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Home My WebLink About207-080New Plugback Esets 7/18/2024 Well Name API Number PTD Number ESet Number Date 1J-162 PB2 50-029-23360-71-00 207-080 T39224 5-21-2009 CD3-125 PB1 50-103-20632-70-00 210-189 T39225 4-15-2011 CD3-301A PB1 50-103-20543-71-00 210-017 T39226 4-13-2010 KIGUN 1 PB1 50-629-23239-70-00 205-025 T39227 9-26-2005 1J-105 PB1 50-029-23346-70-00 207-027 T39228 4-23-2009 2K-28A PB1 50-103-20385-70-00 211-133 T39229 2-6-2012 2L-306 PB1 50-103-20630-70-00 210-182 T39230 4-15-2011 3A-17AL1 PB1 50-029-22691-70-00 210-114 T39231 11-24-2010 3G-22AL2 PB1 50-103-20147-70-00 212-047 T39232 7-24-2012 3H-34L1 PB1 50-103-20643-70-00 211-162 T39233 2-28-2012 3N-16AL1 PB1 50-029-21593-73-00 210-107 T39234 11-24-2010 C-12A PB1 50-029-21373-70-00 199-091 T39235 1-17-2002 ODSN-01 PB1 50-703-20648-70-00 211-166 T39236 5-3-2012 ODST-39 PB1 50-703-20572-70-00 208-040 T39237 3-22-2012 OI06-05 PB1 50-029-23437-70-00 210-165 T39238 11-3-2011 OP17-02 PB1 50-029-23431-70-00 210-125 T39239 1-3-2011 1J-162 PB2 50-029-23360-71-00 207-080 T39224 5-21-2009 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard Drive data drop 1H-111 50-029-23581-00 217133_1H-111_IPROFWFL_03JUL2023 1H-114 50-029-23584-00 217136_1H-114_IPROF_17Oct23 1H-115 50-029-23605-00 218053_1H-115_IPROF RSTWFL_09May2022 1H-116 50-029-23594-00 218012_1H-116_IPROFWFL_05Jul2023 1H-117 50-029-23602-00 218032_1H-117_PPROF-WFL_06July23 218032_1H-117_WFL_18Oct23 1H-119 50-029-23591-00 217178_1H-119_WFL_07Jul2023 1J-102 50-029-23317-00 206110_1J-102_RPPG_18Jul2023 1J-107 50-029-23366-00 207107_1J-107_PPROF_10May2022 1J-162 50-029-23360-00 207080_1J-162_LDL_03May2022 1J-170 50-029-23310-00 206062_1J-170_Temp-Pres_11Jul2023 1J-176 50-029-23364-00 207099_1J-176_LDL_11May2022 4of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38340 T38341 T38342 T38344 T38343 T38345 T38346 T38347 T38348 T38349 T38350 2/29/2024 1J-162 50-029-23360-00 207080_1J-162_LDL_03May2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:34:11 -09'00' ! 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фŵĞůǀŝŶ͘ƌŝǆƐĞΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗&t͗΀ydZE>΁Z͗<Zhϭ:ͲϭϲϮ;WdϮϬϳͲϬϴϬͿϭϬͲϰϬϰ ƌǇĂŶ͕DĞů͕ ŽƵůĚǇŽƵƉůĞĂƐĞƚĂŬĞĂůŽŽŬĂƚƚŚŝƐĂŶĚŚĂŶĚůĞ͘ &ƌŽŵ͗tĂƌĚ͕ƵƐƚǇ<фƵƐƚǇ͘tĂƌĚΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ĞŶƚ͗tĞĚŶĞƐĚĂǇ͕DĂǇϮϱ͕ϮϬϮϮϯ͗ϰϳWD dŽ͗>ŽĞƉƉ͕sŝĐƚŽƌŝĂd;K'ͿфǀŝĐƚŽƌŝĂ͘ůŽĞƉƉΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗&t͗΀ydZE>΁Z͗<Zhϭ:ͲϭϲϮ;WdϮϬϳͲϬϴϬͿϭϬͲϰϬϰ sŝĐƚŽƌŝĂ͕ tĞƐƵďŵŝƚƚĞĚƚŚĞϭϬͲϰϬϰƌĞƉŽƌƚĨŽƌϭ:ͲϭϲϮǇĞƐƚĞƌĚĂǇ͕ƉĞƌĞŵĂŝůƚŚƌĞĂĚďĞůŽǁ͘ /ĚŝĚŶ͛ƚǁĂŶƚƚŚĂƚƐƵďŵŝƐƐŝŽŶƚŽŐĞƚĐŽŶĨƵƐĞĚǁŝƚŚŽƵƌƌĞƋƵĞƐƚƚŽŽƉĞƌĂƚĞƚŚĂƚǁĞůůƉĞƌĂƚƚĂĐŚĞĚ ĞŵĂŝůƚŚŽƵŐŚ͘DǇWƐĂƌĞƐƚŝůůƉŝŶŐŝŶŐŵĞŽŶŝĨ/͛ǀĞŚĞĂƌĚďĂĐŬĨƌŽŵǇŽƵŽŶĂƚƚĂĐŚĞĚƌĞƵĞƐƚ͕ďĞĐĂƵƐĞ ƚŚĞǇ͛ĚůŝŬĞƚŽƉƵůůƚŚĞƉůƵŐďĞůŽǁƚŚĞƉĂĐŬĞƌĂŶĚŐĞƚƚŚĞƉƵŵƉŝŶƐƚĂůůĞĚĂƐƐŽŽŶĂƐƉŽƐƐŝďůĞ͘ ^ŽƉůĞĂƐĞƌĞǀŝĞǁŵǇĚƌĂĨƚϭϬͲϰϬϯĨŽƌŽƉĞƌĂƚŝŶŐƚŚĂƚǁĞůůŝŶĂƚƚĂĐŚĞĚĞŵĂŝůĂƚǇŽƵƌĞĂƌůŝĞƐƚ ĐŽŶǀĞŶŝĞŶĐĞ͘/ƚƐŽƵŶĚĞĚůŝŬĞǇŽƵǁĂŶƚĞĚƚŚĞϭϬͲϰϬϯƚŽĚŽĐƵŵĞŶƚŝƚ͕ĂŶĚ/ƚŚŝŶŬ/ŝŶĐůƵĚĞĚĂůůƚŚŽƐĞ ĂĚĚŝƚŝŽŶĂůĂƚƚĂĐŚŵĞŶƚƐǇŽƵǁĂŶƚĞĚŝŶƚŚĞĂƚƚĂĐŚĞĚ͘ WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨǇŽƵǁĂŶƚĂŶǇƚŚŝŶŐĞůƐĞŝŶƚŚĂƚϭϬͲϰϬϯ͖ďƵƚŝĨŝƚůŽŽŬƐŐŽŽĚĂƐŝƐ͕ƚŚĞŶ/͛ůůƐŝŐŶ ĂŶĚƐƵďŵŝƚŽĨĨŝĐŝĂůůǇĂƐĂƉ͘ ŶĚĚĞĨŝŶŝƚĞůǇůĞƚŵĞŬŶŽǁŝĨǇŽƵŚĂǀĞĂŶǇƋƵĞƐƚŝŽŶƐ͘;ĞůůƉŚŽŶĞŝƐĂůǁĂǇƐďĞƐƚƚŽƌĞĂĐŚŵĞ͘Ϳ dŚĂŶŬƐĂŐĂŝŶĨŽƌǇŽƵƌƚŝŵĞ͘ 'ŽŽĚĚĂǇ͘ ƵƐƚǇtĂƌĚ ^ĞŶŝŽƌtĞůůƐŶŐŝŶĞĞƌ KĨĨŝĐĞ͗ϵϬϳͲϮϲϱͲϲϱϯϭ Ğůů͗ϱϬϯͲϰϳϲͲϮϱϭϵ &ƌŽŵ͗K'WĞƌŵŝƚƚŝŶŐ;ƐƉŽŶƐŽƌĞĚͿфĂŽŐĐĐ͘ƉĞƌŵŝƚƚŝŶŐΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗dƵĞƐĚĂǇ͕DĂǇϮϰ͕ϮϬϮϮϯ͗ϯϱWD dŽ͗ŽŶŬůŝŶ͕ŵǇфŵǇ͘͘ŽŶŬůŝŶΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх Đ͗tĂƌĚ͕ƵƐƚǇ<фƵƐƚǇ͘tĂƌĚΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх͖dĂǇůŽƌ͕:ĞŶŶĂ ф:ĞŶŶĂ͘>͘dĂǇůŽƌΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх͖,ŽďďƐ͕'ƌĞŐ^ф'ƌĞŐ͘^͘,ŽďďƐΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ƵďũĞĐƚ͗΀ydZE>΁Z͗<Zhϭ:ͲϭϲϮ;WdϮϬϳͲϬϴϬͿϭϬͲϰϬϰ CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Received for processing &ƌŽŵ͗ŽŶŬůŝŶ͕ŵǇфŵǇ͘͘ŽŶŬůŝŶΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ĞŶƚ͗dƵĞƐĚĂǇ͕DĂǇϮϰ͕ϮϬϮϮϯ͗ϮϵWD dŽ͗K'WĞƌŵŝƚƚŝŶŐ;ƐƉŽŶƐŽƌĞĚͿфĂŽŐĐĐ͘ƉĞƌŵŝƚƚŝŶŐΛĂůĂƐŬĂ͘ŐŽǀх Đ͗tĂƌĚ͕ƵƐƚǇ<фƵƐƚǇ͘tĂƌĚΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх͖dĂǇůŽƌ͕:ĞŶŶĂ ф:ĞŶŶĂ͘>͘dĂǇůŽƌΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх͖,ŽďďƐ͕'ƌĞŐ^ф'ƌĞŐ͘^͘,ŽďďƐΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ƵďũĞĐƚ͗<Zhϭ:ͲϭϲϮ;WdϮϬϳͲϬϴϬͿϭϬͲϰϬϰ &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP 'RQRWFOLFNOLQNVRURSHQDWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZ WKHFRQWHQWLVVDIH ,ĞůůŽ͕ /ŚĂǀĞĂƚƚĂĐŚĞĚƚŚĞϭϬͲϰϬϰĨŽƌ<Zhϭ:ͲϭϲϮ;WdϮϬϳͲϬϴϬͿZtK͘WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨǇŽƵŶĞĞĚ ĂŶǇĂĚĚŝƚŝŽŶĂůŝŶĨŽƌŵĂƚŝŽŶ͘ dŚĂŶŬǇŽƵ͕ ŵǇ Amy A. Conklin Well Integrity Analyst ConocoPhillips Alaska 700 G Street, ATO 1307, Anchorage, AK 99501 Office: (907) 265-1484 Cell: (907) 841-2477 Amy.A.Conklin@conocophillips.com )URP:DUG'XVW\. 7R/RHSS9LFWRULD72*& &F6HQGHQ57\OHU+REEV*UHJ6%\UQH-DQ 6XEMHFW5(>(;7(51$/@5(-5:2DQG'HVLUHWR2SHUDWHDV3DFNHUOHVV(63 $WWDFKPHQWV=B.58-3URG:HOOSGI sŝĐƚŽƌŝĂ͕ dŚĂŶŬƐĨŽƌƚŚĞƌĞƉůǇĂŐĂŝŶ͘ŚĞĐŬůŝƐƚƐŚĞůƉĂůŽƚ͊ ^ĞĞŵǇĂŶƐǁĞƌƐƚŽƋƵĞƐƚŝŽŶƐďĞůŽǁ͘/ƚƌŝĞĚƚŽĐƌĂĨƚƚŚĞŵĂůůŝŶƚŽƚŚĞZ&dϭϬͲϰϬϯ͕ĂƚƚĂĐŚĞĚ͘/ƐƚŚŝƐ ǁŚĂƚǇŽƵǁĞƌĞůŽŽŬŝŶŐĨŽƌŽŶƚŚĞϭϬͲϰϬϯ͍;/ŚŝƐƚŽƌŝĐĂůůǇŚĂǀĞŶ͛ƚƐƵďŵŝƚƚĞĚŵĂŶǇŽĨƚŚĞƐĞŽƵƚƐŝĚĞŽĨ ĂZŝŐĐŽŵŝŶŐƚŽĂǁĞůů͕ƐŽǁĂƐŶ͛ƚϭϬϬйƐƵƌĞǁŚĂƚĂůůƚŽŝŶĐůƵĚĞ͕ďƵƚƚƌŝĞĚƚŽƚĂĐŬůĞǇŽƵƌůŝƐƚďĞůŽǁͿ͘ /ĨĂƚƚĂĐŚĞĚůŽŽŬƐŐŽŽĚ͕ƚŚĞŶ/͛ůůƐŝŐŶĂŶĚƐĞŶĚĨŽƌǁĂƌĚƚŽǇŽƵƌƚĞĂŵ^WĨŽƌĨƵůůƌĞǀŝĞǁĂŶĚ ĂƉƉƌŽǀĂů͘ WůĞĂƐĞƐĞĞŵǇĐŽŵŵĞŶƚƐďĞůŽǁĂŶĚĂƚƚĂĐŚĞĚ͘ dŚĂŶŬƐĂŐĂŝŶ͘ ,ĂǀĞĂŐŽŽĚĚĂǇ͘ ƵƐƚǇtĂƌĚ ^ĞŶŝŽƌtĞůůƐŶŐŝŶĞĞƌ KĨĨŝĐĞ͗ϵϬϳͲϮϲϱͲϲϱϯϭ Ğůů͗ϱϬϯͲϰϳϲͲϮϱϭϵ &ƌŽŵ͗>ŽĞƉƉ͕sŝĐƚŽƌŝĂd;K'ͿфǀŝĐƚŽƌŝĂ͘ůŽĞƉƉΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗dŚƵƌƐĚĂǇ͕DĂǇϭϮ͕ϮϬϮϮϭϭ͗ϬϭD dŽ͗tĂƌĚ͕ƵƐƚǇ<фƵƐƚǇ͘tĂƌĚΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх Đ͗^ĞŶĚĞŶ͕Z͘dǇůĞƌфZ͘dǇůĞƌ͘^ĞŶĚĞŶΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх͖,ŽďďƐ͕'ƌĞŐ^ ф'ƌĞŐ͘^͘,ŽďďƐΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ƵďũĞĐƚ͗΀ydZE>΁Z͗ϭ:ͲϭϲϮZtKĂŶĚĞƐŝƌĞƚŽKƉĞƌĂƚĞĂƐWĂĐŬĞƌůĞƐƐ^W CAUTION:This email originated from outside of the organization. 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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 Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov &ƌŽŵ͗tĂƌĚ͕ƵƐƚǇ<фƵƐƚǇ͘tĂƌĚΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ĞŶƚ͗tĞĚŶĞƐĚĂǇ͕DĂǇϭϭ͕ϮϬϮϮϭ͗ϯϯWD dŽ͗>ŽĞƉƉ͕sŝĐƚŽƌŝĂd;K'ͿфǀŝĐƚŽƌŝĂ͘ůŽĞƉƉΛĂůĂƐŬĂ͘ŐŽǀх Đ͗^ĞŶĚĞŶ͕Z͘dǇůĞƌфZ͘dǇůĞƌ͘^ĞŶĚĞŶΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх͖,ŽďďƐ͕'ƌĞŐ^ ф'ƌĞŐ͘^͘,ŽďďƐΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ƵďũĞĐƚ͗Z͗ϭ:ͲϭϲϮZtKĂŶĚĞƐŝƌĞƚŽKƉĞƌĂƚĞĂƐWĂĐŬĞƌůĞƐƐ^W 'ŽŽĚĂĨƚĞƌŶŽŽŶsŝĐƚŽƌŝĂ͕ ,ŽƉĞƚŚŝƐĨŝŶĚƐǇŽƵǁĞůů͘/ǁĂƐũƵƐƚĨŽůůŽǁŝŶŐƵƉƚŽƐĞĞŝĨǇŽƵǁĂŶƚͬŶĞĞĚĞĚĂŶǇƚŚŝŶŐĞůƐĞŽŶƚŚŝƐǁĞůů ĨŽƌƌĞǀŝĞǁ͍ WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨǇŽƵŚĂǀĞĂŶǇƋƵĞƐƚŝŽŶƐ͕ǇŽƵĐĂŶĐĂƚĐŚŵĞŽŶŵǇĐĞůůƉŚŽŶĞ͘ŶĚƉůĞĂƐĞůĞƚƵƐ ŬŶŽǁŝĨǁĞĐĂŶƉƌŽĚƵĐĞŝƚĂƐĂƉĂĐŬĞƌůĞƐƐ^WĐŽŵƉůĞƚŝŽŶ͕ƐŝŶĐĞǁĞŚĂǀĞƚŚĞD/dͲdǆ/ĨƌŽŵƚŚĞ ZtK͘ tĞ͛ƌĞǁĂŝƚŝŶŐƚŽďƌŝŶŐƚŚĞǁĞůůŽŶůŝŶĞƵŶƚŝůǁĞŚĞĂƌďĂĐŬĨƌŽŵǇŽƵ͕ƐŽ/ũƵƐƚǁĂŶƚĞĚƚŽĐŚĞĐŬŝŶ͘ dŚĂŶŬƐĂŐĂŝŶĨŽƌǇŽƵƌƚŝŵĞ͘,ĂǀĞĂŐƌĞĂƚĚĂǇ͘ ƵƐƚǇtĂƌĚ ^ĞŶŝŽƌtĞůůƐŶŐŝŶĞĞƌ KĨĨŝĐĞ͗ϵϬϳͲϮϲϱͲϲϱϯϭ Ğůů͗ϱϬϯͲϰϳϲͲϮϱϭϵ &ƌŽŵ͗tĂƌĚ͕ƵƐƚǇ< ^ĞŶƚ͗&ƌŝĚĂǇ͕DĂǇϲ͕ϮϬϮϮϳ͗ϯϬD dŽ͗ǀŝĐƚŽƌŝĂ͘ůŽĞƉƉΛĂůĂƐŬĂ͘ŐŽǀ Đ͗^ĞŶĚĞŶ͕Z͘dǇůĞƌфZ͘dǇůĞƌ͘^ĞŶĚĞŶΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх͖,ŽďďƐ͕'ƌĞŐ^ ф'ƌĞŐ͘^͘,ŽďďƐΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ƵďũĞĐƚ͗ϭ:ͲϭϲϮZtKĂŶĚĞƐŝƌĞƚŽKƉĞƌĂƚĞĂƐWĂĐŬĞƌůĞƐƐ^W sŝĐƚŽƌŝĂ͕ /ŚŽƉĞƚŚŝƐĨŝŶĚƐǇŽƵǁĞůů͘ ZtKǁĂƐƌĞĐĞŶƚůǇĐŽŵƉůĞƚĞĚŽŶǁĞůůϭ:ͲϭϲϮĨŽƌĂƌŝŐůĞƐƐ^WŝŶƚŚĞtĞƐƚ^ĂŬ;ĂƉƉƌŽǀĞĚƐƵŶĚƌǇ ĂƚƚĂĐŚĞĚĨŽƌƌĞĨĞƌĞŶĐĞͿ͘ ƌĞƚƌŝĞǀĂďůĞƉůƵŐǁĂƐƐĞƚŝŶƚƵďŝŶŐ;Εϵϴϱϯ͛ͿďĞůŽǁĂƉĂĐŬĞƌĂŶĚ^ĞĂůŽƌĞǆƚĞŶƐŝŽŶ;^ͿŝŶƚŚĞ ǁĞůůƉƌĞͲƌŝŐ͘dŚĞƌŝŐĐĂŵĞĂŶĚƚŚĞŽůĚƚƵďŝŶŐǁĂƐƌĞŵŽǀĞĚĂŶĚƉƵůůŽƵƚŽĨƚŚĞƐĞĂůďŽƌĞ;ůĞĂǀŝŶŐƚŚĞ ^͕ƉĂĐŬĞƌ͕ĂŶĚƉůƵŐŝŶƚŚĞƚƵďŝŶŐƚĂŝůŝŶƚŚĞǁĞůůͿ͘dŚĞŶƚŚĞŶĞǁϰ͘ϱ͟ƌŝŐůĞƐƐ^WĐŽŵƉůĞƚŝŽŶǁĂƐƌĂŶ ŝŶƚŚĞǁĞůůƚŽƐƚĂďƐĞĂůƐŝŶƚŽƚŚĞ^Ăƚ;Εϵϳϵϭ͛Ϳ͘ /ƚǁĂƐƚŚŽƵŐŚƚƚŚĞŶĞǁĐŽŵƉůĞƚŝŽŶ͛ƐƐĞĂůƐŚĂĚƚĂŐŐĞĚƚŚĞďŽƚƚŽŵŽĨƚŚĞƚĂƌŐĞƚ^͘/ƚǁĂƐƚŚĞŶ ƐƉĂĐĞĚŽƵƚĂďŽƵƚϯ͘ϱ͛ŝŶƚŚĞΕϭϴ͛^͘dŚĞĐŽŵƉůĞƚŝŽŶǁĂƐƚŚĞŶůĂŶĚĞĚ͘ƉƌĞƐƐƵƌĞƚĞƐƚŽŶƚŚĞ ƚƵďŝŶŐĂŶĚĐĂƐŝŶŐǁĂƐƉĞƌĨŽƌŵĞĚ͘dŚĞƚƵďŝŶŐĂƉƉĞĂƌĞĚƚŽŚŽůĚĨŽƌƚŚĞϯϬŵŝŶƵƚĞƉƌĞƐƐƵƌĞƚĞƐƚ͘ dŚĞŶƚŚĞĐĂƐŝŶŐƉĂƐƐĞĚƚŽϮϱϬϬƉƐŝŐ͕ĂůƚŚŽƵŐŚŝƚůŽŽŬĞĚůŝŬĞƚŚĞƚƵďŝŶŐĂŶĚ/ǁĞƌĞƚƌĂĐŬŝŶŐĂƚƚŚŝƐ ƉŽŝŶƚ͕ďƵƚƚŚĞ/ŚĞůĚƉƌĞƐƐƵƌĞĐŽŶƐƚĂŶƚŶŽŶĞͲƚŚĞůĞƐƐ͘dŚĞWsǁĂƐŝŶƐƚĂůůĞĚĂŶĚƚĞƐƚĞĚŝƚ͕ĂŶĚƐŝŶĐĞ ƚŚĞƚƵďŝŶŐĂŶĚ/ǁĞƌĞŶŽǁƚƌĂĐŬŝŶŐ͕ƚŚĞ^KsǁĂƐĂƐƐƵŵĞĚƐŚĞĂƌĞĚďĞĐĂƵƐĞ/ƚŽƚƵďŝŶŐ ĐŽŵŵƵŶŝĐĂƚŝŽŶǁĂƐĞƐƚĂďůŝƐŚĞĚ͘ĨƚĞƌĨŝŶŝƐŚŝŶŐWsƚĞƐƚƐ͕ƚŚĞEŽĨKWĂŶĚEhŽĨƚŚĞƚƌĞĞ ŽĐĐƵƌƌĞĚǁŝƚŚĂƉƉƌŽƉƌŝĂƚĞƚĞƐƚƐĂŶĚƚŚĞƌŝŐǁĂƐZDK͘ KŶƉŽƐƚͲƌŝŐǁŽƌŬ͕ǁŚĞŶĐƌĞǁƐǁĞŶƚƚŽƐǁĂƉƚŚĞ^Ks͕ƚŚĞĐƌĞǁŶŽƚŝĐĞĚƚŚĞ^KsŚĂĚŶŽƚƐŚĞĂƌĚ͕ďƵƚ ǁĞǁĞƌĞƐƚŝůůƐĞĞŝŶŐdǆ/ĐŽŵŵƵŶŝĐĂƚŝŽŶ͘ hƉŽŶĨƵƌƚŚĞƌŝŶǀĞƐƚŝŐĂƚŝŽŶ͕ŝƚĂƉƉĞĂƌƐǁĞŚĂĚĂĐƚƵĂůůǇƚĂŐŐĞĚƚŚĞdKWŽĨŽƵƌ^ĂŶĚƐƉĂĐĞĚŽƵƚϯ͘ϱ͛ ĂďŽǀĞƚŚĂƚ͕ƐŽƚŚĂƚŽƵƌƐĞĂůƐĂƌĞEKdƐƚƵŶŐŝŶƚŽƚŚĞ^ĂƚĂůů͕ďƵƚƌĂƚŚĞƌĂďŽƵƚϯ͘ϱ͛ĂďŽǀĞŝƚĐƌĞĂƚŝŶŐ Ăϯ͘ϱ͛ŐĂƉ;ƐĞĞĂƚƚĂĐŚĞĚĐĂůŝƉĞƌͿ͘dŚĞŶ͕ƌĞǀŝĞǁŝŶŐƚŚĞĐŚĂƌƚĨŽƌƚŚĞWdŽŶƚŚĞƚƵďŝŶŐĂŶĚ/͕ǁĞ ďĞůŝĞǀĞƚŚĂƚƚŚĞ/ƌĞĂĚŝŶŐǁĂƐďůŽĐŬĞĚďǇĂǀĂůǀĞĚƵƌŝŶŐƚŚĞƚƵďŝŶŐƚĞƐƚ͕ĂŶĚƐŽĂƉƉĞĂƌĞĚƚŽďĞϬ ƉƐŝŐĚƵƌŝŶŐƚŚĞƚƵďŝŶŐƚĞƐƚ͕ǁŚĞŶŝŶĨĂĐƚŝƐǁĂƐƉƌĞƐƐƵƌĞĚƵƉƚŽƚŚĞϯϬϬϬƉƐŝŐũƵƐƚůŝŬĞƚŚĞƚƵďŝŶŐ͘ dŚƵƐ͕ǁĞĞĨĨĞĐƚŝǀĞůǇƉĞƌĨŽƌŵĞĚϮD/dͲdǆ/ŽŶͲƌŝŐ͕ŽŶĞƚŽϯϬϬϬƉƐŝŐĂŶĚƚŚĞŶĂƐĞĐŽŶĚƚŽϮϱϬϬƉƐŝŐ͘ dŚŝƐǁĂƐŶŽƚŽƵƌŽƌŝŐŝŶĂůŝŶƚĞŶƚ͕ďƵƚĐŽŶƐŝĚĞƌŝŶŐƚŚĂƚ dŚĞǁĞůůŚĂƐĂƉĂƐƐŝŶŐD/dͲdǆ/ƚŽƉƌŽǀĞƵƉƚŚĞƉƌŽĚƵĐƚŝŽŶĐĂƐŝŶŐĂŶĚ dŚĞƉůĂŶĨŽƌƚŚŝƐƌŝŐůĞƐƐ^WǁĞůůǁĂƐƚŽŽƉĞŶĂDhĂĐŽƵƉůĞƚŚŽƵƐĂŶĚĨĞĞƚĂďŽǀĞƚŚĞƐĞĂůƐͲ ^ŐĂƉ;ƐĞĞĂƚƚĂĐŚĞĚŽŵƉůĞƚŝŽŶdĂůůǇͿƚŽĂůůŽǁdǆ/ĐŽŵŵƵŶŝĐĂƚŝŽŶŝŶĚĞĨŝŶŝƚĞůǇĨŽƌƚŚĞ ƉƌŽĚƵĐŝŶŐƉĞƌŝŽĚŽĨƚŚĞǁĞůů͛ƐůŝĨĞ;ƉƵŵƉĂŶĚŵŽƚŽƌĂƌĞƐĞƚŝŶƚƵďŝŶŐĂďŽǀĞƚŚĞDh͕ƚŚƵƐ͕ ƚŚĞǇ͛ĚŶĞĞĚƚŽďĞƉƵůůĞĚŝŶĨƵƚƵƌĞƚŽĞǀĞƌĂĐĐĞƐƐƚŚŝƐDhƚŽĐůŽƐĞŝƚͿ͘ ŶĚƚŚĞĨĂĐƚƐƚŚĂƚ͗ dŚĞƌĞŝƐŶŽŝŶƚĞŶƚŝŽŶŽĨŝŶũĞĐƚŝŶŐŐĂƐͬD/ŶĞĂƌƚŚŝƐƉĂƚƚĞƌŶĂŶĚ ϭ:ͲϭϲϮŝƐĂŶŽƵƚďŽĂƌĚƉƌŽĚƵĐĞƌ;ŶŽŝŶũĞĐƚŝŽŶƐƵƉƉŽƌƚĨƌŽŵƚŚĞǁĞƐƚͲхůŽǁƌŝƐŬŽĨďƵŝůĚŝŶŐŚŝŐŚ ƌĞƐĞƌǀŽŝƌƉƌĞƐƐƵƌĞǁŚĞŶ^/ͿƉĞƌŽƵƌZĞƐĞƌǀŽŝƌŶŐŝŶĞĞƌ tĞƌĞƋƵĞƐƚƚŚĂƚ͗ tĞďĞƉĞƌŵŝƚƚĞĚƚŽŽƉĞƌĂƚĞϭ:ͲϭϲϮĂƐĂƉĂĐŬĞƌůĞƐƐ^WǁĞůů͘ŽǇŽƵĂƉƉƌŽǀĞŽĨƚŚŝƐ͍ ϭϬͲϰϬϰƌĞƉŽƌƚǁŝůůĂůƐŽŽĐĐƵƌǁŝƚŚŝŶϯϬĚĂǇƐŽĨƌŝŐƌĞůĞĂƐĞ͕ďƵƚǁĞĚĞƐŝƌĞĚƚŽĐŽŶĨŝƌŵǁĞĐĂŶŵŽǀĞ ĨŽƌǁĂƌĚǁŝƚŚ͗ƌĞŵŽǀŝŶŐƚŚĞƉůƵŐ;Εϵϴϱϯ͛ͿďĞůŽǁƚŚĞƉĂĐŬĞƌͬƐĞĂůďŽƌĞ͕ŽƉĞŶŝŶŐƚŚĞDh͕ĂŶĚ ŝŶƐƚĂůůŝŶŐƚŚĞƉƵŵƉͬŵŽƚŽƌ͕ƚŽďƌŝŶŐƚŚŝƐǁĞůůŽŶůŝŶĞĂƐĂƉĂĐŬĞƌůĞƐƐ^WǁĞůů͘ dŚĂŶŬǇŽƵĨŽƌǇŽƵƌƚŝŵĞ͘ĞĨŝŶŝƚĞůǇůĞƚƵƐŬŶŽǁŝĨǇŽƵŚĂǀĞĂŶǇƋƵĞƐƚŝŽŶƐ͘zŽƵƐŚŽƵůĚďĞĂďůĞƚŽ ƌĞĂĐŚŵĞŽŶŵǇĐĞůůƉŚŽŶĞŵŽƐƚŽĨƚŽĚĂǇ͘ 'ŽŽĚĚĂǇ͘ ƵƐƚǇtĂƌĚ ^ĞŶŝŽƌtĞůůƐŶŐŝŶĞĞƌ KĨĨŝĐĞ͗ϵϬϳͲϮϲϱͲϲϱϯϭ Ğůů͗ϱϬϯͲϰϳϲͲϮϱϭϵ C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-0-03_21068_KRU_1J-162_CaliperSurvey_CaliperSurveyLog_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21068 KRU 1J-162 50-029-23360-00 Caliper Survey with Caliper Log Data 03-May-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:207-080 T36604 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.12 15:33:56 -08'00' ! 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Well Name and Number: ADL 25661, 25660, 25663 ' — 1J - 162 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): -• none Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 14490 feet Plugs (measured) None true vertical 3218 feet Junk (measured) None Effective Depth measured 14480 feet Packer (measured) 9823, 10044, 10054 true vertical 3219 feet (true vertical) 3163, 3196, 3197 Casing Length Size MD TVD Burst Collapse CONDUCTOR IN 79 20 120 120 SURFACE 3777 13.375 3820 2201 INTERMEDIATE 10359 10.75 10400 3245 B -SAND LINER 4426 5.5 14480 3219 Perforation depth: Measured depth: 10393'- 10480', 10784'- 13403', 13621'- 14391' OCT '_ 2012 True Vertical Depth: 3244 -3252, 3259 -3241, 3238 -3220 AUG CC Tubing (size, grade, MD, and TVD) 4.5, L - 80, 9924 MD, 3179 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 9823 MD and 3163 PACKER - C -2 ZXP LINER TOP PACKER @ 10044 MD and 3196 TVD PACKER - MLZXP LINER TOP PACKER @ 10054 MD and 3197 TVD SSSV - LANDING NIPPLE @ 522 MD and 520 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: SCANNED JAN 10 2013 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - 14. Attachments - 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development ; Service r Stratigraphic r 16. Well Status after work: r Oil J Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG F'°" GINJ j°' SUSP r SPLUG r 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact • Brett Packer Ca 265 -6845 Email J .Brett.Packer @conocophillips.com Printed Name Brett Packer Title Staff Wells Engineer Signature �Q 77-1,4N_ Phone: 265 -6845 Date (e4q fi Form 10-404 Revised 12/2012RF30MS OCT 31 20110 ` \ T\ 'L' Submit Orginal Only \\ 1, . ft� //Z 1 ■ fi KUP • 1 J -162 ConocoPhillips 11 Well Attributes Max Angle 8 MD TD . Alaska, Inc. Wellbore API /UWI Field Name Well Status Ind(*) MD (ttKB) Act Btm (ftKB) Gm .,,,,,4, 414 . 500292336000 WESTSAK PROD 93.46 13,634.05 14,490.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' SSSV: NIPPLE 0 7/10/2009 Last WO: 9/30/2012 43.81 8/16/2007 Well Conflg' -.11 -162, 10/14120129:16'39 AM Schematic - Actual Annotation Depth (ttKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: ADD SLEEVE ninam 10/14/2012 II I - - __. - Casing Strings �r Casing Description String 0... String ID ... Top (FMB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd HANGER, 36 '' CONDUCTOR 20 19.124 41.5 120.0 120.0 94.00 WELDED Insulated _ Casing Description - String 0... ng . Top .. (ttK Set Dpth (f. Set pth (TVD) .. Strin . g .. g . String . Top Thrd SURFACE 133/8 12.415 ID 43. 1 3,8 2,207.7 68.00 Wt. L -80 . BTC Casing Description String 0.. Stri String ID ... Top (ttKB) Set Depth (f ..... De Set Depth (ND) ... String Wt ... Strin String . .. String Top Thrd INTERMEDIATE 10.75 x 9.625 95!8 8.835 40.3 10,399.5 3,245.0 40.00 L -80 BTCM Casing Description String 0... String ID ... Top (ttKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd B-SAND Liner 8.44 6.190 10,043.6 10,069.8 3,199.4 Packer CONDUCTOR In UCTOR sulated, -e 42 -120 ® Top Depth NIPPLE, 522 (TVD) Top Inc! Nomi... Top (RKB) (ttKB) (°) Item Description Comment ID (In) 10,043.6 3,195.9 81.85 PACKER 'C -2' ZXP LINER TOP PACKER 6.190 10,059.1 3,198.0 82.02 COLLAR NO GO COLLAR 6.190 10,060.0 3,198.2 82.03 TIE BACK TIE BACK SEAL ASSEMBLY - Stabbed into B -Sand Liner Top Packer 6.190 Casing Description String 0... String ID ... Top (MB) Set Depth (6... Set Depth (TVD)... String Wt... String ... String Top Thrd GAS LIFT, MEW LINER HH 5 1/2 4.950 9,949.0 10,225.7 3,217.5 15.50 L - 80 BTC - M 2,325 M Liner Details Top Depth (TVD) Top Incl Nomi... Top (ttKB) (RKB) (°) Kern Description Comment ID (in) 9,949.0 3,181.0 80.80 HANGER Baker Model 'B-1' Hook Hanger 95/8" x 7" (Inside csg) 7.510 SURFACE, • * 9,970.0 3,184.6 81.03 HANGER Baker Model 'B-1' Hook Hanger 95/8" x 7' (Outside csg) 6.290 43 -3.820 9,976.3 3,185.7 81.10 XO BUSHING Crossover Bushing 7" BTC box x 5.1/2' BTC pin 4.930 SLEEVE -C, 10,078.5 3,200.6 82.24 ECP RTD-2 ECP 2600 psi shear, control valve 575 psi (23#) 4.650 9,688 NIPPLE, 9,688 10,182.4 3,214.3 81.93 XO BUSHING Crossover Bushing 5-1/2" BTC box X 4-1/2" BTC pin 3.950 IIIII Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Depth (TVD) ... String Wt... String ... Top Thrd NM B -SAND LINER 1 5 1/2 I 4.950 I 10,054.3 I 14,480.0 I Set D 3,218.5 I 15.50 I L -80 I String BTC SENSOR, _ Liner Details 8,736 Top Depth (ND) Top Incl Nomi... Top (ttKB) (RKB) (°) Item Description Comment ID (in) 10,054.3 3,197.4 81.97 PACKER MLZXP Liner Top Packer 9-5/8" (7.50" X 8.32') 7.500 LOCATOR, 10,075.5 3,200.2 82.21 HANGER F)exLock Liner Hanger 7" x 9-58" (6.09" X 8.30") 6.090 SLEEVE, 9,778 10,080.8 3,200.9 8226 XO BUSHING XO Bushing 4.95" ID, 7.63" OD 7'- H563 x 51/2" H563 4.950 SEAL ASSY. S 10,082.2 3,201.1 82.28 SBE 190-47 SEAL BORE EXTENSION 4.750 SBR, 9.784 r , 14,391.3 3219.9 91.06 XO 5-1/2' BTC -M x 4 -1/2" BTC -M Crossover 4.500 Tubing Strings Tubing Description String 0... String ID ... Top (ttKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd Upper Completion 4 1/2 3.958 35.7 9,800.9 3,158.9 12.60 L -80 IBTM _ Completion (TVD) Top Inc! Nomi... IIIII Top (RKB) (RKB) (°) Item Description Comment ID (in) NIPPLE, 9,881 35.7 35.7 -0.04 HANGER VETCO GRAY 11" x 4 -1/2" HANGER w/ 4.909 MCA Top Conn. 3.900 5 21.7 520.2 10.02 NIPPLE LANDING NIPPLE, 3.875" DB PROFILE 3.875 WLEG, 9,924 PAM 9,687.9 3,140.9 80.55 SLEEVE -C CMU SLIDING SLEEVE ASSY (CLOSED) w/ DB NIPPLE 3.813 9,735.9 3,148.8 80.74 SENSOR GUARDIAN SENSOR 9,782.9 3,155.5 79.79 LOCATOR ' BAKER GBH -22 LOCATOR 3.870 -^ ' 9,784.0 3,155.7 79.80 SEAL ASSY BAKER GBH -22 LOCATING SEAL ASSEMBLY 3.870 Tubing Description String 0... String ID ... Top (ttKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd Lower Completion 4 1/2 3.958 9,777.6 - 9,925.0 3,178.9 12.60 L -80 IBTM Completion Details / Top Depth .- - (ND) Top Inc! Top (RKB) (RKB) ( °) Item Description Comment Nomi... ID (in) : ,) I 9,777.6 3,154.5 79.72 SLEEVE BAKER HR LINER SETTING SLEEVE 7.500 9,790.1 3,156.9 79.88 X0 Reducing CROSSOVER T x 5.5" BSAND Liner Packer, 10,044 - 10.070 p r y - o , 9,791.0 3,157.1 79.89 SBR BAKER 190-47 SEAL BORE EXTENTION 4.750 (I NI 9,809.7 3,160.5 80.13 XO Reducing CROSSOVER 5.5" x 4.5" 4.500 _ 9,822.7 3,162.8 80.30 PACKER 3.880 �r 9,880.8 3,172.1 81.04 NIPPLE BAKER PREMIER PACKER CAMCO DB NIPPLE 5.500 3.750 9,923.6 3,178.7 81.59 WLEG BAKER WIRELINE ENTRY GUIDE 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top loci Top (RKB) (RKB) ( ° ) Description Comment Run Date ID (in) 9,688 3,141.0 80.55 NIPPLE SET INSIDE CMU SLIDING SLEEVE 9/29/2012 ER I D -SAND LIN - 9,949-10.226 Mandrel Details t Top Depth Top Port (ND) Inc! OD Valve Latch Size TRO Run Stn Top (ttKB) (8159) (°1 Make Model (in) Sery Type Type (!n) (psi) Run Date Com... INTERMEDIATE 1 2,324.7 1,854.4 69.03 CAMCO KBMG 1 GAS LIFT SOV BK 0.000 0.0 9/29/2012 10.7509.825, 40- 10. SLOTS, 10,393 - 10.460 SLOTS, 10,784 - 12.497 SLOTS, 12,497 - 13.403 SLOTS, 13.621- 14.391 B -SAND LINER, N 1 t 10,054-14,480 TDii LINER, TD (1J -162), 14,490 • KUP • 1J -162 ConocoPhillips Alaska. Inc. tt;111 KB (k) Rig Release Date "' 43.81 8/16/2007 Well Confie' - Chema /4/201639 AM Schematic 101 - Actual 29'1 Perforations & Slots Shot HANGER, 36 _ Top (TVD) Btm (TVD) Dens Top (10(13) Bfm (kKB) (ftKB) OMB) Zone Date (sh... Type Comment I - - - - 10,393 10,480 3,244.2 3,251.7 WS B, 1J -162 7/23/2007 32.0 SLOTS ALL PERFS: Alternating solid/slotted pipe 2.5" X .125" in 4 circumferential rows/fl 10,784 12,497 3,259.3 3,229.2 WS B, 1J -162 7/23/2007 32.0 SLOTS — 12,497 13,403 3,229.2 3,241.1 WS B, 1J -162 7/23/2007 32.0 SLOTS 13,621 14,391 3,237.7 3220.0 WS B, 1J -162 7/23/2007 32.0 SLOTS CONDUCTOR Notes: General & Safety Insulated, ` End Date Annotation 42 - 120 8/16/2007 NOTE: MULTI - LATERAL WELL 1J - 162 (B SAND), 1J - 162L1 (D - SAND) NIPPLE, 522,,. • GAS LIFT. me 2.325 ile.<: SURFACE, 43 -3,820 SLEEVE -C, NIPPLE, 9 688 N ! a ■ MI SENSOR, 9,736 LOCATOR, 9,783 SLEEVE, 9,778 SEAL A,784— 1. '9 9,784 586. 9,791 7 f MIN NIPPLE, 9,881 UV Mi MI WLEG, 9,924 IS F 9 6.p II ar! 'MIIIIIC' B -SAND Liner ' ' Packer, � 10.044- 10,070 0 -SAND LINER — HH, 9,949 - 10,226 INTERMEDIATE 10.75 x 9.625, 40- 10,400 SLOTS, 10,393 - 10,480 SLOTS, 10,784- 12,497 SLOTS, 12,497 - 13,403 SLOTS, 13,621- 14,391 B LINER, N .1 t 1 TO (I LINER, TD (1J -162), 14,490 • • Time Lo g & Summary C ©nacoPhillips WelNlew Web Reporting Report Well Name: 1J -162 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 9/9/2012 7:00:00 AM Rig Release: 9/30/2012 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/08/2012 24 hr Summary Freeze protect and secure well. Move off 1J -174 and spot rig over 1J -162 18:00 21:00 3.00 0 0 MIRU MOVE MOB P PJSM, Prep rig for move, move pipe sheds, Rock washer, Power pack & stage clear for sub. 21:00 00:00 3.00 0 0 MIRU MOVE MOB P Pull sub off 1J -174, Crab down well row and spot over 1J -162. 09/09/2012 Prep and move over 1J -162 spot complexes, rig accepted @ 0700 well killing operations, N/D wellhead. 00:00 02:00 2.00 0 0 MIRU MOVE MOB P Level sub, lay matting boards, set pit, pump, motor & boiler complexs. 02:00 03:30 1.50 0 0 MIRU MOVE MOB P Set rock washer, spot pipe sheds. 03:30 07:00 3.50 0 0 MIRU MOVE MOB P Connect service lines air, steam, electrical. Test all gas & H2S detectors. Rig accepted @ 0700 07:00 10:45 3.75 0 0 MIRU WELCTI RURD P Take on 8.6 brine, R/U circ. lines t/ tree & tiger tank. R/U scaffolding. 10:45 12:00 1.25 0 0 MIRU WHDBO RURD P R/U lubricator, test t/ 1000 psi, pull BPV, R.D lubricator 12:00 13:00 1.00 0 0 MIRU WELCTL PRTS P Flood surface lines w/ H2O test t/ 3500 psi 13:00 16:15 3.25 0 0 MIRU WELCTL CIRC P Break circ. w/ 120° sea water w/ 3% KCL @ 168 gpm 300 psi ICP, Circ. until clean 600 bbls, 16:15 18:15 2.00 0 0 MIRU WELCTL CIRC P Bull head do IA @ 126 gpm 400 psi ICP 275 bbls fcp 625 psi 18:15 19:30 1.25 0 0 MIRU WELCTL OWFF P Monitor well 450 psi on both sides bleed pressure to zero monitor well, well still flowing back 1.5 BPH. 19:30 21:00 1.50 0 0 MIRU WELCTL CIRC P Rev circ 1 tubing volume light diesel returns, dump to rock. 21:00 21:30 0.50 0 0 MIRU WELCTL OWFF P Observe well for flow well static. 21:30 22:00 0.50 0 0 MIRU WHDBO OTHR P _ Set BPV, blow down & rig down lines to I i git tank. 22:00 00:00 2.00 0 0 MIRU WHDBO NUND P PJSM, N/D tree, prep TBG spool and install blanking plug as per Vetco rep. 09/10/2012 Test BOP's, Unseat hanger pull to floor, POOH standing back tubing in derrick, UD ESP assembly. 00:00 02:30 2.50 0 0 MIRU WHDBO NUND P N/U BOP stack 02:30 03:00 0.50 0 0 MIRU WHDBO RURD P R/U t/ test BOP's fill stack with H2O Page 1 of 19 • • • Time Logs Date From To Dur S. Deoth E. Depth Phase Code Subcode T Comment 03:00 09:30 6.50 0 0 MIRU WHDBO BOPE P Test BOP, Test upper & blind rams, choke valves 1 -14, Auto & man IBOP , HCR & man. choke & kill, 4" Demco, TIW & DART, t/ 250 low 3500 high w/ y 4" & 4.5 test jts. Acc. test. Jeff_ xt Jones AOGCC waived witness 09:30 10:30 1.00 0 0 MIRU WHDBO RURD R/D test equip. blow down choke and kill lines Pull blanking plug. 10:30 10:45 0.25 0 0 MIRU WELCTI OTHR P Fill hole w/ 20 bbls brine no returns 10:45 12:15 1.50 0 0 COMPZ RPCOM RURD P P/U & R/U casing & centrilift equipment, M/U landing jt. to T/D and hanger. 12:15 13:00 0.75 0 0 COMPZ RPCOM OTHR P R/U DHD & shoot ck shot fluid level @ 78', simops BOLDS 13:00 15:00 2.00 0 7,513 COMPZ RPCOM PULL P Unseat hanger w/ 175K, 90k overpull, pull hanger t/ floor diconnect ESP cable & penetrator, UD landing jt, hgr & single. 15:00 22:30 7.50 7,513 111 COMPZ RPCOM PULL P Pooh w/ 4.5 completion racking back 78 stands in derrick, UD 2 GLMs, Unique discharge sub, 6 pup joints and 5 joints to shed. Fill for trip= Act. =95.9 bbls, calc.= 34 bbls 22:30 23:00 0.50 111 111 COMPZ RPCOM OTHR P R/D ESP cable. 23:00 00:00 1.00 111 0 COMPZ RPCOM PULD P P/U ESP assembly with last joint and remove remaining clamps, disassemble ESP. (217 Clamps & 3 Protectolizers) Total tour loss= 140.5 bbls 09/11/2012 RIH P/U singles from shed, CBU a_ 8052' MD Milled pa cker at 8184' MD to 8185' 00:00 00:30 0.50 0 0 COMPZ RPCOM PULD P Finish UD centrilift ESP assembly. 00:30 01:00 0.50 0 0 COMPZ RPCOM OTHR P Clear and clean rig floor. 01:00 02:00 1.00 0 0 COMPZ WELLPF BOPE P Set Test Plug and rig up test equipment. 02:00 04:45 2.75 0 0 COMPZ WELLPF BOPE P Test lower 2 -7/8" X 5" ram and annulur with 4" & 4.5" test joints, 250 low / 3500 high and record on chart. 04:45 05:15 0.50 0 0 COMPZ WELLPF BOPE P R/D test equipment and set 9" ID wear ring. 05:15 05:45 0.50 0 0 COMPZ WELLPF SFTY P PJSM on P/U Baker Packer Mill BHA. 05:45 08:30 2.75 0 0 COMPZ WELLPF PULD P PJSM, M/U Packer Mill BHA 08:30 09:15 0.75 0 500 COMPZ WELLPF TRIP P PJSM, sinlge in the hole with 4" drill pipe T/ 500' well out of balance, flowing out dp. 09:15 09:45 0.50 500 500 COMPZ WELLPF CIRC P Brk circ and pump drill pipe volume, monitor well taking fluid slowly. 09:45 12:00 2.25 500 2,078 COMPZ WELLPF TRIP P Continue RIH with singles from shed T/ 2078' MD, Calc= 23.8 bbls, Act= 1.25 bbls, Total losses for tour= 58.0 bbls. 12:00 18:15 6.25 2,078 8,052 COMPZ WELLPF TRIP P PJSM, continue to RIH F/ 2078' T/ 8052', ran out of down weight. Page 2 of 19 1 Time Logs Date From To Dur S. Depth - E. Depth Phase Code Subcode T Comment 18:15 20:30 2.25 8,052 8,052 COMPZ WELLPF CIRC P M/U Top Drive and brk circ with 3.5 bpm with 100 psi, Observed dies! and gas migration in returnes, Got back 100 bbls of 7.0 ppg diesel and sent to rock washer until 8.6 ppg was attained, conintue to circ surface to surface @ 6.5 bpm with 600 psi. (Loss rate @ 12 bph) Obtained SPRs © 20:15 #1 © 25 SPM= 110 psi, @ 35 SPM= 180 psi #2 © 25 SPM= 120 psi, © 35 SPM= 200 psi 20:30 21:00 0.50 8,052 8,175 COMPZ WELLPF TRIP P Continue RIH while rotating each joint down. F/ 8052' T/ 8175' 21:00 00:00 3.00 8,175 8,185 COMPZ WELLPF MILL P M/U to joint # 248 with top drive, P/U wt= 115K, S/O wt= 35K, Rot wt= 77K, Tq off= 6.5K, pump with= 6.5 bpm= 600 psi, 80 RPM, S/O and tag Packer © 8180' MD, Mill with 1.5 Wt.,Tg on= 8K for 10 min and increase to 100 RPM and stage wt up to 15K, Tq on= 9 -12K, Mill to 8185' and pump 15 bbl hi -vis sweep. Total tour Toss= 72.9 bbls 09/12/2012 POOH and_M/U spear assembly,FtIH tagged (a), 8205' MD, Pushed_fish down to 9058' and engage fish, CBU, POOH 00:00 04:30 4.50 8,185 8,188 COMPZ WELLPF MILL P Continue milling on TorqueMaster Packer F/ 8185' T/ 8188' with 6.5 bpm 600 psi, 100 RPM, WOB= 20 -30K, P/U 115K, S /O= 35K, Rot= 77K. 04:30 04:45 0.25 8,188 8,202 COMPZ WELLPF MILL P Push fish T/ 8202' MD with pumps and roatation, set 25K and torque up could not go any futher. 04:45 06:15 1.50 8,202 8,175 COMPZ WELLPF CIRC P CBU had some gas to surface, 6.5 bpm 550 psi @ 8175' MD, Losses= 35.9 bbls. 06:15 06:45 0.50 8,175 8,175 COMPZ WELLPF OWFF P Monitor well, hole taking fluid @ 6 bph 06:45 12:00 5.25 8,175 3,429 COMPZ WELLPF TRIP P UD 2 joints, POOH F/ 8175' T/3429' MD calc= 27 bbls, Actual= 52 bbls, Total losses= 61.0 bbls 12:00 13:00 1.00 3,429 410 COMPZ WELLPF TRIP P PJSM, Continue POOH F/ 3429' T/ 410'MD 13:00 13:15 0.25 410 410 COMPZ WELLPF OWFF P Monitor well, Observed hole taking fluid, 6 bph. 13:15 15:15 2.00 410 0 COMPZ WELLPF PULD P UD 6 DCs & rack back 2 stands off DCs, Break out junk baskets and clean same. (5 Gal of shavings) 15:15 16:15 1.00 0 0 COMPZ WELLPF PULD P Clear rig floor and UD junk baskets and pick up subs for next BHA 16:15 17:30 1.25 0 215 COMPZ WELLPF PULD P PJSM, M/U spear assembly BHA # 2to215'MD 17:30 21:15 3.75 215 7,385 COMPZ WELLPF TRIP P RIH on 4" dp to 7385' P/U and run 9 jts DCs (4.75 ") and 15 jts 4" HWDP to 8120' for push pipe, Displacement Act = 38.74, Calc= 64.27 bbls. Page 3 of 19 Time Logs • 1110 Date. From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:15 00:00 2.75 7,385 9,058 COMPZ WELLPF FISH P M/U TD on stand 77, P /U= 110K, S /O= 60K, Circ 3 bpm with 350 psi, wash down & tag @ 8205' set down 10K on spear, P/U to 125K, 10K O /P, S/O & tag @ 8209' set down with 15K, P/U to 130K when pulled loose, did not see any drag, P/U single RIH to 8243' did not take any wt., UD single and RIH with 5 stand from derrick to 8692', cont. single in F/ 8692' tagged © 9058', set down w/ 15K, P/U 30' no drag, S/O & set down 20K, P/U 10 off btm & kelly up, P /U= 120K, S /0= 55K. Trip= Act= 0.0, Calc= 5.5 bbls. Total for tour= 41.58 bbls. X9/13/2012 Finish CBU, POOH and UD Fissh, Perform NOV Derrick Inspection 6.1/2" DCs from derrick. M/U clean out BHA _. __�__ 00:00 01:45 1.75 9,029 9,029 COMPZ WELLPF CIRC P CBU at 9029' MD, 5 bpm with 900 psi. 01:45 02:00 0.25 9,029 9,029 COMPZ WELLPF OWFF P Monitor well, fluid dropping slightly. 02:00 08:45 6.75 9,029 215 COMPZ WELLPF TRIP P PJSM, POOH F/ 9029' T/ 215', P /U= 125K, Calc= 66.29, Act= 99.5 08:45 09:00 0.25 215 215 COMPZ WELLPF OWFF P Monitor well, slight loss. 09:00 10:30 1.50 215 0 COMPZ WELLPF TRIP P UD BHA and rack back two stands of DCs. 10:30 11:00 0.50 0 0 COMPZ WELLPF PULD P R/U casing equipment and lay down spear aseembly. 11:00 12:00 1.00 0 0 COMPZ WELLPF PULD P C/O elevators and lay down 4.5" LEM assembly. (Fish) Total loss for tour= 52.51 bbls 12:00 12:15 0.25 0 0 COMPZ WELLPF PULD P Clear rig floor and rig down casing tools. 12:15 17:00 4.75 0 0 COMPZ WELLPF OTHR P PJSM with SIS and perform NOV Derrick dropped object survey. Work on MP2s, Clean around rig. 17:00 18:30 1.50 0 0 COMPZ WELLPF PULD P Load Shed with MI clean out subs and prep for next run 18:30 20:00 1.50 0 0 COMPZ WELLPF OTHR P PJSM, Lay down 6 -1/2" DCs 20:00 21:30 1.50 0 0 COMPZ WELLPF OTHR T Wrong Thread on Mule shoe, Sent jt of 3.5" TBG to get cut, SIM -OPS Swap out power tongs not biting TBG. 21:30 00:00 2.50 0 370 COMPZ WELLPF PULD P P/U and M/U clean out assembly BHA # 3 to 370' MD, Calc= 8.12 bbls, Act= 2.89 bbls. 09/14/2012 RIH to 6290 with clean out BHA took wt and stalling out, decision to POOH and check magnets, Recovered 184.5 # of debris, M/U baker clean out BHA & RIH to 9847' MD. OC:00 00:30 0.50 370 37 COMPZ WELLPF PULD P PJSM, C/O elevators and R/D casg equipment. Page 4 of 19 Time Logs Date FrOm To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 05:00 4.50 370 6,270 COMPZ WELLPF TRIP P RIH picking up 42 joints of dp from shed, Continue RIH from derrick to 4921' MD Took wt. Slack off while rotating & went by spot, Continue RIH and tagged up at 6240' MD (Tagged Junk F/ 4921' T/ 6270') Fill Act= 14.5 bbls, Calc= 32.4 bbls. 05:00 06:00 1.00 6,270 6,290 COMPZ WELLPF REAM P Brk Circ w/ 4bpm 400 psi at 6222' MD, wash and ream to 6240' took wt. increase pump to 7 bpm with 1080 psi attempt to clean up junk, reduce pump to 4 bpm with 15 RPM, Tq= 4K,wash and ream to 6290' MD, stalling out, decision to come out for BHA. 06:00 06:15 0.25 6,290 6,290 COMPZ WELLPF OWFF P Monitor well, Hole taking fluid slightly. 06:15 09:00 2.75 6,290 370 COMPZ WELLPFTRIP P POOH F/ 6290' T/ 370' MD 09:00 09:30 0.50 370 370 COMPZ WELLPF OWFF P Monitor well and Rig up Csg equipment. 09:30 11:15 1.75 370 0 COMPZ WELLPF PULD P Rack back BHA, UD magnets and clean same. ( Recovered 184.5 Ibs of metal) Trip Fill - Act= 55.52 bblss, Calc= 40.5 bbls. 11:15 11:30 0.25 0 0 COMPZ WELLPF PULD P Clear rig floor. 