site was selected on the basis of the best geophysical ãata available. One alternative would be, not to drill addi- tional gas exploratory wells. This would eventually require importing of alternate' fuels to Barrow at much higher monetary cost and resource expenditure. 5.. Summary Refer to the CEISfor Zone A for a further discussion of adverse impacts, short term, long term relationship, and irreversible and irretrievable commitments of resources. By law Naval Petroleum Reserve No. 4 is established to provide petroleum for National Defense use and the Navy is addition- ally charged with providing gas to Federal activities in the Barrow area. The Navy has been charged by Congress with the task of exploration and development of all the Reserves. Accordingly, the use of the land is in conformance with congressional guidance. There are no reasonable alternatives to drilling this well. The immediate benefit may be to add gas reserves for future use in the Barrow area and add to man' s geolo~ical knowledge R~~ R. v. Shafe1(.r\ P.E. , \ LCDR, CEC, USN Officer in Charge - 2 - DEPA", . --C'- .,._. ",:," NTb:¡;THE iNTERIOR' EOlOGiCA~;,SURVEY .::J¡ l\ ¡ ..:.;;) . ~HiH¡~~_i'r .~ . SEP 0 8 1911 i' :ç;.:,L.2 "'"_' ~! f" f,"" !:,' r\_ Å_ ,t·:. .. "'~'" ~1~~ l"_-¡.';'-"fi·~">, -:;0:1. t Si;;~~ t/ttrl~,., liP 1 ~t t U· f h.tl):l It.,. f Ii ,.--' -..., ~,~ J: ~.., _...~ oil ... 1.......,..,01.1...1/.. I,"'·\~¡ 11'1H¡",~"'f, 'I "'iI" PI~¡'"'·.."" , D" NaVd.l, .t"èt.I:Q,l;E)tlm _ Er.:.:;s(.';!.rvg.# 4..__.., u. .... I ~l""'!'Il. Af..~()·r'I·~5 O~i "tU-IU;¡ HAt\H; l ""l!:rt U"f...... N~. f,~',~.Ii,. \;/~: ~_ L. CC:'.¡lPLEìlON OR RECO¡'\¡1PLETION REPORT Aì~D ~OG '" (HI'. W¡;¡,L LJ ~;~~.I. [X' 1)1\\- [] Ot "'r _, .. r""T N/A A.·I(h"i~J tK"i -'NÄ~,¡¡--"--'----' ---- _......._ H _4_ _. _._ ...._ __ __. i¡.. yy ~',&:: \.',...: \"'¡',l~u~ '".-----..-~_...-._.'-_...._-- .-.-.. ;0..,;\0 \\'..,,;, r'O] O\;iH L 1):':1'1" i:N CJ l'I.Ut; 0 ¡I:\\'l\: 4 rl~Ff·. l'~"S\I" O' ¡,/AH . --~ .,-.-.-' .-.....- 0). ',~'Y ~'...; ll ,.," \:;\..)i.'f ;..~·Ãi(JN: , , \': ~:;..r.. .,,;\,J Olh"r ....:___~_, ~. ...",n.". ou I."l\li,~ ~(\»U¡ .- "'-'--~""'_"_'_-'-"" .- -i~- ::'--¡~~ï¡¡c_~:~è'Vi;~;¡:\;1::Õ~£ ._,--,..,-~_..-....-..._..._-~--.-.,.__...~.~-----,-._,---.~,.,.-,,~--_.---'_."--'~---- Dit;ecto~ , ;'-Javal Petroleu~ and Oil Sh¡¡¡le Reserves N/A ~, -- ,. ,----... .;.--_.....:...'-. IJ: WIH....' !III. .'-' ...--~_._---- ;)'',,;,. ~~o ~!:~: -r S,¡- ;::;t..~:~¡¡;~;:~·ö:;-;.¡¡;;~:-:,-:\·n)ii -"--'-'- ~-----:-~-'~~._,...... ......-..--:...,.,~,~._----..;.-_.--,.~...,,---~----. IkQ ill -:ìõ', , ·'-1 nl,¡;-¡¡;¡¡; 'poo:L.-õi'w 'Lï;;:Ã~ '-.:-¡. .,:,~.., '. :, :~Tr550, Crystal Plaza No.6, .Washil1gtO:n, DC 20360* .._: ~¡.. .Ii_:\)~~~tt~~"s-~{~-\\~·î:'¡~~(:- rJi¡:;cþ;:~-¡¡¡;ç¡¡i¡ª,f.I· -ct(7~-¡;1¡~iïíñd m, "~cøi;¡~i;Û:.f- w"{ili~¡ñii 's1~., 'rJ<r"~i;~-i,~;·~II'T·.~ ~.,._," .r\t~U1""~\.C(~ 25ûO ft _FWL¡ 1850 r.t -FSL..- Sect... '-1-6, T21N, Ii16W UPM ~ ~ i~6/275, y = 6,281,650 ¿t to;> ¡¡roü, j¡.I'~'VI\I .cport"d b~l",w S·craight hole At t( fai <Îe¡>t:1 . \-'Jildcat -j'i. i.··..::·~i~~-ã:·¡.::··ô.- 'J~òe](-·^-~·ì.) .IIRY-¡¡Y 011.. Anta.. See t . Umiat. 16, PM T21N, RIW ':';;~. .:."<.'. !1:ï:-¡;iiRM1,.r, NO. ·-Ï>'Ù~;:-·ì~"',n;I>---' "ÙC':O("N:¡;r ',;¡'----r UCti,,-:il.,·;¡','¡¡--- ..... J_ I.....,.. I }"AUI!Hl j .. , . ~/ß I ~~A I AlasKa __-,.......... .. ,___ -., ..._'.._ ,__'~..-.-..__.___..__.,.....,....,.___..-.~'.-'--.------ "'.,..............__...'__. "....___._'. ......,.'.. '.. ,. _. ,,', '. ..__..,., ..~_._ ,._'-;-__,'~_.__o..__...__ l:i',I~"':,"':, "".,.IH''';,.." I' (;, 11A,'r,'~ T,.U',",',i')AC',IE,:P, 1'i. ""ATí¡""(:,'O~,II",,L.,(",.~~a,tl Jtl) I',"OIt,) "I,', is,.,,, I,;¡,r.'..., HO"!'f.8"",<",{,II"".,,, 'K\I.I\.r., CII.",IJ'I!t:,.,.,),. ""I" II).. ilL"'Y" CA"',IN,'HIi'},',AI>, 01 FEE 75 123 FEB 75 08 MAR 75 t GR=28· MSL KB~40·MSt ¡¡-;.~íAL"¡'Ì;n:iï;Îii;U\1Î'Ti~LU¡¡. ÏìÃCKTJ,.. ~oÃTv.;-¡-i2, :i:~'T~~~¡,~~ "t;o~;r;':-~--r2¡C:~f~f~~ I;.~ -·--¡;~;;r.\J\~ -;ú)()"-¡'-'-ë¡-"U¡°TO()ï:a- ,,}73l' KB 2035' KB.,____I~.ee,J?_}a~Ea~_,_ " ,.2_.........,L100%~7T' J_.,.__~_ Z1.¡· h)I)UC¡X" Iwn:RVAI.(S). 01" THIS COl\l¡'L&TION-TOP, IIQTT01<l. SA~¡¡': (&10 AND TV!»