11:30 12:00 0.50 0 0 COMPZ WELLPF SLPC P PJSM, Slip and cut drlg line. Total losses= 51.66 bbls. 12:00 12:15 0.25 0 0 COMPZ WELLPF SLPC P Continue slip and cut drlg line. 12:15 13:00 0.75 0 0 COMPZ WELLPF SVRG P Service TD and Brake linkage, set COM. 13:00 14:00 1.00 0 0 COMPZ WELLPF PULD P Pick up to floor Baker subs for next run. 14:00 15:45 1.75 0 242 COMPZ WELLPF PULD P PJSM, M/U Baker cleanout BHA # 4 to 242' MD 15:45 20:00 4.25 242 6,850 COMPZ WELLPFTRIP P RIH and tag up @ 6234',n P/U 10' kelly up, P /U= 92K, S /O= 42K, Rot with 71 K, Tq= 3K, Circ @ 9.5 bpm with 950 psi wash to 6850' MD. 20:00 00:00 4.00 6,850 9,847 COMPZ WELLPFTRIP P Continue RIH F/ 6850' T/ 7510', with less than 5K string wt. RIH with push pipe, continue RIH from derrick to 9132' ran out of down wt. Kelly up and wash and ream to 9847' MD, P /U= 120K, S /0= 35K, Circ with 9.5 bpm, Rot wt= 85K with 20 rpm, Tq= 6K, P /U= 125K, with pump off P /U= 125K. Total losses= 31.66 bbls. 09/15/2012 RIH to 9939' MD, Pump hi -vis sweep around, Monitor well, POOH & UD Baker BHA, (Recovered 1/2 Bucket of metal),PJUMI clean out BHA # 5. RIH to 5560' MD Wash & ream to 7266' MD. 00:00 00:15 0.25 9,847 9,939 COMPZ WELLPF REAM P continue to wash and ream F/ 9847' T 9939' with 20 RPM, Tq= 7K, 9.5 bpm with 1600 psi, P /U= 130K, Could not slack off, contiue to rotate with 20 RPM. Page 5 of 19 Time Logs • Date From To Dur S. Depth E Depth Phase Code Subcode T Comment 00:15 01:30 1.25 9,939 9,939 COMPZ WELLPFCIRC P Pump 25 bbl hi -vis sweep @ 9.5 bpm 1600 psi 20 RPM, Tq= 7K, and work pipe. 01:30 02:00 0.50 9,939 9,939 COMPZ WELLPF OWFF P SPRs # 1 pump @ 25 spm= 140 psi, @ 35 spm= 240 psi, # 2 pump © 25 spm= 130 psi, @ 35 spm= 240 psi, Monitor well Fluid dropping slightly. 02:00 06:15 4.25 9,939 242 COMPZ WELLPF TRIP P POOH F/ 9939' MD T/ 8240 MD, P /U= 130K, Rack back 5 stds of HWDP & 3 stds of DCs, Cntinue POOH F/ 7510' T/242' MD, Fill= 87.38 bbls, Calc= 67.05 bbls. 06:15 06:30 0.25 242 58 COMPZ WELLPF TRIP P Rack back 2 stds of DCs. T/ 58' MD 06:30 07:45 1.25 58 0 COMPZ WELLPF PULD P UD BHA # 4 as per Baker, (Retreived 1/2 bucket of metal) 07:45 08:00 0.25 0 0 COMPZ WELLPF PULD P Clear and clean rig floor of Baker tools. 08:00 08:30 0.50 0 0 COMPZ WELLPF PULD P R/U csg equipment to P/U 3.5" tbg. 08:30 08:45 0.25 0 0 COMPZ WELLPF SFTY P PJSM, on M/U MI Clean out BHA # 5 08:45 10:15 1.50 0 370 COMPZ WELLPF PULD P M/U Clean out BHA as per MI Rep. to 370' MD 10:15 12:00 1.75 370 2,823 COMPZ WELLPF TRIP P RIH F/ 370' MDT/ 2823' MD, Fill= 7.82 bbls, Calc= 20.62 bbls. Total losses= 43.3 bbls. 12:00 15:00 3.00 2,823 6,300 COMPZ WELLPF TRIP P RIH F/ 2823' MDT /5560' MD, ran out of do wt. Kelly up, P /U =92K, S /O= 37K, RT Wt= 75K, 20 RPM, 4K tq, 4 BPM with350 psi, Wash & ream to 6261' MD, stalling out, work through tight spot. 15:00 00:00 9.00 6,300 7,266 COMPZ WELLPF REAM P Work through tight spot 3 times, Increase pump rate to 7 BPM 1100 psi, with 40 RPM, 4 -5 Tq, Wash & ream slowly due to stalling out, increase limiter to 6K, and 50 RPM, ream F/ 6300' T/ 7266' MD, P /U= 120K, S /O= 35K, Rot wt= 75K.Pumped hi -vis sweep @ 7125' MD, (Total losses= 46.19 bbls) 09/16/2012 Cont. Wash & Ream do to 10024' MD, Could not enter SBE, drop ball, pump sweep, did not_ see_anything back, Monitor well, POOH T/2917' MD. 00:00 :00 — 12.00 7,266 9,224 COMPZ WELLPF REAM P Wash & Ream F/ 7266' T/ 9068' MD, 50 RPM with 5 -6K Tq, Increased RPM to 80 with 6 -8 Tq, Pumping 7 bpm with 1100 psi, Wash & Ream F/ 9068' T/ 9224' MD, P /U= 125K, S /O= 35K, Rot wt= 80K. Pumped hi -vis sweep @ 7543' Total losses= 44 bbls. 12:00 15:00 3.00 9,224 9,947 COMPZ WELLPF REAM P Wash & Ream F/ 9224' T/ 9947' MD, with 80 RPM. 7 bpm, 100 psi, Stop rotation and reduced rate to 4 bpm to clean up top of hook hanger. Page 6 of 19 Time Logs • Date From To Dur S. Depth E. Depth Phase Cods Subcode T Comment 15:00 16:15 1.25 9,947 9,880 COMPZ WELLPF REAM P Attempt to pass throught hook hanger with 1 RPM No go, increase to 10 RPM and penitrated hook hanger, Wash and ream F/ 9959 T/ 10024' MD attempt to slide into SBE No success, pump stand out and rack back 2 stds to 9880'. 16:15 18:15 2.00 9,880 9,880 COMPZ WELLPF CIRC P Drop 1.75" bal, Circ ball down @ 2.5 bpm 150 psi, Shear out ball seat w/ 675 psi, open dual cativation ports, um 20 bbl hi -vis sweep pump @ 15 bpm 2900 psi, increased to 17 bpm and 3400 psi while rotating 80 RPM & reciprcate string 90', 1.5 hole volumes. Did not see anything back with sweep. 18:15 18:45 0.50 9,880 9,787 COMPZ WELLPF OWFF P Rack back std, Blow down, Monitor well, held PJSM 18:45 21:15 2.50 9,787 6,125 COMPZ WELLPFTRIP P POOH with MI clean out BHA # 5 F/ 9787' T/6125' MD, Fill Act= 29.41 bbis, caic= 23.3 bbis. 21:15 22:15 1.00 6,125 6,125 COMPZ WELLPF SVRG P Serviced Rig and Top Drive, (Monitor well across trip tank) 22:15 00:00 1.75 6,125 2,917 COMPZ WELLPFTRIP P Continue POOH F/ 6125' T/ 2917' MD, P /U= 67K, S /O= 55K, Total fill Act= 53.21 bbl, caic= 40.1 bbis. Toati loss tour= 59.15 bbis. 09/17/2012 Finished POOH and found magnets full of shavings (287 Ibs) talked to town engineer and decision made to rerun magnets, RIH to 6261' wash & ream down to 10050' MD attempt to enter SBE three times no go, R/U and reverse circ 1.5 times dp volume, POOH, UD MI clean out BHA, R/U and start testing BOPE. 00:00 00:30 0.50 2,917 370 COMPZ WELLPFTRIP P Continue POOH F/ 2921' T/ 370' MD, Fill Act= 32.6 bbis, Calc= 23.32 bbis. 00:30 00:45 0.25 370 370 COMPZ WELLPF OWFF P Monitor well, static. 00:45 01:15 0.50 370 370 COMPZ WELLPF PULD P Rig up csg tongs and equipment. 01:15 01:30 0.25 370 370 COMPZ WELLPF SFTY P PJSM on LID MI clean out BHA # 5. 01:30 03:15 1.75 370 157 COMPZ WELLPF PULD P UD clean out BHA # 5 as per MI Rep. Recovered 287 Ibs of metal from magnets. Talked to town engineer and we will make another magnet run. 03:15 04:45 1.50 157 220 COMPZ WELLPF PULD P M/U clean out BHA # 6 with magnets and layed down scraper as per -MI. 04:45 07:45 3.00 220 6,261 COMPZ WELLPFTRIP P RIH F/ 220' T/ 6261' MD, P /U= 115K, S /O= OK, Rot wt= 74K, Act= 23.46 bbis, Calc= 39.32 bbis. 07:45 12:00 4.25 6,261 8,808 COMPZ WELLPF REAM P Wash & Ream F/ 6261.0 T/ 8808' MD 60 RPM 3-4 Tq, P/U= 115K, S /O= OK, Rot wt= 74K, Act= 1.19 bbis, Calc= 13.5 bbis. Page 7 of 19 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:15 2.25 8,808 10,044 COMPZ WELLPF REAM P Cont. wash & ream F/ 8808' T/ 10044' MD, RPM= 80, to 9945 and reduce RPM to 10 RPM and entered Hook Hanger © 9955' MD, Increase RPM to 60 and continue washing with 2.5 bpm & 100 psi to 10044' MD, P /U= 130K, S /O= OK, Rot wt= 85K. 14:15 15:15 1.00 10,044 10,050 COMPZ WELLPF CIRC P P/U to tool joint, break and blow down T /D, R/U to rev. circ., M/U tool joint & RIH to 10044' MD, Decision made to circ down dp @ 2 bpm with 75 psi, Rot with 10 RPM 7.5K TQ, rot wt= 85K, attempt to wash down into SBE, after 3 attempts made it to 10050', took 30K over pull to come free, P/U to 10044' MD. 15:15 16:00 0.75 10,050 10,044 COMPZ WELLPF CIRC P Close annular and revr. circ @ 4.5 bpm with 250 psi ICP, FCP 350 psi for 1.5 dp volume. 16:00 16:15 0.25 10,044 10,015 COMPZ WELLPF TRIP P POOH to 10015' rack back std and blow down T/D and kill lines. 16:15 16:45 0.50 10,015 10,015 COMPZ WELLPF OWFF P Monitor well, hole taking fluid. PJSM 16:45 20:15 3.50 10,015 270 COMPZ WELLPF TRIP P POOH F/ 10015' T/ 270' MD 20:15 21:15 1.00 270 0 COMPZ WELLPF PULD P UD MI cleanout BHA and 3.5 tail pipe 21:15 21:30 0.25 0 0 COMPZ WELLPF OTHR P Pull wear ring. 21:30 22:00 0.50 0 0 COMPZ WELLPF OTHR P P/U joint 4" dp & M/U stack washer, flush stack @ 20 bpm 130 psi, UD same. 22:00 23:00 1.00 0 0 COMPZ WHDBO BOPE P P/U test joint and test plug and install same R/U test equipment. 23:00 00:00 1.00 0 0 COMPZ WHDBO BOPE P Test BOPE with 4" test joint, Test # 1 upper 3.5" x 6" VBR, choke valves 1,12,13,14 & manual kill valve. Test waived by AOGCC Inspector Chuck Scheve 09/18/2012 Cont to test BOPE t/ 250/3500 PSI. Test waived by Chuck Scheve of the AOGCC. UD MI SWACO tools and M/U Baker mill clean out BHA. RIH w/ clean out BHA t/ 6530' MD, ran out of weight. Washed f/ 6530' MD t/ 10102' MD. Page 8 of 19 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment - 00:00 07:45 7.75 0 0 COMPZ WHDBO BOPE P Cont. t/ test BOPE t/ 250/3500 PSI w/ 4" test joint. Test #2: Top pipe rams, manual kill and HCR choke. Test #3: Upper IBOP and HCR kill. Test #4: Lower IBOP. Test #5: Dart valve. Test #6: 4" kill line. Test #7: Annular preventer. Test #8: Lower pipe rams. Change out test joint to 4-1/2". Test #9: Top pipe rams, CV 1,12,13 and 14. Test #10: CV 9 and 11. Test #11: CV 5,8 and 10. Test #12: CV 4,6, and 7. Test # 13: Annular preventer and CV 2. Test #14: Lower pipe rams. Test #15: Blind rams. Accumulator test: system pressure =3000 PSI, pressure after closing= 1800 PSI. 200 PSI attained= 34 sec, full pressure after 193 sec. 5 bottle nitrogen avg= 1950 PSI.Lower IBOP failed- functioned and retested, OK. CV #2 failed, serviced and retested, OK. Test waived by AOGCC Inspector Chuck Scheve 07:45 08:00 0.25 0 0 COMPZ WELLPF SFTY P Hold PJSM, HRC and HRW on breaking down MI SWACO tools. 08:00 09:00 1.00 0 0 COMPZ WELLPF PULD P Break apart well scabenger, clean screens and make back up. Break apart sabs tool and L/D as per MI SWACO rep. 09:00 09:45 0.75 0 0 COMPZ WHDBO RURD P R/D test equipment, pull test plug and drain stack. Blow down all BOP equipment. Set 9" ID wear bushing. Clean and clear floor. 09:45 10:45 1.00 0 0 COMPZ WELLPF RURD P Change out power tongs, mobilize 2 -7/8" handling tools to rig floor. Rig up to make up BHA. 10:45 11:00 0.25 0 0 COMPZ WELLPF SFTY P Hold PJSM, HRW and HRC on making up Baker mill clean out BHA. 11:00 12:00 1.00 0 0 COMPZ WELLPF PULD P Make up Baker mill clean out assy as per Baker rep. Losses for tour= 37 bbls. 12:00 17:30 5.50 0 6,530 COMPZ WELLPFTRIP P PJSM, cont. to make up BHA. RIH t/ 6530' MD, ran out of string weight. P /U =100K, S /O =35K. Actual displacement= 28 bbls, Calculated displacement= 39.4 bbls. 17:30 00:00 6.50 6,530 9,906 COMPZ WELLPF WASH P Wash down at 20 RPM w/ 3K TQ. Pump @ 3 BPM =200 PSI, ROT wt= 70K. f/ 6530' MD t/ 9906' MD. P/U = 130K w/ pumps off, S /O= OK, ROT= 85K, 7.5K TQ, 4 BPM= 375 PSI. Actual displacement= 5.6 bbls, Calculated displacement= 26.6 bbls. Losses for tour= 46.7 bbls, Losses for 24 hrs= 83.7 bbls. Page 9 of 19 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/19/2012 24 hr Summary POOH from 10095 to 6436. Washed from 6436 back to bottom. Circ Bottoms up, increased lubes to 4 %. POOH, laid down BHA. Slip /Cut drilling line, serviced rig. M/U LEM Assy as per Baker. 00:00 00:30 0.50 9,906 10,102 COMPZ WELLPF WASH P CONT WASH AND REAM F/9906' MD T/10102" MD @ 20 RPM/7.5K TQ, 4 BPM= 375PSI, STOPPED ROTATION AND CIRC SEAL BORE CLEAN @ 8 BPM= 1200PSI FOR 5 MINS 00:30 02:00 1.50 10,102 10,077 COMPZ WELLPFCIRC P POOH F/ 10102' MD T/ 10077" MD, P/U WT. =132K INCREASE PUMP T /10 BPM= 1800 PSI, PUMP AND CIRC OUT 21 BBL HI VIS SWEEP, CONDITION FLUID W/ 13 BLS 776 LUBE, 14 BLS LOTORQ, 3 SCKS FLOWZAN. 11 ADDTL SCKS FLOWZAN ADDED WHILE CIRC. 02:00 02:30 0.50 10,077 10,095 COMPZ WELLPFCIRC P OBTAIN SLOW PUMP RATES, #1 PUMP @ 25 SPM= 170PSI, 35 SPM =280 PSI #2 PUMP @25 SPM= 180PSI, 35 SPM= 280PSI, ROT. BACK DOWN T/10095' MD @ 20 RPM =7.5K TQ, 4 BPM =375 PSI and UD SINGLE, MONITOR WELL 02:30 04:45 2.25 10,095 6,436 COMPZ WELLPFWASH P PJSM, POOH F/10095', P/U WT. =132K, MD T/6436, ACT FILL =32.13 BBLS, CALC FILL =23.36 BBLS. 04:45 10:15 5.50 6,436 8,606 COMPZ WELLPF WASH P WASH AND REAM @ 20 RPM =3K TQ, 5 BPM =375 PSI, RT WT =72K F/6436' MD, T/ 8606' MD, WASH DWN W/ NO ROTATION F/8608' MD T /10102'MD@ 5 BPM= 500PSI P/U WT. =100K, S /O =60K, POOH F/ 10102' MD T/10077' MD. ACT FILL 18.5 BBLS, CALC FILL =23.36 BBLS 10:15 11:30 1.25 8,606 10,077 COMPZ WELLPF WASH P WASH NO ROTATION@ 8 BPM =1250 PSI, 56% FLOW. 11:30 12:00 0.50 10,077 10,095 COMPZ WELLPF TRIP P RIH F/1077' MDT /10095' MD AND UD SINGLE, B/D TOP DRIVE NOTE: TOTAL TOUR FLUID LOSS =41 BBLS 12:00 12:15 0.25 10,095 10,095 COMPZ WELLPFOWFF P PJSM, SIMOPS MONITOR WELL (SLOWLY TAKING FLUID) P/U WT 105K, S/O WT 65K 12:15 16:30 4.25 10,095 395 COMPZ WELLPF TRIP P POOH F/ 10095' TO 395' FILL F/ TRIP =ACT 80.34 BBL. CALC 62.22 BBL 16:30 18:00 1.50 395 0 COMPZ WELLPF PULD P UD BHA 18:00 18:45 0.75 0 0 COMPZ WELLPF OTHR P CLEAN AND CLEAR FLOOR, HANG BLOCKS 18:45 19:30 0.75 0 0 COMPZ RIGMN1SVRG P PJSM, CUT DRLG LINE 72' (11 WRAPS) 19:30 20:00 0.50 0 0 COMPZ RIGMNT SVRG P SERVICE AND INSPECT BRAKE LINKAGE, T/D AND CROWN 20:00 20:15 0.25 0 0 COMPZ WELLPF OTHR P PULL WEAR BUSHING Page 10 of 19 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:15 21:00 0.75 0 0 COMPZ RPCOM PULD P P/U BOT SUBS, CHK LEW ASSY AND PREP F/ RUN 21:00 00:00 3.00 0 253 COMPZ RPCOM PULD P PJSM, M/U LEM ASSY & MWD AS PER DETAIL TO 253' DISP F/ TRIP= ACT .34 BBL CALC 2.69 BBL 09/20/2012 Continue RIH with LEM to 10048'. Wash down from 10048' to 10071'. Unable to get past 10071'. After several attempts to get past 10071' a decision was made to POOH and make a clean out run. 00:00 00:45 0.75 253 253 COMPZ RPCOM PULD P Mix Pal mix in setting sleeve and let sit for 30 min as per Baker rep. 00:45 01:00 0.25 253 344 COMPZ RPCOM SRVY P PJSM, RIH t/ 344' MD and shallow hole test MWD tools @ 100 gpm= 300 PSI. Good test, blow down top drive. 01:00 10:00 9.00 344 9,868 COMPZ RPCOM TRIP P RIH f/ 344' MD t/ 9869' MD. P /U= 102K, S /O= 66K. Actual displacement= 34.28 bbls, Calculated displacement= 61.15 bbls. 10:00 10:30 0.50 9,868 10,048 COMPZ RPCOM SRVY P Circulate and pulse test MWD tools. MWD reading 154R. Wash down f/ 9869' MD t/ 9960' MD. RIH U 10048' MD on elevators. 10:30 12:00 1.50 10,048 10,069 COMPZ RPCOM WASH P Wash down f/ 10048' MD @ 2.5 BPM =375 PSI. Tagged up © 10056' MD, set down 10K two times to work past. Washed down t/ 10065' MD, tagged up again and worked pipe multiple times. Turned to right 3/4 turn, still no go. Set down 18K observed weight wash off to 16K. Cont. t/ wash down w/ 18 -16K WOB. Increased pump rate to 3 BPM =550 PSI and washed down to 10069' MD. Total losses for tour= 43 bbls. 12:00 16:15 4.25 10,069 10,071 COMPZ RPCOM WASH P Cont to wash down w/ same parameters f/ 10069' MD. P/U and break over w/ 20K overpull after 30-45 min intervals. S/O and tag every 2' high every time w/ 18K max weight on LEM. Avg ROP while washing down= .5 FPH t/ 10071' MD 16:15 17:30 1.25 10,071 10,071 COMPZ RPCOM WASH P Pick up 20'. Shut down pump, close IBOP and annular.Bullhead 50 bbls of fluid down annulus @ 3 BPM =200 PSI ICP and 550 FCP. Pressure broke over @ 550 PSI w/ 40 bbls away. Bleed off 26.2 bbls back to pits and open well up. RIH t/ 10069' MD and attempt to wash down, after several attempts w/ same parameter, no success. Stand back stand, decision made to POOH and make clean out run. 17:30 18:00 0.50 10,071 10,050 COMPZ RPCOM OWFF T Blow down top drive and monitor well., SIMOPS hold PJSM on POOH. Page 11 of 19 • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 18:00 00:00 6.00 10,050 2,331 COMPZ RPCOM TRIP T POOH w/ LEM assy f/ 10050' MD t/ 2331' MD @ 50 FPM. P /U= 60K, S /O= 60K. Actual displacement= 61.61 bbls, Calculated displacement= 46.58 bbls. 09/21/2012 POOH and inspected LEM tool finding a piece of steal in LEM. M/U clean out BHA w/ scraper and rev circ junk basket. RIH t/ 10069' MD and wash hole. POOH and L/D BHA. Found three pieces of steel in the rev circ basket. M/U polish mill and casing scraper and RIH. 00:00 01:00 1.00 2,331 253 COMPZ RPCOM PULL T Continued to POOH from 2331' MD to 253' MD. Actual fill =19.89 BBLS, Calc fill= 14.57 BBLS at 50 FPM. 01:00 03:00 2.00 253 253 COMPZ RPCOM PULL T Laid down LEM assembly and MWD as per Baker and Halliburton reps. 03:00 03:30 0.50 253 253 COMPZ RPCOM OTHR T Clean and clear rig floor, set 9" wear bushing. 03:30 04:00 0.50 253 253 COMPZ WELLPF PULD T Mobilize Baker tools to rig floor. 04:00 04:15 0.25 253 253 COMPZ WELLPF PULD T PJSM, HRC and HRW on picking up and racking back 4.75" Drill Collars. 04:15 05:00 0.75 253 253 COMPZ WELLPF PULD T Picked up and racked back 3 stands of 4.75" Drill Collars. 05:00 06:15 1.25 253 0 COMPZ WELLPF PULD T PJSM, M/U Baker BHA #5. Cleaned out assembly as per Baker rep. 06:15 06:30 0.25 0 0 COMPZ WELLPF OTHR T Clean and clear rig floor 06:30 07:30 1.00 0 0 COMPZ RIGMNISVRG T Service top drive and draworks, greased crown. 07:30 08:15 0.75 0 248 COMPZ WELLPF PULD T Re -dress reverse junk basket assembly and RIH with 2 stands of 4.75" Drill Collars. 08:15 12:00 3.75 248 9,955 COMPZ WELLPF TRIP T RIH f/ 248' MD t/ 9955' MD. Actual displacement= 55.42 bbls, Calculated displacement= 62.56 bbls. 12:00 13:00 1.00 9,955 10,069 COMPZ WELLPF WASH T Wash down f/ 9955' MD t/ 10069' MD, tagged up. Picked up 20' and rotate down @ 20 RPM =4K Tq, pump @ 8 BPM =1500 PSI. Pick up and slide down again, confirm XO bushing @ 10069' MD. 13:00 13:45 0.75 10,069 10,046 COMPZ WELLPF CIRC T Circulate bottoms up at 10046' MD @ 8 BPM =1550 psi. 13:45 14:00 0.25 10,046 10,046 COMPZ WELLPF OWFF T Monitor well, B/D top drive 14:00 18:45 4.75 10,046 300 COMPZ WELLPF TRIP T POOH from 10046' to 300'. Actual displacement= 77.37 bbls, Calculated displacement= 62.56 bbls 18:45 19:00 0.25 300 300 COMPZ WELLPF OWFF T Monitor well (Static) 19:00 19:45 0.75 300 277 COMPZ WELLPF PULD T UD BHA 19:45 20:00 0.25 277 277 COMPZ WELLPFSFTY T PJSM 20:00 20:15 0.25 277 277 COMPZ WELLPF OTHR T Clean and clear rig floor 20:15 22:00 1.75 277 277 COMPZ WELLPF PULD T R/U tongs and M/U BHA 22:00 00:00 2.00 277 5,375 COMPZ WELLPF TRIP T RIH w BHA from 277' MD to 5375' MD Page 12 of 19 i • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/22/2012 24 hr Summary Cont. RIH w/ 4 -11/16 polish mill and 7" scraper t/ 10106' MD. No -Go casing scraper on XO bushing @ 10069' MD. Pump HiVis sweep and circulate hole clean. POOH and UD clean out BHA. M/U LEM and RIH t/ 9870' MD. Wash LEM down, unable to get past 10072' MD. Decision made to POOH and M/U 9 -5/8 casing scraper and clean out down to the hook hanger. 00:00 02:00 2.00 5,375 9,984 COMPZ WELLPFTRIP T Continued to RIH from 5375' MD to 9984' MD (Calculated Displacement 62.56 BBLS Actual 55.4 BBLS) 02:00 02:45 0.75 9,984 10,069 COMPZ WELLPFTRIP T Kelly Up, P/U WT =105K, S /O =66K, ROT. 85K TQ =4K, Pump at 6 BPM =750 PSI Wash Down from 9984' MD to 10069' MD. Tagged up on top scraper and saw pressuer increase to 900 PSI, pulled up 20' and then washed down again and re- tagged. Shut down and go down and tag up 2 times. 02:45 03:00 0.25 10,069 10,069 COMPZ WELLPFCIRC T Circulated at 11 BPM =1875 PSI, 62% flow. 03:00 04:45 1.75 10,069 9,994 COMPZ WELLPF PULD T POOH from 10069' MD to 9994' MD. Circulated at 12 BPM =2150 PSI, pumped 25 BBL high visc sweep while recipricating pipe slowly. (Observed a 50% increase in sand) 04:45 05:45 1.00 9,994 9,893 COMPZ WELLPF PULD T POOH from 9994' MD to 9893' MD and circulated surface to surface at 12 BPM= 2050 PSI. 05:45 06:00 0.25 9,893 9,893 COMPZ WELLPF OWFF T Monitor well B/D T.D. 06:00 10:00 4.00 9,893 277 COMPZ WELLPF PULD T PJSM, POOH from 9893' MD to 277' MD. Actual fill = 73.78 BBLS, calculated fill= 61.56 BBLS. 10:00 11:15 1.25 277 97 COMPZ WELLPF PULD T Lay down 6 joints of 4.75" Drill Collars and BHA as per baker rep. 11:15 12:00 0.75 97 0 COMPZ WELLPF PULL T RIU casing tongs and continued to lay down BHA. (TOTAL NIGHT TOUR LOSS 30 BBLS) 12:00 12:15 0.25 0 0 COMPZ WELLPF PULD T PJSM, continued to lay down BHA 12:15 13:15 1.00 0 0 COMPZ WELLPF OTHR T Clean and clear rig floor. 13:15 13:45 0.50 0 0 COMPZ RPCOM RURD T Pull wear bushing, and rig up to run LEM 13:45 14:00 0.25 0 0 COMPZ RPCOM PUTB T PJSM, make up (LEM) BHA 14:00 15:45 1.75 0 0 COMPZ RPCOM PULD T M/U BHA 15:45 16:00 0.25 0 253 COMPZ RPCOM SRVY T Shallow hole test MWD pump 100 GPM = 250 PSI P/U 39K S/O 43K (Good test) 16:00 23:00 7.00 253 9,870 COMPZ RPCOM TRIP T Continue to RIH on DP from 253' MD to 9870' MD at 30' per minute. Cal displacement= 59.15 BBLS actual =46.75 BBLS 23:00 00:00 1.00 9,870 9,960 COMPZ RPCOM TRIP T Kelly up at 9870' MD wash down to 9960' MD, pump 100 GPM= 380 PSI P/U 97K S/O 66K orient LEM T/155 L, Continue to RIH to 10051'MD. (Total 29 BBL Loss for Tour) Page 13 of 19 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/23/2012 24 hr summary Ran casing scraper down to 9939' MD, Took 5K weight indicating top of hook. Tagged up on junk, washed down to 9934' MD. POOH and UD BHA. Recovered - 40 Ibs of metal off Baker magnets. 00:00 02:00 2.00 9,960 10,700 COMPZ RPCOM WASH T PJSM CONT. RIH W LEM Asseblmy. Started Taking WT @ 10061" MD Continued to S/O to 40K, made it to 10070' MD. Pulled up 117K Pops Free. Pull up w/ 115K then drops off to 100K. Turn String to right to 129 left, same results. Turn string to right 32 left, same results (no change). Look over previous runs, and check depth numbers. CaII Town engineer and decision made to POOH. 02:00 02:15 0.25 10,700 253 COMPZ RPCOM OWFF T Monitor well. (SIMOPS prepare to POOH) 02:15 08:00 5.75 253 0 COMPZ RPCOM TRIP T POOH from 10061' MD to 253' MD. Act fill =77.35 BBLS, Calc Fi11 =61.15 BBLS 08:00 09:30 1.50 0 0 COMPZ RPCOM PULD T Laid down LEM BHA as per Baker rep. 09:30 09:45 0.25 0 0 COMPZ WELLPF OTHR T Clean and clear rig floor 09:45 10:15 0.50 0 0 COMPZ WELLPF PULD T PJSM P/U Baker tool from beaver slide for next clean out run. Bring tools in pipe shed. 10:15 10:45 0.50 0 0 COMPZ WELLPF OTHR T Install 9" wear ring. 10:45 12:00 1.25 0 90 COMPZ WELLPF PULD T M/U BHA #7 scraper clean out run as per Baker rep. (Scraper = 9.625) (Total Tour Fluid Loss= 22 BBLS) 12:00 13:45 1.75 90 5,230 COMPZ WELLPF TRIP T RIH from 90' to 5230' 13:45 14:30 0.75 5,230 5,230 COMPZ WELLPF SFTY T PJSM fix spinner on iron rough neck 14:30 15:00 0.50 5,230 5,230 COMPZ RIGMNT SVRG T Lubricate rig. 15:00 16:30 1.50 5,230 9,934 COMPZ WELLPF TRIP T Continued RIH with scraper from 5230' MD to 9934' MD (Calculated dis 60.49BBLS, Actual 53.73 BBLS) 16:30 17:00 0.50 9,934 9,939 COMPZ WELLPF WASH T Kelly up, P/U 100K 5/0 66K ROT 82K TQ =4K. Washdown to 9939' MD. Took 5K weight indicating top of hook P/U 10' wash down to 9934' MD. Tagged up on junk P/U and rotate @ 15 RPM TQ =4K. Increased pumps to 625 GPM washed down slow to 9934' MD. Took 5K and weight fell off. Cont wash down to 9939' MD worked pipe several times. 17:00 18:00 1.00 9,939 9,939 COMPZ WELLPF CIRC T Pump 30 BBL high visc sweep @ 625 GPM= 2250 PSI saw no cuttings. 18:00 19:00 1.00 9,939 9,906 COMPZ WELLPF TRIP T Laid down single, monitor well pull 10 stands from 9939' MD to 9006' MD 19:00 20:15 1.25 9,906 9,906 COMPZ RIGMNT SLPC T PJSM, Slip and cut drilling line 68'. Page 14 of 19 i • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:15 00:00 3.75 9,906 60 COMPZ WELLPF PULD T Continued to POOH from 9906' MD to 60' MD. (Calc Disp= 59 BBLS Actual= 71.06 losses for Tour =36 BBLS) 09/24/2012 RIH w/ 7" scraper and polish mill, tagged up on junk @ 9994' MD. Work past junk and run down U 10110' MD. POOH t/ 9800' MD and inject 50 bbls. POOH and UD BHA. M/U LEM and RIH. Unable to get past 10073' MD, attempt to work LEM down hole. 00:00 00:30 0.50 60 0 COMPZ WELLPF PULD T PJSM, UD BHA #7 as per Baker Rep 00:30 00:45 0.25 0 0 COMPZ WELLPF OTHR T Clean and clear tools 00:45 01:15 0.50 0 0 COMPZ WELLPF RURD T PJSM, R/U to make up Baker BHA #8. 01:15 03:45 2.50 0 277 COMPZ WELLPF PULD T PJSM, M/U BHA #8 as per Baker rep. 03:45 06:00 2.25 277 9,994 COMPZ WELLPF TRIP T RIH F/ 277' MD, tag junk @ 9994' MD. P/U Weight =100K, S/O Weight =60K, ROT WT =85K. Actual fill= 57.04 BBLS Calc fill= 62.84 BBLS. 06:00 08:00 2.00 9,994 10,110 COMPZ WELLPF WASH T Break circulation @ 8 BPM, 1000 PSI, 55% Flow Rotate 30 RPM, 3.5K torque, tag at 9986' MD stall top drive. P/U rot down several times to 9986' MD top drive stalling every time. Stop rotation and slide down to 10110' MD as per baker rep. 08:00 08:30 0.50 10,110 9,800 COMPZ WELLPF TRIP T POOH F/ 10110' MD to 9800' MD. 08:30 09:00 0.50 9,800 9,800 COMPZ WELLPF CIRC T Inject 50 BBLS @ 5 BPM= 700 PSI, FCP =900 psi. 09:00 09:45 0.75 9,800 9,800 COMPZ WELLPF OWFF T Slowly bleed pressure and monitor well total flow back 12.5 BBLS. 09:45 10:00 0.25 9,800 9,800 COMPZ WELLPF OTHR T Blow down T.D. 10:00 12:00 2.00 9,800 6,125 COMPZ WELLPF TRIP T POOH from 9800' MD to 6125' MD. Total Tour Loss= 67 BBLS 12:00 14:00 2.00 6,125 279 COMPZ WELLPF TRIP T Continue to POOH from 6125' MD to 279'. 14:00 15:45 1.75 279 0 COMPZ WELLPF PULD T Lay down BHA 15:45 16:00 0.25 0 0 COMPZ WELLPF OTHR T Clean and clear rig floor 16:00 16:15 0.25 0 0 COMPZ WELLPF OTHR T Pull wear bushing 16:15 16:30 0.25 0 0 COMPZ RPCOM RURD T R/U to run LEM 16:30 18:15 1.75 0 370 COMPZ RPCOM TRIP T PJSM, Run LEM 18:15 18:45 0.50 370 370 COMPZ RPCOM SRVY T Kelly up on first stand and shallow hole test pump 100 GPM =225 PSI test good 18:45 00:00 5.25 370 9,433 COMPZ RPCOM TRIP T B/D topdrive, RIH with LEM from 370' MD to 9433' MD P/U 100K, S/O 65K. Losses for Tour= 20 BBLS. 09/25/2012 Work string attempt t/ circ. down ann, unable U get down work string, observe well for flow static POOH t/ 345' UD BHA, R/U & inspect derrick w/ 3rd party inspectors, R/U & test BOP. 00:00 00:30 0.50 9,433 9,894 COMPZ RPCOM TRIP T RIH f/ 9433' t/ 9894' Page 15 of 19 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 03:00 2.50 9,894 10,074 COMPZ RPCOM OTHR T CIRC @ 1058 gpm 400 psi, Orient MWD tag up @ 10073' work string t/ 10074', work right hand torque in, stage up t/ setting 30k on string, no change tag up @ 10074', pump 40 bbls down ann. @ 126 gpm 375 psi 03:00 06:45 3.75 10,074 10,074 COMPZ RPCOM OTHR T Attempt t/ slack off no change work string with different deflections w/ samer results. 06:45 07:00 0.25 10,074 10,074 COMPZ RPCOM OWFF T Observe well for flow static. 07:00 12:45 5.75 10,074 345 COMPZ RPCOM TRIP T POOH U 345' 12:45 13:00 0.25 345 345 COMPZ RPCOM OWFF T Observe well for flow static 13:00 15:30 2.50 345 0 COMPZ RPCOM PULD T UD BHA 15:30 15:45 0.25 0 0 COMPZ WELLPF OTHR T Clean and clear rig floor 15:45 19:00 3.25 0 0 COMPZ WELLPF RURD T PJSM, third party derrick inspection (SIMOPS work on iron roughneck 19:00 20:15 1.25 0 0 COMPZ WHDBO RURD T R/U to test BOP 20:15 00:00 3.75 0 0 COMPZ WHDBO BOPE T PJSM test BOP #1 Top pipe rams, valve 1, 12, 13, 14 and manual kill. #2 Upper IBOP, HCR Kill, Valves 9, 11. #3 Lower IBOP, Valaves 5, 8 and 10. #4 Dart valve, Valves 4, 6, 7. #5 Floor valve and valve 2. #6 HCR choke, 4" kill line demco valve. #7 choke valve, HCR kill. 09/26/2012 Cont to test BOPE t/ 250/3500 PSI. Test witnessed by John Crisp, AGOCC. M/U storm packer and RIH. Set packer -1U0' below aT�Waila OA had 110 PSI�on it, seawater down OA t/ kill backside, no success. UD storm packer and RIH the lower packer completion. Set packer w/ WLEG @ 9925' MD. 00:00 03:15 3.25 0 0 COMPZ WHDBO BOPE T Continue testing BOP test 4" test jt, lower rams & ann, c/o & test 4.5 test jt. top & bottom rams & ann. t/ 250/3500, test blind rams & valve #3, acc. test, John Crisp witnessed test. 03:15 04:15 1.00 0 0 COMPZ WHDBO OTHR T Blow down choke manifold, top drive and kill line, R/D test equipment, clean & clear floor. 04:15 04:30 0.25 0 0 COMPZ WELLPF SFTY X Pre job safety meeting on running storm packer 04:30 06:15 1.75 0 965 COMPZ WELLPF RURD X R/U & run storm packer w/ 3 stands of 4.75 DC, 5 stands of 5" HWDP 06:15 07:00 0.75 965 0 COMPZ WELLPF PLUG X Set storm packer @ 110' release form packer pooh, UD packer setting tool, test packer t/ 1500 psi f/ 15 min. 07:00 07:15 0.25 0 0 COMPZ WELLPF SFTY X Pre job safety meeting on rigging up and pulling pack off 07:15 07:30 0.25 0 0 COMPZ WELLPF OTHR X P/U and M/U pack off pulling tool. 07:30 09:45 2.25 0 0 COMPZ WELCTL OTHR X Bleed OA down f/ 110 psi t/ 0 psi observe slight flow from OA shut in OA presure built back t/ 110 psi. 09:45 10:00 0.25 0 0 COMPZ WELCTL SFTY XT Pre job safety meeting on bull heading fluid down OA Page 16 of 19 • • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 11:15 1.25 0 0 COMPZ WELCTI CIRC XT Line up and bull head 100 bbls of 8.6ppg seawater down OA @ 84 gpm 375 psi. 11:15 13:00 1.75 0 0 COMPZ WELCTI OWFF XT Observe well for flow on trip tank, flow steady @ .34 bbls per 10 min. shut in well. 13:00 15:15 2.25 0 0 COMPZ WELLPF PULD XT UD storm packer BHA 15:15 15:45 0.50 0 0 COMPZ RPCOM RURD X Clean & clear floor, R/U t/ run completion. 15:45 16:00 0.25 0 0 COMPZ RPCOM SFTY X Pre Job safety Meeting on running lower completion. 16:00 17:15 1.25 0 0 COMPZ RPCOM PULD X P/U BHA, Lower completion 17:15 17:45 0.50 0 249 COMPZ RPCOM TRIP X RIH with completion T/ 249' MD, Break CIRC. Pump 2 BPM =50 PSI B/D Topdrive 17:45 22:45 5.00 249 9,913 COMPZ RPCOM TRIP X Continue RIH F/ 249' MD T/9913' MD. 22:45 00:00 1.25 9,913 9,925 COMPZ RPCOM PACK X Kelly Up break circulation @ 2 BPM =50 PSI. Shut down pump break connection drop ball, RIH to set depth @ 9925' MD and pump ball down @ 3 BPM= 225 PSI. P/U 125K, S/O 76K. (Calculated disp= 62.63, Actual disp= 53.04) Losses for Tour= 29 BBLS 09/27/2012 POOH laying down drill pipe t/ 4500' MD. M/U and set storm packer — 112' below table. Bull headed 144 bbls of 9.6 ppg brine down OA to kill OA, OWFF. Change Pack Off assembly and test. Cont POOH laying down drill pipe. UD BHA. R/U and RIH w/ 4 -1/2" upper completion. 00:00 00:15 0.25 9,925 9,822 COMPZ RPCOM PACK X PJSM, Pressure up to 4000 psi, set packer at 9822' MD. 00:15 00:30 0.25 9,822 9,822 COMPZ RPCOM PRTS X Pressure test packer to 2500 psi for 5 minutes. (Good) 00:30 00:45 0.25 9,822 9,822 COMPZ RPCOM RURD P R/D test equipment, blow down T.D. and kill line 00:45 01:00 0.25 9,822 9,822 COMPZ RPCOM SFTY P PJSM on laying down pipe. 01:00 02:00 1.00 9,822 9,102 COMPZ RPCOM PULD P Laydown 5 stands, HWDP. 3 stands of drill collars. Desicion made to UD more pipe due to having too much WT to set packer. 02:00 06:15 4.25 9,102 4,450 COMPZ RPCOM PULD P P/U protectors and continue to lay down drill pipe until we reach 70K string weight. 06:15 07:00 0.75 4,450 4,450 COMPZ WELLPF RURD XT R/U and M/U storm packer as per Baker Rep 07:00 07:45 0.75 4,450 4,450 COMPZ WELLPF PACK XT RIH and set storm packer and test T/1500 PSI for 5 min. (Good) as per Baker Rep. (COE@ 112' MD) 07:45 08:00 0.25 4,450 4,450 COMPZ WELLPF SFTY XT PJSM on R/U and pumping down OA. 08:00 09:15 1.25 4,450 4,450 COMPZ WELLPF KLWL XT Pump 144.5 BBLS 9.6 PPG sea water down OA @ 2 BPM, 500 psi, FCP =300 psi. 09:15 10:15 1.00 4,450 4,450 COMPZ WELLPF OWFF XT Monitor OA through trip tank. (.51 BBL gain) Page 17of19 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:15 10:30 0.25 4,450 4,450 COMPZ WELLPF RURD XT R/D Circulating equipment and drain stack. (No flow through OA). 10:30 11:00 0.50 4,450 4,450 COMPZ WHDBO OTHR X R/U and pull old packoff as per Vetco Grey Rep. (Pulled with 2K overpull). 11:00 12:00 1.00 4,450 4,450 COMPZ WHDBO OTHR X Install new packoff as per Vetco Grey rep. 12:00 13:45 1.75 4,450 4,450 COMPZ WHDBO PRTS X PJSM, Continue to run in lock downs, inject packing and pressure test pack off to 5000 psi for 10 mins (test good). R/D pack off setting tool. 13:45 15:00 1.25 4,450 4,450 COMPZ WELLPF RURD X PJSM, R/U and pull storm packer 15:00 15:30 0.50 4,450 4,450 COMPZ WELLPF PULD X UD storm packer. 15:30 16:00 0.50 4,450 4,450 COMPZ RPCOM TRIP P PJSM, RIH with 5 stands in derrick. 16:00 19:30 3.50 4,450 120 COMPZ RPCOM TRIP P PJSM, POOH L/D DP 50 stands (Cal Disp= 27 BBLS Act= 35.53 BBLS) 19:30 20:00 0.50 120 0 COMPZ RPCOM PULD P UD BHA 20:00 20:30 0.50 0 0 COMPZ RPCOM OTHR P Clean and Clear rig floor, UD tools 20:30 21:00 0.50 0 0 COMPZ RPCOM RURD P PJSM, R/U to run 4.5" Liner 21:00 23:00 2.00 0 0 COMPZ RPCOM RURD P R/U centerlift 23:00 23:15 0.25 0 0 COMPZ RPCOM PULD P PJSM, P/U BHA 23:15 00:00 0.75 0 30 COMPZ RPCOM PULD P P/U seal assembly, locator and pup losses for Tour= 29 BBLS. 09/28/2012 Run 4.5 comletion line on_ spool ta d & brok nglee, POOH replace line t/ sensor,run upper completion, rabbiting pipe from derrick and installing canon clamps on jts. 00:00 00:15 0.25 30 30 COMPZ RPCOM SFTY P PJSM on running 4.5 completion 00:15 00:45 0.50 30 66 COMPZ RPCOM RCST P R/U t/ drop rabbit f/ derrick, P/U 1 jt of tubing & sensor housing. 00:45 04:45 4.00 66 66 COMPZ RPCOM OTHR P R/U and M/U control line to sensor as per baker 04:45 06:45 2.00 66 66 COMPZ RPCOM RCST T RIH w/ 5 stands of 4.5 tubing, control line tangled on spool and broke, POOH & repair line. 06:45 09:30 2.75 66 66 COMPZ RPCOM OTHR T Make control line up t/ sensor. 09:30 11:15 1.75 66 66 COMPZ RPCOM OTHR T Repair line spooler. 11:15 00:00 12.75 66 7,756 COMPZ RPCOM RCST P Run upper completion as per detail, installing clamps on every connection, rabbiting pipe from derrick t/ 7756' MD, P /U= 73K, S /O= 55K. Actual displacement= 18.02 bbls, Calculated displacement= 37.67 bbls. 09/29/2012 Cont t/ RIH w/ 4 -1/2" tubing. Space out and land tubing w/ bottom of seals @ 9801' MD. Load IA w/ inhibited brine. Test hanger. Attempt to open SOV, no -go. N/D BOPE and N/U tree. Test tree t/ 5000 PSI. Freeze protest OA w/ 85 bbls of diesel. R/D to move to 2A -08. 00:00 03:00 3.00 7,756 9,490 COMPZ RPCOM RCST P PJSM, Cont to RIH w/ 4 -1/2" tubing t/ 9490' MD. Ran out of control line for sensor. Decision made to cap line. Page 18 of 19 Time Logs • • Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 03:00 04:00 1.00 9,490 9,490 COMPZ RPCOM OTHR T Cap control line and clamp with cannon clamp mid -joint on # 309. 04:00 06:00 2.00 9,490 9,801 COMPZ RPCOM HOSO P Cont t/ RIH and No -Go @ 9800' MD. Set down 20K. Space out tubing w/ 2 10' pups and 1 2' pup. P /U =79K, 5/0= 55K. Bottom of seals @ 9788' MD. Adjusted RKB depth= 9800.94', 7' above located position. 06:00 06:45 0.75 9,801 9,801 COMPZ RPCOM HOSO P M/U Vetco hanger. 06:45 07:15 0.50 9,801 9,801 COMPZ RPCOM RURD P Rig up lines to circulate. 07:15 09:30 2.25 9,801 9,801 COMPZ RPCOM CIRC P PJSM, displace well w/ 430 bbls of 8.6 ppg inhibited seawater © 6 BPM =500 PSI followed by 130 bbls of 8.6 ppg seawater @ 8 BPM= 750 PSI. 09:30 10:00 0.50 9,801 9,801 COMPZ RPCOM OWFF P Monitor well and flush stack. 10:00 11:15 1.25 9,801 0 COMPZ RPCOM THGR P Land tubing hanger, RILDs and test hanger void /seals t/ 5000 PSI for 10 minutes. 11:15 13:30 2.25 0 0 COMPZ RPCOM PRTS P Pressure test IA in 500 PSI increments to 1500 PSI f/ 10 minutes. Pressured up t/ 2700 PSI to shear SOV, no -go. SOV would not shear. Bled of pressure and pressured back up to 3500 PSI and held for 5 minutes several times. SOV would still not shear, decision made to set two way check and let slick line pull SOV. 13:30 14:15 0.75 0 0 COMPZ WHDBO RURD P Rig down landing joint and set TWC. 14:15 18:00 3.75 0 0 COMPZ WHDBO NUND P PJSM, Nipple down BOPs and nipple up tree. 18:00 18:30 0.50 0 0 COMPZ WHDBO PRTS P Test hanger void pack -offs to 250/5000 PSI f/ 15 minutes, good. 18:30 19:45 1.25 0 0 COMPZ WHDBO PRTS P Test tree t/ 250/5000 PSI f/ 5 minutes. 19:45 21:45 2.00 0 0 COMPZ WELLPF FRZP P PJSM, R/U Little Red to freeze protect OA. PT lines to 2500 PSI. Bull head 85 bbls of 70 °diesel down OA. Pump @ 2 BPM, ICP =700 PSI, FCP =900 PSI. 21:45 00:00 2.25 0 0 DEMOB MOVE RURD P Rig down for rig move to 2A -08. Rig leased @ 00:00 hrs on 9 -30 -12 Page 19 of 19 i ~ ~. ~ ~~.: ~~. ~x ~~ b ~~ t..~ ~. ~o-~ ~ ~ ~~ ~' < ~~ s MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS RE~I~iED FEB 1 9 2010 1. Operations Performed: Abandon ~"" Repair w ell ~ Plug Perforations ~"" Stimulate "' , Ottlef ,y ~ Alter Casing )'° Pull Tubing Perforate New Fbol ~ i Waiver Time Ex of""nsio(n~ Change Approved Program ~ Operat. Shutdow n ~ Perforate " Re-enter Suspended Well R~ ~~L` 2. Operator Name: 4. Current Well Status: ~ 5. Permit to Drill Number: ~~ ConocoPhillips Alaska, Inc. Development ~' Exploratory "' 207-080 3. Address: ~ 6. API Number: Stratigraphic Service P. O. Box 100360, Anchorage, Alaska 99510 50-029-23360-00 7. Property D~signatiQn: ~ 8. Well Name and Number: ADL 25661, 25660, 25663 ~ 1 J-162 . Field/Pool(s): Kuparuk River Field /West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 14490 feet Plugs (measured) None true vertical 3218 feet Junk (measured) None Effective Depth measured 14480' feet Packer (measured) 10044', 10054' true vertical 3219' feet (true verucal) 3196', 3197' Casing Length Size MD ND Burst Collapse CONDUCTOR IN 79 20 120 120' SURFACE 3777 13.375 3820 2201' INTERMEDIATE 10359 10.75 10400 3245' B-SAND LINER 4426 5.5 14480 3218' ~~M SCI ~ttr~~ ~f~~ ~- ~ , ~, pkr P~~-sz Perforation de th: Measured de th: 10393'-10480' 10784'-13403' 13621'-14391' "r w ° j p p , , ~- 1 ~ ~S h ' ' ' ' ' ' k ~"~'' True Vertical Depth: 3244 Y ~,~e~. -3252 , 3259 -3241 , 3238 -3220 P ~~' ~ Tubing (size, grade, MD, and TVD) 4.5, L-80, 7513 MD, 2809 TVD Packers &SSSV (type, MD, and TVD) C-2 ZXP liner top pkr @ 10044' MD, 3196' TVD, ToS~ueMaster gkr ta'~ 8185' MD MLZXP liner top pkr @ 10054' MD, 3197' TVD no SSSV ueeze summary: a r` ~'~ ~~~" ? ~~ ~ ~ ~~ ~ ~~~ ~~ Interv ls treated (measured) not applicable ~~ `~~ ' Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-MCf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 157 742 6 -- 195 Subsequent to operation 9 0 276 192 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory Development Service 1 .Well Status after work: Oil ~' Gas WDSPL Daily Report of Well Operations XXX GSTOR `"` WAG ~'"° GASINJ "" WINJ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Erik Nelson 263-4693 Printed Name E ~ NeISO Title Wells Engineer Signature ~ Phone: 263-4693 ..- Date `~ ~~ / se ~ / C w r,~ Form 10-404 Revised 7/2009 ~~S ~ ~ 9 ~ ~~~~~ Submit Original Only .$~ Nl M~ ~,~; ~,' KUP - 1J-162 ~ -~-- -- ~Ot1d~4~1~~~i~'J~ ''';I Well Attributes Max Angle & Ml) TD \I .; Lt I + Wellbore APVU WI Fieltl NameWell Status Intl (°) IMD (ftKB) Act Btm (ftKB) ` i 500292336000 WEST SAKPROD 93.46 13,634.05 14,490.0 (Comment N25 {pp1~l Date Mnotation (End Date KB-Grd (ft) RigR lease Date _w~.C ntlg v t¢g, v2a26 oaa -~~n SSSV-NONE p ( ) ~ I ~,lev Rea~orr E~ P WO~ OVER 1/21/2010 43.S11mosbor 8/16/2007 _ otat on De th ftKB End Data Mnotation Last Mod ... _ _„ Schemel4 Actual A 9 Lr End Date Latt is j 1/24/2010 ,~.- Casmg_Strings .;. Casing Des<r ptlon~.Str y II ~ Top (NKB) Set Depth (f... Set Depth (ND) .. String Wt... String .. Suing Top Thrd rwNGER. 36 'CONDUCTOR ', 20 1r 'I 415 120.0 120.0 ~ 94.00 WELDED - ,Insulated _ _ _ _ _ _. _ _ _ _ - o Casing Descrption it String 0... 'iStr ng II7 _ Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... Strmg String Top Thrd SURFACE 13318 12 ~I I`S 43.1 3,820-3 2,207.7 68.00 L80 _ BTC _ ,: Casing Description (String 0... Str nq IU _ Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... Strmg String Top Thrd INTERMEDIATE '~ 9518 38::5 40-3 10,399.5 3,245.0 40.00 L-80 BTCM 10.75 x 9.625 I ') Casing Description (String 0... String II7 _ Top (kK8) Sel Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd B-SAND LINER 8.44 r; 190 10 043 6 10,069.8 3.199 4 PACKER colvoucroR Liner Details ~~ Insnla,ea-_. " ---..---- 42120 Top Depth (ND) Top Intl Nomi.. ~:, Top (HKB) (ftK61 (°) ItemD rriptian Comment ID (in) 1Q043.6 3,195.9 81.85 PACKER 'C-2' ZXP LINER TOP PACKER 6.19( ;: 10,059.1 3,198.0 82.02COLLitR - - NO GO COLLAR 6.19( 10,060-0 3,1982 8203TIE BACh:. TIE BACK SEAL ASSEMBLY STABBED INTO B-SAND MLZXP LINER 6.79f Esp TOP PACKER MANDREL,- ." __ __..__. 2.066 ~ Casing Description String O._ String ID .. Top (ftKB) Set Depth (t... Sat Depth (ND) ... String Wt... String ... String Top Thrd B-SAND LINER 5112 4!)4G!1 10,054.3 14,480.0 3,215.5 1550 L-80 BTC Liner D__etails ;., ToiND' lh ToP Intl Nomi.. SURFACE,____ ` 10,054-3! 3,1974 81 97 PACKER ~- ~ MLZXP Liner Top Packer 9-5/8" (7.50" X 8.32") LS 43-3,az6 10,075.51 3,200.2 82.21 HANGEF', FlexLOCk Liner Hanger 7" x 9-5/8" (6.09" X 8.30") 6.0 ~~ 10,080.8 3,200.91 82.26 XO L`USI111~k3 XO Bushing 4 95" ID, 7.63" OD 7"- H563 x 5 1/2" H563 4.9 __ -_ _ _ Esa MA DRE -- 10,0822' 3,201.1 ~ 82.28 SBE 190-07 SEAL BORE EXTENSION 4.7 N L, 7.326 ' 14,391.31 12199 91.06 XO 5-1/2" BTC-M x 4-1/2" BTC-M Crossover 4.5 Set Depth (ND).. String Wt... Strng... (String TOp Thrd Set Depth (f_- y ~...TOp (ftKB) Casin Des ri tion Strin O. Str II ~ ~ ( ( ( Il 8,184.2 8,375.0 29414 I 12.60 L-80 IBTM D-La 9LEM w/MWD i 455 DISCHARGE. rIn S 7,400 To ftK81 (Set Depth f...Set Da th ND).. SVin WL.. I~Str'n IStrin To Thrd Tubin Descri bong IStrin 0... Ste II. p( ( p ( g g .. 9 p 9 - 35.7 7,573.2 2,808.5 _72.60 II L-80 IBT-M ESP 9UBING 41/2 i Com letion Details -- Top Depth - -- INTAKE, 7,474 (ND) Top Intl Nort ESP~MOtM --- Top (ftKB) (ftKB) (°) Item D noon Comment ID (' 7p9a '~- k + 35.7 35.7 -0.04 HANf F F. Vetco Gray 11 "x 4-112" Hgr w/ 4 909" MCA Top Conn- 3.9 SENSOR, 7s6s `-~--- .. _- 7,400.1 2,793.0 8243 DISCHAFnE Unique Discharge Sun 3.9 ~EMRALIZER, 7sn --- ~ 7,473.9 - 2,802.7 81.71 INTAKE ( I Perforated Xover Intake TTC ESPCP (5-13" OD) O.C 7 484.4 2,804.3 81.61 SEAL ' LOwer Tantlem Seal GSB3D8 FER HL H6 SSCV SBfS6 PFSA O.C 7,495.2 2,806.3 81.45 ESP Id~trti I I __ -.. MOtor 418 HP KMFI (2610 v 198 amp) (5.62" O.D.) O.C _ J 7,509.2 2,807.9 81.37 SENSOFI A-Well I-Pump Sensor (4.50"OD) O.C "~ 7,517.3 2,808.2 81.35 CENIP,e,p..llER MOtor Centralizer(5.85"O.D.) 4.5 -.., - Perforations 8 Slots Top (TVD) Bbn {1"'ifR.)) Dens .. Top (ftKB) Btm (ftKB) (ftKB) (HKB( Zone Data (sh-' Type Comment 10,393 1 10,480 3,244.2 J, 251. / iNS B, 1J-162 7/23/2007 32.0 Slots Alternating solidlslotted pipe 2-S" X .~ -125" in 4 circumferential rows/ft > 10,784 12,497 3,259.3 3,22 2 1MS B, 1J-162 7/23/2007 32.0, Slots Alternatingsolid/slotted pipe 25" X Diat LEM ~ .125" in 4 circumferential rows/ft wiMwD, - 12,497 13,403 3,229.2 3 241 1 tMS 8, 1J-162 7/23/2007 32.0 Slots Alternating solidlslotted pipe 25" X 8.184-8.3]5 \ B-SAND LINER ~ .125" in 4 circumferential rows/ft t6,6aa omo i-=~. 13,621 14,391 3,237.7 .,T'0111MS 6, 1J-162 7/23/2007 320'Slots Alternating solidlslotted pipe 2-5"X D-SAND HooK ! .125" in 4 circumferential rows/ft 11 ~ i 9: 9- 0,2 6 I ~ _ _. _. Notes: General & Safety ` - _ _ __ _ _ __ _ Ena Date Annotation __ I ..~»~~;.~ 8/16/2007 NOTE: MULTI-Li+.I I F WELL- 1J-162 (BSAND), 1J-162L1 (D-SAND) 10/13/2008 (NOTE: VIEW SCHEA~h~.I IC w/Alaska Schematic9.0 10.75 x 9.625, 40-10,400 \ 1 2,003.7 1,712 8 2 7,319.6 2,779.7 oD vane Latcn II spa Run Date Cam... 1 /23/2010 1/21/2010 - Slots, 13621-14391 ;_'7 t - - -s--' A' B-SAND LINER. 10,054-14,480 TD (t J~t62), 14 A90 r Conoc©Phillips Time Log & Summary We/!view Web Reporting Report WeII Name: 1 J-162 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 1/11/2010 12:00:00 PM Rig Release: 1/21/2010 12:00:00 PM Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 1/10/2010 24 hr summary Prepping rig for move 08:00 12:00 4.00 MIRU MOVE MOB P Move Rig F/36 to 1Q 12:00 15:00 3.00 MIRU MOVE MOB P Move Rig F/1Q to KOC 15:00 16:00 1.00 MIRU MOVE MOB P Grease Planetaries, load agitator 16:00 21:00 5.00 MIRU MOVE MOB P Move Rig F/KOC to 1J Pad 21:00 00:00 3.00 MIRU MOVE RURD P Assemble 13-5/8" BOPE 1/11/2010 Finished prepping 13 5/8" BOPE in cellar. Move rig over well. Accept Nordic 3 rig @ 1200 hrs 1-11-10. 00:00 10:00 10.00 MIRU MOVE RURD P Continue Assembly of 13-5/8" BOPE, Install lifting plate and re-attach annular. 10:00 12:00 2.00 MIRU MOVE MOB P Move rig around and spot over well. Rig containment. Accept Nordic 3 ri 1200 hrs 1-11-10. 12:00 14:30 2.50 MIRU WELCTL RURD P Bearm up (containment). Spot Equipment. PU & RU Lubricator.Pull BPV. 500 si on tb . LD lubricator. 14:30 19:00 4.50 MIRU WELCTL RURD P RU circulating hoses, load pits with seawater w/6% KCL. Thaw kill line. 19:00 22:30 3.50 MIRU WELCTL RURD P Remove flange from cutting chute, s of cuttin s bin, hook u hi h line. 22:30 00:00 1.50 MIRU WELCTL RURD P Blow through cellar lines, found more blockages, thaw lines, clear all blocka es. 1/12/2010 Kill well. Set BPV. ND tree. 00:00 01:30 1.50 COMPZ WELCTL RURD P PT circulating and hardline to 2500 si. 01:30 06:00 4.50 COMPZ WELCTL KLWL P Open well. SITP = 400 psi, SICP = 650 psi. Bled tbg & IA to 0. Pump 15 bbls down IA at 3.5 bpm, ICP = 760 psi, FCP = 760 psi. No returns. Pump 120 bbls hot SW w/ 6% KCL down tbg, ICP = 60 psi, FCP = 60 psi. Swap over to IA and pump at 3.5 bpm down IA, seeing +/_50% returns out the tbg. Pumped a total of 480 bbls down IA. ICP = 330 psi, FCP = 550 psi. Shut down and monitor well. Page 1 of 9' t Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment _ 06:00 09:00 3.00 COMPZ WELCTL KLWL P Take on 580 bbls hot SW w/ 6% KCL, bullhead 300 bbls down the tubing to the formation. Bleed tubing & IA off f/400 psi to 0. Monitor well. Press 0 but still ettin as. 09:00 12:00 3.00 COMPZ WELCTL KLWL P Bullhead 300 bbls seawater w/6% KCL down tubing. @ 6 BPM ICP = 110 psi .Pump pressure came up to 2000 psi slowed pump rate down to 1 BPM Broke over to 670 psi. Increase pump rate back to 5 BPM @ 670 psi pump rate came up to 6 BPM @ 360 psi. SD monitor well. Same results after 30 min. 0 Press. but still assin . 12:00 14:00 2.00 COMPZ WELCTL KLWL P Circulated with charge pump down tubing 50 psi venting gas to kill tank. Pumped 268 bbls with 20 bbls returns (crude). Blow down lines and minitor well. Let gas bleed to kill tank. Bled down to 0. 14:00 16:00 2.00 COMPZ WELCTL KLWL P Shot fluid. level, top of fluid @ 835'. PJSM. Blow down lines. RD lines. Bleed of OA from 100 psi is 30 seconds shut valve and pressure would return to 100 si in 4 min. 16:00 18:00 2.00 COMPZ WELCTL MPSP P Set BPV. ND tree. 18:00 19:00 1.00 COMPZ WELCTL NUND P Nipple down Production tree. Inspect tubin hna er threads. -All ood. 19:00 20:30 1.50 COMPZ WELCTL NUND P Install Blanking plug, Nipple up Double studded ada ter. 20:30 00:00 3.50 COMPZ WELCTL NUND P Ni le u 13 5/8" BOP stack choke & kill lines. 1/13/2010 Continue NU BOP stack & Lines. RU & Test BOP's. BOPE test witnessed by J. Chrisp, AOGCC Rep. V~ 00:00 03:30 3.50 COMPZ WHDBO NUND P Continue NU 13 5/8" BOP stack, choke & kill lines.. Function test Blind rams. RU test a ui ment. 03:30 06:00 2.50 COMPZ WHDBO NUND P Observed leak on choke side HCR lines. Rea it HCR line. 06:00 09:00 3.00 COMPZ WHDBO NUND P verify all Koomey valves/regulators are workin . RU test a ui ment. 09:00 20:30 11.50 COMPZ WHDBO BOPE P ~T 6~PE and choke maniflold t 2,5,O/5000 osj, Shot fluid levels on IA to keep up with top of fluid. 8:OOam 45', 1:OOpm 72', & 5:30 pm 2350. Loaded hole with SW. ROPE test witnessed by J. Chrisp, AOGCC Re . 20:30 21:00 0.50 COMPZ WHDBO MPSP P Pick up Landing Joint and pull Blankin Plu . 21:00 00:00 3.00 COMPZ RPCOM RURD P PJSM. Spot Crane. Remove spreader bar. Lift Guards, Spooling Unit, and Em S ool to ri Floor. 1/14/2010 Circulate Well. Pull 4 1/2" ESP Completion. Lay down ESP Assembly. 4/ Page 2 of 9 Time Lo s Date From To Dur S. De th E. De th Phase .Code Subcode T Comment 00:00 01:30 1.50 COMPZ RPCOM RURD P Complete rigging up Spooling Unit on Ri Floor. 01:30 04:00 2.50 COMPZ WELCTL CIRC P Attempt to pull Back Pressure Valve. Found trapped gas below BPV. Pump 35 bbls down tubing at 2.0 bpm. Well on vacuum. Pull BPV. La down same. 04:00 06:00 2.00 COMPZ WELCTL CIRC P Pick up Landing Joint. Monitor Well. RU IA to kill tank and bleed 100 psi from I. A. 06:00 08:30 2.50 COMPZ RPCOM RURD P Load centrilift equip. and move up to rig floor. RU circulating lines to IA & tubin for reversin . 08:30 11:30 3.00 COMPZ RPCOM CIRC P Pumped 230 bbls Seawater w/6% KCL down tubing. Switched lines and reverse circulated 725 bbls taking returns to kill tank. 275 bbls retums. SD well on vacumm. 11:30 14:00 2.50 COMPZ RPCOM RURD P RU extra 20' hose to kill line on tubing. Install mouse hole. RU tools on floor for pulling tubing. RU centrilift a ui ment. 14:00 15:00 1.00 COMPZ RPCOM PULL P PJSM covering pulling ESP & 4.5" tubing. BQLDS. Pulled hanger free 150K. Pulled han er to ri floor. 15:00 16:00 1.00 COMPZ RPCOM CIRC P Attempt to fill hole. Pumped 102 bbls SW w/6% KCL but could not catch fluid. Well on vac. 16:00 17:00 1.00 COMPZ RPCOM RURD P Break out penetrator. Cut ESP cable at pigtail. Pick up on string. Wt = 75K. String cable tru sheave and hang sheave in derrick, thread cable to s ooler. 17:00 00:00 7.00 COMPZ RPCOM PULL P Start pulled completion, drifting 4.5" tubing w/3.833" drift, racking back tubing in derrick and spooling up cable. Lay down GLM Assembly. Have 60 Stands (-5,600-ft) in Derrick at Midni ht. 1/15/2010 Load and Tally 3 1/2" Drill Pipe and 5" Drill Collars in Pipe Shed. 00:00 02:00 2.00 COMPZ RPCOM PULL P Finish Pulling 4 1/2" Tubing, standing back in Derrick and ESP Com letion. 02:00 06:00 4.00 COMPZ RPCOM PULL P Lev down and insoect ESP Assembl . Found a hole burned in ESP Cable at -70-ft above the Discharge Sub. Recovered all ESP Completion, Clamps, Guards. Lost 4 bands. 06:00 21:00 15.00 COMPZ RPCOM PULD P Clean rig floor and running equipment. Start loading pipe shed with 3 1/2" drillpipe and Snozzlator wash down tools. Clean snow out of drill pipe, strap and number. Total 320 ea 3 1/2" Drill Pi a in Pi a Shed. 21:00 22:00 1.00 COMPZ WELLPF PULD P PJSM. Install Wear Bushing. Page 3 of 9 a a Time Lo s ::Date From To Dur S. De th E. De th Phase Gode Subcode T Comment 22:00 00:00 2.00 COMPZ WELLPF PULD P Make up BHA as follows: 4 1/2" Bull Nose Wash Nozzle, 3 1/2" EUE 8rd Pin x 3 1/2" IBTM Box Pup Jt XO, 3 Jts ea 3 1/2"IBTM Tubing, 3 1/2" IBTM Pin x 3 1/2" EUE 8rd Box Pup Jt XO, Lateral Wash Nozzle, 1 Jt ea 3 1/2" EUE 8rd Tubing, 3 1/2" EUE 8rd Pin x 3 1/2" IF Box XO, 4 3/4" Bumper Sub, 4 3/4" Oil Jar, 4 11/16" Pum Out Sub, 1 /16/2010 RIH with BHA and Drill Pipe. Wash D-Lateral Hook Hanger down to bottom of Seal Bore at 10,102-ft. 00:00 02:00 2.00 0 441 COMPZ WELLPF PULD P Continue to make up BHA. Change handling equipment to pickup Drill Collars. Finish making up BHA as follows: 3 1/2" IF Pin x 4" XT39 Box, 9 ea 5" Drill Collars, 4" XT39 Box x 3 1/2" IF Pin. 02:00 07:00. 5.00 441 4,452 COMPZ WELLPF PULD P Rig up to handle 3 1/2" Drill Pipe. PU &RIH with 3 1/2" 13.3 Ib/ft, IF, S-135 Drill Pi a from Pi a Shed. 07:00 09:00 2.00 4,452 6,900 COMPZ WELLPF PULD P Load Lateral Entry Module w/ MWD equipment into pipe shed to thaw out. Continue to RIH. UP wt 92K Dwn wt 50K 6900' 09:00 10:00 1.00 6,900 6,900 COMPZ WELLPF CIRC P RU lines, pump DP volume to clear wash out tool. 1750 psi ICP 3270 si FCP. 10:00 11:30 1.50 6,900 8,740 COMPZ WELLPF PULD P Rd lines. Continue to RIH from 6900' to 8740. Pipe falling slowly. Up wt 110K Dwn. 35K. Stopped falling on its own. Screwed in Top Drive, rotate 1 jt down with 4K ft.lbs torque. SD wait on tube. 11:30 13:00 1.50 8,740 COMPZ WELLPF CIRC P Mixed and pumped 150 bbls of Safelube, chased w/125 bbls SW/KCL. Working pipe up and down. 13:00 18:00 5.00 9,352 COMPZ WELLPF PULD P Continue RIH slowely. PUW = 100K. SOW = 40K. RTW = 75K. RPMs = 30. 18:00 22:30 4.50 9,900 COMPZ WELLPF PULD P Continue RIH slowely. PUW = 110K. RTW = 75K. RPMs = 30. Tor ue = 4K. Nozzle at 9,900-ft. 22:30 23:00 0.50 9,900 9,970 COMPZ WELLPF CIRC P Bring Pump #1 and #2 on line at 7.6 bpm/3,200 psi. ~iegin to wash from 9 900-ft. down to 9 970-ft. IA remains full while washin . 23:00 00:00 1.00 9,970 COMPZ WELLPF EQRP T Repair leak at the Rotary Hose/Goose Neck connection on To Drive. 1/17/2010 Continue to wash down f/ 9,970' t/ 10,102'. Flush down IA w/ 120 bbls @ 7.5 bpm. POOH with D-Lat C/O BHA. MU BHA for LEM. RIH to 8 375-ft w/ WLEG and PKR 8.184' and ulled ti ht. 00:00 02:00 2.00 COMPZ WELLPF EQRP T Complete repairs to Rotary Hose/Goose Neck connection on To Drive. Page 4 of 9 l~ Time Lo s Date Fram To Dur S. De th E. De th Phase Code Subcode T Comment 02:00 03:30 1.50 9,970 10,102 COMPZ WELLPF CIRC P Continue to wash down from 9,970-ft at 7.5 bpm/3,200 psi. PUW = 110K. ROTW = 75K RPMs = 15. Troque = 4K. Washed through the D-Lateral Hook Hanger and down to the bottom of the Seal Bore at 10,102-ft. No indication of an fill. 03:30 04:00 0.50 8,375 COMPZ WELLPF SFT( P PJSM. 04:00 04:30 0.50 10,102 9,902 COMPZ WELLPF TRIP P Pull 2 stands of 3 1/2" Drill Pipe. Blow down To Drive. 04:30 05:00 0.50 9,902 9,902 COMPZ WELLPF CIRC P Bullhead 120 bbls down IA at 7.5 bpm/300 psi to flush any fines down hole. 05:00 13:30 8.50 9,902 0 COMPZ WELLPF TRIP P Trip out with the Wash Down BHA, standing back 3 1/2" Drill Pipe. Laying down 5"drill collars. LD jars, Bum er Sub and Wash Down Tool. 13:30 15:00 1.50 COMPZ WELLPF OTHR P Clean rig floor. Change elevators, or anize i e shed. 15:00 15:30 0.50 8,375 COMPZ WELLPF SFTf P PJSM. 15:30 17:30 2.00 COMPZ WELLPF PULD P Dump 1 drum 776 tube down hole. MU u BHA for LEM w/MWD. 17:30 18:00 0.50 COMPZ WELLPF OTHR P Change out floor equipment. 18:00 18:30 0.50 0 266 COMPZ WELLPF TRIP P Run in with one Stand of Drill Pipe. Perform MWD shallow pulse test at 2.0 bpm/130 - 200 PSI. Pump #1 @ 42 s m. Pum #2 34 s m. 18:30 23:00 4.50 266 7,171 COMPZ WELLPF TRIP P Trip in with BHA for LEM with MWD and 3 1/2" Drill Pipe from Derrick. Running speed = 90 seconds per stand. Weight check at 23:00 hrs: Up weight = 75K. Down weight = 60K. 23:00 00:00 1.00 7,171 8,375 COMPZ WELLPF TRIP T Continue run in hole. Attempted weight check at Midnight. Down weight = 55k. However, when attempting to get the up weight, saw a bobble just as full string weight was reached at -85K. Total fluid lost to well u to this date = 3,330 bbls 1/18/2010 Discuss Options w/ town engr. Set PKR @ 8,184' and release off w/ running tool. PT 9 5/8" above PKR @ 2,500 si for 15 min. POOH LD 3 1/2" Drill Pi e. LD MWD and Baker Settin Tool. 00:00 03:30 3.50 8,184 8,184 COMPZ WELLPF TRIP T Attempt to go down hole. Set down to 35K. Packer will not move down hole. Pick back up to 125K. Packer a ears to be set °Yry one more time to go back down. Pick back up to 150K. Discuss options and plan forward with slope and Anchorage Engineering, Baker slope and - Anchorage Engineering, and Day ; Company Man. fill'tubing with 20 bbls. filflA with 70 bbls. Monitor IA Flluid level remaihs static,at surface. Page 5 of 9 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 03:30 07:00 3.50 8,184 8,184 COMPZ WELLPF PACK T Received orders to complete setting the packer per Baker setting procedures. Set packer. Pressure test IA @ 2,500 psi x 15 min. Good test. Record same on chart. Release Settin Tool 07:00 08:00 1.00 8,184 7,000 COMPZ WELLPF TRIP P POOH standing back drill pipe from 8184' to 7000'. 08:00 09:30 1.50 7,000 COMPZ WELLPF RURD P Shut down pulling pipe. Set up crane to remove used spool of cable from s ooler and re lace with news ool. 09:30 11:00 1.50 COMPZ WELLPF OTHR P Loading pipe shed with ESP equipment to warm up before running. Move pipe etc around in pipe shed to accomadate next move. 11:00 18:00 7.00 4,278 COMPZ WELLPF PULD P Continue to POOH laying down drill pipe. Lay down MWD and setting tools. RIH with remaining 3 1/2" Drill Pi a from Derrick. 18:00 18:30 0.50 COMPZ WELLPF SFTY P PJSM with Crew just rotating back to work. 18:30 23:00 4.50 4,278 0 COMPZ WELLPF PULD P Continue to single down 3 1/2" Drill Pipe in Pipe Shed. Clear Drill Pipe from Pi a Shed. 23:00 00:00 1.00 0 COMPZ RPCOM OTHR P Prep to pick up ESP equipment. Weatherford Servicehand perform checks to the A-Well I-Pum sensor. 1/19/2010 PU and MU ESP Completion equipment and RIH to 356'. RU HES and set pump and pack off, PT @ 1,000 psig, set slip stop. Continue to RIH w/ completion. Make final splice and land hanger. RILDS and test han er void 5,000 si for 10 minutes. Set BPV. 00:00 01:00 1.00 0 0 COMPZ RPCOM OTHR P Pull Wear Bushing. Clear Floor. Rig u Floor to handle 4 1/2" Tubin . 01:00 01:30 0.50 COMPZ RPCOM SFTY P PJSM. 01:30 06:00 4.50 0 0 COMPZ RPCOM PULD P Pick up and service ESP Assembly as follows: Centralizer, A-Well I-Pump Sensor, Motor, Tandem Seal Section, TTC Crossover. String ESP Cable over sheave. Attach ESP cable motor lead. Install discharge pressure capillary tubing. S of Halliburton S-Line Unit. 06:00 08:00 2.00 107 356 COMPZ RPCOM PULD P Continue with ESP Completion. Run 2 Jts of 4 1/2" Tubing, Make up 4 1/2" Unique Discharge Sub and tie in capillary tubing. Test A-Well I-Pump Sensor. Press/Temp readings good. Test ESP Cable, good. Run 2 Jts, Install GLM assembly w/Dummy Valve. Run in with Tubing from Derrick. Sto to Ri u Halliburton 08:00 08:30 0.50 COMPZ RPCOM SFTY P PJSM. Page 6 of 9 Time Lo s Date From To Dur S. De th E. De th Phase Gode Subcode T Comment 08:30 10:30 2.00 356 356 COMPZ RPCOM SLKL P Ri u Halliburton Slick Line Unit. Make up Pump Assembly with Gas Separator. RIH and set. Pick up Pack Off. RIH and set. Pressure test pack off at 1,000 psi x 15 min. Good test. Pick up Slip Stop. RIH and set. Ri down Halliburton. 10:30 19:00 8.50 356 7,475 COMPZ RPCOM RCST P i RIH with ESP Com letion to 7,475'. MU hanger and landing jt. and space out for final splice. Used 217 Cannon Clamps 3 Protectolizers Note: There were no Bands used. 19:00 21:00 2.00 7,475 7,475 COMPZ RPCOM OTHR P Centrilift Service Rep make ESP cable splice to penetrator connector. Test same. Good. 21:00 23:00 2.00 7,475 7,511 COMPZ RPCOM HOSO P Final pick up weight = 85K. Final down weight = 62K. Land Hanger. Final depth 7,511.3-ft ORKB. Visualize orientation through 4" side outlet. Run in lock down pins. Test Hanger pack off seals at 5,000 psi x 10 minutes. Good. 23:00 23:30 0.50 COMPZ RPCOM MPSP P Set BPV. Lay Landing Joint. Clear Floor. 23:30 00:00 0.50 COMPZ WHDBO SFTY P PJSM. Ready Cellar. Prep to nipple down Riser and BOP Stack. 1 /20/2010 ND BOPE. NU Tree. Test adapter seals and failed around penetrator. ND tree and inspect. Hang back tree and NU BOPE and Test @ 2,500/250 psig. Notified AOGCC @ 0700 hrs, John Crisp returned call @ 0805 hrs and and requested a full BOP Test. Pull Tubing Hanger and inspect. Land Tubing Hanger. RILDS. Test Hanger seals at 5,000 psi x 10 min. Nipple up BOPE. NU Tree. Test Tree void. Leak @ 1,500 psi. Fluid b assin Penetrator. 00:00 04:00 4.00 COMPZ WHDBO NUND P Nipple down Riser and Flow Nipple. Nipple down 13 5/8" BOP Stack. Set back on stump. Nipple down the 13 5/8" Spacer Spool. Test ESP Cable and the A-Well I-Pump Sensor. Both tests ood. 04:00 06:00 2.00 COMPZ WHDBO NUND P Nipple up Tubing Adapter Flange and Production Tree. 06:00 06:30 0.50 COMPZ WHDBO PRTS T Pressure up and attempt to test adapter -failed @ penetrator. Found hanger not properly landing -offset enough to keep penetrator and TBG seal neck out of ali nment. 06:30 07:30 1.00 COMPZ WHDBO NUND T ND Tree and Adapter. Notified AOGCC @ 0700 hrs, John Crisp returned call @ 0805 hrs and and re uested a full BOP Test. 07:30 10:30 3.00 COMPZ WHDBO NUND T NU 13 5/8 5M BOPE 10:30 17:00 6.50 COMPZ WHDBO BOPE T Test BOPE to 4 1/2" @ 2,500/250 si . Page 7 of 9 Time Lo s Date From To Dur S. De th E. De th Phase -.Code Subcode T Comment 17:00 18:30 1.50 COMPZ WHDBO BOPE T Rig down test equipment. Pull Blanking Plug. Pull Tubing Hanger to floor. Hanger pulled free at 130K and pulled to floor at 85K. Inspect Tubin Han er. 18:30 20:00 1.50 COMPZ RPCOM HOSO T Final pick up weight = 85K. Final down weight = 62K. Land Hanger. Final depth 7,511.3-ft ORKB. Visualize orientation through 4" side outlet. Run in lock down pins. Test Hanger pack off seals at 5,000 psi x 10 minutes. Good. 20:00 20:30 0.50 COMPZ WHDBO SFTY T PJSM. Ready Cellar and prep to Ni le down BOPE. 20:30 23:00 2.50 COMPZ WHDBO NUND T Nipple down Riser and Flow Nipple. Nipple down BOP Stack and set back on stump. Nipple down 13 5/8" S aver S ool. 23:00 00:00 1.00 COMPZ WHDBO NUND T ,~,_, Attempted to test Tree void. H w v r 1 500 le k was coming from outside of the Penetrator. Apply additional torque to flange bolts with Hydra-Torque wrench. Re-test Tree void. This time the leak occurred with zero ressure. 