- ' " " '2, 5, ...,' 'A, N, 1''''¡;;''',T,''IO, :CAJ. . , IUIlYII'Y )fADa See Diagram ' ,'.,' ,'l,¥ª$i ",;#1>.7y-nÉ¡;i:n¡a,c AN ) o,..HJ>R 1,9&.8 RUN (rBL--;-BQreî'l()Ie-geõñi¥~~"W»{:r. èQ.~ '" i '}){~tL,b,ipmeter, ~eüt,ron!c;ÇlItUn¿:¡'RaY/, ,~onie#, J?roximi t:Y¡Þ-1.i~rolq$f"d;:,,<Ye~> ',', '.,",' '." :IS" ,',' " ,,', ',,',,' ',,"" ,,'. "e^$INGR~CORn(R(¡¡o..t"¡¡.trj"l1ff.eH~lCtU)" "',', ".,. ,,'. ,,' .,..,:~o~~~i1I~~ ':m;¡~. - c.~TQii'¡;L t.h"'T." ~~TW 1I&£~'~1~_ " .~·,i~~~~~'~~!'ti~~--lr:~':~_~~·~~'0:~T~~~~:Î~~~~Q.~~~,_,~. ,','.,',',.' '..",", _!~().!~~ìfL¡'~:, ,~,_Lt,~, -,~/, ;;ll,·,~,,.-"-,-,," -~, -},i, ,i,..,:-7",l,-i,',~,,&,_·:, .",~~B,B,'.,'. -:,-, -~i':,';·~}.,·,jt,''--, ',', -"-¡~,.î-~,. "",i"',,,~,',',',"~, ¡,~.ç,'c~,~, '~,ªf~,~, ~:,,"'~~'~,\,~,. """-7'n~--''' '-'---23~-- T-Ž-7 0 ï-"K~---'9 'Vø-Ìl--c---"-"¡-36~O--SX .,perÌTi·ã"'ri'(-)s1:-cmt ,t i --'-~""'~-::i-----"---~-"':-·-'.----··'- ..'_·..'0'·..-,-'- Ll:NÍ!;R RECORD 30, " 'l'('UiNG HloJC01U) Bo;;~~r,.,;~B¡I"SA,C,KS ;¡M¡;ST~~, k-~:-;¡;;i,<~,t'~L ,-, '~1~~~~1~'-~tj~~;cIt~."..'I.~ACii~~·:()lD),- .., ' '.,' , ." "I 31. 'I'¡¡;;t1i'OR.'·'¡OI<' ¡¡¡¡:ço¡¡n íbltel'lIal. ";:/1 and 11""'_'1') L~:~~__.__~~:~~0>l..OT..!~~AC~~~~U;. C_B~!~:'I'$QUE~OI;.~:::____ See diagFam 1.~~g~~t~"L (MP) __~". A~I)~~N\) O"~"'Ti:rUAL ~~___ I I ! ,__-err_- a ~-_,i: ',', , 2\). 1HZI'; 'rO I' < MP} ~-" 1212 KB t~' , , ¡¡3.- laAT" t'ms7 l·it(h)¡;,~TIO=- I'RODUCTtON .liOTtlOP N/A HOllRS '1'E!lTGO I'nODCCTÌO~ (Fiow,ÎnJ1'. (/". liJI, pump'if,¡,,;"';.io:iUñ';[ tJlP~- oj pump) \V Jo:Lï:'ï,-T4T"G"'ã·Tj'roduc¡,., or .h Ill-in} Shut in I U:'8.'OIl' 1Ù.)'IO OIL CRAV'TY-API (COaa.). J ,if. ------... 04¡-;: Oi' .".~~;;¡.~ ClIOKII8IZi; PROl}':-ï,. 1'·03 TEST P,:i\IOP > "" on,.....ldIL;, .',. UAS"--.ICII'. 'w ATEII-D'II.., l...l..~_~jJ~Jl_ ___7._5 I !'tow. 'U:;.NG 1'~;;.J"·1 CA>;INO "'¡U!I!lSl'l\liI ,I', CAI',C, ,U,.I.A,'tE, .0, 24'noua' I\ATa &10 PSIG . ~ ~.f:~~t;~i'i·'~:;~¡;¡-GA.S (i'í\J{t¡~ u'ae~,J(lr ¡,~e¡;·v«n-I.4Þ .~c..k .-..... 'w ATi:R-'UI1.. o I I T~STWI~~Ê~~i:D BY Oll.-RBI.. GAII-)1(:¡-. J639 MCFD o "~--'--'----'_. 3;JÞ' I~¡~:ï: t)~: /!.~":1"..\C¡~~~~;-;~..'3 Loeê~tion diagram, completion profile -,-:---.-,---.. ,'---_...--:--'~- , .-' -- -,_:.- - - - -.- '.. - -,' '.- -- :,', ,-_: - :>¡;. ¡ ¡".("I';O ,,~~ti{J' HI.., tii~ foregolno: a;µt,.;-tt2td l.i.ltOfDlSY;l\ Ie co¡t¡Ú¡ei., and cow~\1t all ¡¡et~"D1t~Î;;¡Cfr-öm'ï.¡¡-itv;i¡,I¡..¡~"iecQrdïi~~-·~-- --" ,.:/~-..:-~ '7""'-- ~~;..;.r .-;~"1- /0 - . . 1 17 M'I\ Y 7 c.-. ;)Ií;:\i;¡",-,.-->:¡_C'",,-.,,~.",,_ '," / "" " 'i'I-;'{;,¡:'" ();::i:l.eer:_l.n, C11a_1':-.9,~_,__ OA'¡'J'J' · ft _-::__ .... \.. \ ....}.;, J,.\..... .j. '- ofÞ I . .., .. 1iI(S~'= ¡;.~Zl\;ct¡ü;;$ ù,ld S~~C~) ior )\~,..,~:~¡onc: r)~~Q on Rev\!r>.~ S¡,!~) (>,Lt1"Ç r-1 ~.\CK U;; þIFF, r-1 .."V",L-J, Othi!'r ¡ \\ .1 .' ¡. :,ì J.n .. Ltp' ,}-<':!"::>'~. UII.IK"t lI'H""" .\'{o, .2-.ìU ¡5.~, '"" '. ~ '1 UNIJEQ "AT !is $Q11,UT IN DEPARTMENt OF THE lNTERIOR ,,' ._ ---,-:,-/,_.,_:-,:_,-;..',.:-.:" --" "_'-'_:'-',,:,-,;\'., _'_'_';- :;:-. < - _'. . ,- t," _ ~. GEOL~ø.~:ÇAL, .pµ~\"EY t!,:;:;. WELL COMPLETION OR RECOMPI.ETION REPÖRT AND! LOG · :~~::i-;'<:":',-:',.~;-1":··'-'- -,.: ,_" '.. -:"'" -', :~-" '- :-,_'_' '.' " ,',' - -', 'n"-: ¡¡LL: ~~I~LI. 0 ;=':t.L (j: . ". ~8TO Otht'r....-L ': '.1r·t.~, . 'If:~¡ï¡¡¡Á~íi:il '' 4"HJ~-'iiií\ïAï:''''ijí): aval Petroleum Roserve #4 '-if,ï,'"íNM Ú¡;-Aí;í;í:ìTi¡'¡'¡~Qa-;~iìï..·iÍÌ"¡¡¡1iï'¡ , ~ I ~: ~ ~; If; ~~ ,~ ~ ~. .~ i ~ iff ,~. "I I '!t~ -.,~: ~;' ~ '; .,~, J¡ ~ì "'I' ,.-__t ",' ," _::~~- -,.\ _;;'.';.' 'I «.~ '...1' . .~ ,~ >::; -~ .;~ : '- .: :-: -~ -' ,;!~~ ,- 't. ..~ ',I I,.;, -'~!;~ '~ ~' :~ ~¡;~ ,1,- ~'.I: ' . "¡,~,' I ""I' "ì'~ :::(';.'- ;,j~ 'I·i . Jé . ~~ Ji m I~",;;' {i4;~ ~;,~ :~1t ~1 ~1~ ,.~'J, I'" ~ ~l~ .~~t;\ ~/1\ 1':~'ifJi-<Ã" 1 ¡'¡j~ïiÑT"'ÑAiï¡ I'i..a:r· [J, $N ' , ¡-,:,," ~;.. ~;,~ "l ; f- " ~lA ~õ;'""'wjï:i7Ñ\):-~--'-- Petroleum ari4 Oil$~l~,Resèrves D. C. 20360"; ¡¡It, $t(ltfj r?;9í."'tlKOI'.tìfr·) ~ 6. 6,30:>,30, IN , Approx'. 7P 14'16~ 6"N 156°20'lS.0"W ' .: i _ .:;1..2 _..,,_._..._,..__..~__~ 10. 1!'III1.O ^~P )'()Qt~ OR WfWCA:r 'South Barrow . ù.' a~c"T.;ß7.M~;Qk-'¡ï:õèK¡í~:·" SIJRYIIŸ óà Alita ' Cr rstal Plaza#f:lxWq.$~ir1. "WEI.I. (R,'f7"¡,¡¡:neèãiiò" ,&, e4rTI!, :..