1 /21 /2010 Nipple down Tree. Inspect Penetrator and the inside of the Tubing Bonnet bore. Found a rough spot and a nicked o-ring. Corrected problem and replaced o-ring. Nipple up Tree. Tested Tree void at 5,000 psi x 10 minutes. Good Test. Test Tree at 5,000 psi. Good test. FP well. Set BPV and secure tree. Empty and clean its. Release Nordic Ri 3 1200 hrs. 00:00 03:30 3.50 COMPZ WHDBO NUND T Nipple down Tree. Inspect Penetrator. Saw a small "rolled" area on the lip of the o-ring groove. Pulled o-ring and found a small nick. Inspected the inside of the Penetrator bore in the Tubing Bonnet. Found a small rough area that matched the marks on the Penetrator and the nick in the o-ring. Dressed up the Penetrator o-ring groove and shinned up the marks with 100 grit sand paper. Also dressed off the inside of the Tubing Bonnet with same. Installed new o-ring from another Penetrator. Nip le u Tree. Tested Tree void 5 000 six 10 minutes 'o .Good test. 03:30 05:00 1.50 COMPZ WELCTt PRTS P Pull BPV. Install Test plug. Pressure test Production Tree at 5,000 si. Good test. 05:00 08:00 3.00 COMPZ RPEQPI FRZP P Spot Lil' Red Hot Oil Unit. PJSM. Pressure test line at 2,500 psi. Freeze protect Tubing with 30 bbls of Diesel and the IA with 200 bbls of Diesel. Page 8 of 9 • Time Lo s `Date From To Dur S. De th E. De th-Phase . Cotle Subcode T Comment 08:00 10:00 2.00 COMPZ RPEOPI MPSP P Monitor TBG for flow and set 4" HPBV, Secure tree. 10:00 12:00 2.00 COMPZ MOVE OTHR P Empty and clean pits, Release Nordic Ri 3 1200 hrs. Page 9 of 9 ~J-162 Pre and Post Rig Summary DATE JOBTYP SUMMARY 7/11/09 ESP /Jet Pum RIH WITH FISHING TOOLS TO PULL SLIP-STOP AND TAGGED FILL @ 7300' CTMD.RIH AGAIN WITH JSN AND CLEAN DOWN TO TOP OF SLIP-STOP @ 7427 CTMD. RIH AGAIN WITH FISHING TOOLS AFTER FCO AND MADE SEVERAL ATTEMPT TO LATCH SS WITH NO SUCCESS.FOUND MORE SAND PACK AROUND G-SPEAR.RETURN IN AM FOR ANOTHER ATTEMPT. 7/12/09 ESP /Jet Pum PULLED SLIP-STOP, PACKOFF AND INSTALL ESP IN DEPLOYMENT FLANGE. READY FOR SLICK-LINE TO REMOVE PUMP. NOTE: PUMP IS 43.5 FEET LONG.PUMPED THROUGH SOV WHILE PULLING ESP TO WASH OFF ANY SAND.MADE SURE ESP STILL MOVE FREELY @ 100' / 75' AND 50' FROM SURFACE. 7/14/09 ESP /Jet Pum PULLED 47' 3/4"-ESP FROM TREE. PULLED SOV @ 2276' RKB AND SET GLV. TESTED TBG WITH HOLEFINDER @ 2288' SLM, GOOD. COMPLETE. 8R/09 Ice Plug .Remc RAN 2" ICE PICK NOZZLE BUT DID NOT TAG UP ICE. ATTEMPTED TO INJECT IN WELL SEVERAL TIMES WHILE RIH BUT TBG PRESSURED UP. STOPPED NOZZLE JUST ABOVE MOTOR SPLINE @ 7476' CTMD WITH OUT TAGGING. SHUT THE WING VALVE. WELL TAKING FLUID NOW 1.2 BPM @ 100 PSI WHP. SUSPECT A SMALL SAND BRIDGE WAS CLEARED-POOH LEAVING WELL FREEZE PROTECTED. DSO PUT WELL ON PRODUCTION. JOB COMPLETE. 10/27/09 Slickline Misc. GAUGE 3.855" TO 2250' SLM, THICK FLUID, IN PROGRESS. 10/28/09 Slickline Misc. DRIFT 2.72" CENT TO 2598' SLM. DRIFT 2.67" G-RING TO 4739' SLM. COMPLETE. 12/3/09 Ann-Comm PRE RWO T-POT (PASSED ), T-PPPOT (FAILED ), UT-POT (PASSED ), UT- PPPOT (PASSED ), LT-POT (PASSED ), LT-PPPOT (PASSED ), IC-POT FAILED ), IC- PPPOT (FAILED ), FT-LDS ALL NORMAL. 1/3/10 Ann-Comm IC POT -FAILED. IC PPPOT -FAILED. 1/3/10 Drilling Suppor MEASURED SBHP (714 PSI )@ 7210' SLM, GRADIENT STOPS (634 PSI )@ 6010' SLM & (625 PSI) @ 5910' SLM. COMPLETE 1/19/10 Drilling Suppor NORDIC RIG JOB.SET 4 1/2" ESP OAL=37.42'.SET PACKOFF ASSY OAL=8.39' WITH CHECK AND KOBE K.O.TESTED TO 1000#.SET TBG STOP ON PACKOFF 1/23/10 Drilling Suppor SET SLIP STOP CATCHER. SET 2000# TBG> TEST. PULL CATCHER. JOB COMPLETE ~,osr ~`~ 1 b 5~.~ DATA SUBMITTAL COMPLIANCE REPORT , 7/20/2009 Permit to Drill 2070800 Well Name/No. KUPARUK RIV U WSAK 1J-162 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23360-00-00 MD 14490 ND 3218 Completion Date 8/16/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION ~/~~/ Mud Log No Samples No Directional Survey es DATA INFORMATI~N Types Electric or Other Logs Run: GR / RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / iy e meairrmt rvumoer Name aca~e mea~a no ~rar[ stop ~n rcece~vea ~ommenrs D D Asc Directional Survey 0 14490 Open 9/12/2007 D D Asc Directional Survey 0 7947 Open 9/12/2007 PB 1 D D Asc Directional Survey 0 11035 Open 9/12/2007 PB 2 :I'ED C Lis 15666 ~Induction/Resistivity 3785 14490 Open 11/12/2007 LIS Veri, GR, RPS, FET, ROP pt 15666' LIS Verification 3785 14490 Open 11/12/2007 LIS Veri, GR, RPS, FET, ROP D C Lis 15667/Induction/Resistivity 3785 11035 Open 11/12/2007 P62 LIS Veri, GR, RPS, FET, ROP pt 15667 LIS Verification 3785 11035 Open 11/12/2007 P62 LIS Veri, GR, RPS, FET, ROP ~ ~ ~ ~ `~ D C ~ s ~ "~ = See-Id+otes ~,,, ~.~ .~ =~ .~. 18050 0 0 Open 5/21/2009 EWR Logs + P61 logs, in EMF, CGM and PDS graphics ~ Log Induction/Resistivity 25 Col 120 3218 Open 5/21/2009 ND DGR, EWR ~ Log Induction/Resistivity 25 Col 120 14490 Open 5/21/2009 MD DGR, EWR Log / Induction/Resistivity 25 Col 120 3249 Open 5/21/2009 P61 ND DGR, EWR Log~, Induction/Resistivity 25 Col 120 11035 Open 5/21/2009 P61 MD DGR, EWR Well Cores/Samples Information: ~ ~ Sample Interval Set Name StaR Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 7/20I2009 Permit to Drill 2070800 Well Name/No. KUPARUK RIV U WSAK 1J-162 Operator CONOCOPHILLIPS ALASKA INC MD 14490 ND 3218 Completion Date 8/16/2007 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-23360-00-00 UIC N ADDITIONAL INFORMATION Well Cored? YQ- Daily History Received? ~~ N Chips Received? -~-/-PI~ Formation Tops ~%N Analysis aU-Id~ Received? Comments: Compliance Reviewed By: Date: ~ ~ ~ ~ . ~ # ,~ ~~~~~~~~~ ~ STATE OF ALASKA ~~~~ ~ ~ ~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ,~~~~~~ ~e; ~~ ~~~ ~ F ~~/~~t~~~Po~;F6~ REPORT OF SUNDRY WELL OPERATIONS ~~,,,~; ,.~,~~,, 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate ^ Other Q ^ ESP to Gaslift Alter Casing ^ Pull Tubing ^ Pertorate New Pool ~ Waiver ^ Time Extension Change Approved Program ^ Operat. Shutdown^ Pertorate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConoCOPhlllips Alaska, InC. Development ~' Exploratory ^ 207-080 • 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23360-00 • 7. KB Elevation (ft): 9. Well Name and Number: RKB 122' • 1J-162 . 8. Property Designation: ~ 10. Field/Pool(s): ALK 25661, 25660, 25663 Kuparuk River Unit / West Sak Oil Pool ` 11. Present Well Condition Summary: Total Depth measured 14490' ~ feet true vertical 3218' , feet Plugs (measured) Effective Depth measured 14480 . feet Junk (measured) true vertical 3218 , feet Casing Length Size MD ND Burst Collapse CONDUCTOR 79' 20" 120 120' SURFACE 3777' 13-3/8" 3820 2208' iNTERMEDIATE 10360' 10-3/4" x 9-5/8" 10400 3245' B SAND LINER 4426' 5-1/2" 14480 3219' D SAND LINER 4292' 4-1/2" 14477 3144' Perforation depth: Measured depth: 10393 - 10480; 10784 - 13403; 13621 - 14391 true vertical depth: 3244 - 3252; 3259 - 3241; 3238 - 3220 Tubing (size, grade, and measured depth) 4-1/2", L-80, 7512 MD. Packers & SSSV (type & measured depth) SSSV = NONE PACKER = C-2 B-SAND LINER TOP PKR, D-SAND SBR 10043', 10195' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 431 129 34 199 201 Subsequent to operation 285 12 12 397 227 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ~, Service ^ Daily Report of Well Operations X 16. Well Status after proposed work: Oil^~ " Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt N/A Contact B. Christensen/ D. Humphrey Printed Name ber . Ch ' nsen Title Production Engineering Specialist - Phone:659-7535 Date Signature ~ ~ ~ ~~ ~ ~ ~~ i~~~ ~ ~ ~t~~~ N~' ~C ~ ~~ /~ ~~ Form 10-404 Revised 04/2004 ~- ~~~ 5ubmit Origin~lz~tfl~'~y~~~, ~ ~ 1 J-162 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/14/09 07/12/09 07/11/09 PULLED 47' 3/4" ESP FROM TREE. PULLED SOV @ 2276' RKB AND SET GLV. TESTED TBG WITH HOLEFINDER @ 2288' SLM, GOOD. COMPLETE. PULLED SLIP-STOP, PACKOFF AND INSTALL ESP IN DEPLOYMENT FLANGE. READY FOR SLICK-LINE TO REMOVE PUMP. NOTE: PUMP IS 43.5 FEET LONG.PUMPED THROUGH SOV WHILE PULLING ESP TO WASH OFF ANY SAND.MADE SURE ESP STILL MOVE FREELY @ 100' / 75' AND 50' FROM SURFACE. ' , RIH WITH FISHING TOOLS TO PULL SLIP-STOP AND TAGGED FILL @ 7300' CTMD.RIH 'AGAIN WITH JSN AND CLEAN DOWN TO TOP OF SLIP-STOP @ 7427' CTMD. RIH AGAIN WITH FISHING TOOLS AFTER FCO AND MADE SEVERAL ATTEMPT TO LATCH SS WITH NO SUCCESS.FOUND MORE SAND PACK AROUND G-SPEAR.RETURN IN AM FOR ANOTHER ATTEMPT. ~ . . • KUP ~ 1J-162 -~ ConoCOPhilllps ~ Well Attributes Max An le & MD r~ /ll.i5k,f, I~ i WeIlDora API/UWI Fieltl Nama Well Status Incl ~°) MO (ftN9) Mt etm (ffKB) 500292336000 WESTSAK PROD 93.46 13,634.05 14,490.0 WMIConR.-1J-7 IH520091.02:/6PM SSSV:NONE 0 12/262007 LastWO: 43.81 8/16/2( ~6c- I ~notatlon DapM (fINO) Entl Oab Mnotation La~t Mod ey Entl Date Last Tag: Rev Reason: PULL PUMP, G W C/O Imosbor 7/15/2( Casin Strin s C~~Inp ~escripHon Strinp 0... Strlnp 10 ... Top (ItKB) Sat Dept~ (1... Set Dept~ (TVO) ... String WL.. String ... 541ng Top T CONDUCTOR 20 19.124 41.5 120.0 120.0 94.00 WELDE HANGER, 36 Insulated Ca~ing Daacrlptlon String 0... Strlnp ID ... Top ~Po(B) Set DepM ~f... Set Dept~ (TVD) ... Slring Wt... Strlnp ... String Top T SURFACE 133/8 12.415 43.1 3,820.3 2,207.7 68.00 L-80 BTC ~ ; Casin De~cri tlon 9 P Strin 0... 8 Strln ID ... 9 To ttK8 P I I Set Da th f... P ( Sat De th TVD P ( 1... Siring Wt... S[rlnp ... String ToP T INTERMEDIATE 95/8 8.835 40.3 10,399.5 3,245.0 40.00 L-80 BTCA 10.75 x 9.625 Caeing Dascrlption String 0... String ID ... Top ((tNB) Set Depth (1... Sat Dapt~ (TVD) ... String Wt... Strinp ... String Top T B-SAND LINER 51/2 4.950 10,054.3 14,480.0 3,218.5 15.50 L-80 BTC Liner Details rov oepm (TVDI Top Inel Top (ItKB) (ttNe) (°) IOem Oe~crlption Comment coNOUCroe 10,054.3 3,197.4 81.97 PACKER MLZXPLinerTopPacker9-5/8"(7.50"X8.37') i~s~i.~ee, 92-120 10,075.5 3,200.2 8221 HANGER FlexLOCk Liner Hanger 7" x 9-5/8" (6.09" X 8.30") EsP ...................,,...... .......„,,... ...~.~,y~..... ,,.r~~,..,.~ ~o.voM.~~i,...,,a...oN.~~~~.v~... u.~~~~ar.._. ~.~~~~y... ~.~~„e~,.N~~ TUBING 41/2 3.958 35.6 7,512.4 2,808.4 12.60 L-80 IBT-M M/W~REL. 2 276 COIII le tion De tails . Top Oept~ (T~O~ Top Incl ~ Top (ltNB) (RKB~ (°) Itrm Descrlptlon Comment II 35.6 35.6 -0.04 HANGER Vetco Gray 11 "x 4-1/2" Hgr w/ 4.909" MCA Top Conn. 7,373.1 2,788.0 81.43 DISCHARGE Unique Discharge Sub 7,450.1 2,799.4 81.94 INTAKE Perforated Xwer Intake TTC ESPCP (5.13" OD) SURFACE, 7,460.7 2,800.8 81.84 SEAL Upper Tandem Seal GSB30B FER HL H6 SSCV SB/SB PFSA ~3 ~ 7,467.6 2,801.8 81.77 SEAL Laver Tandem S~I GSB3DB FER HL H6 SSCV SB/SB PFSA 7,474.5 2,802.8 81.71 MOTOR Motor 418 HP KMH (2610 v/ 9S amp) (5.62" O.D.) 7,508.4 2,807.8 81.38 SENSOR A-Well I-Pump Sensor (4.50" OD) oiscnnace, 7,373 7,510.5 2,808.1 81.36 CENTRALIZER MotorCentralizer(5.85"O.D.) Other In Hole Wireline retrievable lu s, valves um s flsh, etc. Top Oept~ ~TVO) Top Incl Top (ftl(9) (RKB) ~°) pa~criptlon Comment Run Oate II iNTacE. ~,aso - SEAL, 14fi1 10,043 3,195.8 81.84 PACKER C-2 B-SAND LINER TOP PACKER 8/16/2008 sE^~. ~,^se 10,059 3,198.0 82.02 COLLAR &SAND LINER NO GO COLLAR &16Y2008 MOTOR, ] 070 seNSOR. 10,060 3,1952 82.03 TIE BACK BSAND LINER TIE BACK SEAL ASSEMBLY 8/16/2008 ~ sae CENTRALIZER, ] 510 SEAL . PACKER ,o,oe3 PerForations 8 Slots co~~uz. ~ sno~ ~~~'9 TIE 9AGK ~ 7op~7VD) Btm~TVD) Dane SEAL, 10 oso Top ~Po(B) 8hn (RNB) (RKB) (RNB) Zona Data (~h~~~ Type Comment o~snrvo nooK 10,393 10,480 3,244.2 3,251.7 WS 8, 1J-162 7/23/2007 32.0 Slots Altemating solid/slotted pipe 2.5" MANGER. s,sas-io.rzs .125" in 4 circumfe2ntlal rows/R 10,784 12,497 3,259.3 3,229.2 WS B, 1J-162 7Q3I2007 32.0 Slots Altemating solid/slotted pipe 2.5" .125" in 4 circumferentlal rows/R 12,497 13,403 3,229.2 3,241.1 WS B, 1J-162 7123/2007 32.0 Slots Altemating solid/siotted pipe 2.5" .125" in 4 circumferentlal rowslk 13,621 14,391 3,237.7 3,220.0 WS B, 1J-162 7Y23/2007 32.0 Slots Alternating solid/slotted pipe 2.5" .725" in 4 circumferential rowsHt Is~~ ITOp (RI(B) I ~ B) I'~ ~ I M~ka I MoGel I(~) I Serv I Type I 7ype I ~~~~ ITR~Run I Run Date I Com... I 70,393-10,680 ~ ~ Sbb, f 0, 78412,997 Sbb, 12.197.13.~03 Sbb. 13.621-i<,~7 B-SAND LINER, 10.050-10,98~ ~ TD (1 J-162). 1l.09p 1J-162 (207-080) Report of failed ESP ~ Page 1 of 1 ~ ll~aunder, Thomas ~ (DQA) From: Maunder, Thomas E (~OA) Sent: 11Aonday, July 43, 2f}E~9 1:21 RM TQ; 'AISK Probism Well Supv'; F~~gg, James B(DOA) Cc: Schwartz, Guy L(~QA); NSK RrQd Engr Speeialist Subject: R~: 1J~162 (247-q80) F~~port vf failed ESP ~res~~, ~i ~~ s~b~i~ th~ ~t~ ~~~~~ting ~~ ~h~~g~ i~ l~~t ~thtad: ~om AA~und~r, ~~ ~~~~ From; NSK Problem W~li Supv [maitkc~;n~,fiZ?C~?eonacophill~ps.com] S~ttt; Tu~d~Y. .~~iy ~17, 2~!9 $:26 Af+~ To: Maunder, T#~omas E(Dt3~A); Re9g, James B(DOA) Gc: Schwartz, Guy L(aQA); NSK Problem 1t~ell Supv; NSK Prod Engr ~peciatist SuMb~ect: 13~162 (207-Q8f?} Report of f~ited ESP Torn, The electric ~ubmersible pump (ESP) ir~ the 1J-162 well (PT~-~47~0€~4) fail~d c~r~ 47lU4fQ9 du~ ta an els~trical short downhc~le. This ~vell was completed in August of 2007 and c~c~s nc~t mention ga~fifik as a conti~g~ney in the Permit To Drill. CPA! r~quests permission t~ convert 1 J-162 to ~aslift until a workaver to replace ~he pump and mfltpr can be performed. if approved, pisase confirm that a 10-~Q4 afker v~ork is completed is suff~~i~nt. Brent Roger~tM~rtir~ Walters Prc~btern Wells Supervis4r ~on~cQPhiitips Alaska, Inc. De~k F'hone (907) 659-722~1 Rager (~07) 659-~OQQ pgr. 9Q9 7/~ 3/2009 ~ ~ ~ ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-162+L1+L1PB1+pB2 May 18, 2009 AK-MW-5034902 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling, Arctic Blvd., Anchorage, AK 99518 1J-162+L1+L1PB1+pB2 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 5 0-029-23 3 60-00, 60, 71, 72 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23360-00,60,71,72 Digital Log Images 3 CD Rom 50-029-23360-00,60,71,72 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 B i on.com BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ ~, . Date: MAY ~ ~ ~o~g signed: ~: ~ ~~! ~ ~°~~~ c~r~r~o~sQ~~ ~c~-a ~~~ ~ ~o'~ ~o ~~os b ~o~-~~~ ~g~~ ~~ ~-~~~ ~~~a e ~ ~ ~ • • ConoeaPh~llips Alaska P.O, BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 27, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 995Q1 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Cement was pumped October 30, 2008 and the corrosion inhibitor/sealant was pumped November 7 and Novemberl7, ~008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Projects Supervisor ,.~ ~ ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field n~+e Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft a~ 1F-18A 204-167 15' S" 2.50 44" 10/30/2008 27.2 11/7/2008 1 E-7 68 204-200 15" NA 15" NA 3.4 11 /7/2008 1E-17 205-074 13" NA 13" NA 5.53 19/7/2008 1J-12~ 207-070 15" NA 15" NA 3.4 11/7/2008 1 J-14 200-200 16" NA 16" NA 1.27 11 /7/200$ 1J-152' 206-016 3' NA 3' NA 19.55 11/17/2008 1 J-158 207-054 6' NA 6' NA 27.2 11 /7/2008 1J-162 2 7-080 15" NA 15" NA 2.55 14/7/200$ 1J-166 205-198 12" NA 12" NA 8.5 11/7/2008 1J-168 205-060 10" NA 10" NA 3.82 11/7/2008 1J-170 206-062 8" NA 8" NA 1 11/7/2008 1J-174 207-143 24" NA 24" NA 17 11/7/2008 1J-178 207-121 12" NA 12" NA 5.95 11/7/2008 ~ ~ ~r • Ct~noCt~Ph ~ I I t p5 May 13, 2008 T. Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, Alaska 99501 Subject: Additional Well Summaries Dear Mr. Maunder: ~ J. Eggemeyer Engineering Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6049 ~ ~ ~ 0 ~ ~~ o C7 `~ ~ ~ ~ ~ c~ 0 ~ 3 4 ~ 1r~~~vc~~~ ~ +~~~ ~ ~ ~ ~ ~j'~ ~ ~ ~ ~ ~ ~ ~-. o ~ 0 m ConocoPhillips Alaska, Inc. submits the attached well summaries for wells 1A-01, CD4-07, 1 J-122, 1 J-122L1, 1 J-122L2, CD4-322, 1 J-162, 1 J-162L1 you requested. These summaries will replace the shorter summaries a ready submitted with the completion reports for these wells. If you have any questions regarding this matter, pfease contact me at 265-6049. Sincerely, ~ / . Eggemeyer Engineering Team Leader CPAI Drilling J E/skad u Maunder, Thomas E (DOA) ~ Page 1 of 1 From: Eggemeyer, Jerome C. [Jerome.C.Eggemeyer@conocophillips.com] Sent: Wednesday, January 30, 2008 8:13 AM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Subject: RE: Operations Reports thanks tom. I am sure we can accommodate. jce From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, January 30, 2008 8:07 AM To: Eggemeyer, Jerome C. Cc: Allsup-Drake, Sharon K Subject: RE: Operations Reports Thanks Jerome. These aren't urgently needed. Only other request, is send the reports "single sided". When we get double-sided, we have to shoot additional copies in order to scan. Tom From: Eggemeyer, Jerome C. [mailto:Jerome.C.Eggemeyer@conocophillips.com] Sent: Tuesday, January 29, 2008 10:36 PM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Subject: RE: Operations Reports thanks tom. As soon as Sharon is able to organize the data it will be sent over (hopefully only a few days depending on other activities). Let us know if it is needed more urgently. jce From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, January 29, 2008 4:38 PM To: Eggemeyer, ]erome C. Cc: Allsup-Drake, Sharon K Subject: Operations Reports Jerome and Sharon, Thanks for sending the more detailed operations reports. I have further reviewed the Commission's files regarding 407's submitted since about August and found that more complete reports are needed for a few other wells. The wells are: 1 J-162, -162L1 207-080, 207-181 ~ hC'~~ ~ ~~ ~ ~ ~~ ~ CD4-322 ~bT~~" 1 J-122, -122L1, -122L2 207-070, 207-071, 207-072 For the multilateral wells, a complete summary is only needed for the main wellbore with only the specific operations needed for the laterals. Your assistance in making the well records complete is appreciated. I will be reviewing the recently submitted sundry reports shortly and will send another message if necessary. Call or message with any questions. Tom Maunder, PE ~~ AOGCC ~~ ~ ~ ~~ 8/18/2009 ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`h Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-162 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23360-00 ~ October 15, 2007 AK-MW-5034902 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURI~ING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~~~~~~~~~a ~~..~~~, , ~,1~`~,' ; °? '~JL i Date. r~= ~~E' ~~s v~ ~ t.,. ~~r~ ~:-~ ~ - . I r~ ~ / Signed ~ ~' _~.,., ~- c7U~ - ~8 ~~ I 5(~.~(~4~ ~ ~ WELL LOG TRANSMITTAL To: State of Alaska October 15, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-162 PB2 AK-MW-5034902 1 LDWG formatted CD Rom with verification listing. API# : 5 0-029-2 3 3 60-71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 %'- ~ " 1 ' ~~ i.~ r °~, ~ ~~=~ ~ .~:~ ~ ~:-~ . , v... . ,. + ~!J ~` _2 j Date: , , .:~~': __..r. , i Signed: ~ ~~~~~ ~a~--o~ Message ~ ~ Page 1 of 2 Maunder, Thomas E (DOA} From: Eggemeyer, Jerome C. {Jerome.C.Eggemeyer@conocophillips.com) Sent: Friday, October 12, 2007 12:05 PM To: Maunder, Thomas E (DOA) Cc: Reilly, Patrick J Subject: RE: 1J-162 (207-080) and 1J-162L1 {207-081) Tom, I just sent a notice to the rigs requesting that they increase the information in the 24 hour summary such that an experienced drilling person should be able to understand what was accomplished, what went wrong and also get reasonable evidence of compliance with basic regulations. I am hoping we can find a good middle ground on the level of detail without ending up with a re-write of the hourly activity. Thanks for the dialogue, pat is out today but he will be available monday and can answer other questions if this does not cover it. Regarding diverter NU and BOP testing, window depth and OH sidetrack questions, following is information from the daily activity report: 7/5/07 0800 Nipple down 20" diverter stack. Flush annular. 7/6/07 0615 Test BOPE. Witness of test waived by AOGCC inspector John Crisp. Test annular w/ 5", Test upper variable rams( 3-1/2"x 6") w/ 5" and 5-1/2". Test lower pipe rams w/ 9-5/8" test joint. Testing all componets to 250 psi low and 3000 psi high. Koomey test: 200 psi build up in 25 seconds, full pressure 3 min 20 sec. Nitrogen BU 2300 psi avg. Vatve # 3 in choke manifold leaked, greased and retested OK. 7/19/07 0930 Flush OA with 105 BBLs of water with rig pumps, final circulating pressure = 2 BPM - 200 PSI. Initial injectivity test indicated a 10.7 PPG EMW. Continue dress mud pump with 6" liners. Continue clean mud pits. 7/26/07 0900 Mill window from 9954' - 9972'. Pumps at 450 GPM's - 1750 PSI. TQ on - 12K. WOB = 2-5K. Sweep hole at bottom of slide. Average mill speed through casing = 6.15 ft/hr. TOW = 9954', BOW = 9970'. 7/28/07 1100 PerForm OH sidetrack troughing from 10000' - 10035' MD. Thanks, Jerome °---Origina{ Message----- From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov} Ser~t: Friday, October 12, 2007 9:34 AM To: Eggemeyer, Jerome C.; Reitty, Patrick J Subject: 1J-162 (207-080) and 1J-162L1 (207-081) 10/12/2007 Message ~ . Page 2 of 2 Jerome and Pat, I am reviewing the campletion repo~t for the subject welL I am aware that the nar~ative summary of the drilling operat~ons has been changed and Jerome has asked me i~ the information now presented is sufficient. It is difficult to make a generat statement regarding tFte sufFciency ather than when some specific work item is accomplished, +t is probably appropriate to include sorr~ detail. Test BOP, test casing and test tubing seem to be incompfete when at least a pressure value and maybe a time are not included. In the case af these weits, the na~rative does have not provide sufficient informati~n on severat items as noted below. 1. There is no mention of NU diverter or testing it 2. All that is mentioned about the initial BOP test is "NU 13-5/8° BOP staclc_ For either the diverter or initiat BOP test, there is no mention if an tnspector was present ar if witness was waived. Such infarmatian is inctuded iR regarciing the test on 8l1. !t rrtay be appropriate to inctude the test pressures. 3. On 7-20, it is stated that the OA was flushed with water. Shot~td th~s refer ta the fA and what pr~ssures or EMW was determined? 4. I cannot easily tell where the window was cut. The depth of a windaw is an item that shoukd be include in the narrative. A comment an 7/31 may indicate that the top af #he window is at 9954. 5. Pat and ! exchanged a message on August 1 regarding a sidetrack that c~ccurred on 7/28. It appears t~at prob~ms were ~ncauntered with ~e initiat section af 4J-162L1. Ac~ording to the message 10035 -10524 was "abandaned" ta coflapse. ft is very dififtculfi to discern that an OH sidetrack oceurred fiom the narratives af 7/27 - 7/28. Look forward to your reply. Cali or message with any quesfions. Tom Maunder, PE AOGCC 10/12/2007 ~ ~ Ilr N ~t~~nc~c~Ph ~ ~ I ~ pS October 2, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1J-162 and 1J-162L1 Dear Commissioner: ~ Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ~~~~~~~~ :~;f:~~ ~~ ~ Z~i~ ` ~laJk~ ~i~~ ~~ C~~ r;~~n~. Cw~r~~mis~~~~~ ~ ,~ a ,tk ~~.~~.E ~~ ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak multi-lateral 1J-162 and 1J- 162L1. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, -.._.._ \ ., P... ,..~~~'~~ m..,„-.,~r y~.~«..~~ \ \ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad --- "~~~ ~` `"~` ~ ~ : ~ ~~ ~: ~~ ~ ~ ~ ~D//~~ ~ ° ~ ~ _,~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 4, ~ ~'{r;,`) ' ~~.. a, WELL COMPLETION OR RECOMPLETION REPOR~3~I~C~ ~:Qt~=~ ~~ ~=~-~s~rrr~~~ 1a. Well Status: Oil ~ Gas Plugged Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: .,,, ;,, ~~ ; Development Q Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., ~~ oraband.: August 16, 2007 12. Permit to Drill Number: 207-080 /' 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: June 30, 2007 13. API Number: 50-029-23360-00 - 4a. Location of Well (Governmental Section): _ , , ~ Surface: 1958' FSL, 2527' FEL, Sec. 35, T11 N, R10E, UM 7. Date TD Reached: July 22, 2007 14. Well Name and Number: 1J-162 _ Top of Productive Horizon: 261' FSL, 32' FVVL, Sec. 34, T11 N, R10E, UM 8. KB (ft above MSL): 41' RKB Ground (ft MSL): 121.8' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 1414' FSL, 61' FWL, Sec. 3, T10N, R10E, UM 9. Plug Back Depth (MD + ND): ! 14480' MD / 3218' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558683 y- 5945769 Zone- 4 10. Total Depth (MD + ND): 14490' MD / 3218' ND 16. Property Designation: ~ i ALK 25661, 25660, 25663 TPI: x- 550697 y- 5944014 Zone- 4 Total Depth: x- 550764 - 5939888 Zone- 4 11. SSSV Depth (MD + ND): none 17. Land Use Permit: 471, 470, 472 ' 18. Directional Survey: Yes Q No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL} 20. Thickness of Permafrost (TVD): 2194' TVD ~ 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): ~~ ~ w~ ~ ~~r~~~~~~~ ~A~ GR/RES ~ F+v `~ 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD pULLED 20" x 34" 78.6# H-40 41' 120' 41' 120' 42" 36o sx AS 1 13.375" 68# L-80 41' 3820' 41' 2201' 16" 843 sx AS Lite, 223 sx DeepCRETE 10.75" x 9-5/8" 73# / 40# L-80 41' 1536' / 10400' 41' 3245' 12.25" 735 sx Class G 5.5" 15.5# L-80 10076' 14480' 3200' 3218' 8.5" slotted liner 23. Open to production or injection? Yes No ~ If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 7440' 10043' & 10054', 10078' slotted liner from 14480'-14391', 13620'-13402', 10783'-10479', 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10393'-10107' MD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERiAL USED na 26. PRODUCTION TEST Date First Production waiting on facility hook-up Method of Operation (Flowing, gas lift, etc.) ESP oil - shares production with 1 J-162L1 Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIo Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes No Q Sidewall Cores Acquired? Yes ~ No Q If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical resu(ts per 20 AAC 25.071. t- cn~~«rra~ ~ ~ ~~~ NONE Form 10-407 Revised 2/2007 R~ G ~~ A L CONTINUED ON REVERSE SIDE ~~~,~ 0 ~ + 28. GEOLOGIC MARKERS (List all formations and mark rs encountered): 29. FORMATION TESTS NAME MD ND Well tested? Yes ~ No If yes, list intervals and formations tested, PermBfrOSt - TOp g~ound surface gr0ultd SurfBCe briefly summarizing test results. Attach separate sheets to this form, if PermBfrOSt - BOttOm 3750' 2194' needed, and submit detailed test information per 20 AAC 25.071. T-3 3750' 2194' K15 3750' 2194' Ugnu C 6760' 2693' Ugnu B 7796' 2852' Ugnu A 8330' 2935' K13 8969' 3031' West Sak D 9890' 3174' West Sak C 10730' 3260' West Sak B 10358' 3240' West Sak A4 14490' 3218' West Sak A3 14490' 3218' N/A West Sak A2 14490' 3218' 1J-162P61 TD 7947' 2994' 1 J-162PB2 TD 11035' 3250' Formation at total depth: West Sak B 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, cement detail sheets, slotted liner detail sheets 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ContaCt: Pat Reilly @ 265-6048 Printed Name„_ Randv Thomas ritie: Drillina Team Leader ~„ . ~> ,~.