îí#..., ., 00 Ileo Alaska State Coora..Syste '850 (E); Umiat Prime Meridian.. "prod, Interval rl!portl!d below /1,"',', ."."I',',',"',.,,',a,',N..,.~, ....',." ""0",,., I>p.i.iiüi~.-...-Üa-;-~~rz.J riïl~3."iÃ1'1I - ...1'NtA ,,", , ' NorthSlF¥I,L I Alaska 11;' ::; ,T~.~RII.cHÐP.'I't:~' ,=CÖ;:1,.',.~~*u" to',','~4.) '1 ~8·I(i{;~;;þ(Pl!'i.,.i..ar·,.,fa;,~Tc,,~~-. f,fø:·~"i1~~!~O~'~,~, I,' ~U,', Pt.,', U",ø., ,· ACI(,.;D.Ò_O, ., ,'"n, 0 ,I",~a;,',I, r',M,', "U""',I".",T"."i,,r, L, III CO, ", f'L".,..,',~ ", " ",',,:,,·,.,',",',1· 11;" 'NT, ""IIf!.V,,'A, ',..,'," '...,',."",",..',,', ~,',Q,'"','1',""'.''',',,.ß,..,,.,;,,',,'1, ,...,),0,,1..,. , " ,C",A, ..t.",',',,"',.,.,', ,',Tf,}91",,' 20S8 ,'~ 'HOW~ï~·',,: ",:' ¡ )Rt'.L= )~~I,2'2,a7f~.~~L__,·0 ,,',",' , UITlJ8V.u.ls),ÒF 'rillS I;OMN,CTIElN" ~..; .O~~,.I'JANJ!I(ItID ""D'TV!). ;". .,'.', ":m, W"3f11~1IIC''''IOII.U, ." " " , IiIUavJ J~fUD. rrOw Gas Sand,.. Geologic, al pa.rtiQulars on. file Qff<icer .in. , ' .' Sectio.n 26, 'l'22N ,'R], 1w , ;. Yes' . ......--,.....'~-'7. W /Iii" Wia.I.'. CORJIIO W8iÖITT. La,/"_ 175# NßO 51# PSI 23# C"SING k1l1COJ.\D (J't'epl/l"' an "rifla. .6' "I' wetl) , ~ DlDi>'1'U ..'1' (J(I>~iiÕf. IJ-.ßI¡iÎ1---:. -- '-'~"--fiiìj'iti't;îÑìiÏíil¿:¡U )''''-~~' -. ~._¡ '160" 22" '345 ISX PermafrQst' 1067' , 14 ~. It ....950 S~ I?E'rmafr.)st-----~·- 1884' '9~8" 340 . SX pe~m." :nõ-sx~çî~ 1884 LINERREêóaD BOTTOAf (NI» 2062 .ACKaCIIMI11'1'i. 30. "'., "TU'lJJNOJU!ì<';QRD"',, " ,',',.,' ':~:t= '. 't~~ " .1~i7...~(~!212.~;*...(··) 82. ~~.$IJÓ'l'. rttM'J"t1lU~:' CEM:¡;N'r SQVEEZ~. Ê'1'C. ............:---' .._-~~~~ )IU,'T" fNT.RVÁ~, '(,JiD) Å~'qlÏ"T A,III) K' NO or &wr~IUA¡;' TillED r None ." T ,,' TOP (~ID) o ~uttO"BlI:CORD (1!1tervol, n." _4.._"cr) ~,. -.-.- .... .-. -.- - - o 3601\' . .:1 . , _I,. WJr.Li,-, ,iT.TU8 ,(-:rl"flrific¡nl1-¡;;;-, ' , ø¡lId...,,)' " ',' Shut in .' ", ~ATIIR-~B"L. I UA8~ILt~I~> ~nL. 1011. ~;~TY~A"(C~;) [TID8T WI"1']\I11I"8.0' BY . I A,. Crane ~{/,~><: t_~, ..ODUCTION roduced I ROllalll TI1ST.1) I CA8INDP.ID~IlIUR ¡ Þ faitlON otOA8 (80ld. sued Irw "'d. vMUtI..,O.) PUODUCTION I f'80I>VCTfON _wHoa ( i'IO..ÌII'.'~lflt.' I..."¡!lrt...,....y. ...If .",.. 0/'1118') . ..' , " ", . ':: ì ,;t I f'ROI)·8. ..08 " TII.~.""", 1',' .,,' ",ÌOD ,'.' ). OIL-o-....; .~.í:)../lTTACH)IJl:NT8 "'(S4:~ In$ttuctions on'" SpQCeafor Additional Data on Reverse Side) ~~tipo.i ;-, t back Pl"<=,;sure test. I?,rm..t,,· , "rm,au<!o 18C!OjJì'l!, ',,0,' I"., <',0, "',-h!te ., od",e, ,o,rreèt ...determloed t,rOQlI ÌI ,v.\lïi;)'I.;r;ië"ï.;t¡~ ~~-,lþ, , . ;lTt~ _ifÜ'ci:r..j,n Chilxqe DATI~ __~:.2B-75 ,..,..=--:7r</~~ :G1IJ'BJ) _, . , ..,- "..... L~ R l. ,. ... Form P-7 . 51 A TE Of ALASKA OIL AND GAS CONSERVATION SUBMIT IN DU.E. (St:~ other in~ struct¡ons on reverse side J , ~ COMMITTEE 5, API NUMERICAL CODE WELL COMPLETION OR RECOMPLETlON REPORT AND LOG * --¡::-'Tý'PÉõ t b, TYPE OF COMPLETION: ~EW rv wonI( 0 WELL L£). O,'F.R 2. NAME OF QP.RATOß 011, 0 GAS 0 DRY 0 WELL WELL Other DEEP, 0 PLUG 0 )IFF, 0 ES DACK r..ESVR. Other N/A 8, UNIT,FARM OR LEASE NAME Director, Naval Petroleum & Oil Shale Reserves N/A 9, WELL NO, 3. ADDR~SS 01" OPERATOR Iko No. 1 Rm 550, Cr stal Plaza No.6 Washin ton DC 20360* 4'. LOCATIO:'I 01" WELL (Report location clear III and in accordance with anI! State requiremenl8)· At surface 2500 ft. FWL, 1850 ft. FSL, Sect. 16, T21N, R16W, UPM x = 716,275, y = 6,281,650 A.t top prod. Interval reported below Straight hole At total depth 10, FIELD AND POOL, OR WILDCAT Wildcat 11, SEC" T" R., M., (BOTI'OM HOLE OBJECTIV~) Sect. 1.6, T21N, R16W, Umiat PM 12, PERMIT NO, N 13, DATE SPUDDED 14. DATE T,D, ·REACHED 15, DATE COMP SUSP OR ABAND, 16, ELEVATIONS (DF, RKB, RT, GR, '.ITC). 17. ELEV. CASINGHEAD 01 FEB 75 21, ROTARY TOOLS 100% INTERVALS DRILLED BY See Diagram CAULE TOOLS 0% 23, WAS DIRECTIONAL , SURVEY MADE I j Yes Borehole geometry 2731' KB 22. PRODUCING INTERVAL(S), 24, TYPE ELECTRIC AND OTHER LOGS RUN DIL, Dipmeter, Neutron, -2;;, Gamma Ray, Sonic, Proximity/Micro log, CBL, CASlJ.'G SIZE WEIGHT, LB/FT, GRADE DEPTH SET (MD) HOLE SIZE CE1\ILNTlNG RECORD AMOUNT PULLED 16" 75 N-80 149'KB 22" 660 sx frost cmt 0 10 ï4" 51 P-II0 1190 KB 14 3j/¿ I 810 sx permafrost cmt 0 7" 23 x 1270 KB 9 :>j", I 360 sx permafrost cmt 0 26, LINER RECORD 27, TUBING RECORD SIZE TOP (MD) BOTI'OM (MD) SACKS CEMENT' SCREEN (MD) SIZE DEPTH SET (MD) ¡ PACKER SET (MD) 7" 1?12 KR 19¡:;o KR () :00 1"); "',.,. ? 7/0" 191<) KR 1\1 r. 28, PERFORATIONS OPEN TO PRODUC'I'Iu~ (Interv~, size and number) 29, ACID, SHOT, F~ACTURE, CEf\IENT SQUEEZE, ETC, See diagram DEPTII INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED none CASING RECORD (Report all strings set in w~U) 3{), DATE FIRST PRODUCTION 11 MAR 75 PRODUCTION PRODUCTION ME1HOD(Flowil1g, gas lift, pumping-size and type of pump) DATE OF TEST. HOURS TESTED CHOKE SIZE GA.S-MCF, GAS-OIL RATIO PROD'N FOR OIL-BEL. TEST PERIOD --.. FLOW, TUBING CASING PRESSURE CALCULATED OIL-BBL. PRESS, 21-HOUR RATE 810 PSIG . 0 31. DISPOSITION OF GAS (Sold, uoed Jar uel, vented, ete,) 32, LIST 01" ATTACHMENTS Location àiagram, completion profile "j~, ,,"u, '""' ,", "'''''.~' ~O. " ".,1..,.., """",. ",,,.1.., 1m. ,II ,..11.'1< "",', SIGNE~ ~I.e!Officer in Charge DATE 17 MAY 75__,_ *(See Instructions and Spaces for Additional Data on Reverse Side) FORM LA 56 .- DEVELOPMENT ((',.'11 t~o -Ö~3- d!OOO'/ .., 5M- 564 -LPC AREA: AJf;2 - II CORRELATION DATA REASON FOR DRILLING FIELD WELL NAME: -, ~'-=::'-:==' I BASE EXPLORATORY WELL ( ,i/~ ELEVATION: ~ &"e?') OPERATOR: \) <':.:> rJ(),.Þ)~- LEASE: '-:J.~:- k ('.:J SEC. / ~ T. ç) t to LOCATION: ,)¡Ch' l ê) t!, 0. () I (, J) () ;;50ö'[, COUNTY: STATE: QÝ() J-I¡J,.. (' ~ NAMF.: I TOP -, -'~"-'-- t;,tR -(.';'.~~~l c ,:i;Ç , 1 :":~I~ i. ,"""" .._- ,,- R\ ~ uJ WELL NO. 1 ¿/B Be M. " Co ..--....' - r,. j' )(",/j/AJ /Y ,~c I'¡_ l!):J',\( j.. '::1 ) I,¡;' ..-Þ ........ (.h. ,,- R¡':NG 1 Of:OL I\<. -12'ì'GLÖ\_\ ·T..··~~, (;CC)L , " ..l'</.._L DATE STARTED :;-1.-1>' COMPLETED: 3 - 1271S ABAND.: TOTAL DEPTH .J"7 'i I / P. B. I.P. CASING LINER AND PERFORATION RECORD DIAMETER DEPTH CEM. PT. SACKS I PERFORATIONS AND REMARKS "¡:", :,: ,---- i /~ (I 103j.¡ ILf~' / /7D I x~ 7)1o)~7~ Y ~ fa I ~ <6 ,) to 5'0 , .j J ¡", ! -¡ I 'I ¡I /J",ì'ì' /: / J~_," ELEe. LOG INT. BY PALEO BY FORMATION AT TOTAL DEPTH WAS ELECTRIC LOG RUN? DEPTHS: DATE DEPTH HISTORICAL AND MECHANICAL INFORMATION ~ lohi 1.\ ,() ()('"'\I, -l~ N '.'¡ , ,:....~'" ) / _~J\ ,k, A" ~""Á1' \ cy. /), '-, ":1 J))~ff?.;¡ {\'~(I.· (1- JJ'_A) 1_.. -"/"Å,Cn:' ¡ T .A, , ¿..Ji" ~..... A'a {/ rrf lì / ¡''/}'" "~ /)I//ì( /;í ~ ) )1") r7\ í), I 7. .¿;; /;/,. < (. // j"C1 I k( ,~, :',,:r. 7jl/) , ' / (7¡) -7 1 :;2]L¡!-¡)" I L'l I) Y')( r\jL~...r~~-:fÞ ^-~ r pJ'v'\,Ø. 7~ (ð 14t, / ,-:Ill' //7.1 / ~')/Jr". %'3T/1 p ~/9ð J /1 CJ d 3 Û 0' ,&1-. ("~"_'-- tP.. ;J utð 1 L. A'/frFatv .du'vt.'( 1 () f?n _I~..n -¡-tl J j. " -;;( )-) ) ), ~. ':d. , (j " .-!., \ II J..."1", ¡ -Vl.1:ð .(' /] I, if), ;;.wf11~ ....v-. JL.- ,-I-h '" - 1/.,$- JJ /í1""" .&/'u>l , ùw"'7l/; , I Bo~ -'~)f\? ( ....-- ;jJ,. fh¡ AJ ~ ~ðO' _C) OO('J~("ì) 0....u ./1 .¿'nO sf.iIAn 11 , '..' Î') T?"'-/î j j", IJ' 'J:p :J ~~ () T V I I (ì.À.,...' :01',£" .:J'7/JrJ ..?1 ~L () J' -IJ-: 11.:..:J 2>;3 'l d 3 9 Í> I ,;) " I ()- ,). i/1D ! :J 7on- 31' J?/'I\ (),' / --DSJÍJ ;2 ,¡;¡¿j / I _ ,) /) c¡ I ~..A /¿Ji¡JtÌ, . f1 ¿IT' L) ,1()~ AvId J Á..{V I" "7:: b "7lj "~.I fi :r¡ ()1'7 A _.~J7IA7: ~ ""':"'AI{ p{¿ ). ./..!- - d _ ( /~:/ ) d /') I' -I !- hr-..", /Å /YYJ..U ,{/ 7, 7f :7 _'7r 7;;,~~ /J _ _/ 'h~ A'.n /1 r I ¿¡ <¡; =. !/:>,.7¡ 3 '7Fl5 =- ..=J_ b "7 'F ~fl,=- :},I;"7 P<'~- -r - :J q, L./ ¡::.Jj .0' -= £.3,~:::P . A¿.~/,jJ~..;,,.,~ C¡¿' /' ,'.J<¡, , ,-# .ij ;'¿,1/ . ¡-.(; ((' ð), Ii / . X ," /', ". , . _.1. _" " .I / I ~,;/ /,<;,' . r ¡.t' " Cy' r'....@...)u~' ;~. , , . .........'v. \ ' 1'-'/ ~ rc (¡1) r'> _ n 'ì'In f6 ~ \.!::¡ 1$ L;¡ U \:I u.. Jl " T ~ '''. . u'\""7' 1111-\:\ I " I;:I/,J hit! T", i;! I..... 1'>11 A .r" ,.,." Vl1 "l'J!ni~t 1t(\':.'~",~n.v\JÆ,J . A ~ A~ .0 I , ~ - ~ 2.3 IKO No.1 WELLBORE COMPLETION PROFILE Depths"KB (feet) 18 149 166 1190 1212 1220 1270 1939 1950 2035 2210 2702 2731 .0" '. "0 :: ", . , . . .: . " . . , ' :. :: ~: " :. . 