~ Signature ~- •~~ one Z ~ ~ ~ ~ ~ ~_ Date ~ C ~ ~ ~~ ~ INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 weli completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground levei elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ~ ~ Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 8/27/2007 Tiate: 09:38:50 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1 J-162; True North Site: Kuparuk 1J Pad Vertical,(TVD)Reference: 1J-162: 122:0 Well: 1J-162 Section {VS) Reference: Welf (O.OON,O:OOE,180:OOAzi) Wellpath: 1J-162 Survey Calculatio n Methodc Minimurn Cuwature Db: Orade Field: Kuparuk River Unit North Slope Alaska ~ United States I Map System:US State Plane Coordinate Syste m 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: '69Vell Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 j Well: 1J-162 SlatName: ~ API50-029-23360-00 ~ Well Position: +N/-S -149.19 ft Northing: 594576 9.63 ft Latitude: 70 75 44.790 N ~ +E/-W -107.98 ft Easti ng : 55868 3.15 ft Longitude: 149 31 32.149 W i I Position Uncertainty: 0.00 ft I Wellpath: 1 J-162 Drilled From: 1 J-162PB2 API 50-029-23360-00 Tie-on Depth: 10497.30 ft C'urrent Datum: 1 J-162: Height 122.00 ft Above System Datum: 16iFean Sea Level Magnetic Data: 6/26/2007 Declination: 23.30 deg Field Strength: 57613 nT Mag Dip Angl e: 80.79 deg Vertical Section: Depth From (TVD) +N/-S +E/-W IDirection I ft ft ft deg 41.00 0.00 0.00 1$L9.00 Survey Program for Definitive Wellpath Date: 7/22/2007 Validated: Yes Versioa: 4 Actual From To Survey Toolcade Tool P7ame ft ft 100.00 651.00 1J-162P6 1 Gyro (100.00-651.00) CB-GYRO-SS Camera based gyro sin gle shot 713.37 3805.42 1J-162P6 1 IIFR+MS+Sag (713.37- MWD+IfR-AK-CAZ-SC MWD'+IFR AK CAZ SC C 3820.00 10497.30 1J-162P62 IIFR+MS+Sag (3820.00 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 10550.00 14461.76 1J-162 IIF R+MS+Sag (10550.00-1 MWD+IFR-AK-CAZ-SC MWD~IFR AK CAZ SC C Survey MD Incl Azim TVD Sys TVD N/S F1W MapN MapE Tool ft deg deg ft ft ft ft ft ft 41.00 0.00 0.00 41.00 -81.00 0.00 0.00 5945769.63 558683.15 TIE LINE 100.00 0.45 234.36 100.00 -22.00 -0.14 -0.19 5945769.49 558682.96 CB-GYRO-SS 149.00 0.51 214.60 149.00 27.00 -0.43 -0.47 5945769.20 558682.68 CB-GYRO-SS 200.00 0.30 227.66 200.00 78.00 -0.70 -0.70 5945768.92 558682.46 CB-GYRO-SS 273.00 1.65 260.52 272.98 150.98 -1.01 -1.87 5945768.61 558681.28 CB-GYRO-SS 367.00 4.51 269.00 366.54 244.84 -1.29 -6.91 5945768.28 558676.26 CB-GYRO-SS 461.00 8.00 273.66 460.27 338.27 -0.94 -17.13 5945768.56 558666.03 CB-GYRO-SS 556.00 10.87 274.86 553.97 431.97 0.24 -32.66 5945769.62 558650.50 CB-GYRO-SS 651.00 13.23 278.48 646.87 524.87 2.60 -52.34 5945771.83 558630.80 CB-GYRO-SS 713.37 15.42 274.60 707.30 585.30 4.32 -67.66 5945773.42 558615.46 MWD+IFR-AK-CAZ-SC 780.65 17.90 271.82 771.75 649.75 5.37 -86.92 5945774.32 558596.20 MWD+IFR-AK-CAZ-SC 875.53 19.09 274.68 561.73 739.73 7.10 -116.96 5945775.81 558566.15 MWD+IFR-AK-CAZ-SC 971.53 23.62 270.59 951.12 829.12 8.58 -151.85 5945777.02 558531.25 MWD+IFR-AK-CAZ-SC 1065.93 27.76 267.98 1036.18 914.18 8.00 -192.75 5945776.12 558490.36 MWD+IFR-AK-CAZ-SC 1162.64 30.48 267.25 1120.65 998.65 6.02 -239.77 5945773.79 558443.36 MWD+IFR-AK-CAZ-SC 1256.73 35.19 267.65 1199.69 1077.69 3.77 -290.72 5945771.13 558392.43 MWD+IFR-AK-CAZ-SC 1351.53 36.44 269.48 1276.57 1154.57 2.39 -346.17 5945769.32 558337.00 MWD+IFR-AK-CAZ-SC 1446.88 38.52 270.63 1352.23 1230.23 2.46 -404.19 5945768.94 558278.99 MWD+IFR-AK-CAZ-SC 1542.11 41.52 271.90 1425.15 1303.15 3.83 -485.40 5945769.84 558217.78 MWD+IFR-AK-CAZ-SC 163724 46.26 271.68 1493.69 1371.69 5.89 -531.30 5945771.38 558151.87 MWD+IFR-AK-CAZ-SC I 1732.33 49.51 271.47 1557.45 1435.45 7.82 -601.80 5945772.76 558081.36 MWD+IFR-AK-CAZ-SC 1827.63 54.06 271.76 1616.39 1494.39 9.94 -676.63 5945774.29 558006.53 MWD+IFR-AK-CAZ-SC 1920.91 57.06 272.59 1669.14 1547.14 12.87 -753.49 5945776.62 557929.65 MWD+IFR-AK-CAZ-SC 2015.25 59.56 272.77 1718.69 1596.69 16.62 -833.67 5945779.75 557849.45 MWD+IFR-AK-CAZ-SC 2113.84 62.11 271.22 1766.74 1644.74 19.60 -919.70 5945782.07 557763.41 MWD+IFR-AK-CAZ-SC 2207.83 64.87 271.31 1808.68 1686.68 21.46 -1003.78 5945783.27 557679.33 MWD+IFR-AK-CAZ-SC 2303.12 68.09 271.35 184671 1724.71 23.49 -1091.12 5945784.61 557591.99 MWD+IFR-AK-CAZ-SC ~ Halliburton Company Survey Report ~ Company: ConocoPhillips Alaska InC. , Date: 8/27/2007 Time: 09:38:50 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-162, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-162: 422A WeR: 1J-162 Section (VS) Reference: Well (O:OON,O: OOE,180.OOAzi) Wellpath: 1J-162 Survey Calculation Method: Minimum CuNature Db: Oracle Survey ~ MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool' ft deg deg ft ft ft ft ft ft ~ 2397.67 72.20 270.13 1878.81 1756.81 24.63 -1180.02 5945785.06 557503.09 MWD+IFR-AK-CAZ-SC 2492.72 74.15 269.25 1906.32 1784.32 24.13 -1270.99 5945783.85 557412.13 MWD+IFR-AK-CAZ-SC 2588.87 75.34 270.26 1931.62 1809.62 23.74 -1363.75 5945782.74 557319.38 MWD+IFR-AK-CAZ-SC 2683.19 76.39 271.85 1954.66 1832.66 25.42 -1455.20 5945783.71 557227.94 MWD+IFR-AK-CAZ-SC 2778.52 75.54 271.47 1977.78 1855.78 28.10 -1547.64 5945785.67 557135.49 MWD+IFR-AK-CAZ-SC 2872.79 78.01 270.17 1999.34 1877.34 29.41 -1639.39 5945786.26 557043.74 MWD+IFR-AK-CAZ-SC 2968.90 77.95 271.18 2019.36 1897.36 30.52 -1733.39 5945786.64 556949.74 MWD+IFR-AK-CAZ-SC 3064.56 76.42 270.50 2040.58 1918.58 31.89 -1826.65 5945787.28 556856.48 MWD+IFR-AK-CAZ-SC 3159.86 77.43 271.73 2062.14 1940.14 33.70 -1919.46 5945788.36 556763.67 MWD+IFR-AK-CAZ-SC ~ 3253.23 75.67 273.78 2083.85 1961.85 38.05 -2010.16 5945792.01 556672.95 MWD+IFR-AK-CAZ-SC ~ 3349.74 74.71 275.05 2108.52 1886.b2 45.23 -21C3. ~8 5945798.47 556579.88 MWD+IFR-AK-CAZ-SC 3443.93 76.41 273.80 2132.01 2010.01 52.27 -2194.92 5945804.79 556488.90 MWD+IFR-AK-CAZ-SC 3540.57 77.66 270.39 2153.70 2031.70 55.70 -2288.21 5945807.49 556394.79 MWD+IFR-AK-CAZ-SC 3635.13 79.11 268.74 2172.74 2050.74 55.00 -2380.83 5945806.07 556302.19 MWD+IFR-AK-CAZ-SC 3707.38 79.75 269.81 2185.99 2063.99 54.10 -2451.85 5945804.61 556231.19 MWD+IFR-AK-CAZ-SC 3805.42 78.85 267.67 2204.20 2082.20 51.98 -2548.15 5945801.75 556134.92 MWD+IFR-AK-CAZ-SC 382Q.00 78.47 267.53 2207.06 2085.06 51.38 -2562.43 5945801.04 556120.64 MWD+IFR-AK-CAZ-SC 3858,15 79.89 267.79 2214.23 2092.23 49.85 -2599.87 5945799.22 556083.22 MWD+IFR-AK-CAZ-SC 3953.80 79.44 266.37 2231.39 2109.39 45.06 -2693.85 5945793.69 555989.29 MWD+IFR-AK-CAZ-SC 4034.80 79.87 266.75 2245.93 2123.93 40.28 -2773.39 5945788.29 555909.80 MWD+IFR-AK-CAZ-SC ~ 4143.86 79.90 266.60 2265.09 2143.09 34.05 -2880.57 5945781.23 555802.68 MWD+IFR-AK-CAZ-SC 4236.17 77.56 267.10 2283.12 2161.12 29.08 -2970.96 5945775.55 555712.34 MWD+IFR-AK-CAZ-SC 4333.04 79.39 267.52 2302.48 2180.48 24.62 -3065.76 5945770.36 555617.58 MWD+IFR-AK-CAZ-SC 4427.98 78.93 269.61 2320.34 2198.34 22.29 -3158.98 5945767.30 555524.40 MWD+IFR-AK-CAZ-SC 4523.16 78.50 270.05 2338.96 2216.96 22.01 -3252.31 5945766.29 555431.08 MWD+IFR-AK-CAZ-SC 4617.91 79.53 270.85 2357.02 2235.02 22.74 -3345.32 5945766.30 555338.07 MWD+IFR-AK-CAZ-SC 4713.53 80.27 2.71.44 2373.78 2251.78 24.62 -3439.44 5945767.45 555243.95 MWD+IFR-AK-CAZ-SC 4808.18 80.75 271.61 2389.39 2267.39 27.11 -3532.76 5945769.20 555150.62 MWD+IFR-AK-CAZ-SC 4903.20 80.98 271.22 2404.48 2282.48 29.42 -3626.55 5945770.79 555056.83 MWD+IFR-AK-CAZ-SC 4998.32 80.51 270.33 2419.77 2297.77 30.70 -3720.42 5945771.33 554962.96 MWD+IFR-AK-CAZ-SC 5093.55 81.40 270.36 2434.74 2312.74 31.26 -3814.46 5945771.16 554868.93 MWD+IFR-AK-CAZ-SC 5188.46 81.74 270.44 2448.66 2326.66 31.92 -3908.35 5945771.09 554775.05 MWD+IFR-AK-CAZ-SC 5283.91 80.28 269.58 2463.57 2341.57 31.93 -4002.62 5945770.37 554680.79 MWD+IFR-AK-CAZ-SC 5378.94 81.82 270.19 2478.36 2356.36 31.75 -4096.49 5945769.45 554586.93 MWD+IFR-AK-CAZ-SC I 5473.58 80.92 270.67 2492.56 2370.56 32.45 -4190.05 5945769.42 554493.37 MWD+IFR-AK-CAZ-SC 5569.13 80.17 268.84 2508.26 2386.26 32.05 -4284.30 5945768.29 554399.14 MWD+IFR-AK-CAZ-SC 5663.45 81.15 268.92 2523.56 2401.56 30.23 -4377.35 5945765.74 554306.12 MWD+IFR-AK-CAZ-SC 5759.60 80.99 268.63 2538.49 2416.49 28.20 -4472.31 5945762.97 554211.18 MWD+IFR-AK-CAZ-SC 5854.41 80.81 270.25 2553.48 2431.48 27.28 -4565.92 5945761.33 554117.59 MWD+IFR-AK-CAZ-SC 5949.37 81.78 271.07 2567.86 2445.86 28.36 -4659.78 5945761.68 554023.74 MWD+IFR-AK-CAZ-SC 6044.68 81.12 271.30 2582.03 2460.03 30.31 -4754.01 5945762.89 553929.50 MWD+IFR-AK-CAZ-SC 6140.01 81.04 272.45 2596.81 2474.81 33.40 -4848.14 5945765.24 553835.37 MWD+IFR-AK-CAZ-SC 6234.72 81.42 271.28 2611.25 2489.25 36.44 -4941.69 5945767.56 553741.80 MWD+IFR-AK-CAZ-SC 6330.24 81.87 270.30 2625.13 2503.13 37.74 -5036.18 5945768.12 553647.31 MWD+IFR-AK-CAZ-SC 6424.66 79.86 269.83 2640.12 2518.12 37.85 -5129.40 5945767.50 553554.10 MWD+IFR-AK-CAZ-SC 6520.62 80.57 269.88 2656.43 2534.43 37.61 -5223.96 5945766.53 553459.55 MWD+IFR-AK-CAZ-SC 6615.44 80.79 269.92 2671.78 2549.78 37.45 -5317.53 5945765.63 553366.00 MWD+IFR-AK-CAZ-SC 6709.92 81.78 270.34 2686.10 2564.10 37.66 -5410.92 5945765.12 553272.62 MWD+IFR-AK-CAZ-SC 6805.97 82.05 270.29 2699.61 2577.61 38.18 -5506.01 5945764.90 553177.54 MWD+IFR-AK-CAZ-SC I I 6901.06 81.92 269.80 2712.87 2590.87 38.26 -5600.17 5945764.24 553083.39 MWD+IFR-AK-CAZ-SC 6995.88 80.61 268.52 2727.27 2605.27 36.88 -5693.88 5945762.14 552989.70 MWD+IFR-AK-CAZ-SC 7090.82 79.86 268.10 2743.37 2621.37 34.13 -5787.40 5945758.65 552896.21 MWD+IFR-AK-CAZ-SC 7186.20 81.32 270.64 2758,96 2636.96 33.10 -5881.48 5945756.89 552802.15 MWD+IFR-AK-CAZ-SC i ~ Halliburton Company Survey Report Company: ConoCOPhillips Alaska InC. Date: 8/27/2007 Time: 09:38:50 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-162, True North Site: Kuparuk 1J Pad Vertical(TVD)Reference: 1J-162: 122.0 Well: 1J -162 Section(VS)Reference: Well(O.OON,O. OOE,180.OOAzi) Wellpath: 1J -162 Survey Calculati on Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ~ ft d eg deg ft ft ft ft ft ft I 7281.60 80 .76 271 .27 2773.82 2651 .82 34 ,67 -5975.70 5945757 .72 552707.93 MWD+IFR-AK-CAZ-SC ~ 7376.12 81 .A5 271 .62 2788.44 2666 .44 37 .02 -6069.06 5945759 .35 552614.57 MWD+IFR-AK-CAZ-SC ~ 7470.95 81 .74 27~ .88 2802.30 2680 .30 39 .07 -6162.85 5945780 .67 552526.78 MWD+IFR-AK-CAZ-SC I 7517.30 81 .29 270 .24 2809.14 2687 .14 39 .52 -6208.69 5945760 .76 552474.94 MWD+IFR-AK-CAZ-SC 7566.28 81 .49 268 .04 2816.47 2694 .47 38 .79 -6257.10 5945759 .65 552426.53 MWD+IFR-AK-CAZ-SC 7661.46 81 .30 263 .99 2830.72 2708 .72 32 .25 -6350.97 5945752 .38 552332.74 MWD+IFR-AK-CAZ-SC 7757.51 81 .00 261. 99 2845.50 2723 .50 20 .67 -6445.16 5945740 .07 552238.65 MWD+IFR-AK-CAZ-SC 7852.83 81 .43 259. 05 2860.06 2738 .06 5 .15 -6538.06 5945723 .83 552145.87 MWD+IFR-AK-CAZ-SC 7947.35 81 .24 257 .52 2874.30 2752 .30 -13 .82 -6629.55 5945704 .15 552054.54 MWD+IFR-AK-CAZ-SC 8036.06 80 .35 255. 09 2888.49 2766 .49 -34 .55 -6714.62 5945682 .76 551969.64 MWD+IFR-AK-CAZ-SC 8131.09 80 .98 250 .28 2903.91 2781 .91 -62 .45 -6804.12 5945654 .17 551880.38 MWD+IFR-AK-CAZ-SC 8225.86 80 .79 246. 51 2918.93 2796 .93 -96 .90 -6891.10 5945619 .05 551793.68 MWD+IFR-AK-CAZ-SC 8320.62 81 .53 244. 17 2933.50 2811 .50 -135 .96 -6976.19 5945579 .32 551708.90 MWD+IFR-AK-CAZ-SC 8416.06 81 .73 243. 97 2947.39 2825 .39 -177 .25 -7061.11 5945537 .38 551624.32 MWD+IFR-AK-CAZ-SC ~ 8511.22 81 .72 244. 92 2961.09 2839 .09 -217 .87 -7146.06 5945496 .10 551539.69 MWD+IFR-AK-CAZ-SC 8606.57 81 .91 243. 84 2974.66 2852 .66 -258 .68 -7231.16 5945454 .63 55145A.92 MWD+IFR-AK-CAZ-SC 8700.33 80 .79 240. 88 2988.77 2866 .77 -301 .67 -7313.27 5945411 .00 551373.16 MWD+IFR-AK-CAZ-SC 8797.77 81 .66 236. 71 3003.64 2881 .64 -351 .56 -7395.61 5945360 .48 551291.21 MWD+IFR-AK-CAZ-SC 8891.18 80 .47 233. 11 3018.15 2896. 15 -404 .59 -7471.10 5945306 .87 551216.14 MWD+IFR-AK-CAZ-SC 8986.81 81 .29 229. 58 3033.31 2911 .31 -463 .56 -7544.82 5945247 .33 551142.89 MWD+IFR-AK-CAZ-SC 9082.21 81 .97 225. 12 3047.20 2925. 20 -527 .49 -7614.22 5945182 .87 551074.00 MWD+IFR-AK-CAZ-SC 9176.76 82 .41 220. 40 3060.06 2938 .06 -596 .25 -7677.80 5945113 .62 551010.97 MWD+{FR-AK-CAZ-SC 9271.96 81 .66 216. 17 3073.26 2951 .26 -670 .24 -7736.20 5945039 .19 550953.15 MWD+IFR-AK-CAZ~SC 9366.44 80 .60 211. 70 3087.83 2965. 83 -747 .66 -7788.31 5944961. 37 550901.66 MWD+IFR-AK-CAZ-SC 9461.48 80 .35 206. 70 3103.57 2981. 57 -829 .45 -7834.02 5944879. 24 550856.59 MWD+IFR-AK-CAZ-SC 9556.96 80 .60 202. 63 3119.38 2997. 38 -915 .00 -7873.30 5944793. 39 550817.97 MWD+IFR-AK-CAZ-SC 9651.96 80 .41 198. 47 3135.05 3013. 05 -1002 .72 -7906.19 5944705. 43 550785.78 MWD+IFR-AK-CAZ-SC 9746.23 80 .78 194. 17 3150.47 3028. 47 -1091 .95 -7932.31 5944616. 00 550760.35 MWD+IFR-AK-CAZ-SC 9841.65 80 .54 190. 19 3165.96 3043. 96 -1183 .97 -7952.18 5944523. 84 550741.21 MWD+IFR-AK-CAZ-SC 9936.58 81 .76 186. 37 3180.57 3058. 57 -1276 .77 -7965.68 5944430. 94 550728.43 MWD+IFR-AK-CAZ-SC 10031J8 81 .72 185. 83 3194.24 3072. 24 -1370 .45 -7975.69 5944337. 20 550719.15 MWD+IFR-AK-CAZ-SC 10126.16 82 .77 184. 54 3206.98 3084. 98 -1463 .58 -7984.14 5944244. 01 550711.43 MWD+IFR-AK-CAZ-SC 10221.01 81 .78 18a. 08 3219.73 3097. 73 -1557 .30 -7991.20 5944150. 25 550705.10 MWD+IFR-AK-CAZ-SC 10316.60 81 .41 183. 14 3233.70 3111. 70 -1651 .68 -7997.16 5944055. 84 550699.88 MWD+IFR-AK-CAZ-SC 10368.53 82 .38 183. 05 3241.02 3119. 02 -1703 .01 -7999.93 594400A. 49 550697.50 MWD+IFR-AK-CAZ-SC 10402.13 82 .94 182. 91 3245.32 3123. 32 -1736 .29 -8001.66 5943971. 20 550696.03 MWD+IFR-AK-CAZ-SC 10497.30 88 .52 182. 52 3252.40 3130. 40 -1831 .06 -8006.16 5943876. 42 550692.28 MWD+IFR-AK-CAZ-SC 10550.00 90 .66 182. 31 3252.78 3130. 78 -1883 .70 -8008.38 5943823. 76 550690.47 MWD+IFR-AK-CAZ-SC 10593.51 88 .69 182. 12 3253.02 3131. 02 -1927 .18 -8010.06 5943780. 27 550689.12 MWD+IFR-AK-CAZ-SC 10687.12 86 .34 179. 45 3257.08 3135. 08 -2020 .68 -8011.34 5943686. 78 550688.57 MWD+IFR-AK-CAZ-SC ~ 10781.47 87 .71 178. 53 3261.98 3139. 98 -2114 .88 -8009.68 5943592. 60 550690.96 MWD+IFR-AK-CAZ-SC 10876.23 88 .95 179. 71 3264.74 3142. 74 -2209 .59 -8008.23 5943497. 92 550693.16 MWD+IFR-AK-CAZ-SC 10975.25 91 .48 178. 72 3264.37 3142. 37 -2308 .59 -8006.87 5943398. 94 550695.28 MWD+IFR-AK-CAZ-SC 11066.60 92 .40 177. 68 3261.28 3139. 28 -2399. 84 -8004.00 5943307. 72 550698.86 MWD+IFR-AK-CAZ-SC 11162.77 92 .90 176. 19 3256.83 3134. 83 -2495 .76 -7998.87 5943211. 85 550704.75 MWD+IFR-AK-CAZ-SC 11259.10 93 .21 176. 24 3251.70 3129. 70 -2591 .75 -7992.52 5943115. 93 550711.84 MWD+IFR-AK-CAZ-SC 11353.61 93 .08 176. 50 3246.51 3124. 51 -2685 .93 -7986.54 5943021. 81 550718.55 MWD+IFR-AK-CAZ-SC 11449.52 91 .04 174. 94 3243.06 3121. 06 -2781 .50 -7979.39 5942926. 30 550726.45 MWD+IFR-AK-CAZ-SC 11542.93 91 .17 175. 83 3241.26 3119. 26 -2874 .59 -7971.87 5942833. 28 550734.69 MWD+IFR-AK-CAZ-SC 11638.64 91 .48 177. 03 3239.05 3117. 05 -2970 .08 -7965.91 5942737. 84 550741.39 MWD+IFR-AK-CAZ-SC 11734.36 91 .35 178. 12 3236.69 3114. 69 -3065 .69 -7961.87 5942642. 28 550746.18 MWD+IFR-AK-CAZ-SC 11830.35 ~ 90 .92 177. 15 3234.78 3112. 78 -3161 .58 -7957.91 5942546. 44 550750.89 MWD+IFR-AK-CAZ-SC ~ ~ Halliburton Company Survey Report Company: ConocoPhillips Alaska Ina Date: 8/27/2007 Time: 09:38:50 Page: 4 Field: Kuparuk River Unlt Co-ordinate(NE) Reference: Well: 1J-162, True NORh Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-162: 122.0 Well: 1J -162 Section (VS) Reference: Well (U.OON,O:OOE,180.OOAzi) Wellpath: 1J -162 Survey Calculation Method: Minimum Curvature Db: Orac9e Survey MD I~cl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft ~ 11926.61 90.05 175.98 3233.97 3111.97 -3257.66 -7952.14 5942450.42 550757.40 MWD+IFR-AK-CAZ-SC 12021.00 89.62 177.77 3234.24 3112.24 -3351.90 -7946.99 5942356.22 550763.28 MWD+IFR-AK-CAZ-SC 12116.07 89.69 180.18 3234.81 3112.81 -3446.95 -7945.29 5942261.20 550765.72 MWD+IFR-AK-CAZ-SC 12210.00 91.05 180.65 3234.21 3112.21 -3540.87 -7945.97 5942167.28 550765.78 MWD+IFR-AK-CAZ-SC 12305.48 90.61 181.18 3232.82 3110.82 -3636.33 -7947.50 5942071.83 550764.99 MWD+IFR-AK-CAZ-SC 12400.85 92.22 183.38 3230.47 3108.47 -3731.59 -7951.29 5941976.55 550761.95 MWD+IFR-AK-CAZ-SC 12494.89 89.31 183.84 3229.21 3107.21 -3825.42 -7957.21 5941882.68 550756.76 MWD+IFR-AK-CAZ-SC 12589.77 87.27 180.04 3232.05 3110.05 -3920.18 -7960.42 5941787.91 550754.28 MWD+IFR-AK-CAZ-SC 12684.24 87.28 17879 3236.54 3114.54 -4014.54 -7959.46 5941693.57 550755.98 MWD+IFR-AK-CAZ-SC 12779.45 88.45 179.45 3240.08 3118.08 -4109.67 -7958.00 5941598.47 550758.19 MWD+IFR-AK-CAZ-SC 12874.03 89.07 178.96 3242.13 3120.13 -4204.22 -7956.68 5941503.94 550760.23 MWD+IFR-AK-CAZ-SC 12969.33 91.73 179.45 3241.47 3119.47 -4299.50 -7955.36 5941408.68 550762.30 MWD+IFR-AK-CAZ-SC 13064.87 92.15 180.46 3238.23 3116.23 -4394.98 -7955.29 5941313.21 550763.12 MWD+IFR-AK-CAZ-SC 13159.42 89.68 179.24 3236.72 3114.72 -4489.51 -7955.04 5941218.70 550764.10 MWD+IFR-AK-CAZ-SC 13255.65 88.45 178.81 3238.29 3116.29 -4585.71 -7953.40 5941122.52 550766:49 MWD+IFR-AK-CAZ-SC 13349.88 88.64 181.40 3240.68 3118.68 -4679.90 -7953.58 5941028.34 550767.05 MWD+IFR-AK-CAZ-S~C 13444.78 89.38 179.59 3242.32 3120.32 -4774.78 -7954.39 5940933.47 550766.97 MWD+IFR-AK-CAZ-SC 13539.78 91.91 180.10 3241.26 3119.26 -4869.76 -7954.14 5940838.50 550767.97 MWD+IFR-AK-CAZ-SC 13634.04 93.46 180.06 3236.84 3114.84 -4963.92 -7954.27 5940744.35 550768.57 MWD+IFR-AK-CAZ-SC 13729.02 91.47 179.94 3232.75 3110.75 -5058.80 -7954.27 5940649.48 550769.31 MWD+IFR-AK-CAZ-SC 13824.50 91.72 179.68 3230.10 3108.10 -5154.25 -7953.95 5940554.05 550770.37 MWD+IFR-AK-CAZ-SC 13919.31 91.91 179.80 3227.09 3105.09 -5249.01 -7953.52 5940459.31 550771.54 MWD+IFR-AK-CAZ-SC 14014.54 91.35 180.20 3224.39 3102.39 -5344.20 -7953.52 5940364.13 550772.28 MWD+IFR-AK-CAZ-SC 14109.70 91.97 180.32 3221:63 3099.63 -5439.32 -7953.95 5940269.02 550772.59 MWD+IFR-AK-CAZ-SG 14204.35 89.43 179.39 3220.47 3098.47 -5533.95 -7953.71 5940174.40 550773.57 MWD+IFR-AK-CAZ-SC 14299.69 90.12 181.09 3220.85 3098.85 -5629.29 -7954.11 5940079.07 550773.91 MWD+IFR-AK-CAZ-SC 14395.11 91.05 184.60 3219.87 3097.87 -5724.57 -7958.85 5939983.76 550769.92 MWD+IFR-AK-CAZ-SC 14461.76 90.80 183.45 3218.80 3096.80 -5791.04 -7963.53 5939917.26 550765.76 MWD+IFR-AK-CAZ-SC 14490.00 90.80 183.45 3218.40 3096.40 -5819.23 -7965.23 5939889.07 550764.28 PROJECTED to TD ~ ~ Halliburton Company Survey Report Company: ConocoPhillipsAlaska Inc. Date: 8/27/2007 Time: 09:28:33 Page: 1 Field: Kuparuk River Unlt Co-ordinate(NE) Reference: Well: 1J-162, True NoRh Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-162: 122A We1L• 1J-162 Section (VS) Refe rence: Well (O.OON,O~OOE,180.OOAzi) Wellpath: 1J-162PB1 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate Syste m 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bg gm2007 Well: 1 J-162 Slot Name: API 50-029-23360-00 Well Position: +N/-S -149.19 ft Northing: 594576 9.63 ft Latitude: 70 15 44.790 N +E/-W -107.98 ft Easti ng : 55868 3.15 ft Longitude: 149 31 32.149 W Position Uncertainty: 0.00 ft Wellpath: 1J-162P61 DrilledFrom: Well Ref. Point API 50-029-23360-70 Tie-on Depth: 41.00 ft Current Datum: 1J-162: Height 12 2.00 ft Above System Datum: Mean Sea Level Magnetic Data: 6/26/2007 Declination: 23.30 deg Field Strength: 57613 nT Mag Dip Angle: 80.79 deg Vertical Sec tion: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 41.00 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 7/3/2007 Validated: Yes V ersion: 15 Actual From To Survey Toolcode Tool Na me ft ft 100.00 651.00 1J-162P61 Gyro (100.00-651.00) C B-GYRO-SS Camera based gyro single shot 713.37 3949.63 1J-162P61 IIFR+MS+Sag (713.37- M WD+IFR-AK-C AZ-SC MWD+I FR AK CAZ SC C Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ff ft 41.00 0.00 0.00 41.00 -81.00 0.00 0.00 5945769.63 558683.15 TIE LINE 100.00 0.45 234.36 100.00 -22_00 -0.14 -0.19 5945769.49 558682.96 CB-GYRO-SS 149.00 0.51 214.60 149.00 27_00 -0.43 -0.47 5945769.20 558682.68 CB-GYRO-SS 200.00 0.30 227.66 200.00 78_00 -0.70 -0.70 5945768.92 558682.46 CB-GYRO-SS 273.00 1.65 260.52 272.98 150.98 -1.01 -1.87 5945768.61 558681.28 CB-GYRO-SS 367.00 4.51 269.00 366.84 244.84 -1.29 -6.91 5945768.28 558676.26 CB-GYRO-SS 461.00 8.00 273.66 460.27 338:27 -0.94 -17.13 5945768.56 558666.03 CB-GYRO-SS 556.00 10.87 274.86 553.97 431.97 0.24 -32.66 5945769.62 558650.50 CB-GYRO-SS 651.00 13.23 278,48 646.87 524.87 2.60 -52.34 5945771.83 558630.80 CB-GYRO-SS 713.37 15.42 274.60 707.30 585_30 4.32 -67.66 5945773.42 558615.46 MWD+IFR-AK-CAZ-SC 780.65 17.90 . 271.82 771.75 649.75 5.37 -86.92 5945774.32 558596.20 MWD+IFR-AK-CAZ-SC 875.53 19.09 274.68 861.73 739.73 7.10 -116.96 5945775.81 558566.15 MWD+IFR-AK-CAZ-SC 971.53 23.62 270.59 951.12 823_12 8.58 -151.85 5945777.02 558531.25 MWD+IFR-AK-CAZ-SC 1065.93 27.76 267.98 1036.18 914_18 8.00 -192J5 5945776.12 558490.36 MWD+IFR-AK-CAZ-SC 1162.64 30.48 267.25 1120.65 99$.65 6.02 -239.77 5945773J9 558443.36 MWD+IFR-AK-CAZ-SC 1256.73 35.19 267.65 1199.69 1077.59 3.77 -290.72 5945771.13 558392.43 MWD+IFR-AK-CAZ-SC 1351.53 36.44 269.48 9276.57 1154.57 2.39 -346.17 5945769.32 558337.00 MWD+IFR-AK-CAZ-SC 1446.88 38.52 270.63 1352.23 1230_23 2.46 -404.19 5945768.94 558278.99 MWD+IFR-AK-CAZ-SC 1542.11 41.52 271.90 1425.15 1303.15 3.83 -465.40 5945769.84 558217.78 MWD+IFR-AK-CAZ-SC 1637.24 46.26 271.68 1493.69 1371_S9 5.89 -531.30 5945771.38 558151.87 MWD+IFR-AK-CAZ-SC 1732.33 49.51 271.47 1557.45 1435_45 7.82 -601.80 594577276 558081.36 MWD+IFR-AK-CAZ-SC 1827.63 54.06 271.76 1616.39 1494.39 9.94 -676.63 594577429 558006.53 MWD+IFR-AK-CAZ-SC 1920.91 57.06 272.59 1669.14 1547.14 12.87 -753.49 5945776.62 557929.65 MWD+IFR-AK-CAZ-SC 2015.25 59.56 272,77 1718.69 159&_fi9 16.62 -833.67 5945779.75 557849.45 MWD+IFR-AK-CAZ-SC 2113.84 62.11 271.22 1766.74 1644.74 19.60 -919.70 5945782.07 557763.41 MWD+IFR-AK-CAZ-SC 2207.83 64.87 271.31 1808.68 1686_88 21.46 -1003.78 5945783.27 557679.33 MWD+IFR-AK-CAZ-SC 2303.12 68.09 271.35 1846.71 1724_71 23.49 -1091.12 5945784.61 557591.99 MWD+IFR-AK-CAZ-SC 2397.67 72.20 270.13 1878.81 1756_81 24.63 -1180.02 5945785.06 557503.09 MWD+IFR-AK-CAZ-SC 2492.72 74.15 269.25 1906.32 1784=32 24.13 -1270.99 5945783.85 557412.13 MWD+IFR-AK-CAZ-SC ! ~ Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 8/27/2007 Time: 09:28:33 Page; 2 Field: KuparuKRiver Unit Co-ordinate(NE) Reference: Well: 1J-162, T rue North Site: Kuparuk 1J Pad Vertieal(TVD)Reference: 1J-162: 122:0 Well: 1J -162 Sec tiou (VS) Reference; Well (O.~ON,O.OOE,180:OOAzi) Wellpath: 1J -162P61 Survey Calculation Method: M'inimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 2588.87 75.34 270.26 1931.62 1809.62 23.74 -1363.75 5945782.74 557399.38 MWD+IFR-AK-CAZ-SC 2683.19 76.39 271.85 1954.66 1832.66 25.42 -1455.20 5945783.71 557227.94 MWD+IFR-AK-CAZ-SG 2778.52 75.54 271.47 1977.78 1855.78 28.10 -1547.64 5945785.67 557'635.49 MWD+IFR-AK-CAZ-SC 2872.79 78.01 270.17 1999.34 1877.34 29.41 -1639.39 5945786.26 557Q43.74 MWD+IFR-AK-CAZ-SC 2968.90 77.95 271.18 2019.36 1897.36 30.52 -1733.39 5945786.64 556949.74 MWD+IFR-AK-CAZ-SC 3064.56 76.42 270.50 2040.58 1918.58 31.89 -1826.65 5945787.28 556856.48 MWD+IFR-AK-CAZ-SC 3159.86 77.43 271.73 2062.14 1940.14 33.70 -1919.46 5945788.36 556763.67 MWD+IFR-AK-CAZ-SC I 3253.23 75.67 273.78 2083.85 1961.85 38.05 -2010.16 5945792.01 5566~2.95 MWD+IFR-AK-CAZ-SC ; 3349.74 74J1 275.05 2108.52 1986.52 45.23 -2103.18 5945798.47 556579.88 MWD+IFR-AK-CAZ-SC 3443.93 76.41 273.80 2132.01 2010.01 52.27 -2194.12 5945804.79 5564$8.90 MWD+IFR-AK-CAZ-SC 3540.57 77.66 270.39 2153.70 2031.70 55.70 -2288.21 5945807.49 556394.79 MWD+IFR-AK-CAZ-SC 3635.13 79.11 268.74 2172.74 2050.74 55.00 -2380.83 5945806.07 556302.19 MWD+IFR-AK-CAZ-SC 3707.38 79.75 269.81 2185.99 2063.99 54.10 -2451.85 5945804.61 556231.19 MWD+IFR-AK-CAZ-SC 3805.42 78.85 267.67 2204.20 2082.20 51.98 -2548.15 5945801.75 556734.92 MWD+IFR-AK-CAZ-SC 3897.51 76.48 266.77 2223.87 2101.87 47.62 -2638.00 5945796.69 556045.11 MWD+IFR-AK-CAZ-SC 3949.63 79.06 265.80 2234.91 2112.91 44.32 -2688.83 5945792.99 555994.32 MWD+IFR-AK-CAZ-SC 3998.00 79.06 265.80 2244.09 2122.09 40.84 -2736.19 5945789.14 555946.99 PROJECTED to TD ~ ~ Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 8/27/2007 Time: 09;34:02 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-162; True North Site: Kuparuk ?J Pad Vertical (TVD) Reference: 1J-162: 122A Well: 1J-162 Section(VS)Refe rence: Well(O.OON,O.OOE,180.OOAzi) Wellpath: 1J-162PB2 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Kuparuk River Unit ~ North Slope Alaska ' United States ~ Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: 1 J-162 Slot Name: API 50-029-23360-00 Well Position: +N/-S -149.19 ft Northing: 594576 9.63 ft Latitude: 70 15 44.790 N +E/-W -107.98 ft Easti ng : 55868 3.15 ft Longitude: 149 31 32.149 W Position Uncertainty: 0:00 ft Wellpath: 1 J-162P62 Drilled From: 1 J-162P61 API 50-029-23360-71 Tie-on Depth: 3805.42 ft Current Datum: 1 J-162: Height 12 2.00 ft Above System Datum: Mean Sea Level Magnetic Data: 6/26/2007 Dectination: 23.30 deg Field Strength: 57613 nT Mag Dip Angle: 8~J9 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 41.00 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 7/20/2007 Validated: Yes Version: 6 Actual From To Survey Toolcode Tool Name ft ft 100.00 651.00 1J-162P61 Gyro (100.00-651.00) CB-GYRO-SS Camera based gyro sin gle shot 713.37 3805.42 1J-162P61 IIFR+MS+Sag (713.37- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3820.00 10973.60 1J-162PB2 IIFR+MS+Sag (3820.00 MWD+fFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey MD Incl Azim TVD , Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 41.00 0.00 0.00 41.00 -81.00 0.00 0.00 5945769.63 558683.15 TIE LINE 100.00 0.45 234.36 100.00 -22.00 -0.14 -0.19 5945769.49 558682.96 CB-GYRO-SS 149.00 0.51 214.60 149.00 27.00 -0.43 -0.47 5945769.20 558682.68 CB-GYRO-SS 200.00 0.30 227.66 200.00 78.00 -0.70 -0.70 5945768.92 558682.46 CB-GYRO-SS 273.00 1.65 260.52 272.98 150.98 -1.01 -1.87 5945768.61 558681.28 CB-GYRO-SS 367.00 4.51 269.00 366.84 244.84 -1.29 -6.91 5945768.28 558676.26 CB-GYRO-SS 461.00 8.00 273.66 46027 338.27 -0.94 -17.13 5945768.56 558666.03 CB-GYRO-SS 556.00 10.87 274.86 553.97 431.97 0.24 -32.66 5945769.62 558650.50 CB-GYRO-SS 651.00 13.23 278.48 646.87 524.87 2.60 -52.34 5945771.83 55863(1.80 CB-GYRO-SS 713.37 15.42 274.60 707.30 585.30 4.32 -67.66 5945773.42 558615.46 MWD+IFR-AK-CAZ-SC 780.65 17.90 271.82 771.75 649.75 5.37 -86.92 5945774.32 558596.20 MWD+IFR-AK-CAZ-SC 875.53 19.09 274.68 86173 739J3 7.10 -116.96 5945775.81 558566.15 MWD+IFR-AK-GAZ-SC 971.53 23.62 270.59 951.12 829.12 8.58 -151.85 5945777.02 558531.25 MWD+IFR-AK-GAZ-SC 1065.93 27.76 267.98 1036.18 914.18 8.00 -192.75 5945776.12 558490.36 MWD+IFR-AK-EAZ-SC 1162.64 30.48 267.25 1120.65 998.65 6.02 -239.77 594577379 558443.36 MWD+IFR-AK-CAZ-SC 1256.73 35.19 267.65 1199.69 1077.69 3.77 -290.72 5945771.13 558392.43 MWD+IFR-AK-CAZ-SC 1351.53 36.44 269.48 1276.57 1154.57 2.39 -346.17 5945769.32 558337.00 MWD+IFR-AK-CAZ-SC 1446.88 38.52 270.63 1352.23 1230.23 2.46 -404.19 5945768.94 558278.99 MWD+IFR-AK-CAZ-SC 1542.11 41.52 271.90 1425.15 1303.15 3.83 -465.40 5945769.84 558217.78 MWD+IFR-AK-G}1Z-SC 1637.24 46.26 271.68 1493.69 1371.69 5.89 -531.30 5945771.38 558151.87 MWD+IFR-AK-~AZ-SC 1732.33 49.51 271.47 1557.45 1435.45 7.82 -601.80 5945772.76 558081.36 MWD+IFR-AK-GAZ-SC 1827.63 54.06 271.76 1616.39 1494.39 9.94 -676.63 5945774.29 558006.53 MWD+IFR-AK-eAZ-SC 1920.91 57.06 272.59 1669.14 1547.14 12.87 -753.49 5945776.62 557929.65 MWD+IFR-AK-CAZ-SC 2015.25 59.56 272.77 1718.69 1596.69 16.62 -833.67 5945779.75 557849.45 MWD+IFR-AK-CAZ-SC , 2113.84 62.11 271.22 176674 1644.74 19.60 -919.70 5945782.07 557763.41 MWD+IFR-AK-CAZ-SC I, 2207.83 64.87 271.31 1808.68 1686.68 21.46 -10~3.78 5945783.27 557679.33 MWD+IFR-AK-GAZ-SC 2303.12 68.09 271.35 1846.71 1724.71 23.49 -1091.12 5945784.61 557591.99 MWD+IFR-AK-CAZ-SC I 2397.67 72.20 270.13 1878.81 1756.81 24.63 -1180.02 5945785.06 557503.09 MWD+IFR-AK-GAZ-SC ~ ~ Halliburton Company Survey Repor~ Company: ConocoPhil lips Alaska I nc. Date: 8/27/2Q07 Tim e: 09:34:02 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-162, True North Site: Kuparuk 1J Pad Vertical(TVD)Reference: 1J-162: 122.0 Well: 1J -162 Sec tion(VS)ReSe rence: Well(O.OON,O. OOE,180.OOAzi) Welipath: 1J-162 PB2 Sarvey Calculation Method: Minimum Curvatu~e Db: ~racfe Survey MD Inc l Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 2492.72 74 .15 269. 25 1906 .32 1784 .32 24 .13 -1270.99 5945783 .85 557412 .13 MWD+IFR-AK-CP~Z-SC 2588:87 75 .34 270. 26 1931 .62 1809 .62 23 .74 -1363.75 5945782 .74 557319 .38 MWD+IFR-AK-CAZ-SC 2683.19 76 .39 271. 85 1954 .66 1832. 66 25 .42 -1455.20 5945783 .71 557227. 94 MWD+IFR-AK-G~iZ-SC ~ 2778.52 75 .54 271. 47 1977 .78 1855. 78 28 .10 -1547.64 5945785 .67 557135. 49 MWD+IFR-AK-CAZ-SC I 2872J9 78 .01 270. 17 1999 .34 1877. 34 29 .41 -1639.39 5945786 .26 557043. 74 MWD+IFR-AK-CF4Z-SC 2968.90 77 .95 271. 18 2019 .36 1897. 36 30 .52 -1733.39 5945786 .64 556949. 74 MWD+IFR-AK-CAZ-SC 3064.56 76 .42 270. 50 2040 .58 1918. 58 31 .89 -1826.65 5945787 .28 556856. 48 MWD+IFR-AK-CpZ-SC 3159.86 77 .43 271. 73 2062 .14 1940 .14 33 .70 -1919.46 5945788 .36 556763. 67 MWD+IFR-AK-CA,Z-SC 3253.23 75 .67 273. 78 2083 .85 1961 .85 38 .05 -2010.16 5945792 .01 556672. 95 MWD+IFR-AK-CAZ-SC 3349.74 74 .71 275. 05 2108. 52 1986 .52 45 .23 -2103.18 5945798 .47 556579. 88 MWD+IFR-AK-CAZ-SC 3443.93 76 .41 273. 80 2132. 01 2010. 01 52 .27 -2194.12 5945804 .79 556488. 90 MWD+IFR-AK-CAZ-SC 3540.57 77 .66 270. 39 2153. 70 2031. 70 55 .70 -2288.21 5945807 .49 556394. 79 MWD+IFR-AK-CAZ-SC 3635.13 79 .11 268. 74 2172. 74 2050. 74 55 .00 -2380.83 5945806 .07 556302. 19 MWD+IFR-AK-CAZ-SC 3707.38 79 .75 269. 81 2185. 99 2063. 99 54 .10 -2451.85 5945804 .61 556231. 19 MWD+IFR-AK-CAZ-SC 3805.42 78 .85 267. 67 2204. 20 2082. 20 51 .98 -2548.15 5945801 .75 556134. 92 MWD+IFR-AK-CAZ-SC 3820.00 78 .47 267. 53 2207. 06 2085. 06 51 .38 -2562.43 5945801 .04 556120. 64 MWD+IFR-AK-C/iZ-SC 3858.15 79 .89 267. 79 2214. 23 2092. 23 49 .85 -2599.87 5945799 .22 556083. 22 MWD+IFR-AK-CA~Z-SC 3953.80 79. 44 266. 37 2231. 39 2109. 39 45 .06 -2693.85 5945793 .69 555989. 29 MWD+IFR-AK-CAZ-SC 4034.80 79. 87 266 J5 2245. 93 2123. 93 40 .28 -2773.39 5945788 .29 555909. 80 MWD+IFR-AK-C/iZ-SC 4143.86 79. 90 266. 60 2265. 09 2143. 09 34 .05 -2880.57 5945781 .23 555802. 68 MWD+IFR-AK-CAZ-SC 4236.17 77. 56 267. 10 2283. 12 2161. 12 29 .08 -2970.96 5945775 .55 555712. 34 MWD+IFR-AK-C/iZ-SC 4333.04 79. 39 267. 52 2302. 48 2180. 48 24 .62 -3065.76 5945770 .36 555617. 58 MWD+IFR-AK-C/~-SC 4427.98 78 .93 269. 61 2320. 34 2198. 34 22 .29 3158.98 5945767 .30 555524. 40 MWD+IFR-AK-CA~-SC 4523.16 78. 50 270. 05 2338. 96 2216. 96 22 .01 -3252.31 5945766 .29 555431. 08 MWD+IFR-AK-CAZ-SC 4617.91 79. 53 270. 85 2357. 02 2235. 02 22 .74 -3345.32 5945766 .30 555338. 07 MWD+IFR-AK-CAZ-SC 4713.53 80. 27 271. 44 2373. 78 2251. 78 24 .62 -3439.44 5945767 .45 555243. 95 MWD+IFR-AK-CAZ-SC 4808.18 80. 75 271. 61 2389. 39 2267. 39 27 .11 3532.76 5945769 .20 555150. 62 MWD+IFR-AK-C/iZ-SC 4903.20 80. 98 271. 22 2404. 48 2282. 48 29 .42 -3626.55 5945770 .79 555056. 83 MWD+IFR-AK-CAZ-SC 4998.32 80. 51 270. 33 2419. 77 2297. 77 30 .70 -3720.42 5945771 .33 554962. 96 MWD+IFR-AK-CAZ-SC 5093.55 81 .40 270. 36 2434. 74 2312. 74 31 .26 -3814.46 5945771 .16 554868. 93 MWD+IFR-AK-CAZ-SC 5188.46 81 .74 270. 44 2448. 66 2326. 