24" Conductor Pipe, I J't. 22" Hole 16!f N-80 Casing: 4 Jts, 751b/ft Range 3, 8 Rnd T & C I 4 3/.." Ho I e 10%" P-IIO Csg: 37 Jts, 51lb/h, R-2 Buttress T&C, Topped wi I Jt. 103;;," N-80 Csg: 51lb/ft, R-<3, 8 Rnd HC 2%" Hydri II CS Tubing,; 61 Jts, 6.5/llft R-2 BROWN Liner Hanger 7" Extreme I ine Casing, 32 Jts, 23/IIH Range 3, Flush joint 7" Extreme I ine Casing: 32 .Jts, 23/llft Range 3, flush joint. Slotted over the fol lowing intervals: 1242 to 1274 1307 'to 1370 1469 to 1536 1562 to 1648 1732 to 1775 1905 to 1950 Cement plug 9%" hole 7%11 core hole .. w. .. fit 4t 2 I L¡ LaC A T ION ~1A P 29 28 27 32 33 35 T22N ~ T21N ~ 4 3 .~ C 8 9 ~ ~ \ IS\) 18 17 ~~ 23 24 ~~ 19 20 ~~ I KO No. I WELL LOCATION scale: J: 63,360 -. ~-, " ,-IGURE 50 lSOp~""" LITItoFAcIES-!f,1p fR.Jb . '-';~'~:>...,~ .,' " ~ -". <:/~:,;"i:_.: . S' "'--5 ;f;';:e,r- .5'-", ý... d/" -, lie"f~"5"'i> ' .~" ~ I;:'.;:",,&- :tlg,¡,;" Pol;, I. ' 100 QUth Ba,.,.O., 3 ," , 16~ ""ù3ì- SOUth Barro., '13- -ofto SO"th Barro", 11 _ /'6 ~/()~ ~ Cape Ha, kett 1- ,,00-0«3 - West Dease --1 """, 100"('1t D"e~ POlntL'__, , ¡':b~/OO: liest Fish Creek i, , . /:;,;~~ I~'~ "-¡~~s.. Boil 10ù-~ Ikpl/cPUk 1 ' 16ú_I~ [ni90k 1 ' 10õ-161f North lnigole 1 160_tsS-Kugrua 1 IOú -15(, KtlJ'anak' 1 :::: -I<{'j L , sb""ne 1 '15"<-( South "'eade 1 10ó -J.;)c. Peard 1 IO~-1('3 Simpson 1 ___ 106_~1 East Simpson 1 1 ð6 ~;}63 East Simpson 2 ICo-/~':1 South Simpson 1 1O<J"6'J.. East TeShekpUIe 1 ICJ(J_ /"is- TopagOruk 1 100 'o<t]. Tû, ageak 1 100':J;JS-Tllna'lk 1 10ó"¢C.(;J Wa lakpa 1 100-o<1t Walakpa 2 '''>'<81 S'nèl.'r Cn"'II. Arco It/cilllk River 1 n.d., not dete~ined. In the nOrthern San.stone. 1lre Part 0' the N/>1¡A. f.lrl, I '0 36 't (IJ oJ U::' ~:~~ 'hn thickness f:;~b 21c:n::'n(~6 the Sag Ili ver JUs, sOU'h 0' ... s C....t I "'th nJ ., _..... I the SOuth .c"'ss Par."., '0 the Bar';'" ~f '... 'hlC/r.st "'.'0""'.., nort"'rn """ 0' th th~ lles.r.. .n. Þro""b,.I' g~. 0..""1' thins t....r. north ....... I, I· 'RA. In the B.r..... s ''''s.nt "'.1' In 'h. ·P."",. S"",.. :c"ÞS 'h. Barr... ~Igh. E.s~""'¡ fR'3b 'hlns '....... 'h. ·Þoo.rs to 'hlct. ""i0""'~ 'runcat.. fR 3b OM lleas. Inl.,. 'h. baS.1 "'hether trunCation ~ O"'a,r. t... nOrth'nor~St ear Deas. In'.,. lR.Jb ' . r .. aþ OCcurs. . .n. It I. .'c.rt.'n - Unit TR·3b Is th . I R.s..... 0. · c ··"st· stra"g. hi t... nort....... ·Pa':,"s~", 1Itha'.CI.. :, '.:. 7/t :~III.. t. da'. ... 'he . . '. , c.n., Sting 0'. 0 'he NI>IIA ....... It I. . or '''r Is """r/ct.d t, - .> >" . I 1I<"".s "11.1' sf I ~ S:rl.s ., .'.r J .Þþ f ng b..;....t ~'t. s.... Þ"'bab '.1' '\:"''' " ":', fR -3b COns f sts ., J f....... the "St ... Sooth . I h. Un It b.c.... s ~':' .' . . ;..n'~~.~:'~!~!~;~~.::r.:. .h.... '.cI.; ., ;'a~~~r:~~s:.:r~ ". .s.n...sJ>;, ¡¡........ fo' " ' .', .. 'P'.. . , .. ::~!'Of;I¡;¡,...:\ 1he · b "fc.t., t.. · .....s .,. '. ........,.g.;;:,., Soo'h·si: .... r.... ."". f. ~rt::. ."r I.þþ I ng bar" t. "'"'' the ·..th..st· t .,.,.." 11 I. the north . nOrth.....,." 1IPR.4. ':<$'8 10o<l 'san. "';'0 · ...... -.fn, I t. t... n.rth t. ...... I .n. ICuWl'Ua I '0 ,:.t':;~9: thl.... ....".r .f!r!ot, Is .sSOCI.... '" th '... "1,~j, C 1100 sec."" ..... ., " """0,, the FIsh Cre~\ 0 Pls·"'Geat.. .t Itþltout I ....t PI.".".. ~ '·~~!.tlc... '. , .t,.". bar .r ea. r..r.":!..."".n ..._.. "-. -._~. -------..-..:..-: "\{,'94 47 ' 50 80 , 131 , 151 fl04 36 " 54 "d06, ":,51 44 93 132 132 (1) 122 216 116 157 154 143 129 150 117 88 126 147 46 74 37 66 35 48 47 44 39 46 36 21 38 45 14 23 29 14 IS 24 40 46 32 II 17 32 16 13 28 40 40 n.d.. <118 Sand-Shale Ratto 3.4 ' 1.8 >118 1.4 1.6 1.8 3.JJ_ >8 111.2 . 3.1 1.6 <118 115.2 2 4.8 1.2 ' 1.8 2.1 2.3 3.0 2.6.... 111.3 - 1.1 2.0 <118 2.86 2.3 ...' · . II \.'L"W'~ V- ki ;'£l~k Thickness Feet· Meters ~nd-Shlle, _ Ratio ' , íÒl>-lo<{ Atigaru Pointc-1 IOD-~ South Barrow 3 100-03'7- -South Barrow 13 I()O-O'tO South Barrow'17 IOÞ-/öl Cape Ha)kett 1 10ó~3 West Dease 1 H~(J-I't Drew Point 1 IOO-I/)() West Fi sh Creek 1 IQo-/o3South Harrison Bay 1 joo--ØP lko Bay 1 IDó-iJ(X.) lkpikpuk 1 loo'ffl In.igot 1 ~-IOtJ North Inigot 1 tOO "(5"j- Kugrua 1 IOÓ"sc. Kuyanak 1 oO-/1.Ft Lisburne 1 100 -1S"t/ South Meade 1 IOi:p-~ Peard,!" d_ 100 ~/"3 Simpson 1 IOI)"~1 East Siaapson 1 IOO~ East Simpson 2 lOb -;~ South Simpson 1 100 -'6J. East Teshekpuk 1 lðO-fØtS- Topagoruk 1 (06-df9. Tulageak 1 IOO-~s-TuAa1ik 1 t DO..dId Wa \akpa 1 loo-óC{1!WaJ.akpa 2 750 148 181 503 178 431 71 252 667 643 580 150 136 616 581 ,(f) 714 205 520 282 87 814 1,038 782 812 140 640 613 *n.d~, not detenm1ned. 229 228 57 153 54 131 22 77 203 196 177 46 41 188 119 218 63 159 86 27 248 316 238 248 43 195 187 <1/16 n.d.· 1/8.4 1/3.2 <1/16 1/8 1/16 <1/16 <1/16 1/3.9 1/16 <1/16 1/11.4 <1/16 1/11.2 1/7 <1/16 (1/16 1/16 1/8 (1/16 (1/16 1/16 1/9. 1 (1/16 1/1.7 1.f1.1 ~ Unit J-1, which contains the reservoir "Barrow sandstoneu in the Barrow area, lies unconforaaably on TR-3 and is restricted to the northern part,of the NPRA. J-l is Early-Middle(?) Jurassic and coincides with foraminiferal zones F-17 and F-18 (Anderson, Warren, and Associates, 1974-1979). d The thickness ~ of J-1 is related to its truncation by the overlying aaid-Jurassic and basal "Pebble Shale" unconformities. The thickest section penetrated is 1,038 ft (316 III) thick at East Teshekpuk 1; this section extends to the west and parallels the Barrow Arch. Northward, toward the Barrow High and the Barrow Arch, unit J-l is progressively truncated by the basal uPebble Shale- unconfonaity. In the eastern half of the NPRA, the lIid-Jurassic unconformity deeply truncates .I-I toward the southeast; .1-1 thickness ranges from 580 ft (171 .) at Ikp1kpuk 1 to 136 ftJ42 II) ,at North Inigolt 1.." ~:.,.' ~. . ' \ In the western half of the Reserve, trUnèai10n by the båsa1 "Pebble Shale" unconfona1ty' is more gradual, and 140 ft (43 .) of J-l is present at Tunalik-,1. J. The''.¿'nìicí;''Ju.rassic unconforlll1ty probably truncates .1-1 cQlPletelyttn aReast-west direction across the middle of the .PRA. ::;';~:::~.-~<.-_.~.__.",:~.~~:_::~_.,"~~ --:l:;.;-".._-:~: ¿~ ~,;.~-,,::.:,_.:.;.__:~,;;,> _'_ ~~. :'. _'_ _. .'_<: . " :,:_< ,- _ , ,_ _,' ''__ _ _ _ ." _c, '"-, -:!.\ :?--'¡'-'-:: '\c-:-~'-"'un1'toi.r.;l~è()ditst$~bf---~iC:f;-Ci¡-'j·;"deposi'tedc 'shá-le-ün1ts-that,coàf"se.,úpWa'd~'· , into:siltstone or sandstone. The only econOllica11y illPortant sandstone in J-l is the -Barrow sandstone.- The unit'becomes increasingly argillaceous toward the south, away frOll the Barrow area. At South Meade I., I ~ sand-shale ratio of 1 to 1 probably denotes the southern Hlltt of Iny potential reservoir rock in J-l. )-'='~-'':'-._._-- ....,.~~~-.."'==-=..............:~·-:';·.-s::'~.-.:~~_·.-~-_·_·· --I --'---'-"-'--...- .. _~ _ ___.__._ __'__... ,.. -----'---.-'I--'. .',. u'" _ ,~_~~~. _ ",'_~ ~,~_~,--::-~~::::=~~".~- ~~~,~." ,-,~, ",L___, ~--_.~.,. --. ',',.. .jf- ( I J I [ , "I .... , ", '-~~> ^':'~~"i;i ':'..'~; .. I .'," ".::. ,:; , --I [ I I I I J J ] ] -"-"--~"'.=..'''''''_~--''''.- ] --'] ..,G IN WEST BASED ON SEISMIC ~PHIC INTERPRETATION. L~ ~ BARRO~~&~R:;W'æV ~Ò SO....I.URO," "'" ~, ,~ _2.~I.'~.'·id:~ I.. . ,.~~ I!>O _Ò , 0,' ~,SO.~&itROW' i 2::~:::.:1:,~~$,r~~ ~' ,.K~, ,~O "'-- ~';':'4 "':-:":':"_.I,)tl:':,:,,,,:;rIO&,:::::] ,D£·~r!,: ':,;,'" " ,..' ' ,,' ,-.;.:,,~t, . ,''it' , 151 , '. 4Q.'-." ,:,'>/:\'"::,.::,,,- j,;/i:,::Ji!:' ~,~&·~fr::n~\J~::: '::::::'/\':}\:-- IlImN I + " ~':;,,:::,:":':':',:,:,~ .;;:' ,::,:6:':...,:·' W&L&KN'i .::::,:,,~...::,:..r;:-:~'~{f:':': :.: + A:' ',' ',',:',",'.. '''-..+ ...'rA.:,:¡:.;.,: :~~t\,ç,...~"....",,· .~~ :,~l"" .0 + ' t'~:, ::::'::~ ~'" ,0;;::', ',:.:,:',','::~ ,::::. V:':, ~ ¡..;~:~~:::: '::=>fV.:~i:~,: :6;i:¡, ',', :.. ,,'. ,1I1~ ON 2 ì .. ..,.. ...... '.....(.... .,.; '....... .;,,, ,,~,/¡; ~. .i:: .ii.',: ';;;:+-;',;~~~'i': . " .W .." ..", -' ~~~ ,'.'::" ......; ~~ ,:>~; ~::~'~~R :::4.:~~:::::..::.,.::::;:,:, "'::;;':~::'~ :',~..',','''::': ,:,:~6;:::,.... ,.:.f...J!, ..i~: --;...':( rr:1' .." _~WT FORM I , ~ .~ .,', ;',:.:,~, ':'y,y;/"'~:'''':,'''':::':r ,';~ ,'".. :... .:," '..' ". ~.....""., 'II!", ':',':.... .... '&:"" ;"I'\N~ .iT K ;;::., ,,.""... 'CO ¡¿. .....:. :·"i,:·.'i,'·i,:":. i.':"'" :'i&j;':""'>'""":"i' ", ..,'.i;¡. ",' it w,... . ,.., . .,,,,,,.:.'. "'" AT. ~, ,", Y7Xl ~~~;~:;":::::êç./,~]X;;f;;'I?;\+¡~;:t~:';; , 'nn?:tf;~~ , ,>;,,::,"!So' i-;'·,::' ," ,:' ".: ':·:,'::'::':'::':;:.>':Y::~:::":~::~~,I~Û::,:-~":':::':-:~',.:.::.;;.x::',:,::,,':[F::'::·· ::",' - ::::<:;: ''':'ir\\\>?>~: " '~'Jß ...' ", ~·:::'·:':,':l,,':':~~:~~£~":';:':"~",'.llf~;b¡'· - - ',", ,::',:::;'':>'::,:-:'., c:';f"""' ';;/-'" ~): ..' ~. ,~~:!, """,," '. '.. . , ,;,.....