66 31 .92 3908.35 5945771 .09 554775. 05 MWD+IFR-AK-CAZ-SC 5283.91 80. 28 269. 58 2463. 57 2341. 57 31 .93 , -4002.62 5945770 .37 554680. 79 MWD+lFR-AK-CAZ-SC 5378.94 81. 82 270. 19 2478. 36 2356. 36 31 .75 -4096.49 5945769 .45 554586. 93 MWD+IFR-AK-CAZ-SC 5473.58 80. 92 270. 67 2492. 56 2370. 56 32 .45 -4190.05 5945769 .42 554493. 37 MWD+IFR-AK-CAZ-SC 5569.13 80. 17 268. 84 2508. 26 2386. 26 32 .05 -4284.30 5945768 .29 554399. 14 MWD+IFR-AK-CAZ-SC 5663.45 81. 15 268. 92 2523. 56 2401. 56 30 .23 -4377.35 5945765 .74 554306. 12 MWD+IFR-AK-CAZ-SC 5759.60 80 .99 268. 63 2538. 49 2416. 49 28 .20 -4472.31 5945762 .97 554211. 18 MWD+IFR-AK-CAZ-SC 5854.41 80. 81 270. 25 2553. 48 2431. 4$ 27 28 -4565.92 5945761 .33 554117. 59 MWD+IFR-AK-CAZ-SC 5949.37 81. 78 271. 07 2567. 86 2445. 86 28 .36 -4659.78 5945761 .68 554023. 74 MWD+IFR-AK-CAZ-SC 6044.68 81. 12 271. 30 2582. 03 2460. 03 30 .31 -4754.01 5945762 .89 553929. 50 MWD+IFR-AK-CAZ-SC i 6140.01 81. 04 272. 45 2596. 81 2474. 81 33 .40 -4848.14 5945765 .24 553835. 37 MWD+IFR-AK-CAZ-SC 6234.72 81. 42 271 28 2611. 25 2489. 25 36 .44 -4941.69 5945767 .56 553741. 80 MWD+IFR-AK-CAZ-SC 6330.24 81 .87 270. 30 2625. 13 2503. 13 37 .74 -5036.18 5945768 .12 553647. 31 MWD+IFR-AK-CAZ-SC 6424.66 79 .86 269. 83 2640. 12 2518. 12 37 .85 -5129.40 5945767 .50 553554. 10 MWD+IFR-AK-CAZ-SC 6520.62 80 .57 269. 88 2656. 43 2534. 43 37 .61 -5223.96 5945766 .53 553459. 55 MWD+IFR-AK-CAZ-SC 6615.44 80. 79 269. 92 2671. 78 2549. 78 37 .45 -5397.53 5945765 .63 553366. 00 MWD+IFR-AK-CA,Z-SC 6709.92 81 .78 270. 34 2686. 10 2564. 10 37 .66 -5410.92 5945765 .12 553272. 62 MWD+IFR-AK-CAZ-SC 6805.97 82 .05 270. 29 2699. 61 2577. 61 38 .18 -5506.01 5945764 .90 553177. 54 MWD+IFR-AK-CAZ-SC 6901.06 81 .92 269. 80 2712. 87 2590. 87 38 .26 -5600.17 5945764 .24 553083. 39 MWD+~FR-AK-CAZ-SC 6995.88 80 .61 268. 52 2727. 27 . 2605. 27 36 .88 -5693.88 5945762 .14 552989. 70 MWD+IFR-AK-CAZ-SC 7090.82 79 .86 268. 10 2743 .37 2621. 37 34 .13 -5787.40 5945758 .65 552896. 21 MWD+IFR-AK-CAa-SC 7186.20 81 .32 270. 64 2758 .96 2636. 96 33 .10 -5881.48 5945756 .89 552802. 15 MWD+IFR-AK-CAZ-SC ~ ~ Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit Date: 8/27/2007 Co-ordinate(NEj Reference: Time: 09:34:02 Page: 3 Well: 1J-162, True North Site: Kuparuk 1J Pad Vertical(TVD)Reference: 1J-162: 122.0 Well: 1J -162 Sec tion (VS) Reference: Well (O.OON,O. OOE,180.OOAzi) I Wellpath: 1J -162 P62 Survey Calculation Method: Minimum Curvature Db: OraCle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 7281.60 80 .76 271.27 2773. 82 2651 .82 34 .67 -5975 .70 5945757 ,72 552707.93 MWD+IFR-AK-CAZ-SG 7376.12 81 .45 271.62 2788. 44 2666 .44 37 .02 -6069 .06 5945759 .35 552614.57 MWD+IFR-AK-CAZ-SC 7470.95 81 .74 270.88 2802. 30 2680 .30 39 .07 -6162 .85 5945760 .67 552520.78 MWD+IFR-AK-CAZ-SC 7517.30 81 .29 270.24 2809. 14 2687 .14 39 .52 -6208 .69 5945760 .76 552474.94 MWD+IFR-AK-CAZ-SG 7566.28 81 .49 268.04 2816. 47 2694 .47 38 .79 -6257 .10 5945759 .65 552426.53 MWD+IFR-AK-CAZ-SG 7661.46 81 .30 263.99 2830. 72 2708 .72 32 .25 -6350 .97 5945752 .38 552332.74 MWD+IFR-AK-CAZ-SG 7757.51 81 .00 261.99 2845. 50 2723 .50 20 .67 -6445 .16 5945740 .07 552238.65 MWD+IFR-AK-CAZ-SG 7852.83 81 .43 259.05 2860. 06 2738 .06 5 .15 -6538 .06 5945723 .83 552145.87 MWD+IFR-AK-CAZ-SC 7947.35 81 .24 257.52 2874. 30 2752 .30 -13 .82 -6629 .55 5945704 .15 552054.54 MWD+IFR-AK-CAZ-SC 8036.06 80 .35 255.09 2888. 49 2766 .49 -34 .55 -6714 .62 5945682 .76 551969.64 MWD+IFR-AK-CAZ-SG 8131.09 80 .98 25028 2903. 91 2781 .91 -62 .45 -6804 .12 5945654 .17 551880.38 MWD+IFR-AK-CAZ-SC 8225.86 80 .79 246.51 2918. 93 2796 .93 -96 .90 -6891 .10 5945619 .05 551793.68 MWD+IFR-AK-CAZ-3C 8320.62 81 .53 244.17 2933. 50 2811 .50 -135 .96 -6976 .19 5945579 .32 551708.90 MWD+IFR-AK-CAZ-SC 8416.06 81 .73 243.97 2947. 39 2825 .39 -977 .25 -7061 .11 5945537 .38 551624.32 MWD+IFR-AK-CAZ-SG 8511.22 81 .72 244.92 2961. 09 2839 .09 -217 .87 -7146 .06 5945496 .10 551539.69 MWD+IFR-AK-CAZ-SG 8606.57 81 .91 243.84 2974. 66 2852 .66 -258 .68 -7231 .16 5945454 .63 551454.92 MWD+IFR-AK-CAZ-SC 8700.33 80 .79 240.88 2988. 77 2866 77 -301 .67 -7313 .27 5945411 .00 551373.16 MWD+IFR-AK-CAZ-SC 8797.77 81 .66 236.71 3003. 64 2881 .64 -351 .56 -7395 .61 5945360 .48 551291.21 MWD+IFR-AK-CAZ-SG 8891.18 80 .47 233.11 3018. 15 2896 .15 -404 .59 -7471 .10 5945306 .87 551216.14 MWD+IFR-AK-CAZ-SC 8986.81 81 .29 229.58 3033. 31 2911 .31 -463 .56 -7544 .82 5945247 .33 551142.89 MWD+IFR-AK-CAZ-SC 9082.21 81 .97 225.12 3047. 20 2925 .20 -527 .49 -7614 .22 5945182 .87 551074.00 MWD+IFR-AK-CAZ-SC 9176.76 82 .41 220.40 3060. 06 2938 .06 -596 .25 -7677 .80 5945113 .62 551010.97 MWD+IFR-AK-CAZ-SC 9271.96 81 .66 216.17 3073. 26 2951. 26 -670 .24 -7736 .20 5945039 .19 550953.15 MWD+IFR-AK-CAZ-SG 9366.44 80 .60 211.70 3087. 83 2965 .83 -747 .66 -7788 .31 5944961 .37 550901.66 MWD+IFR-AK-CAZ-SG 9461.48 80 .35 206.70 3103. 57 2981. 57 -829 .45 -7834 .02 5944879 .24 550856.59 MWD+IFR-AK-CAZ-SC 9556.96 80 .60 202.63 3119. 38 2997 .38 -915 .00 -7873 .30 5944793 .39 550817.97 MWD+IFR-AK-CAZ-SC 9651.96 80 .41 198.47 3135. 05 3013 .05 -1002 .72 -7906 .19 5944705 .43 550785.78 MWD+IFR-AK-CAZ-SC 9746.23 80 .78 194.17 3150. 47 3028 .47 -1091 .95 -7932 .31 . 5944616 .00 550760.35 MWD+IFR-AK-CAZ-SG 9841.65 80 .54 190.19 3165. 96 3043. 96 -1183 .97 -7952. 18 5944523. 84 550741.21 MWD+IFR-AK-CAZ-SC 9936.58 81 76 186.37 3180. 57 3058. 57 -1276 .77 -7965. 68 5944430. 94 550728.43 MWD+IFR-AK-CAZ-SC 10031.78 81 .72 185.83 3194. 24 3072. 24 -1370 .45 -7975. 69 5944337. 20 550719.15 MWD+IFR-AK-CAZ-SC 10126.16 82 .77 184.54 3206. 98 3084. 98 -1463 .58 -7984. 14 5944244. 01 550711.43 MWD+IFR-AK-GAZSG 10221.01 81 .78 184.08 3219. 73 3097 J3 -1557 .30 -7991. 20 5944150. 25 550705.10 MWD+IFR-AK-CAZ-SG 10316.60 81 .41 183.14 3233. 70 3111. 70 -1651 .68 -7997. 16 5944055. 84 550699.88 MWD+~FR-AK-GAZ-SC 10368.53 82 .38 183.05 3241. 02 3119. 02 -1703 .01 -7999. 93 5944004. 49 550697.50 MWD+IFR-AK-CAZ-SC 10402.13 82 .94 182.91 3245. 32 3123. 32 -1736 .29 -8001. 66 5943971. 20 550696.03 MWD+IFR-AK-CAZ-SC 10497.30 88 .52 182.52 3252. 40 3130. 40 -1831 .06 -8006. 16 5943876. 42 550692.28 MWD+IFR-AK=CAZ-SC 10592.60 92 .40 182.14 3251. 63 3129. 63 -1926 .26 -8010. 03 5943781. 20 550689.14 MWD+IFR-AK-GAZ-~C 10687.68 93 .08 179.82 3247. 09 3125. 09 -2021 .21 -8011. 65 5943686. 25 550688.26 MWD+IFR-AK-CAZ-SG 10782.55 90 .79 177.16 3243. 89 3121. 89 -2115 .97 -8009. 15 5943591. 51 550691.50 MWD+IFR-AK-CAZ-~C 10877.39 87 .39 175.74 3245. 39 3123. 39 -2210 .60 -8003. 28 5943496. 94 550698.10 MWD+IFR-AK-CA2-SG 10973.60 88 .82 175.05 3248. 57 3126. 57 -2306 .45 -7995. 56 5943401. 17 550706.57 MWD+IFR-AK-CAZ-SG 11035.Q0 88. 82 175.05 3249. 84 3127. 84 -2367 .61 -7990. 27 5943340 .06 550712.3A PROJECTED to TD ~ Ct~rt+r-~t~-P'h i l 11 p-s NielN7ew Web Repo!ifng Well Name: 1 J-162 Job Type: DRILLING ORIGINAL Time Log Summary 06/28/2007 06:00 07:30 1.50 0 0 MIRU MOVE MOB P Lay down Herculite pit liner & spot rig mats on 1J-162. Prep Doyon 15 rig for move. Split pits & sub. Disconnect interconnects. 07:30 09:00 1.50 0 0 MIRU MOVE DMOB P Held PJSM. Discuss skidding rig floor. Skid ri floor into osition for move. 09:00 10:00 1.00 0 0 MIRU MOVE DMOB P Raise Stomper jacks in cellar & pin landing for BOP's. Continue spot rig mats. 10:00 12:00 2.00 0 0 MIRU MOVE MOB P Held PJSM with crew. Discuss rig move procedure. Crab walk pit module & sub module off of rig mats. Move mats & install on 1J-162. Pick up pit liner off of 1J-158. 12:00 15:30 3.50 0 0 MIRU MOVE MOB P Move & spot sub module over 1J-162. Spot pit module next to sub. Lay down Herculite pit liner for berming up Rockwasher. 15:30 16:30 1.00 0 0 MIRU MOVE RURD P Skid rig floor over center of well. Pull handling equipment to rig floor. Install rooof caps & floor grating. Attach 2" hoses from its to sub. 16:30 18:00 1.50 0 0 MIRU MOVE RURD P Rig up all water, air, steam & hydraulic lines on rig floor. Spot rockwasher module. Berm in rig. Rig up all lines in Rockwasher. Rig up VAC system. Rig up pump room mud lines. Pull beaver slide into position. Rig on Hi Line power @ 1730 HRS. Crew Change NOTE: Doyon 15 Rig acceptance @ 1200 HRS. Time correction from last rig release on 1 J-158. 18:00 00:00 6.00 0 0 MIRU MOVE RURD P Nipple up 20" Diverter "T' and starting head. Held PJSM. Discuss procedure to make up Diverter system. complete installation of ODS pipe elevator. Continue weld braces in cellar for installation of heaters. Install cellar alram & ground strap. Rig up cellar pump. and floor grating around cellar. Bring more dirt in and lay around cellar for subsidence issues. Rig up mud lines in No Mans land to rig floor. Rig I up cheoke lines, and flowline interconnects. Set cuttings tanks, landings, walkarounds, stairs & handrails. Berm around rockwasher. 06/29/2007 00:00 06:00 6.00 0 0 MIRU MOVE RURD P Continue berming around rockwasher & rig. Continue make up Diverter line cannons. Attach koomey lines to Diverter Hydril & Knife valve. Instaii Screens on shakers in pits. Load pipe shed with 180 jnts of 5" DP, and 30 jnts of 5" HWDP. Load 580 BBLS of spud mud on pits. NU Flow nipple. Attach & tighten turnbuckles to center stack. Lockdown starting head & obtain RKB to load shoulder @ 43.12'. Crew Chan e 06:00 08:30 2.50 0 0 MIRU MOVE RURD P Clean & prep rig floor. Continue dress shakers. erform walkthrou h. 08:30 10:30 2.00 0 0 MIRU MOVE RURD P Condition mud, Pull tools and BHA equipment to rig floor. Pull handling equipment to rig floor. Heid PJSM. Discuss picking up and racking back 5" DP. 10:30 12:00 1.50 0 0 MIRU MOVE RURD P Pick up 5" dritl pipe from shed, racking back stands in derrick. Drift each joint picked up.Obtain SLM. Set crown-o-matic, and function test same. 12:00 14:00 2.00 0 0 MIRU MOVE RURD P Pick up 5" drili pipe from shed, racking back stands in derrick. Drift each joint icked u . Obtain SLM 14:00 14:30 0.50 0 0 MIRU RIGMN SVRG P Adjust new brakes on draw works. Veri ro erl s aced and ti htened. 14:30 17:45 3.25 0 0 MIRU MOVE RURD P Continue pick up 5" drill pipe from shed, racking back stands in derrick. Drift each joint picked up. Obtain SLM. Total stands in derrick = 60 stnds. 17:45 18:00 0.25 0 0 MIRU MOVE RURD P Begin picking up 5" HWDP from shed, racking back stands in derrick. Crew chan e 18:00 19:30 1.50 0 0 MIRU MOVE RURD P Continue picking up 5" HWDP form shed racking back a total of 10 stands. Drift all 'nts and obtain SLM. 19:30 19:45 0.25 0 0 MIRU MOVE RURD P Remove mousehole from rotary table. Clean & clear ri floor. 19:45 20:45 1.00 0 0 MIRU MOVE OTHR T RIH & tag up at 92' MD. Function diverter system. Tighten leak on fittings on Hydril. Stand back 2 stands. 20:45 21:15 0.50 0 0 MIRU MOVE OTHR P Pick up 5 joints of HWDP 7 Dailey drillin 'ars. rack back in derrick. 21:15 21:45 0.50 0 0 MIRU MOVE OTHR P Rig up Gyro unit & sheaves. 21:45 22:45 1.00 0 0 MIRU WELCT OTHR P Function test Hydril and Knife valve. Valve open in 20 seconds. Perform Accumulator draw down test. Observed full pressure in 2 minutes - 39 seconds. Witness of test waived by AOGCC re~ - John Crisp. ~ . ~ 07/01/2007 02:45 04:30 1.75 1,592 1,592 SURFA DRILL REAM P Wash & ream hole from 1592' - 1500' to clean up hole and reduce hole angle with um s 680 GPM's - 1350 PSI. 04:30 06:00 1.50 1,592 1,686 SURFA DRILL DDRL P Continue directional drill surface hole from 1592' -1686' MD. TVD = 1524'. WOB = 25K. RPM = 40. GPM's - 575 - 1280 PSI. ADT = 2.75 HRS. Bit Hrs = 16.33 Obtain Checkshot surveys. Crew chan e 06:00 09:30 3.50 1,686 1,972 SURFA DRILL DDRL P Continue directional driil surface hole from 1686' - 1972' MD. WOB = 25K. RPM = 40. GPM's - 560 - 1250 PSI. Obtain Checkshot surve s. 09:30 11:00 1.50 1,972 1,972 SURFA DRILL CIRC P Rotate & reciprocate drill string to clean hole with pumps @ 600 GPM's - 1350 PSI. 11:00 11:45 0.75 1,972 2,066 SURFA DRILL DDRL P Continue directional drill surface hole from 1972' - 2066' MD. ND = 1740'. WOB = 25K. RPM = 40. GPM's - 575 - 1240 PSI. ADT = 2.66 HRS. Bit Hrs = 19.01. Obtain Checkshot surve s. 11:45 13:00 1.25 2,066 2,066 SURFA DRILL REAM P BROOH from 2066' - 1972', cleaning hole with 40 RPM's, 575 GPM's - 1340 PSI. Obtain bottoms up with hole cleaned. 13:00 14:15 1.25 2,066 2,163 SURFA DRILL DDRL P Continue directional drill surface hole from 2066' - 2163' MD. ND = 1779'. WOB = 25K. RPM = 40. GPM's - 575 - 1350 PSI. Obtain Checkshot suroe s. 14:15 16:45 2.50 2,163 2,163 SURFA DRILL REAM P BROOH from 2163' - 2066' MD, cleaning hole with 40 RPM's, 897 GPM's - 2620 PSI. Obtain bottoms up with hole cleaned. 16:45 18:00 1.25 2,163 2,245 SURFA DRILL DDRL P Continue directional drill surface hole from 2163' - 2245' MD. ND = 1820'. WOB = 25K. RPM = 40. GPM's - 575 - 1240 PSI. ADT = 2.12 HRS. Bit Hrs = 21.13, Obtain Checkshot surveys. Crew Chan e 18:00 20:15 2.25 2,245 2,348 SURFA DRILL DDRL P Continue directional driii surface hole from 2245' - 2348' MD. WOB = 25K. RPM = 40. GPM's - 575 - 1320 PSI. Obtain Checkshot surve s. 20:15 21:00 0.75 2,348 2,348 SURFA DRILL CIRC P Circulate & condition hole while reciprocate & rotate drill string. Change out shaker screens as we observed clay runnig over and blinding shakers screens off. 21:00 21:15 025 2,348 2,352 SURFA DRILL DDRL P Continue drill from 2348' - 2352' MD. Obtain Checkshot surve s. 21:15 22:45 1.50 2,352 2,352 SURFA DRILL REAM P Wash & ream hole to reduce hole angle with pumps @ 600 GPM's - 1200 PSI. 40 RPM's. ~ ~ 07/01/2007 22:45 00:00 1.25 2,352 2,450 SURFA DRILL DRLG P Continue directionai drill surface hole from 2352' - 2450' MD. ND = 1889'. WOB = 25K. RPM = 40. GPM's - 575 - 1380 PSI. ADT = 1.93 HRS. Bit Hrs = 23.06, Obtain Checkshot surve s. 07/02/2007 00:00 06:00 6.00 2,450 2,856 SURFA DRILL DDRL P Continue directional drill surface hole from 2450' - 2856' MD. ND = 1992'. WOB = 30K. RPM = 40. GPM's - 575 - 1600 PSI. ADT = 3.86 HRS. Bit Hrs = 27.27, Obtain Checkshot surveys. Crew Chan e 06:00 07:45 1.75 2,856 2,950 SURFA DRILL DDRL P Continue directionat drill surface hole from 2856' - 2950' MD. WOB = 28K. RPM = 40. GPM's - 580 - 1140 PSI. Obtain Checkshot surveys. Change out suction screen on #1 Mud pump. Observed loss of um ressure. 07:45 09:30 1.75 2,950 3,018 SURFA DRILL DDRL P Continue directional drill surface hole from 2950' - 3018' MD. TVD = 2005'. WOB = 30K. RPM = 40. GPM's - 680 - 1940 PSI. Obtain Checkshot surveys. Change out suction screen on #2 Mud pump. Observed loss of um ressure: 09:30 12:00 2.50 3,018 3,018 SURFA DRILL REAM P Ream hole from 2980' - 2950' as per DD. Ream operation to wipe out excessive dogleg. Pumps at 865 GPM's - 2050 PSI. 12:00 18:00 6.00 3,018 3,018 SURFA DRILL REAM P Continue ream hole from 2980' - 2950' as per DD. Ream operation to wipe out excessive dogleg. Pumps at 865 GPM's - 2050 PSI. Crew Chan e 18:00 18:15 0.25 3,018 3,018 SURFA DRILL REAM P Continue ream hole from 2980' - 2950' as per DD. Ream operation to wipe out excessive dogleg. Pumps at 865 GPM's - 2050 PSI. 18:15 00:00 5.75 3,018 3,460 SURFA DRILL DDRL P Continue directional drill surface hole from 3018' - 3460' MD. ND = 2131'. WOB = 25K. RPM = 40. GPM's - 650 - 2100 PSI. ADT = 3.09 HRS. Bit Hrs = 34.60, Obtain Checkshot surve s. 07/03/2007 00:00 05:30 5.50 3,460 3,775 SURFA DRILL DDRL P Continue directional drill surface hole. Obtain Check shot surve s. 05:30 06:00 0.50 3,775 3,304 SURFA DRILL TRIP P POOH to install 5" HWDP on top of strin for more down wt for slidin . 06:00 06:30 0.50 3,304 3,304 SURFA DRILL CIRC P Circulate with headpin, while retrieving a stand of HWDP after being dropped across the derrick. 06:30 07:45 1.25 3,304 3,673 SURFA DRILL TRIP P Trip in the hole w/ 5" HWDP. 07:45 09:00 1.25 3,673 3,716 SURFA DRILL CIRC P Circulate. Stage pumps to 900 gpm. Rotate 60 rpm w/ 4k ft Ibs torque. Wash f/ 3673' to 3716'. 09:00 11:00 2.00 3,775 3,820 SURFA DRILL DDRL P Continue directional drill surface hole. 11:00 11:30 0.50 3,820 3,827 SURFA DRILL DDRL P Continue directional drill surface hole. ~ 07/03/2007 11:30 12:15 0.75 3,827 3,827 SURFA DRILL REAM P Trough 3750' to 3827' to reduce inclination while circulating to cleaning hole. 12:15 13:45 1.50 3,827 3,998 SURFA DRILL DDRL P Continue directional drill surface hole. TD 3998' MD 2234' ND 13:45 16:30 2.75 3,998 3,650 SURFA DRILL CIRC P Circulate to clean hole (3 BU). Backream while circulating setting a stand back when pulled up. Circulated a total of 2700 bbls. 16:30 16:45 0.25 3,650 3,998 SURFA DRILL TRIP P Trip in the hole. Tag bottom @ 3998' 48' in on stand #39 . 16:45 18:00 1.25 3,998 3,370 SURFA DRILL REAM P Backream out of the hole. Pumping 900 gpm w/ 2900 psi initial. Pumped a 40 bbls lube pill prior to leaving bottom. Rotate 60 rpm w/ 5k ft Ib tor ue. 18:00 00:00 6.00 3,370 833 SURFA DRILL REAM P Backream out of the hole. Pumping 900 gpm w/ 2900 psi initial, 2200 psi final to 1784'. Backream out of the hole. Pumping 600 gpm w/ 1400 psi initial, 1200 psi final to 833'. Rotate 45 rpm w/ 4-6k ft Ib torque. Pulling speed 25 feet er min. 07/04/2007 00:00 01:00 1.00 833 643 SURFA DRILL REAM P Backream out of the hole. Pumping 600 gpm w/ 1200 psi to 643'. Rotate 45 rpm w/ 4-5k ft Ib torque. Pulling s eed 5 feet er min. 01:00 01:15 0.25 643 643 SURFA DRILL OTHR P Blow down top drive. A1:15 02:15 1.00 643 73 SURFA DRILL TRIP P POOH on elevators. 02:15 02:30 0.25 73 73 SURFA DRILL SFTY P PJSM on laying down BHA #1. 02:30 04:30 2.00 73 0 SURFA DRILL PULD P POOH/LD BHA #1. Break and grade bit. 04:30 05:00 0.50 0 0 SURFA DRILL OTHR P Clean rig floor. 05:00 09:00 4.00 0 0 SURFA CASIN RURD P Rig up to run 13-3/8" 68 ppf L-80 BTC surFace casing casing. Flush mount slips set on top of riser. Remove flush mount slips to use conventional s iders. 09:00 09:15 0.25 0 0 SURFA CASIN SFTY P PJSM on running surface 13-3/8" casin . 09:15 10:00 0.75 0 120 SURFA CASIN RNCS P MU float equipment, check floats, OK. 10:00 10:30 0.50 120 120 SURFA CASIN RURD T Rig down stab-Rite. Not working right. 10:30 12:15 1.75 120 1,051 SURFA CASIN RNCS P Continue running 13-3/8" 68 ppf L-80 BTC casing. Installed 22 total centralizers on the first 20 joints. one 5' above the shoe, one 10' below the FC and 10' above the float collar. every collar on the other 20 joints. 25 total ioints in the hole. ~ 07/04/2007 12:15 12:30 025 1,051 1,051 SURFA CASIN CIRC P Circulate Bottom's up w/ Frank's fillup tool. Circulate @ 7 bpm w/ 400 psi, 32% flow. 12:30 14:30 2.00 1,051 2,071 SURFA CASIN RNCS P Continue running 13-3/8" casing. Total of 50 'oints in the hole. 14:30 15:15 0.75 2,071 2,071 SURFA CASIN CIRC P Circulate Bottom's up w/ Frank's fiilup tool. Circulate 7 b m w/ 400 si. 15:15 16:30 1.25 2,071 3,143 SURFA CASIN RNCS P Continue running casing. Total of 75 'oints in the hole. 16:30 17:15 0.75 3,143 3,143 SURFA CASIN CIRC P Circulate Bottom's up w/ Frank's fillup tool. Circulate @ 7 bpm w/ 480 psi, 34% flow. 17:15 18:15 1.00 3,143 3,832 SURFA CASIN RNCS P Continue running casing. Casing sto ed 3832'. 18:15 21:00 2.75 3,832 3,832 SURFA CASiNC CIRC P Circulate w/ Frank's fillup tool and attempt to work through 3832'. PU wt 270-290k, SO wt 140k. Circulate 7.4 bpm w/ 650 psi. Circulated a total of 1233 bbls. 21:00 22:15 1.25 3,832 3,770 SURFA CASINC RNCS T Rig up, then lay down 2 joints of casing Qts # 92 and #91). Pull up and install a centralizer on jt # 89 and #88 on the collar. RIH jts # 88 and #89 and 90. La down Frank's fillu tool. 22:15 22:30 0.25 3,770 3,775 SURFA CASIN( RNCS P Make up Vetco Gray 18.18" OD hanger. Lay down handling joint. PU/MU Landin 'oint LH thread . 22:30 22:45 0.25 3,775 3,775 SURFA CASIN RURD P Remove casing slips from rotary table. 22:45 23:00 0.25 3,775 3,820 SURFA CASIN( RNCS P RIH and land 13-3/8" casing on Vetco Gray hanger w/ shoe @ 3820.26'. PU wt 290k, SO wt 135-130k. 23:00 23:30 0.50 3,820 3,820 SURFA CEME~ RURD P RU Dowell cementing head. Connect circulatin hose. 23:30 00:00 0.50 3,820 3,820 SURFA CEME CIRC P Circulate @ 7 bpm with 270 psi. Reciprocate casing 30' stroke w/ traveling speed of 6-7 ft per min in down stroke. PU wt while circulating 270k, SO wt 145k. Circulated a total of 280 bbls @ midnight. Held a PJSM with Rig team (Vac truck drivers, cementers, Rig crew, Tourpusher and Mud engineer) on ~ 07 00:00 ~ 00:30 ~ 0.50 ~ 3,820 ~ 3,820 ~ CEME~ CIRC P Circulate @ 7 bpm with 270 psi. Reciprocate casing 30' stroke w/ traveling speed of 6-7 ft per min in down stroke. PU wt while circulating 270k, SO wt 145k. Circulated a total of 425 bbls with Dowell cement head. Mud properties prior to conditioning: Weight 9.3, Vis 110, Gels 32/58/69, PV/YP 20/47 Mud Properties after conditioning: Weight 9.4, Vis 63, Gels 7/10/13, 00:30 01:00 0.50 3,820 3,820 SURFA CEME~ OTHR P Dowell pump 10 bbls CW 100 (8.3ppg), attempt to pressure test lines to 3000 psi. Leak under rig floor. Replace gasket and retighten hammer union on rig. Pressure test to 3000 si. OK. 01:00 03:30 2.50 3,820 3,820 SURFA CEME~ OTHR P Dowell pump another 40 bbls CW100 @ 6bpm w/ 400 psi, mix and pump 48 bbls MudPush (10.5 ppg) @ 5bpm w/ 300 psi. Shut down, drop bottom plug, Mix and pump 668 bbls ~ead cement ASL (842.73 sx, yield 4.45 cuft/sx, 21.765 gal/sx H2O, 10.7 ppg) @ 7.1 bpm w/ 500 psi, mix and pump 98 bbls Tail cement Lite Crete (222.74 sx, yield 2.47 cuft/sx, 8.459 gal/sx H2O, 12 ppg) @ 5.7-7.3 bpm w/ 544-800 psi, shut down, drop top plug, follow w/ 20 bbls water through the tub. Recip pipe 30' stroke until lead cement around the shoe, then recip 10' stroke. Quit recip w/ 114 bbls of cement around the shoe. Down wt was 115k, PU wt 290k @ that time. Prior to cement @ the shoe, the down wei ht was 155k, PU 280k. 03:30 04:45 125 3,820 3,820 SURFA CEME DISP P Rig displace cement w/ rig pumps. Pumping 7.3 bpm w/ initial 400 psi and final of 670 psi prior to slowing pumps to 3 bpm. Last 10 bbls was pumped @ 3 bpm w/ 500 psi. Bumped plug on calculated strokes w/ 500 psi, then increased pressure to 1050 psi. Mud push w/ red dye was @ surface 1500 strokes into displacement with rig pumps. Good 10.7 ppg cement was at surface with 3100 strokes of rig displacement. A total of 225 bbls of good cement was circulated to surface, final wt 10.7 ppg. Full circulation maintained throuqhout iob. ~ ~ 07/05/2007 04:45 05:00 0.25 3,820 3 SURFA CEME OTHR P Held pressure f/ 5 min @ 1050 psi, bleed off pressure to check floats. OK. CIP 0445 hrs 7/5/2007. 05:00 05:30 0.50 3,820 3,820 SURFA CEME RURD P Blow down cement line. Rig down Doweli cement head. 05:30 06:30 1.00 3,820 3,820 SURFA CASIN RURD P Back out Vetco Gray 13-3/8" landing joint (LH thread). Lay down to the pipe shed. 06:30 08:00 1.50 3,820 3,820 SURFA CASINC RURD P Rig down casing elevators, long bales and PU siing. Rinse off and laydown casing elevators, bales, casing tongs, spiders, Frank's fiilup tool, Dowell cement head. Lay down control panel for the flush mounted slips and all ri in associated with same. 08:00 10:45 2.75 3,820 3,820 SURFA WELC NUND P Nipple down 20" diverter stack. Flush annular. 10:45 12:15 1.50 3,820 3,820 SURFA WELC NUND P Nipple up Vetco Gray multibowl wellhead (MB222A). Tested grayloc seal to 5000 si. Good test. 12:15 18:00 5.75 3,820 3,820 SURFA WELC NUND P Nipple up 13-5/8" BOPE. Installing new cables and rigging to secure BOP stack in the cellar. Simops: cleaning pits, installing super sliders on 120 jts of drill pipe, putting drill pipe in the shed, changing swabs and liners in mud pumps (changing from 6" to 6-1/2"). Rigging u to PU drill i e. 18:00 19:30 1.50 3,820 3,820 SURFA WELC NUND P Nipple up 13-5/8" BOPE. Installing new cables and rigging to secure BOP stack in the cellar. Simops: cleaning pits, putting drill pipe in the shed, changing swabs and liners in mud pumps (changing from 6" to 6-1/2" . Ri in u to PU drill i e. 19:30 19:45 0.25 3,820 3,820 SURFA DRILL SFTY P PJSM on picking up 5" drill pipe and standin back in the derrick. 19:45 00:00 4.25 3,820 3,820 SURFA DRILL PULD P Install mouse hole in the rotary table. PU/MU/Standback 35 stands of 5" drill pipe with super sliders installed. Stand back on the driller's side. Drifted to 2 7/8". Stra len th in derrick. 07/06/2007 00:00 01:15 1.25 SURFA DRILL PULD P With mouse hole in the rotary table. PU/MU/Standback 5 stands of 5" drill pipe with super sliders installed (total of 40 stands in derrick). Stand back on the driller's side. Drifted to 2 7/8". Stra len th in derrick. 01:15 03:00 1.75 SURFA DRILL PULD P With mouse hole in the rotary table. PU/MU/Standback 13 stands of 5" drill pipe slick. Stand back on the off driller's side. Drifted to 2 7/8". Strap lenqth in derrick. • ~ 07/06/2007 03:00 04:15 1.25 SURFA DRILL PULD P With mouse hole in the rotary table. PU/MU/Standback 4 stands of 5" HWDP. Stand back on the off driller's side. Drifted to 2 7/8". Strap length in derrick. 04:15 05:45 1.50 SURFA WELCT OTHR P RU to test BOPE.Chart recorder, testin lines and fill stack with water. 05:45 06:00 0.25 SURFA WELCT BOPE P Test BOPE. Witness of test waived by AOGCC ins ector John Cris . 06:00 06:15 0.25 SURFA WELCT NUND T Tighten bolts on choke line manual valve to the mud cross. 06:15 12:00 5.75 SURFA WELCT BOPE P Test BOPE. Witness of test waived by AOGCC inspector John Crisp. Test annular w/ 5", Test upper variable rams( 3-1/2"x 6") w/ 5" and 5-1/2". Test lower pipe rams w/ 9-5/8" test joint. Testing all componets to 250 psi low and 3000 psi high. Koomey test: 200 psi build up in 25 seconds, full pressure 3 min 20 sec. Nitrogen BU 2300 psi avg. All tests passed to this point. Valve # 3 in choke manifold leaked, reased and retested OK. 12:00 12:45 0.75 SURFA WELCT OTHR P Pull Vetco Gray test plug. Set wear bushing (12-3/8" ID), rig down testing equipment. Line up valves on choke manifold and stack for drillin . 12:45 13:15 0.50 SURFA WELC OTHR P Clear and clean rig floor. 13:15 13:30 0.25 SURFA DRILL SFTY P PJSM on PU/MU BHA #2. 13:30 15:15 1.75 0 70 SURFA DRILL PULD P MU bit #2, Geopilot 9600 (TL 038), N/M flex collar, stab, MWD, pulsar and float sub. 15:15 16:15 1.00 70 70 SURFA DRILL OTHR P Upload Sperry Sun MWD. 16:15 17:15 1.00 70 455 SURFA DRILL PULD P Continue to PU/MU BHA #2: MU stab, (3) NM flex drill collars, jars and 8jts 5" HWDP. Corrosion ring on top of stand w/'ars in the HWDP. 17:15 18:00 0.75 455 1,125 SURFA DRILL PULD P PU/MU/RIH w/ 5" drill pipe from pipe shed. Drift drill i e w/ 2-7/8" rabbit. 18:00 20:00 2.00 1,125 2,360 SURFA DRILL PULD P PU/MU/RIH w/ 5" drill pipe from pipe shed. Drift drill i e w/ 2-7/8" rabbit. 20:00 21:15 1.25 2,360 2,360 SURFA DRILL CIRC P Fill pipe. Circ. Break in seals on Geopilot. Pump a total of 945 bbls. Check MWD for detection and ability to send signal to the geopilot. Flow Rates and pressures: 740 gpm = 1500 psi, 850 gpm = 1700 psi, 900 m= 1880 si, 950 m= 2100 si. 21:15 23:00 1.75 2,360 3,717 SURFA DRILL PULD P PU/MU/RIH w! 5" drill pipe from pipe shed. Drift drill pipe w/ 2-7/8" rabbit. MU top drive. Five foot in from 3700' to taa up Ca~ 3717'. • ~ 07/06/2007 23:00 23:45 0.75 3,717 3,697 SURFA DRILL CIRC P Circulate 1-3/4 bottom's up conditioning and evening out MW to 9.4 ppg. (814 bbls circulated). Circ 750 gpm w/ 1700 psi. Lay down a sin le. 23:45 00:00 0.25 3,697 3,697 SURFA DRILL SFTY P PJSM on RU and testing 13-3/8" 68 f L-80 BTC surface casin . 07/07l2007 00:00 01:00 1.00 3,697 3,697 SURFA DRILL DHEQ P Testing 13-3/8" 68 ppf L-80 BTC surface casing. Teset to 3075 psi f/ 30 min. Chart test. Lost 25 psi. Good test. Bleed back 6.2 bbls. 01:00 01:45 0.75 3,697 3,319 SURFA DRILL TRIP P POOH 4 stands of 5" drill pipe. 01:45 02:00 0.25 3,319 3,319 SURFA RIGMN' SFTY P PJSM on slip and cut drilling line. 02:00 03:00 1.00 3,319 3,319 SURFA RIGMN SVRG P Hang blocks. Slip and cut 89' of drillin line. 03:00 04:30 1.50 3,319 3,319 SURFA RIGMN SVRG P Service top drive, blocks, drawworks, and crown (inspect chains, brakes on the drawworks, change dies in the rabs for the to drive. 04:30 04:45 0.25 3,319 3,319 SURFA DRILL SFTY P PJSM on stripping drill. 04:45 07:00 2.25 3,319 3,319 SURFA DRILL SFTY P Fill choke and poor boy degasser w/ 9.4 ppg to perform stripping drill. PerForm stripping drill w/ Chad Johnson's crew. 07:00 08:30 1.50 3,319 3,319 SURFA DRILL SFTY P Perform stripping drill with Shane Barber's crew. 08:30 08:45 0.25 3,319 3,319 SURFA DRILL OTHR P Blow down choke and kill lines and choke manifold. Line up manifold for drillin . 08:45 09:00 0.25 3,319 3,700 SURFA DRILL TRIP P Trip in the hole 4 stands. 09:00 09:15 0.25 3,700 3,700 SURFA DRILL OTHR P Move 4 stands of 5" HWDP in the derrick from the ODS to the driller's side. 09:15 09:30 0.25 3,700 3,700 SURFA RIGMN' SVRG P Inspect grabbers on the top drive. 09:30 09:45 0.25 3,700 3,700 SURFA DRILL PULD P PU/MU three singles of 5" drill pipe from the i e shed and build a stand. 09:45 12:45 3.00 3,700 3,820 SURFA CEME~ COCF P Tag cement on top of wiper plugs @ 3731', wiper plugs, FC @ 3131', cement, and Float shoe @ 3818'-3820'. 12:45 13:45 1.00 3,820 3,870 SURFA DRILL DRLG P Directional drill intermediate hole. 13:45 14:00 0.25 3,870 3,795 SURFA DRILL TRIP P POOH 14:00 15:30 1.50 3,795 3,795 SURFA DRILL CIRC P Circulate hole clean, then displace to new 9.0 ppg, 63 vis LSND mud. Rotate 100 m w/ 8k ft Ib tor ue. 15:30 16:30 1.00 3,795 3,795 SURFA DRILL LOT P Rig up and perform LOT. MW 9.0, TVD = 2200.64' , 680 psi applied = 14.9 EMW. Ri down. 16:30 16:45 025 3,795 3,820 INTRM1 DRILL TRIP P Trip in the hole. ~ ~ ~ ~ • ~ 07/10/2007 15:00 16:15 1.25 72 0 INTRM1 DRILL PULD T Lay down Sperry Sun MWD and GeoPilot TL 038 . 16:15 16:45 0.50 0 0 INTRM1 DRILL OTHR T Clean floor. Grease drawworks. 