~~ _ - - - ,:'~z. - ,,".;;u- - _ !K~Kt' . ,~~;.' I" _ - - - :':( ~i· !!!!i"- _ .. u - .. . . ..../.;ë!. : _~: ___ . ___-.:..:-_-_-_-_-:...-=~--.:r----......F=~-- -_ N, ::;:.',..' :~~~~ J~ ¡JJ - :...:;u- :----.:---------:::--=-~---=~ - ~"'--:.. ----~ - -t-__-__-_-.:-=-=_~~.~-:. _ _ - - ..:-:-~---:--~~. :, ? ~\~~~~=: =-- - - - -,-: ~~::::::=::l.!-::---:- I ~ ,,-i..-_ \J(~I.., fl' ~ ,-~..;r----- - -' ~ - ;_u --;: ~ 'c ~=-~;--;:--:--~ -'" ~ :-~tt - ~:::.=t.J.z¡,. _ -.;" ;'1'" "- I 41. \ ._,¿, .' "'-~~=-- -_-_ .-f . _.,. - _--u tc~ : c?Š;:-: _F+_-_ -."".-, ~ - ~ - ci~-::Y' vto,., } r'. . ~ ~ ,s -.. :C? :~,~, - --~;:, - -,~.~.:;~:~-I ~~">:--O'i':c_::f~ ~¡'" -1:_ c: _~:~:~u ! .' ~ r '/. "} ~ ~-+- -:--;,---:::,:-' ,"' ~tJ~.~%; --j"£~ :-~ ':!Ç~-:" -¡.- ., -- If 'l~y:'~~IJ ~iMì~:.,,,~f~';;::~~ ,; .. ) ! I' 11 TN.R,' ß\ ~.OL:;t~~~. \ '. ' ". '-.-/.. _.! ..'! ...~:: 7; OJ ---.- '-;.. T -- ~,r, /-/p\ rç \,\ \~ \ 11 { ''''jF - _ ~_ \., v-..v ~!) , J¡¡ n", , Ii 4;,:,:","" '. -1 ! ~ "T ...,._, '~__ ..JL-~ '\ ~J '" \, .......~: '; _~f_ y\.,... ...... ..,~ ~,._ :__, ; T i \- - '" of'~! ~;:-i.' 1.,._ ~ìE1I2 ,ìo....L ~!\. J I to, ....oo I·I·.'..~ ,..,.-., ".... ....-' ......1\ ".'....il "".'''1\' 1" l \ 'Yt".1 ,I 0 J!f. I JZ.L ,! I ... ...... '- '" \, t. ~ ~.A ~_.._ 1'--- T ...V, .,~ --- -r , I;"" \ ; (. "-' ~~ I .... ~...... '. ~ _I \ WNIFULAIIE i ¿ ~MTWIIT'-' --\. V~_J"II n -L- ~N,'!:...1' \~' ,\ -.... V'U7-h \ I ! ....ï~ ^- \.J .' '-- ...... i ..,,- ...'. I..c.;¡¡¡ .i ~ 1I'l~.\ J~ ..,~~.:r -'l,~~ ,~ ...- ---rv ~~'·...~I ·····Jí. :.......4 .··,·~J:~~Ûthf '\- ~L 1 ~~ ,I . 1 '14 ~,. 7' 7"""'" ~ I r!: 1l5'-'P If''--'''-r 1\ I \ II V_ ! ,,\ I ! 1 \J ~-.:.._~L(1- f ' I 1:9..~ "71 I 'r;>~- \' ..J..s-c.~ ~ L; tho f-';"'(:..¡~--s I?ctr TF(-3b C UH'I t ,,\-/¡"..s S o..~ J?, Ve.f" Ss. ) '-re-tr--rti.. k-~~h h;" tt- ( Ti¥ i: (No. 1S..2.(0) I '1"il:¿ F I ~, ~p + + + CHUKCHI SEA WAINW. . . ~... , ""\Jo______ - .-- _l ¡·.."l- I , I... ...0) ,. ' t? I ··i ~j,...... I ",.rW~ I I T I I ..J.!....-o. . , '. -.-'-" '. Thi cknesš yt\ Feet, Meters Sand-Shaléi Ratio';<: '()ó-:ltJ!.l,;: At i garu> ,Poi nt 1," /Ob~ South Barrow 3 " /Öó-/OI Cape Halkett 1 /Ci.>-ao'J.<J. W. Dalton 1 i06-ö'l3FW. Dease 1 IOb-1CJ'8' Drew Point 1 /Dö-/OD West, Fish Creek 1 /06-/~"H w. T., Foran 1 - 100-103 South Harrison Bay 1 10ò - 03(.. Iko ·Bay 1 (0() -drP Ikpi kpuk 1 100- ,~ Ini gOk 1 IDO-Ioft North Inigolt 1 loO-tss-Kugrua ,1 100 ' ,S1c, Kuyanak 1 /00-#1 Lisburne 1 /Oó-t5"<{ South Meade 1 IDO, ~'-. Peard 1 ()O ,11,3 Simpson 1 loo-got East Simpson 1 loo,~3 East Simpson 2 laJ-f}~ South Simpson 1 IOO-/ð;). East Teshekpuk 1 I£?ö-,~~Topagoruk 1 IOO-Dn Tulageak 1 Ico_~~Tunalik 1 100 -w;) Wa 1 akpa 1 IOO-cI-I1J Walakpa 2 255 165 215 139 67 510 231 93 284 58 480 343 152+ 372 184 250(1) 238 300 269 431 382 524 181 370 67 , 470 284 313 '~~-&5I Sinclair Colville 1 324 , Arco Itkillik 'River F . 322 ,78:' 50 66· 43 21 155 70 . 28 ·87 18 146 105 46+ 113 56 76 73 91 82 131 116 160 55 113 20 143 87 95 99 99 ~ ~~: ~J_2;:",:':'''2~: :.':.,iifi~·)C 1/1.4 3.1' 1/1.2' ,0 1/1.2 O· 1.2 9 <1/8 1.8 1/2.5 14 1/10 1/6 2.4 . 13.5 1/7 ~.4}'j 1/6 18 n.d. n.d. <1/8 1.9 1.1 0 1.2 1/1.6 1/9.5 0 5.1 18 1/2.4 . 0 1/8.3 10 o 1/1.1 <1/8 23 <1/8 1.6 <1/8 0 1/1.3 0 1.1 5.6 2.3 8.5 2.1 7.9 n.d. n.d. *R.d., ,.not determined. n.d. n.d.' , ':'""' -~, ~,' \,,~?1f.:~;~tf··{';/0~0·o..-'L;¡:,}The,.-.TIi:3â,j·un.it(ê~in¿1desS'w1O,th' the Shub 1 i k , Formation. The ~;:~£~!~:;Ii:,.,;~,;·r:£:~~ë';;:rj:~c:.~~~:Varlab 1 e,èithicknessXof the ·'uni t is assoè1 ated w~ ththe i(~;~~:i~' " 'Iffi.t~cipa~te~~ºn!ç:"feao~Mr~,~;~f.,tJt,e,8PRA.;/.J,r!:th~lJ!~~terlLh.a 1 f Y~>,lš'~¡~'p,,,, O!:2~:.t~,~i~êservei( the! maximum' thickness ,,' of TR-3a occurs 'at .", . -, . .; ".' -,.:.' _ !..,~-.:~.;'::.~',~~~-;--~::~~:-:J . _,,<;""",-:-.';':::-,:,;.," ,-:-~' -_;'~-:I:_',_,"--' .' '.'" ~'-::"è~<' .:"il:~,iC(;~t;ft,~,>·,},-;:~;.,·· ",.) '.',',';, ' . ',::-',- - - :?~; ,- .~ ',' . . ". ,",'-., :: ,.- :. _ :·::t.'~~;~.:::~6'.~. --_"~~-~-:~,;_,~,,,".~. ':. -'.". -~ .. -.. .--.. ..--.---. . --.-..-,.-,- -,.'.. ..- - '.- .........--" }t:·'~:·(i~"'£~~;þ¡)l~~:~~~;t;l~-~,, .:c·c ..", "'.0· .,'''.' ," .....