16:45 19:00 2.25 0 75 INTRMI DRILL PULD T PU/MU BHA # 3. MU new bit (rebuilt), Geopilot 9600 (ser # TL 140), nm flex collar, smart stab, Sperry Sun RLL, pulsar, nm float sub, welded blade stabilizer 19:00 20:00 1.00 75 75 INTRM1 DRILL OTHR T Upload Sperry Sun MWD. 20:00 20:30 0.50 75 458 INTRM1 DRILL TRIP T Continue RIH w/ BHA #3 (one stand of 8" nm flex collars and 3 stands includin ~ars of 5" HWDP . 20:30 24:00 0.50 458 1,785 INTRM1 DRILL TRIP T Trip in the hole. Record PU and SO wt's every 10 stands. RIH 14 stands of 5" d. PU and SO wt 110k. 21:00 21:15 0.25 1,785 1,785 INTRM1 DRILL OTHR T Shallow test Sperry Sun MWD. Break in seals on the GeoPilot. Pumping 1050 gpm w/ 2350 psi. Rotate 30 rpm w/ 3k ft Ibs of tor ue. 21:15 21:30 0.25 1,785 2,235 INTRM1 DRILL TRIP T Continue to trip in the hole w! BHA #3. BHA stopped going in the hole while running stand # 19. Actual 18 stands and a double. 21:30 22:30 1.00 2,235 2,235 INTRM1 DRILL OTHR T PU wt was 118k, SO wt was 110k. Pick up to 185k, slack off to 110k and verify depth to be 2235'. Pickup to 200k, then slack off and set slips. Check drilling line at the crown and blocks, OK. 22:30 22:45 0.25 2,235 2,230 INTRM1 DRILL OTHR T Pick up to 215k (97k overpull) and string was moving, although dragging somethin alon side of it. 22:45 23:00 0.25 2,230 2,230 INTRM1 DRILL PULD T Set the slips. Break off the top single of 5" drill pipe on stand # 19, then lay down. 23:00 23:15 0.25 2,230 2,230 INTRM1 RIGMN' SFTY P PJSM on changing out the saver sub on the top drive. The saver sub was planned to be changed when we got to the shoe. 23:15 00:00 0.75 2,230 2,230 INTRM1 RIGMN SVRG P Change out the saver sub on the top drive. 07/11/2007 00:00 00:15 0.25 2,230 2,230 INTRM1 RIGMN OTHR P Change out the saver sub on the top drive. 00:15 00:30 0.25 2,230 2,230 INTRM1 DRILL PULD T Change out a joint of 5" drill pipe, drift to 2-7/8". Top single on stand # 19. No correction on len th- the same. 00:30 01:15 0.75 2,230 2,170 INTRM1 DRILL CIRC T Make a top drive connection. Circ 3 BU, total of 934 bbls. Pumping 1050 gpm w/ 2900 psi. Hole is clean. No reciprocation or rotation. Pump out stand #19, ullin 60' f/ 2230' to 2170'. 01:15 02:45 1.50 2,170 456 INTRM1 DRILL TRIP T POOH to inspect BHA. No overpull. Monitor well on trip tank. ~ • 07/11/2007 02:45 05:15 2.50 456 0 INTRM1 DRILL OTHR T Work BHA # 3. Inspect and rack back in the derrick. No bad damage noted- some pizza cutters chipped. Plug in and turn off the MWD tools. Note: Some pictures posted to the "X" drive. 05:15 06:00 0.75 0 0 INTRM1 RIGMN SVRG T Service Top drive and crown. Clean and clear ri floor. Shut blind rams. 06:00 07:00 1.00 0 0 INTRM1 FISH PULD T Bring Baker Oil Tools equipment to the floor. Reverse circ junk basket, 2 junk baskets, string magnet, LBS and fishin 'ar. 07:00 07:15 0.25 0 0 INTRM1 FISH SFTY T PJSM on making up BHA #4. 07:15 09:00 1.75 0 40 INTRMI FISH PULD T PU/MU BHA #4 (12" OD Head-Reverse circ junk basket, (2) junk baskets, string magnet, LBS, fishin 'ar. 09:00 11:00 2.00 40 1,600 INTRM1 FISH TRIP T Trip in the hole w/ BHA #4. 11:00 11:30 0.50 1,600 1,600 INTRM1 FISH CIRC T Fill pipe. Circulate pumping 530 gpm w/ 980 si. PU wt 135k. 11:30 12:00 0.50 1,600 2,108 INTRM1 FISH TRIP T Continue trip in w/ BHA # 4 12:00 12:30 0.50 2,108 2,240 ~ INTRM1 FISH CIRC T Establish circulation pumping 100 gpm w/ 80 psi. Trip in the hole. Tagged up @ 2240' w/ 5k (127k on weight indicator). PU wt 140k, SO wt 133k. 12:30 14:00 1.50 2,240 2,463 INTRM1 FISH CIRC T Pick up 7' to 2333'. Drop 1 1-7/8" steel ball. Circulate ball down, pressure up to 1375 psi w/ 563 gpm. Rotate w/ 50 rpm w/ 3-4k ft Ibs of torque. Rotating wt 133k. While reverse circulating, travel f/ 2233' to 2463'. 14:00 15:30 1.50 2,463 3,428 INTRM1 FISH TRIP T Trip in the hole BHA # 4. At the depth of 3428': PU wt 140k, SO wt 120k 15:30 16:15 0.75 3,428 3,815 ( INTRM1 FISH CIRC T Establish circulation pumping 522 gpm w/ 1360 psi. Rotating wt 125k, Rot torque 5-6k ft Ibs. Work in the hole f/ 3428' to 3845' circulating w/ reverse circ basket, while picking up- hung the 13-3/8" casing shoe w/ 30k overpull. Then pulled up to 3815'. The 13-3/8" casing shoe is at 3820'. Note: Small damage was noted on the upper junk basket when pulled out of the hole. (13' above reverse junk basket 16:15 16:45 0.50 3,815 3,815 INTRM1 FISH CIRC T Circulate bottom's up. Pumping 650 gpm w/ 1940 psi. Circulate a total of 531 bbls. 16:45 17:00 0.25 3,815 3,815 ~INTRM1 FISH OTHR T Monitorwell, OK. i ~ 07/11/2007 17:00 17:15 0.25 3,815 3,815 INTRM1 FISH CIRC T Pump a 20 bbl dry job (11.2 ppg, 45 vis). Blow down top drive. instaA air sli s and stri in rubbers. 17:15 17:45 0.50 3,815 3,428 INTRM1 FISH TRIP T POOH w/ BHA # 4. Pulled 70k over while pulling out at 3428'. Slack off to 100k. MU top drive, establish circulation w/ 210 gpm w/ ?? psi. Try to rotate, torque went to 15k ft Ibs, release torque. Work bumper sub down. With 10k down wt string freed up. Rotate up to 30' above = 3398'. Stop circulating. Slack off and go down to 3428' with normal 115k down wt, then took wei ht 3428'. 17:45 18:15 0.50 3,428 3,360 INTRM1 FISH TRIP T Lost ail string weight in 5 more feet of travel to 3433'. Pickup stiil dragging 30-40k over. Set a stand back, while pulling the next 10', pulled 80k over. Slack off, then PU and POOH. First two stands pulled 20-25k over, then OK. 18:15 20:45 2.50 3,360 39 INTRM1 FISH TRIP T Continue POOH w/ BHA #4 20:45 22:30 1.75 39 0 INTRM1 FISH PULD T Lay down and inspect reverse basket, magnets and junk baskets. Note: Pictures posted on the "X" drive. Gravel in junk baskets which were in open hole. Not much in the reverse basket, and iron picked up with the strin ma net. 22:30 23:30 1.00 0 0 INTRM1 RIGMN' SVRG T Service top drive, blocks and drawworks. Blind rams shut. 23:30 00:00 0.50 0 0 INTRM1 DRILL PULD T Removejunk baskets, string magnet, reverse basket and tools from rig floor. PU 12-1/4" hole o ener to the floor. 07/12/2007 00:00 00:15 0.25 0 0 INTRM1 DRILL OTHR T PJSM on laying down stand in derrick w/ the geoPilot and stabilizer needed for next BHA. 00:15 02:00 1.75 0 0 INTRM1 DRILL PULD T Lay down stand w/ GeoPilot and MWD in the derrick. 02:00 02:30 0.50 0 0 INTRM1 DRILL PULD T Remove subs from BHA #3 & 4 from rig floor. PU subs for hole opener run BHA #5 . 02:30 03:45 1.25 0 390 INTRM1 DRILL PULD T Make up BHA #5 (12-1/4" Hole opener run . 03:45 06:00 2.25 390 4,481 INTRM1 DRILL TRIP T Trip in the hole w/ the hole opener on 5" drill pipe. Monitor displacement on the trip tank. Fill pipe @ 2201', then circ @ 800 gpm w/ 950 psi. Fill pipe @ 4195', then circ 800 gpm w/ 1210 si. 06:00 06:30 0.50 4,481 5,621 INTRM1 DRILL TRIP T Trip in the hole w/ the hole opener on 5" drill pipe. Monitor displacement on the trip tank. Fill pipe @ 5621'. PU wt 155k, SO wt 95k. ~ 07/12/2007~06:30 I07:30 ~ 1.00 ~ 5,621 ~ 5,621 ~INTRM1 ~ DRILL ~ CIRC 07:30 ~ 08:30 ~ 1.00 ~ 5,621 ~ 7,432 ~INTRM1 ~ DRILL ~ TRIP 08:30 ~ 08:45 ~ 0.25 ~ 7,432 ~ 7,432 ~INTRM1 ~ DRILL ~ CIRC 08:45 ~09:30 ~ 0.75 ~ 7,432 ~ 7,991 ~INTRM1 ~ DRILL ~ TRIP 09:30 ~ 12:00 ~ 2.50 ~ 7,991 ~ 7,991 ~INTRM1 ~ DRILL ~ CIRC 12:00 ~ 12:45 ~ 0.75 ~ 7,991 ~ 7,991 ~INTRM1 ~ DRILL ~ CIRC 12:45 13:00 13:00 13:30 13:30 13:45 13:45 14:00 14:00 15:45 15:45 16:00 16:00 17:30 0.25 7,991 7,991 INTRM1 DRILL OWFF 0.50 7,991 7,300 INTRM1 DRILL TRIP 0.25 7,300 7,300 INTRM1 DRILL CIRC 0.25 7,300 7,300 INTRM1 DRILL OTHR 1.75 7,300 3,815 INTRM1 DRILL TRIP 0.25 3,815 3,815 INTRM1 RIGMN SVRG 1.50 ~ 3,815 ~ 3,815 ~INTRM1 ~ DRILL ~ CIRC 17:30 ~ 17:45 ~ 0.25 ~ 3,815 ~ 3,408 ~INTRM1 ~ DRILL ~ TRIP 17:45 ~ 18:45 ~ 1.00 ~ 3,408 ~ 3,408 ~INTRM1 ~ DRILL ~ CIRC 18:45 19:00 0.25 3,408 3,408 INTRM1 DRILL OWFF 19:00 19:15 0.25 3,408 3,408 INTRM1 DRILL CIRC • Fill pipe. CBU x2. Pumping 800 gpm f/ first BU w/ 1430 psi. Circ 1000 gpm after a BU w/ 1000 psi and 2100 psi. Trip in the hole w/ the hole opener on 5" drill pipe. Monitor displacement on the trip tank. Fill pipe @ 7432'. PU wt 170k, SO wt 95k. Fill pipe. Circ 700 gpm w! 1380 psi. Rotate 130 rpm w! 10k ft Ib torque. Circulate a total of 165 bbls. Trip in the hole w/ the hole opener on 5" drili pipe. Monitor displacement on the trip tank. Fill pipe @ 7991'. PU wt 170k, SO wt 95k. Caiculated displacement 79 bbls, actual 68 bbis. Circulate bottom's up. Pumping 1050 gpm w! 2750 psi. Rotate 120 rpm w/ 11-12k ft Ibs torque. Rotating weight 130k.Pump a 40 bbls sweep (10.5 ppg, 130 vis) at 1015 hrs. Totai volume of 3257 bbls pumped. Slight increase in cuttings w/ the sweep. Continue to circulate. Pumping 1050 gpm w/ 2750 psi. Rotate 120 rpm w/ 11-12k ft Ibs torque. Rotating wt 130k. Volume pumped 1180 bbls. Monitor well, OK. POOH on elevators. T Pump a dry job (112 ppg, 50 vis) Pum in 65 s m w/ 250 psi. T Blow down top drive. Install pipe stri in rubbers. T POOH. Correct fill. PU wt 145k, SO wt 95k. T Lubricate top drive and drawworks. T Pump a 40 bbl hi vis hi weight sweep (10.5 ppg/ 130 vis). Pumping 1050 gpm w/ 1760 psi. Rotate 120 rpm w/ 5-6k ft Ibs of torque. Rotating wt 118k. Pumped a total of 1365 bbls. Si nificant increase in cuttin s. T POOH. Correct fill. PU wt 135k, SO wt 100k. T Pump a 40 bbl hi vis hi weight sweep (10.5 ppg/ 135 vis). Pumping 1050 gpm w/ 1630 psi. Rotate 120 rpm w/ 4-5k ft Ibs of torque. Rotating wt 118k. Pum ed a total of 1377 bbls. T Monitor well, OK. T Pump a dry job. • 07/1 19:15 20:30 20:30 21:15 21:15 21:30 21:30 22:00 22:00 22:15 22:15 22:30 22:30 23:15 23:15 00:00 00:00 01:15 1.25 3,408 390 INTRM1 DRILL TRIP 0.75 390 0 INTRM1 DRILL TRIP 0.25 0 0 INTRMI DRILL PULD 0.50 0 0 INTRM1 FISH PULD 0.25 0 0 INTRM1 FISH SFTY 0.25 0 65 INTRM1 FISH PULD 0.75 65 85 INTRM1 FISH PULD 0.75 85 2,375 INTRM1 FISH TRIP 1.25 2,375 3,478 INTRM1 FISH TRIP ~ T POOH w/ 12-1/4" Hole opener (BHA # 51. T Working BHA. T Lay down hole opener. No scars on hole o ener. T PU/MU two joints of 5" drill pipe. Rabbit to 2-7/8". T PJSM on PU/MU BHA # 6(Impression block and RTTS . T PU/MU 12-1l8" impression block, RIH thru BOP stack. T PU/MU HOWCO 13-3/8" RTTS, T Trip in the hole with BHA # 6 (Imqression block and RTTSI. T ~ Trip in the hole with BHA # 6 l4GK, JV WI 73LK. 01:15 01:30 0.25 3,478 3,477 INTRM1 CASINC DHEQ T Make a top drive connection. Rotate 1/2 turn to the right, slack off to block wt. RTTS is set. Center of the element is 3407.64'. 01:30 02:00 0.50 3,477 3,477 INTRM1 CASINC DHEQ T Rig up to test casing w/ the center of the element on the RTTS 3407.64'. 02:00 03:15 1.25 3,477 3,477 INTRM1 CASIN( DHEQ T Establish circulation through the kill line. Close upper pipe rams (3-1/2" x 6"). Pumping down the annulus of the 13-3l8" x 5" drill pipe. Pump 4 spm, recording pressure every 2 strokes. Stop at every 500 psi increase, hold f/ 3 min prior to increasing to the next 500 psi. Held finai test pressure of 3120 psi for 15 min, pressure bleed down to 3105 psi (Lost 15 psi in 15 min). Good test. This test - tests to about the middle of jt #10 of the casin in the hole. 03:15 03:30 0.25 3,477 3,477 INTRM1 CASIN DHEQ T Rig down testing equipment. 03:30 05:15 1.75 3,477 83 INTRM1 FISH TRIP T Pick up to 145k and release RTTS packer, PU weight 142k, SO wt 132k. Install air slips. POOH w/ BHA #6 (Impression block and RTTS packer f/ 133/8" . 05:15 05:45 0.50 83 0 INTRM1 FISH PULD T Lay down the 13-3/8" HOWCO RTTS, ins ect the Lead im ression block. 05:45 06:00 0.25 0 0 INTRM1 FISH PULD T Remove subs and impression block from the floor. Clear and clean floor. Shut blind rams. 06:00 07:00 1.00 0 0 INTRM1 DRILL OTHR T RU to run 4 jts of 9-5/8" casing insdie of 13-3/8" casing. Dummy run on 5" d. RU elevators, sli s and ton s. 07:00 08:00 1.00 0 0 INTRM1 DRILL OTHR T Waiting on orders. Service rig (top drive, blocks, drawworks, inspect chains on drawworks. Check saver sub on top drvie. OK. Check oil i 07/13/2007108:00 109:15 I 1.25 I 0 I 178 IINTRM1 I DRILL I OTHR 09:15 09:45 0.50 178 178 INTRM1 DRILL OTHR 09:45 13:15 3.50 178 3,820 INTRM1 DRILL OTHR 13:15 14:15 1.00 3,820 2,928 ~ INTRM1 DRILL OTHR 14:15 14:30 14:30 16:30 07/1 16:30 I 16:45 16:45 I 17:30 17:30 18:00 18:00 18:45 18:45 19:15 19:15 20:30 20:30 I 23:30 23:30 00:00 00:00 00:15 00:15 00:30 00:30 01:00 01:00 01:45 01:45 02:00 02:00 I 02:30 0.25 2,928 2,928 INTRM1 DRILL OTHR 2.00 2,928 155 INTRM1 DRILL OTHR 0.25 155 155 INTRM1 DRILL OTHR 0.75 I 155 I 0 IINTRM1 I DRILL I OTHR 0.50 0 0 INTRM1 DRILL OTHR 0.75 0 75 INTRMI DRILL PULD 0.50 75 75 INTRM1 DRILL OTHR 1.25 75 455 INTRM1 DRILL PULD 3.00 455 5,350 INTRM1 DRILL TRIP 0.50 5,350 5,350 INTRM1 DRILL CIRC 0.25 5,350 5,350 INTRM1 DRILL CIRC 0.25 5,350 6,165 INTRM1 DRILL TRIP 0.50 6,165 6,261 INTRM1 DRILL REAM 0.75 6,261 7,400 INTRM1 DRILL TRIP 0.25 7,400 7,500 INTRM1 DRILL REAM 0.50 ~ 7,500 ~ 7,878 ~INTRM1 ~ DRILL ~ TRIP ! PU MU 9-5/8"casing dummy run assembly (WeatherFord modei 303 float shoe, 4 joints of 9-5/8" 40 ppf L-80 BTC-m w/ a Brunnei Oilfield services centralizer floating on each jt., crossover, LBS, fishing jar, circ sub, then 5" drill pipe). Rig down casing tools T Trip in the hole w/ 4 joints of casing on 5" driil pipe. Calculated displacement 40 bbls, actual 34 bbls. T POOH W/ 9-5/8"casing dummy run assembl BHA #7 T Pump 20 bbl dry job. (11.2 ppg, 51vis) T POOH w/ 5" dp. Calculated fill 42 bbls, actual 57 bbls. T PJSM on laying down 9-5/8" casing usin side door elevators. T UD four joints of 9-5/8" 40 ppf L-80 BTC-m casin T Ciear rig floor, UD toois. T PU/MU BHA #8. T Upload MWD T PU/MU BHA #8. T Trip in the hole with BHA #8 on 5" drill i e. T Circulate bottom's up. ECD's 9.3 ppg. T Circulate bottom's up. ECD's 9.3 ppg. Rotate 40 rpm w! 7k ft Ibs of torque. Reciprocate f/5350' to 5255'. PU wt 152k, SO wt 100k. Circulate a total of 979 bbls. T I RIH to 6216'- SO wt went to 80k PU to 6165', make TD connection. Ream hole. Rotate 30 rpm w/ 7-9k ft Ibs torque. Circulate a toatl of 300 bbls. RIH to 7460'-- SO wt went to 80k PU to 7400', make TD connection. Ream hole. Rotate 40 rpm w/ 10k ft Ibs torque. RIH w/ BHA #8. ~ • ~ ~ 07/16/2007 06:00 12:00 6.00 6,163 4,739 INTRM1 DRILL REAM P Pulling speed 7-8'/min. BROOH w/ 130 rpm w/ 6-7k torque. Pumping 1055 gpm w/ 2840- 2490 psi. PU wt 155-145k, SO wt 105. Rot wt 140-125k. ECD's 9.66- 9.44 ppg. Record PU and SO wt's every 5 stands. At the depth of 5110', pulled 10k over, slacked off to 5117', then pulled up through same area and did not see an thin . 12:00 14:15 2.25 4,739 3,880 INTRM1 DRILL REAM P Pulling speed 7-8'/min. BROOH w/ 130 rpm w/ 9-10k torque. Pumping 1055 gpm w/ 2490- 2240 psi. PU wt 145k, SO wt 105. Rot wt 125k. ECD's 9.66- 9.44 ppg. Record PU and SO wYs eve 5 stands. 14:15 14:30 0.25 3,880 3,785 INTRM1 DRILL TRIP P POOH on elevators to above the shoe 3820'. 14:30 15:45 125 3,785 3,690 INTRM1 DRILL CIRC P Make a top drive connection. Pump a 40 bbl weighted hi vis sweep (10.5 ppg/ 130 vis), pumping 1055 gpm w/ 2220 psi. Rotate 130 rpm w/ 5k ft Ibs of torque. Reciprocate f/ 3785' to 3690'. Circulate a total of 1534 bbls. No increase in cuttings when the sweep came back to surface. 15:45 16:15 0.50 3,690 3,310 INTRM1 DRILL REAM P Pump out of the hole. Pumping 1050 m w/ 2110 si. 16:15 17:45 1.50 3,310 3,213 INTRM1 DRILL CIRC P Pump a 40 bbl weighted hi vis sweep (10.5 ppg/130 vis), pumping 1045 gpm w/ 2120 psi. Rotate 130 rpm w/ 5k ft Ibs of torque. Reciprocate f/ 3310'- 3213'. Circulate a total of 1846 bbls. No increase in cuttings when the sweep came back to surface. 17:45 18:00 025 3,310 3,310 INTRM1 DRILL CIRC P Pump a 66 bbl Steel lube pill( 6% lube) follow w/23.6 bbls mud, then 25 bbl d'ob, chase lines w/ 10 bbls. 18:00 18:15 0.25 3,310 3,310 INTRM1 RIGMN SFTY P PJSM on slip and cut drilling 18:15 19:15 1.00 3,310 3,310 INTRM1 RIGMN SVRG P Slip and cut 108' of 1-3/8" drilling line. 19:15 20:45 1.50 3,310 458 INTRM1 DRILL TRIP P POOH to the BHA. SLM was .21' shorter-- No correction. 20:45 22:00 1.25 458 70 INTRM1 DRILL PULD P Work BHA #8. Lay down the jars and 2 jts of 5" HWDP, pull the corrosion ring f/ the top single on the stand w/ the jars. UD (3) 8" flex NMDC's, stabilizer and float sub. 22:00 22:45 0.75 70 70 INTRM1 DRILL OTHR P Download MWD. 22:45 23:45 1.00 70 0 INTRM1 DRILL PULD P Continue to laydown all of BHA #8. Grade bit. 23:45 00:00 0.25 0 0 ~INTRM1 DRILL OTHR P Clear floor of BHA handling equipment. • ~ 07/17/2007 00:00 00:45 0.75 0 0 INTRMI DRILL PULD P Clear floor of BHA handling equipment. 00:45 02:15 1.50 0 0 INTRM1 WELCT OTHR P PU 2 joints of 5" dp. Make up wear bushing pulling tool and pull wear bushing. A little trouble pulling, would not pull with the air hoist. Vetco check things over, then pulled with the blocks. 02:15 03:15 1.00 0 0 INTRM1 DRILL PULD P Pick the Geopilot back up. Break out the lift sub so Sperry Sun MWD can access their robe. 03:15 06:00 2.75 0 0 INTRM1 WELC OTHR P Close the blind rams. Change the upper pipe rams from 3-1/2" x 6" to 10-3/4". PU test joint, MU test plug. Rigging up casing equipment while chan in rams. 06:00 06:30 0.50 0 0 INTRM1 WELC BOPE P Fill stack with water. Test rams to 250 psi low and 3000 psi high. Hold for 5 min each. Witness of test waived by AOGCC ins ector Bob Noble. 06:30 07:00 0.50 0 0 INTRM1 WELCT OTHR P Blow down choke and kill lines. Rig down testin e ui ment. 07:00 08:00 1.00 0 0 INTRM1 CASINC RURD P Rig up to run 9 5/8" intermediate casing.Held PJSM with crew & GBR reps. Discuss safety & hazard recognition issues. Discuss procedure to run 9 5/8" casin with centralizers. 08:00 12:00 4.00 0 2,690 INTRM1 CASIN RNCS P Pick up and RIH with 9 5/8" casing to 2690'. Observed proper hole flll. Run 40 seconds er'oint. 12:00 13:15 1.25 2,690 3,808 INTRM1 CASIN RNCS P Continue pick up and RIH with 9 5/8" casing from 2690' - 3808'. Observed proper hole fill. Run 40 seconds per joint. Obtain T&D parameters as per ri en ineer. 13:15 15:15 2.00 3,808 3,808 INTRMI CASIN( CIRC P Circulate & condition mud while reciprocate casing string @ 215 GPM - 240 PSI. Pum ed 5166 strokes. 15:15 17:45 2.50 3,808 5,813 INTRMI CASIN RNCS P Continue pick up and RIH with 9 5/8" casing from 3808' - 5813'. Observed proper hole fill. Run 40 seconds per joint. Obtain T&D parameters as per ri en ineer. 17:45 18:00 0.25 5,813 5,813 INTRM1 CASINC CIRC P Circulate & condition mud while reciprocate casing string @ 215 GPM - 240 PSI. Pumped 5166 strokes. Crew Chan e 18:00 19:15 1.25 5,813 5,813 INTRM1 CASIN CIRC P Continue circulate & condition mud while reciprocate casing string @ 215 GPM - 240 PSI. Pumped 3800 strokes. 19:15 20:45 1.50 5,813 6,860 INTRM1 CASIN RNCS P Continue pick up and RIH with 9 5/8" casing from 5813' - 6860'. Observed proper hole fill. Run 40 seconds per joint. Obtain T&D parameters as per ! • 07/17/2007 20:45 22:00 1.25 6,860 6,860 INTRM1 CASIN CIRC P Circulate & condition mud while reciprocate casing string staging pump rates slowly from 3 BPM - 200 PSI to 7 BPM - 410 PSI. Pumped 3500 strokes. Observed 13 BBLS of fluid loss, while adding water at 40 BBLS / HR. 22:00 23:30 1.50 6,860 7,870 INTRM1 CASINC RNCS P Continue pick up and RIH with 9 5/8" casing from 6860' - 7870'. Observed proper hole fill. Run 40 seconds per joint. Obtain T&D parameters as per ri en ineer. 23:30 00:00 0.50 7,870 7,870 INTRM1 CASINC CIRC P Circulate & condition mud while reciprocate casing string staging pump rates slowly from 3 BPM - 200 PSI. 07/18/2007 00:00 01:00 1.00 7,870 7,870 INTRM1 CASIN( CIRC P Circulate & condition mud while reciprocate casing string staging pump rates slowly from 3 BPM - 200 PSI. Final circulating pressure at 7 BPM - 450 PSI. 01:00 02:30 1.50 7,870 8,858 INTRM1 CASIN RNCS P Continue pick up and RIH with 9 5/8" casing from 7870' - 8858'. Observed proper hole fill. Run 40 seconds per joint. Obtain T&D parameters as per rig engineer. Total of 227 Joints of 9 5/8" casing ran. UP WT = 260K, SO WT = 100 K.Total losses while running casing = 3 BBLS. Total losses while circulatin = 20 BBLS. 02:30 06:00 3.50 8,858 8,858 INTRMI CASINC CIRC P Circulate & condition mud while reciprocate casing string as planned staging pump rates slowly from 3 BPM - 200 PSI, to 7 BPM - 400 PSI. Load pipe shed with 38 joints of 10 3/4" casing, checking strap and perpare casing for RIH. UP WT = 250K, SO WT = 105K. Crew Chan e 06:00 07:00 1.00 8,858 INTRM1 CASIN CIRC P Continue circulate & condition mud while reciprocate casing string as planned @ 7 BPM - 400 PSI. UP Wf = 260K, SO Wf = 100K. Total stroke um ed - 13647. 07:00 08:00 1.00 8,858 8,858 INTRM1 CASIN RURD P Change out surface equipment to be sized for 10 3/4" - 73# casing. Change out inserts in slips & elevators. Swp heads in power tongs. Change out Franks Fill u tool. 08:00 11:30 3.50 8,858 10,393 INTRM1 CASIN RNCS P Continue run 10 3/4" 73# casing ftom 8858' - 10393'. Running speed at 10 ft/minute. Observed proper hole displacement. Obtain T&D parameters as ~er ria enaineer. i ~ 07/18/2007 11:30 12:00 0.50 10,393 10,393 INTRM1 CAStN Rl1RD P ftig down GBR casing running equipment. Rig up 2" cement hose and pre-loaded cement head as per Dowell reps. UP WT = 330K, SO WT = 158K. 12:00 17:00 5.00 10,393 10,399 INTRM1 CEME~ CIRC P Circulate & condition mud while reciprocate casing string as planned staging pump rates slowly to 7 BPM - 320 PSI.UP WT = 300K, SO WT = 155K. All vac trucks & Dowell spotted on location & rigged up. Held PJSM with crew, vac truck drivers and Doweii reps. Discuss safety & hazard recognition issues. Discuss rigging up and pumping Intermediate cementjob. Total strokes pumped = 9214 (1094 BBLS). Pre- cement mud properties = 9.0 PPG, Visc = 44, PV = 12, YP = 13, Gels 3,4. 17:00 18:00 1.00 10,399 10,399 INTRM1 CEME~ DISP P Turn over to Dowell. Pump TO BBLS CW 100. Pressure test lines to 3500 PSI. Continue pump 65 BBLS of CW 100. Pump 71.7 BBLs of MudPush II. Reciprocate casing string in 40' increments with no movement issues. 18:00 19:00 1.00 10,399 10,399 INTRM1 CEME DISP P Drop bottom plug. Continue pump a total of 302.5 BBLS of Tail cement. Drop Top plug. Pump 5 BBLS of water spacer. Observed full returns during pumping and no losses. Reciprocate casing string in 40' increments with no 19:00 21:30 2.50 10,399 10,399 INTRM1 CEME~ DISP P Turn overto rig pumps. Displace cement with MOBM at 7 BPM - 260 PSI. Observed bottom plug land and show increase of 350 PSI to rupture disk at 512 BBLS, slowing pump to 3 BPM at 652 BBLS pumped away, continue to pump a total of 6714 stks ( 797.6 BBLS) as calculated. Did not bump plug. FCP = 3 BPM - 330 PSI. Held Pressure 10 minutes and bled off. Check floats - floats held. CIP @ 21:33 HRS, with casing set ob depth as planned at 10399'. We reciprocated casing string during cement job until a total of 712 BBLS pumped away.Set in lace as free movement ceased. 21:30 23:00 1.50 0 0 INTRM1 CEME RURD P Blow down lines. Rig down cement head & hoses. Send tools outside. Vac out OBM from inside joint of casing to wellhead. Clean & clear rig floor of tools. ~ ~ 07/18/2007 23:00 00:00 1.00 0 0 INTRM1 CASIN( NUND P Drain BOP stack. Nipple down BOP's breaking flange as per Vetco rep. Rig up Bridge cranes lifting BOP stack for settin of sli s and makin cut. 07/19/2007 00:00 00:30 0.50 0 0 INTRM1 CASINC NUND P Continiue nipple down BOP's breaking flange as per Vetco rep. Rig up Bridge cranes lifting BOP stack for setting of sli s and makin cut. 00:30 02:00 1.50 0 0 INTRM1 CASIN OTHR P Install 10 3/4" emergency slips as per Vetco Gray reps. Set slips with 265K pulled on casing. Note: 190K over biock wei ht. 02:00 03:30 1.50 0 0 INTRM1 CASIN OTHR P Rig up Wachs pneumatic casing cutter, and cut 10 3/4" casing as per Vetco Gray reps. Rig down cutter. Pull casing from BOP stack. Dress stump. La down Casin elevators. 03:30 05:00 1.50 0 0 INTRM1 CASIN( OTHR P Install 10 3/4" casing pack-off. Lay down long Bales for top drive. Pick up short bales. 05:00 06:00 1.00 0 0 INTRM1 CASIN NUND P Nipple up BOP stack. Rig up lines in prepration to flush 10 3/4" x 13 3/8" annulus. Open ram doors, change out upper rams to 3 1/2" x 6" variable bore rams. Crew Chan e 06:00 08:15 2.25 0 0 INTRM1 CASINC NUND P Continue changeing out upper pipe rams installing 3 1/2" x 6" VBR's. Test pack-off in wellhead to 5000 PSI as per Vetco Gray for 10 minutes. SIMOPS: Install 6" liners in mud um s. Cleanin mud its. 08:15 09:30 1.25 0 0 INTRM1 CASIN( NUND P Nipple up turnbuckles on BOP stack. NU Flowline, flow nipple and hole fill line. Rig up lines to OA, and purge line for flush. Continue dress mud pumps with 6" liners and cleanin its. 09:30 11:15 1.75 0 0 INTRM1 CEME~ FIT P Flush OA with 105 BBLs of water with rig pumps, final circulating pressure = 2 BPM - 200 PSI. Initial injectivity test indicated a 10.7 PPG EMW. Continue dress mud pump with 6" liners. Continue clean mud its. 11:15 11:30 0.25 0 0 INTRM1 WELC BOPE P Rig up test lines and pump to test BOP's. Continue dressing mud pump with 6" liners, and cleanin mud its. 11:30 12:00 0.50 0 0 INTRM1 WELC BOPE P Test BOP's. Test choke manifold valves, floor valves, and BOP stack. Continue dressing mud pump with 6" liners. and cleanina mud ~its. ~ 07/19/2007 12:00 14:45 2.75 0 0 INTRM1 WELCT BOPE P Continue test BOP's. Test choke manifold valves, floor valves, and BOP stack. perform Koomey draw down test. First 200 PSI increase in 26 seconds, with full 3000 PSI pressure back in 3 minutes, 26 seconds. 5 bottles of nitrogen average pressure at 2250 PSI. All tests passed. Witness of test waived by AOGCC rep - John Crisp. Continue dressing mud pump with 6" liners, and cleanin mud its. 14:45 15:30 0.75 0 0 INTRM1 WELCT BOPE P Rig down BOP test equipment. Blow down all lines. Install wear bushing & RILDS. 15:30 15:45 0.25 0 0 INTRM1 DRILL PULD P Transfer 5" HWDP in derrick to acess DP with with installed super sliders. Continue cleanin mud its. 15:45 16:00 0.25 0 0 INTRM1 DRILL SFTY P Held PJSM with crew and Sperry Sun reps. Discuss safety & hazard recognition issues. Discuss making u 8 1/2" Drillin BHA. 16:00 18:00 2.00 0 0 INTRM1 DRILL PULD P Make up BHA # 9, 8 1/2" drilling assembly as per DD & MWD reps. Crew Chan e 18:00 20:15 2.25 0 350 INTRM1 DRILL PULD P Continue make up BHA #9. Upload MWD assembly. MU Float sub, flex drill collars and HWDP. Total BHA len th = 350.68'. 20:15 20:30 0.25 350 350 INTRM1 DRILL CIRC P Perform shallow pulse test @ 550 GPM's - 600 PSI. 20:30 21:15 0.75 350 2,720 INTRM1 DRILL TRIP P Trip in hole from 350' - 2720'. Observed ro er hole fill. 21:15 21:45 0.50 2,720 2,720 INTRMI DRILL CIRC P Fill driii string, and rotate driil string @ 30 RPM's to break in seals on Geo- ilot. 21:45 22:30 0.75 2,720 5,220 INTRMI DRILL TRIP P Trip in hole from 2720' - 5220'. Observed ro er hole fiil. 22:30 22:45 0.25 5,220 5,220 INTRM1 DRILL CIRC P Fill drill string, and rotate drill string @ 30 RPM's to break in seals on Geo- ilot. 22:45 23:45 1.00 5,220 7,580 INTRM1 DRILL TRIP P Trip in hole from 5220' - 7580'. Observed ro er hole fill. 23:45 00:00 0.25 7,580 7,580 INTRM1 DRILL CIRC P Fill drill string, and rotate drill string @ 30 RPM's to break in seals on Geo- ilot. 07/20/2007 00:00 01:45 1.75 7,580 10,315 INTRM1 DRILL TRIP P Continue trip in hole from 7580' to tag up on the floats at 10315' MD. Note: FC 10317' MD. 01:45 02:45 1.00 10,315 10,315 INTRMI DRILL CIRC P Circulate bottoms up at 600 GPM's - 2800 PSI. Observed 8.6 PPG in / out. Visc = 62. 02:45 04:15 1.50 10,315 10,315 INTRM1 CASIN DHEQ P Rig up lines and testing equipment including chart recorder. Pump down killl line & DP to 96 strokes for 3000 PSI casing test for 30 minutes. Bleed qressure and ri4 down test eauipment. i ~ . ~ 07/21/2007 12:00 18:00 6.00 12,509 12,807 PROD1 DRILL DDRL P Continue Directional drill 8 1/2" B lateral from 12509' - 12807' MD. ND = 3242'. ADT = 3.36 HRS. ECD = 11.22 PPG EMW. Crew Chan e 18:00 00:00 6.00 12,807 13,472 PROD1 DRILL DDRL P Continue Directional drill 8 1/2" B lateral from 12807' - 13472' MD. TVD = 3243'. ADT = 3.31 HRS. ECD = 11.38 PPG EMW. Total concretions drilled today = 20, total length = 158', avg thickness = 7.9' as er Geolo ist. 07/22/2007 00:00 06:00 6.00 13,472 13,947 PROD1 DRILL DDRL P Continue Directional drill 8 1/2" B lateral from 13472' - 13947' MD. ND = 3226'. ADT = 2.09 HRS. ECD = 11.49 PPG EMW. Crew Chan e 06:00 12:00 6.00 13,947 14,363 PROD1 DRILL DDRL P Continue Directional drill 8 1/2" B lateral from 13947' - 14363' MD. ND = 3220'. ADT = 3.10 HRS. ECD = 11.50 PPG EMW. 12:00 13:30 1.50 14,363 14,490 PROD1 DRILL DDRL P Continue Directional drill 8 1/2" B lateral from 14363' - 14490' MD. ND = 3217'. ADT = 1.07 HRS. ECD = 11.40 PPG EMW. Obtain Slow pump rates. Total concretios drilied since midnight = 9 for a total depth of 65', avg thickness = 7.2'. 13:30 14:15 0.75 14,490 14,327 PROD1 DRILL REAM P BROOH from 14490' - 14327' while pumping 20 BBL sweep @ 485 GPM - 3360 PSI. RPM's -150. Rate at 30 ft/min. Observed little increase in cuttin s across shakers. 14:15 18:00 3.75 14,327 12,809 PROD1 DRILL REAM P Continue BROOH from 14327' - 12809' MD @ 700 GPM - 3300 PSI. RPM's -150. rate @ 30 FUmin. Obtain T&D parameters every 10 stands as per rig en ineer. Crew Chan e 18:00 22:45 4.75 12,809 10,399 PROD1 DRILL REAM P Continue BROOH from 12809'to inside shoe at 10370'. MD @ 700 GPM - 3300 PSI. RPM's -150. rate @ 30 FUmin. Obtain T&D parameters eve 10 stands as er ri en ineer. 22:45 00:00 1.25 10,399 10,399 PROD1 DRILL CIRC P Pump 40 BBL sweep around and continue with 3 bottoms up to clean & condition hole. Observed little increase in cuttings when sweep across 07/23/2007 00:00 00:30 0.50 10,399 10,399 PROD1 DRILL CIRC P Continue with 3 bottoms up to clean & condition hole. Observed little increase in cuttings when sweep across shakers. Reciprocate & rotate drill string while pumping. Monitor well - static. 