~""-=-....-.. ,_ __ ,--.-.--.;....c-:=-~~_=:_:_..--_-.:::-~~=::::.:....=;;:-'~_-=-__. -,o.-:-,;-:,,:,:~:~.~.__~~_____ 0"' ______._ t·" ",.., - . . Ikpikpuk 1 (480 ft, or 146 m) and Inigok 1 (343 ft, or 15 m) in the Ikpikpuk Basin. East of the Dease Inlet, the basðl "Pebble Shale" unconformity truncates TR-3a. The truncation zone runs roughly east-west and is just north of J. W. Dalton 1 and W. T. Foran 1. West of Dease Inlet, the unit onlaps the Barrow High. Thicknesses of TR-3a at East Teshekpuk 1 and West Fish Creek 1 indicate thinning over the Fish Creek Platform. Thinning also is apparent on the flanks of the Meade Arch, as indicated at South Meade 1 and Kugrua 1. In the western half of the Reserve, the unit is thickest at Tunalik 1 and thins northeastward toward the Barrow High. Lithology and high ganuna-ray curve deflections within TR-3a suggest that the thinning may be due to periodic nondeposition. The TR-3a unit consists of calcareous carbonaceous shales and siltstones, silty limestones, and silty calcareous sandstones. Glauconite is a common accessory mineral in the sandstones, and thi n shell beds occur throughout the interval. Sand-shale ratios and clastic ratios indicate that tbe best sand development is in the northwestern part of the Reserve. High sand-shale ratios at Peard 1, Walakpa ,1, Walakpa 2, and Iko Bay 1 i ndi cate a source area northwest of the present shoreline. TR-3a is progressively more argillaceous toward the southeast and more calcareous toward the south. Over the Fi sh Creek Pl at form, the amount of 1 imestone present increases significantly. At South Harrison Bay 1, the unit is mostly limestone. At Lisburne 1, with no nearby control, arenaceous limestone is indicated. Apparent lithologic anomal i es occur at East 5i mpson 2 where the uni tis interbedded si 1 tstone and 1 imestone and Drew Poi nt 1 where the high sand count may be caused by statistical variations, or may indi.cate a small barlike body flanking the Barrow High. " - - ~-~_.._._._. T BASED ON SEISMIC :RPRETATlON, + + CHUKCHI SEA . + Isopo--C..), 'i- LJ· Utifi....~ e..s TR- 3 Q.. s ), ...kIrk F I"rJ SMULL + JVJct.p PEBBLE SHA:'~ 1/1,2 ON I : I W~1)ALT" ~j.' " + Z Do FIGURE 72 i TYPE LOG OF UNCONFORMITY,BETWEEN SAG RI'VER SANDSTONE AND KINGAK FORMATIONi SOUTH MEADE 1. WALAKPA 1, AND WEST DEASE I This, figure shows representative sections of the Sag River Sandstone at South Meade 1, Walakpa 1, and West Dease 1. In this report, the top of the Sag River Sandstone is chosen at a prominent gamma -ray and resistivity deflection that can be recognized regionally. These sections show that the log character of the Sag River Sandstone is fairly consistent in the vicinity of the Meade Arch, while the overlying rocks are vario�ble. The "Barrow sandstone" and Sag River Sandstone are sepa�ated by a shale and siltstone unit. I ·V \7 \/1 f r1- ,.' -;> ~ " f \ ¡ \ / "\i/ '\)' \j - a:: w > æ Y- 0:1 u _I ~~ \,~7 '--r N I « Cl. :.:: « ...J « ~ - ~ :.:: « ...J « ~ - :.:: :J « z :::> >- - :.:: « tLI ~ « ...J :::> >- *;;; ::I a:: g ~ g - :.:: :::> :1. :.:: W ::r (f) w .... 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N.P N.P NP N.P NP N.P NP NP NP 80 N.P NP NP NP NP N.P NP N.P NP NP N l' NP NP .--4---- N.p N.P 790 N.P N.P N.p. N.P. N.P. 533 NP NP N.P. NP N.P 2320 N.P N.P NP NP. N.P. 830? P N Np N.P. N.~ NP NP Np 3040 N.P. N.P. N.P. N.P N.P 050 I N,? N.~ NP Np N l' N.P + I NP NP 4480 N.P. N.P. N.P. N.P. N.p 540 I N l' N.P 510 I NP 00 I ! NP. Np NP 0820 N.P. N.P. N.P. N.P. N.P. 940 I N.P , >%~ looe 460 í N.P. NP N.p N.P. 6620 t -+- J t 90 t ?90 05 N.p. 2100 670 N.p 15 i Jr-l ~ 90 E,Cr.t. , 10669 N,P N,P N.P. N.F' __ NP , N.P ~ , lit·? -:-~-+-~+~ I ~ N-~--t.--'--L'.:- (.-'''1--( l' N.P.! N P. I ! i NP NP! NP NP~. : _ N.P N.P I NP NP I I _~~! Np I Np ! Np I' L--J --t " NP I NP ! NP' I . ~ N? NP. N 100 ~-+---- I NP I Q< ! _ 0 ¡-- 1740 .... ~ N.? fIp N? Np Np N? N,P' N.p Np Np N.P Np ill l' 80 N.P N.P N~ 90 t J, fIP Np Np Np Np Np N l' I F- ~ U~¡C l' " r N NP NF Np NP N.P N.P N.p N.p N l' NP NP F- 2 Np Np N.P N.P N.P NP N.P NP N. N.P NP N.P N.P N.I? N.P N.P N.I? N.P F-3 N P NP ?120 N.P N.P N.P N.I? 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