00:30 02:00 1.50 10,399 12,620 PROD1 DRILL TRIP P Trip in hole from 10399' -12260 feet until run out of down weight. Fill drill string every 10 stands. Observed qroper hole fill. ~ 02:00 ~ 04:00 ~ 2.00 ~ 12,620 ~ 14,490 ~ DRILL REAM P Wash & ream each stand from 12260' - 14490' MD. UP WT = 220K , SO Wf = 72K, ROT WT = 140K: 150 RPM's with 14K TQ. 04:00 05:30 1.50 14,490 14,490 PROD1 DRILL CIRC P Pump 40 BBL sweep to clean hole and prep for displacement of SFMOBM. Pumps at 700 GPM's - 3550 PSI. SIMOPS: Held PJSM with rig crew & vac truck drivers, Discuss safety & hazard recognition issues. Discuss procedure to Displace well with SFMOBM. Designate Spill Cham ion. 05:30 06:00 0.50 14,490 14,490 PROD1 DRILL CIRC P Displace well with SFMOBM @ 650 GPM's 3000 PSI. Reciprocate & rotate drill string during displacement. Crew Chan e 06:00 07:00 1.00 14,490 14,490 PROD1 DRILL CIRC P Continue displace well with SFMOBM @ 650 GPM's 3000 PSI. Reciprocate & rotate drill string during dis lacement. 07:00 07:15 025 14,490 14,490 PROD1 DRILL CIRC P Obtain sfow pump rates. Monitor well - static. Install slips and stripping rubbers. 07:15 12:00 4.75 14,490 6,910 PROD1 DRILL TRIP P POOH on elevators from 14490' - 6910' MD. Observed proper hole fill. Obtain 7&D parameters as per rig engineer. every 10 stands. Observed not able to gain down weight until reaching depth of 9500" MD. Drop 1 7/8" drift in drill i e. 12:00 15:30 3.50 6,910 350 PROD1 DRILL TRIP P Contiue POOH on elevators from 6910' - 350'. Monitor well - static. Observed ro er hole fill. 15:30 16:30 1.00 350 350 PROD1 DRILL PULD P Held PJSM with crew, DD & MWD reps. Discuss safety & hazard recognitions issues. Discuss procedure to breakout & lay down BHA #9. Rack back HWDP. Lay down drillin 'ars. 16:30 17:00 0.50 350 85 PROD1 DRILL PULD P Plug in and download MWD assembl . 17:00 18:00 1.00 85 0 PROD1 DRILL PULD P Continue breakout & lay down BHA #9. breakout, inspect & grade bit to 1/0/WT/N/E/NO/TD. Inspect & lay down Geopilot assembly as per DD. Crew Chan e 18:00 19:00 1.00 0 0 COMPZ CASINC RURD P Held PJSM with crew, GBR reps, and BOT reps. Discuss safety & hazard recognition issues. Discuss procedure to rig up and run 5 1/2" Slotted liner. Rig up GBR casing service & equipment. Check all equipment in pipe shed. Verify count ort Spiralglider ~ ~ ~ ~ 07/24/2007 19:30 00:00 4.50 9,950 0 COMPZ CASIN RUNL P POOH from 9950' - Surface. Observed ro er hole fill. 07/25/2007 00:00 00:45 0.75 0 0 COMPZ CASIN RUNL P Make service breaks on tools as per BOT rep. Inspect & lay down running & setting tools. Observed tools indicated proper shearing when setting & releasing from PKR & liner hanger assembly. Decision to run C-2 ZXP PKR to stack on to of MLZXP. 00:45 01:15 0.50 0 0 COMPZ CASIN OTHR P Ciean & clear Rig floor of OBM & tools. 01:15 02:45 1.50 0 0 COMPZ RIGMN' SVRG P Service top drive & draw works. Perfom weekly derrick inspection, while wait on BOT toois. 02:45 03:15 0.50 0 47 COMPZ CASIN RUNL T Load C-2 ZXP packer in shed. Check measurements, and pull to rig floor. Make up packer assembly, with DP pup & setting tools. Totai length = 46.82'. 03:15 06:00 2.75 47 4,420 COMPZ CASIN RUNL T Trip in hole with C-2 ZXP PKR assembly to 4420' MD. Runnning speed = 90 - 100 ft/minute as per BOT rep. Observed proper displacement in hole. Crew Chan e 06:00 10:00 4.00 4,420 10,037 COMPZ CASIN( RUNL T Continue trip in hole with C-2 ZXP PKR assembly from 4420' -10037' MD. Runnning speed = 90 - 100 ft/minute as per BOT rep. Observed ro er dis lacement in hole. 10:00 14:15 4.25 10,037 10,043 COMPZ CASIN( RUNL T Obtain parameters. Establish circulation. Tag up top of MLZXP, and sting seals into packer until no-go landed on depth as planned. Attempt to test OA pumping down annulus. Test failed. Pull out of MLZXP, and circulate long enough to observe losses. No fluid loss. Sting back into packer, and drop 1 3/4" ball. Pump ball down to observe seated. Set packer as per BOT rep. with 4000 PSI pumped. Bleed pressure. Close annular. Test down OA to 2500 PSI for 5- minutes. record on chart - good test. Rotate 22 right hand turns in drill string to release, pick up and pull free. New Top of liner = 10043' MD. Slack off and tag TOL to verify depth. Pump down DP to shear ball at 4100 PSI. 14:15 14:30 0.25 10,043 10,043 COMPZ CASIN( RUNL T Monitor well - static. 14:30 18:00 3.50 10,043 3,200 COMPZ CASIN RUNL T POOH from 10043' - 3200' MD. Observed proper displacement. Crew Chan e 18:00 20:00 2.00 3,200 0 ICOMPZ CASIN( RUNL T Continue POOH from 3200' - surface. Observed proper disqlacement. • 07/25/2007 20:00 20:30 0.50 0 0 COMPZ CASIN( RUNL T Make service breaks, inspect and lay down running tools. Tools indicated ro er shearin as er BOT re . 20:30 22:45 2.25 0 398 PROD2 STK PULD P Clean & clear rig floor area of tools and OBM. Pull tools to rig floor. Heid PJSM with crew, MWD, and BOT rep. Discuss safety & hazard recogniiton issues, discuss procedure to MU whipstock BHA. Make up 8 1/2" Whipstock BHA as per BOT rep, with double bum er'ars. 22:45 23:30 0.75 398 398 PROD2 STK PULD P Piug in and Upioad MWD assembiy. 23:30 00:00 0.50 398 398 PROD2 STK PULD P Make up remainng BHA picking up Flex drill collars and HWDP. 07/26/2007 00:00 00:15 0.25 398 398 PROD2 STK PULD P Continue MU Whipstock & milling assembl . 00:15 00:30 0.25 398 398 PROD2 STK CIRC P Perform shallow pulse test. Pumps at 550 GPM's - 900 PSI. 00:30 06:00 5.50 398 8,292 PROD2 STK TRIP P Trip in hole with whipstock assembly at running speed of 2 minutes / stand as per BOT rep. Observed proper displacement. Trip to 8292' MD. Crew Chan e 06:00 07:00 1.00 8,292 8,975 PROD2 STK TRIP P Continue trip in hole with whipstock assembly from 8292' - 8975' MD. MAke Top drive connection. Fill drill strin . 07:00 07:30 0.50 8,975 9,045 PROD2 STK OTHR P Perform MAD PASS log from 8975' - 9045' MD as per MWD rep. pumps at 665 GPM's - 3000 PSI. 07:30 08:15 0.75 9,045 9,988 PROD2 STK TRIP P Continue trip in hole from 9045' - 9988' MD. Tag Top of liner at 10043' MD as planned. Obtain parameters. UP WT = 220K, SO WT = 125K. 08:15 09:00 0.75 9,988 10,043 PROD2 STK WPST P Orient whipstock face to 16 degress left of high side as per DD & Co. Man. Set BTA, pull 10K over upweight to verify set. Slack off and shear bolt at 35K. Pull to neutral position, rotate free with initial torque reading of 10K ft/Ibs. Top of whipstock at 9954' MD as lanned. 09:00 12:00 3.00 9,954 9,972 PROD2 STK WPST P Mill window from 9954' - 9972'. Pumps at 450 GPM's - 1750 PSI. TQ on - 12K. WOB = 2-5K. Sweep hole at bottom of slide. Average mill speed through casing = 6.15 ft/hr. TOW = 9954', BOW = 9970'. 12:00 16:15 4.25 9,972 10,006 PROD2 STK WPST P Continue mill through open hole from 9972' -10006'. Pumps at 450 GPM's - 1750 PSI. TQ on -12K. WOB = 2-5K. Swee~ hole at bottom of hole. ~ 07/26/2007 16:15 17:30 1.25 10,006 10,006 PROD2 STK CIRC P Circulate sweep out of hole and clean up iron cuttings. pumps at 450 GPM's - 1800 PSI. Work mills through window area verifying good, clean window. UP WT = 220K, SO WT = 125K, ROT WT = 150K. Gauged hole to 9986' MD. 16' below BO 17:30 18:00 0.50 10,006 9,850 PROD2 STK WPST P Work mills through window area repeated times with no pump. Monitor well - static. Pull and rack back 2 stands of DP. Crew Chan e 18:00 19:30 1.50 9,850 9,850 PROD2 RIGMN' RGRP NP Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to rig up welder and lines to crown section. RU and weld in crown section on derrick climber brace. Obtain man-rider & hot work permits. RD all equipment. Inspect derrick & crown of tools & e ui ment used. 19:30 20:00 0.50 9,850 9,850 PROD2 STK WPST P Monitor well - static. pump dry job. 20:00 23:45 3.75 9,850 308 PROD2 STK TRIP P Trip out of hole with milling assembly from 9850' - 308'. Observe 20 BBLs loss on tri out. 23:45 00:00 0.25 308 308 PROD2 STK PULD P Breakout & lay down double Bumper ~ars, 07/27/2007 00:00 00:30 0.50 308 308 PROD2 STK PULD P Continue lay down double bumper jars, and rack back Non Mag flex drill collars. rack back stand with drilling 'ars. 00:30 01:00 0.50 308 308 PROD2 STK PULD P Plug in and down load MWD assembl . 01:00 01:45 0.75 308 0 PROD2 STK PULD P Breakout & lay down milling assembly. Inspect and gauge mills to full au e of 8 1/2". 01:45 02:00 0.25 0 0 PROD2 STK OTHR P Clean & clear rig floor of tools and OBM. 02:00 03:45 1.75 0 0 PROD2 STK OTHR P MU running tools and RIH to pull wear bushing. MU stack washing tool, flush BOP stack of iron cuttings. lay down tools. Install Wear bushin . RILDS. 03:45 06:00 2.25 0 30 PROD2 DRILL PULD P Held PJSM with crew, DD & MWD reps. Discuss safety & hazard recognition issues. Discuss making up BHA. Pull tools to floor. Make up 8 1/2" drilling assembly with Geo-pilot assembly for the D lateral. MU 8 1/2" Hycalog RSX 616MB33 with TFA of 1.66 sq. in. Plug in and upload MWD assembl . Crew Chan e 06:00 06:30 0.50 30 351 PROD2 DRILL PULD P Continue make up remaining BHA picking up HWDP & drilling jars. Perform Shallow ulse test. 06:30 12:00 5.50 351 9,950 PROD2 DRILL TRIP P Trip in hole from 351' - 9950' MD. observed proper displacement. Fill drill strinig every 25 stands. Obtain T&D qarameters as per ria enaineer. ~ ~ 07/27/2007 12:00 12:30 0.50 9,950 9,950 PROD2 RIGMN' SVRG P Service top drive & draw works. 12:30 13:00 0.50 9,950 10,006 PROD2 DRILL REAM P Make Top drive connection. Begin wash & ream from 9985' -10006' MD. observed no issues when going through whipstock face. Pumps at 550 GPM's -1750 PSI. 13:00 15:15 2.25 10,006 10,312 PROD2 DRILL DDRL P Directional drill 8 1/2" hole in the D lateral from 10006' - 10312' MD. ND = 3267'. ECD = 10.2 PPG. 15:15 15:30 0.25 10,312 10,312 PROD2 DRILL SRVY P PerForm MAD PASS from 10266' - 10307' MD. 555 GPM's - 2350 PSI. 15:30 17:00 1.50 10,312 10,312 PROD2 DRILL REAM P Wash & ream hole for directional correction as per DD. 650 GPM's - 3000 PSI. 17:00 17:30 0.50 10,312 10,524 PROD2 DRILL DDRL P Directional drill 8 1/2" hole in the D lateral from 10312' - 10524' MD. ND = 3252'. Total ADT = 2.09 HRS. ECD = 10.41 PPG. Observed difficulty in steering with surveys indicating out of zone. 17:30 18:00 0.50 10,524 9,954 PROD2 DRILL TRIP T Decision to POOH. POOH from 10524' - 9954' MD above window. No issues going back through tthe window area. Crew chan e 18:00 18:30 0.50 9,954 9,954 PROD2 DRILL OWFF T Monitor well - static. Pump dry job. Blow down To drive & lines. 18:30 21:30 3.00 9,954 350 PROD2 DRILL TRIP T Trip out of hole from 9954' - 350'. Observed ro er hole fill. 21:30 21:45 0.25 350 350 PROD2 DRILL PULD T Rack back HWDP, drilling jars & flex drill collars. 21:45 22:30 0.75 350 350 PROD2 DRILL OTHR T Piug in and down load MWD assemb . Pre for bit chan e. 22:30 00:00 1.50 350 0 PROD2 DRILL PULD T Breakout & lay down BHA. Inspect & grade bit to 1/1/CT/A/X/I/NO/HP. Observed excessive cutting wear on MWD stabilizers. Obtain pictures. Lay down MWD. Remove battery & install in back u tool. 07/28/2007 00:00 00:30 0.50 0 0 PROD2 DRILL PULD T MU BHA # 13, with 8 1/2" Security FMF3643Z bit with a TFA of 1.66 sq. in. Change out Pulser in MWD assembl . 00:30 01:15 0.75 0 0 PROD2 DRILL OTHR T Plug in and download MWD assembl . 01:15 01:45 0.50 0 351 PROD2 DRILL PULD T Make up remaining BHA picking up HWDP, Drilling jars and Flex drill collars. 01:45 02:00 0.25 351 351 PROD2 DRILL CIRC T Make Top drive connection & Perform shallow ulse test. 02:00 05:15 3.25 351 9,861 PROD2 DRILL TRIP T Trip in hole with BHA #13 from 351° - 9861'. Observed proper displacement. Fill drill strinq everv 25 stands. ~ ~ 07/28/2007 05:15 06:00 0.75 9,861 9,861 PROD2 RIGMN SVRG T Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to Slip & cut. Hang blocks, and slip & cut drilling line. Adjust brakes, and service top drive & draw works. Crew Chan e 06:00 08:00 2.00 9,861 9,861 PROD2 RIGMN SVRG T Continue slip & cut drilling line. Adjust brakes, and service top drive & draw works. Lubricate ri . 08:00 10:30 2.50 9,861 9,861 PROD2 RIGMN SVRG T Change out saver sub on top drive. Change out stabilizer bushings, and ad'ust clam s on bales. 10:30 11:00 0.50 9,861 10,000 PROD2 DRILL TRIP T Trip in hole from 9861' - 10000' MD. Make Top drive connection. UP Wf = 195K, SO WT = 95K, ROT WT = 112K. Pumps at 610 GPM's - 2750 PSI. 100 RPM's with 8K TQ> 11:00 12:00 1.00 10,000 10,035 PROD2 DRILL DDRL T Perform OH sidetrack troughing from 1000' - 10035' MD. 12:00 17:15 5.25 10,035 10,035 PROD2 DRILL DDRL T Continue perform OH sidetrack from 10000' - 10035' MD. Observed kick off. 17:15 18:00 0.75 10,035 10,240 PROD2 DRILL DDRL T Directional drill 8 1/2" hote in the D lateral from 10035' - 10240' MD. ND = 3211'. ADT =.47 HRS, ECD = 10.0 PPG Crew Chan e 18:00 19:45 1.75 10,240 10,524 PROD2 DRILL DDRL T Directional drill 8 1/2" hole in the D lateral from 10240' - 10524' MD. TVD = 3193'. ECD = 1025 PPG 19:45 00:00 4.25 10,524 10,961 PROD2 DRILL DDRL P Directional drill 8 1/2" hole in the D lateral from 10524' - 10961' MD. TVD = 3174'. ADT = 3.18 HRS, ECD = 10.42 PPG 07/29/2007 00:00 06:00 6.00 10,961 11,447 PROD2 DRILL DDRL P Directional drill 8 1/2" hole in the D lateral from 10961' - 11447' MD. ND = 3176'. ADT = 4.69 HRS, ECD = 10.87 PPG. Crew Chan e 06:00 12:00 6.00 11,447 12,237 PROD2 DRILL DDRL P Directional drill 8 1/2" hole in the D lateral from 11447' - 12237' MD. ND = 3165'. ADT = 3.76 HRS, ECD = 10.86 PPG 12:00 17:15 5.25 12,237 13,002 PROD2 DRILL DDRL P Directional drill8 1/2" hole in the D lateral from 12237' - 13002' MD. ND = 3161'. ADT = 3.16 HRS, ECD = 11.30 PPG 17:15 18:00 0.75 13,002 13,002 PROD2 RIGMN' RGRP T Observed leak in shock hose from mud pump. No spills. Change out shock hose while reciprocate & rotate drill string utilizing secondary kill line hose for circulatin . Crew Chan e 18:00 20:15 2.25 13,002 13,002 PROD2 RIGMN RGRP T Continue change out shock hose while reciprocate & rotate drill string utilizing seconda kill line hose for circulatin . 20:15 20:45 0.50 13,002 13,002 PROD2 RIGMN' RGRP T Blow down Top drive & lines. Pressure test new shock hose to 4000 PSI. Good test. ~ 07/29/2007 20:45 00:00 3.25 13,002 13,378 PROD2 DRILL DDRL P Directional drill 8 1/2" hole in the D lateral from 13002' -13378' MD. ND = 3167'. ADT = 2.31 HRS, ECD = 10.81 PPG 07/30/2007 00:00 06:00 6.00 13,378 14,403 PROD2 DRILL DDRL P Directional drill 8 1/2" hole in the D lateral from 13378' - 14403' MD. TVD = 3150'. ADT = 3.72 HRS, ECD = 11.18 PPG Crew Chan e 06:00 09:00 3.00 14,403 14,489 PROD2 DRILL DDRL P Directional drill 8 1/2" hole in the D lateral from 14403' - 14489' MD. ND = 3143'. ADT = 1.78 HRS, ECD = 11.35 PPG. TD'd the lateral. 09:00 12:00 3.00 14,489 14,489 PROD2 DRILL CIRC P Circulate 40 BBL Hi Visc weighted sweep around while reciprocate & rotate drill string. Pumps @ 635 GPM's - 3260 PSI. Obse-ved little increase in cuttings when sweep returned. Obtain slow pump rates. Monitor weil - static. 12:00 18:00 6.00 14,489 11,030 PROD2 DRILL REAM P BROOH from 14489' - 11030' MD. ftotate @ 150 RPM's with 700 GPM's - 3100 PSI. Observed proper displacement. Obtain T&D parameters as er ri en ineer. Crew chan e 18:00 21:30 3.50 11,030 9,954 PROD2 DRILL REAM P Continue BROOH from 11030' - 9954' MD. Rotate @ 150 RPM's with 700 GPM's - 3100 PSI. Observed tight hole at bit depth of 10166'. Work through slowly rotating while pull through. No issues pulling assembly through whipstock face. Observed proper displacement. Obtain T&D arameters as er ri en ineer. 21:30 23:00 1.50 9,954 9,954 PROD2 DRILL CIRC P Circulate 40 BBL Hi Visc weighted sweep around plus 1 bottoms up while reciprocate & rotate drill string. Pumps @ 700 GPM's - 3260 PSI. Observed little increase in cuttings when sweep returned. Monitor well - static. 23:00 00:00 1.00 9,954 9,954 PROD2 DRILL TRIP P perform short trip back in hole to 10623' MD verifying assembly able to stay in wellbore and not track back into Plug back well bore. POOH. Continue to observe issues with assembly getting in and out of 10166' MD. Suspect stabilizers hanging up on concretion at this de th. 07/31/2007 00:00 03:30 3.50 9,954 9,954 PROD2 DRILL CIRC P Circulate 40 BBL Hi Visc weighted sweep (10.2ppg/ 200 vis) around plus 4 bottoms up while reciprocate & rotate drill string 120 rpm's. Pumps @ 700 GPM's - 2970 PSI. Observed little increase in cuttings when sweep returned. Monitor well - static. ~ 07/31/2007 03:30 04:30 1.00 9,954 9,954 PROD2 RIGMN SVRG P Service top drive & draw works. Inspect saver sub. Service crown section. Inspect man rider sheave in crown. 04:30 06:00 1.50 9,954 10,812 PROD2 DRILL TRIP P Trip back in hole from 9954' - 10812'. 06:00 07:30 1.50 10,812 12,050 PROD2 DRILL REAM P Wash and ream in the hole. Pumping 3-5 b m. Rotate 30 r m. 07:30 09:00 1.50 12,050 12,050 PROD2 RIGMN RGRP T Electricain trouble shooting the Varco TDS-8SA to drive electrical s stem. 09:00 10:45 1.75 12,050 9,862 PROD2 DRILL TRIP T Pull out of the hole on elevators. No excessive overpull while pulling throu h the window. 10:45 15:45 5.00 9,862 9,862 PROD2 RIGMN' RGRP T Electrician continues to troubleshoot the electrical s stem of the to drive. 15:45 17:00 1.25 9,862 8,150 PROD2 DRILL TRIP T Pull out of the hole on elevators. Plans to test BOPE with a 9-5/8" storm packer set in the 9-5/8" intermediate casin . 17:00 19:30 2.50 8,150 8,150 PROD2 RIGMN' RGRP T Electrician continues to troubleshoot the electrical s stem of the to drive. 19:30 19:45 0.25 8,150 8,150 PROD2 DRILL OWFF T Monitorwell.OK. 19:45 20:00 0.25 8,150 8,150 PROD2 DRILL SFTY T PJSM on POOH. 20:00 20:15 0.25 8,150 8,055 PROD2 DRILL TRIP T POOH. Decide to lay down BHA #13, then test BOPE. 20:15 20:45 0.50 8,055 8,055 PROD2 DRILL CIRC T Pump a 20 bbls dry job for trip out. 20:45 00:00 3.25 8,055 636 PROD2 DRILL TRIP T POOH to UD BHA # 13. 08/01/2007 00:00 01:15 1.25 636 74 PROD2 DRILL TRIP T Continue to POOH to UD BHA # 13. 01:15 02:15 1.00 74 74 PROD2 DRILL OTHR T Download Sperry Sun MWD. 02:15 04:00 1.75 74 0 PROD2 DRILL PULD P Lay down BHA # 13. Calculated fill 107.83 bbls, actual 122.7 bbls. 04:00 04:30 0.50 0 0 PROD2 DRILL OTHR P Clean and clear floor. 04:30 05:45 1.25 0 0 PROD2 WELCT OTHR P Pull wear bushing. Install Vetco Gray test plug. RU to test BOPE. Fill stack with water • ~ 08/01/2007 05:45 13:00 7.25 0 0 PROD2 WELCT BOPE P Test BOPE. Witness of test waived by AOGCC inspector Lou Grimaldi. Accumulator test: Starting w/ 3000 psi, after closing 1500 psi. 200 psi build up in 45 seconds. Full charge in 3 min. 21 seconds. Five Nitrogen bottles avg 2250 psi. Test Annular to 250 psi low and 3000 psi high w/ a 4-1/2" test joint. Test upper pipe rams (3-1/2" x 6" variable rams) w/ 4-1/2" and 5". Test to 250 psi low and 3000 psi high. Hold each test f/ 5 min. Test top drive manual and automatic IBOP to 250 psi low and 3000 psi high. Test floor safety vlaves to 250 psi and 3000 psi. Test choke manifold valves, kill line valves and choke line valves to 250 psi low and 3000 psi high. Hold all tests f/ 5 min. Test H2S and methane as alarms. All tests assed. 13:00 13:45 0.75 0 0 PROD2 DRILL OTHR P Doyon employee meeting with the Do on Board of directors. 13:45 15:15 1.50 0 0 PROD2 WELCT OTHR P Rig down test equipment. Pull test lu . Install wear bushin . 15:15 15:45 0.50 0 0 PROD2 DRILL OTHR T Clean and clear rig floor. 15:45 16:45 1.00 0 0 PROD2 DRILL PULD T Make up BHA # 14 (8-1/2" hole o ener. 16:45 18:00 1.25 0 5,050 PROD2 DRILL TRIP T Trip in the hole. Fill pipe every 25 stands. Record PU and SO wYs. 18:00 19:00 1.00 5,050 5,050 PROD2 DRILL SFTY P Install floor safety valve, secure well (close annular). Hold a safety standup meeting with both crews in the welding 19:00 19:15 0.25 5,050 5,050 PROD2 DRILL SFTY P PJSM on opening up the well after bein secured. 19:15 19:45 0.50 5,050 5,050 PROD2 DRILL OTHR P Open annular, well is static. Remove floor safety valve. Blow down choke manifold. 19:45 00:00 4.25 5,050 9,895 PROD2 DRILL TRIP T Continue trip in the hole w/ BHA #14. Record PU and SO wYs every 10 stands. Fill i e eve 25 stands. 08/02/2007 00:00 04:00 4.00 9,895 9,895 PROD2 DRILL CIRC T Establish circulation. Stage pumps up to 900 gpm w/ 3420 psi. Recip 60' stroke, up fast, down slow. Before circ: PU 190, SO 80k. After circ: PU 185k, SO 102k. Cire surf to surface then 7 more BU. Initial MW 8.6 ppg, final MW 8.4 ppg. ~ ~ 08/02/2007 04:00 06:00 2.00 9,895 9,895 PROD2 RIGMN WOEQ T Continue to wait on parts to fix the Varco TDS-8SA top drive. Monitor weli on the trip tank. Loss of 1.5 bbls in 2 hrs. While waiting on parts: Grease crown, PM on the Hook, change vaives and seats in # 1 mud pump. cleaning cattle chute, cleaning rig floor. 06:00 18:00 12.00 9,895 9,895 PROD2 RIGMN WOEQ T Continue to wait on parts to fix the Varco TDS-8SA top drive. Monitor well on the trip tank. Loss of 12 bbls in 12 hrs. While waiting on parts: remove electrical service loop from top drive. Cleanin ri floor windwalls. 18:00 21:00 3.00 9,895 9,895 PROD2 RIGMN WOEQ T Continue to wait on parts to fix the Varco TDS-8SA top drive. Monitor well on the trip tank. While waiting on parts: Electricians trouble shooting the variable frequency contoller for the top drive. Cleaning rig floor, cleaning roof of the pipe shed. Inspect the drawworks: Brake pads, rollers, automatic driller, crown o matic. 21:00 00:00 3.00 9,895 9,895 PROD2 RIGMN RGRP T Electrical service loop for the Varco TDS-8SA top drive arrived. Uncrate same, electricians prepare and install ends. Monitor well on the trip tank. Total fluid lost in the last 6 hrs = 1.5 bbls. 08/03/2007 00:00 00:30 0.50 9,895 9,895 PROD2 RIGMN RGRP T Prepare and install ends to the electrical service loop for the top drive.. Monitor well on the tri tank. 00:30 00:45 0.25 9,895 9,895 PROD2 RIGMN SFTY T PJSM on bringing service loop to the floor and han in it in the derrick. 00:45 06:00 5.25 9,895 9,895 PROD2 RIGMN RGRP T Hang the electrical service loop in the derrick. Prepare to be attatched to the top drive and junction box in the derrick. Cleaning around the rig. Work on PM's. Hole lost 3 bbls over last 6 06:00 12:00 6.00 9,895 9,895 PROD2 RIGMN' RGRP T Continue to work on the Varco TDS-8SA to dsive. 12:00 18:00 6.00 9,895 9,895 PROD2 RIGMN RGRP T Electricians continue to work on the Varco TDS-8SA top drive. Circulate two bottom's up @ 1700 hrs. Pumping 500 gpm w/ 1240 psi. Lost a total of 2.5 bblsfor the last 12 hours. 18:00 22:00 4.00 9,895 9,895 PROD2 RIGMN WOEQ T Cleaning on the rig while waiting on service tech's to arrive. Arranging for parts to arrive as well. ~ ~ 08/03/2007 22:00 00:00 2.00 9,895 9,895 PROD2 DRILL SFTY P RLG rep Capt. Kirk-- giving a workshop with the rig crew on the book written by Captain D. Michael Abrashoff. Book's name IYs Your Ship. Note: Zero bbls of mud lost f/ the last 6 hours. 08/04/2007 00:00 06:00 6.00 9,895 9,895 PROD2 RIGMN' WOEQ T Cleaning and painting on the rig_while waiting for parts and service technician's to arrive and help to fix the Varco TDS-8SA to drive. 06:00 12:00 6.00 9,895 9,895 PROD2 RIGMtV' WOEQ T Cleaning and painting on the rig while waiting for parts and service technician's to arrive and help to fix the Varco TDS-8SA to drive. 12:00 18:00 6.00 9,895 9,895 PROD2 RIGMN' WOEQ T Cleaning and painting on the rig while waiting for parts and service technician's to arrive and help to fix the Varco TDS-8SA to drive. 18:00 21:00 3.00 9,895 9,895 PROD2 RIGMN' WOEQ T Cleaning and painting on the rig while waiting for parts and service technician's to arrive and help to fix the Varco TDS-8SA to drive. 21:00 23:45 2.75 9,895 9,895 PROD2 RIGMN WOEQ T Circulate 4 BU (18100 strokes). Pum in 725 m w/ 2360 si. 23:45 00:00 0.25 9,895 9,895 PROD2 RIGMN WOEQ T Cleaning and painting on the rig while waiting for parts and service techoician's to arrive and help to fix the Varco TDS-8SA to drive. 08/05/2007 00:00 10:00 10.00 9,895 9,895 PROD2 RIGMN' WOEQ T Cleaning and painting on the rig while waiting for parts and service technician's to arrive and help to fix the Varco TDS-8SA to drive. 10:00 11:30 1.50 9,895 9,895 PROD2 RIGMN WOECI P RLG rep Capt. Kirk-- giving a workshop with the rig crew on the book written by Captain D. Michael Abrashoff. Book's name IYs Your Shi . 11:30 17:30 6.00 9,895 9,895 PROD2 RIGMN WOEQ T Cleaning and painting on the rig while waiting for parts and service technician's to arrive and help to fix the Varco TDS-8SA top drive. Rig electricians and Varco rep's working to check out Inverter bay of Top drive house. 17:30 20:30 3.00 9,895 9,895 PROD2 RIGMN WOEQ T Circulate 4 BU (19400 strokes). Pum in 725 m w/ 2360 si. 20:30 00:00 3.50 9,895 9,895 PROD2 RIGMN WOEQ T Cleaning and painting on the rig while waiting for parts and service technician to arrive and help to fix the Varco TDS-8SA top drive. Note: Total of 3.5 bbls of fluid lost to the hole for the da . OS/06l2007 OO:OQ 06:OQ 6.00 9,895 9,895 PROD2 RIGMN WOEQ T Cleaning and painting on the rig whife waiting for parts and service technician to arrive and help to fix the Varco i ~ 08/06/2007 06:00 12:00 6.00 9,895 9,895 PROD2 RIGMN WOEQ T Cleaning and painting on the rig while waiting for parts and service technician to arrive and help to fix the Varco 7DS-8SA top drive. Perform a derrick ins ection. 12:00 18:00 6.00 9,895 9,895 PROD2 RIGMN' RGRP T Cleaning and painting on the rig while service technician's help to fix the Varco TDS-8SA top drive. Off of hiline @ 1430 hrs. Work on connecting service loo to the to drive. 18:00 18:30 0.50 9,895 9,895 PROD2 RIGMN' RGRP T Service technician's helping to fix the Varco TDS-8SA top drive. Circulate bottom's up. Pumping 700 gpm w/ 2210 si. PU wt 190k, SO wt 100k. 18:30 19:30 1.00 9,895 9,895 PROD2 RIGMN RGRP T Break the top drive off of the drill string usin ton s and chain ton . 19:30 20:30 1.00 9,895 9,895 PROD2 RIGMN RGRP T Run and function top drive, monitoring Variable fre uenc control house. 20:30 21:00 0.50 9,895 9,895 PROD2 RIGMN RGRP T Finish putting all pieces in place. Top drive a ears to be read to run. 21:00 21:15 0.25 9,895 9,895 PROD2 RIGMN RGRP T Screw into drill string. Pump and rotate top drive. While letting out the torque of 10k ft Ibs, a capacitor in the control house failed. 21:15 00:00 2.75 9,895 9,895 PROD2 RIGMN RGRP T Start to re --trouble shoot problems with the top drive control house. Rig crew working on projects: change out shaker screens on scalper shakers f/ next well, inspect mud cleaner, ins ect collar clam . 08/07/2007 00:00 03:30 3.50 9,895 9,895 PROD2 RIGMN RGRP T Start to re --trouble shoot problems with the top drive control house. Rig crew working on projects: change out shaker screens on scalper shakers f/ next wefl, inspect mud cleaner, ins ect collar clam . 0330 06:00 2.50 9,895 9,895 PROD2 RIGMN RGRP T Parts installed and checked out. Will check with Siemens and Varco this morning as a conference call to further identi an roblems. 06:00 08:00 2.00 9,895 9,895 PROD2 RIGMN' RGRP T Checking with Siemens and Varco to trouble shoot the Varco Top drive s stem. 08:00 17:00 9.00 9,895 9,895 PROD2 RIGMN RGRP T Start testing of Variable control unit and to drive. 17:00 19:15 2.25 9,895 9,895 PROD2 RIGMN RGRP T Noticed a part in the top drive control house emmitting sparks. Found problem to be in the computer control module?? 19:15 20:45 1.50 9,895 9,895 PROD2 RIGMN RGRP T Circulate two bottom's up. Pumping 700 gpm w/ 2190 psi. Checked and found that the computer control unit in ri 141's controls will work. 20:45 21:00 0.25 9,895 IPROD2 RIGMN RGRP T Obtain SPR's. Then line up on the trip tank to monitor the well. • ~ 21:00 23:00 2.00 9,895 9,895 PROD2 DRILL SFTY P Swap some parts and instalt controt module in the control house. RLG rep Capt. Kirk-- giving a workshop with the rig crew on the book written by Captain D. Michael Abrashoff. Book's name IYs Your Shi . 23:00 00:00 1.00 9,895 9,895 PROD2 RIGMN RGRP T Continue installing the computer control unit in the top drive control house. Note: Zero mud lost to the hole 08/08/2007 00:00 01:00 1.00 9,895 9,895 PROD2 RIGMN RGRP T Continue instaliing the computer control unit in the top drive controi house. 01:00 02:00 1.00 9,895 9,895 PROD2 RIGMN' RGRP T Function testing top drive. 02:00 03:30 1.50 9,895 9,895 PROD2 RIGMN RGRP T Screw top drive into the drill string. Function testing. Rotating 70 rpm w/ 8-12k ft Ibs of torque. Pumping 148 gpm w/ 240 psi. Recip pipe. All appears to be good. Monitoring top drive control house. 03:30 03:45 0.25 9,895 9,895 PROD2 RIGMN SFTY T PJSM on RIH/ Ream in the hole. 03:45 04:15 0.50 9,895 9,895 PROD2 RIGMN' RGRP T Unscrew top drive f/ the drill string. Run Top drive up through the derrick to check how service loop runs w! Kelly hose. Adjust traveling hardware. OK. Note: No ain or loss f/ last 6 hrs. 04:15 05:00 0.75 9,895 10,690 PROD2 DRILL TRIP T RIH. Record PU and SO wt's every 5 stands. Ran out of down wt. 05:00 06:15 1.25 10,690 11,230 PROD2 DRILL REAM T Ream in the hole. Pumping 148 gpm w/ 280 psi, 26% flow. Rotate 30 rpm w/ 10k ft Ibs of tor ue. 06:15 07:00 0.75 11,230 11,421 PROD2 DRILL REAM T Ream in the hole. Pumping 700 gpm w/ 2450 psi, 37% flow. Rotate 30 rpm w/ 10-12k ft Ibs of tor ue. 07:00 08:15 1.25 11,421 12,050 PROD2 DRILL REAM T Ream in the hole. Pumping 700 gpm w/ 2490 psi, 37% flow. Rotate 120 rpm w112-15k ft Ibs of tor ue. 08:15 14:15 6.00 12,050 14,489 PROD2 DRILL REAM P Continue to ream in the hole. Pumping 700 gpm w/ 2490-3050 psi, 37% flow. Rotate 120 rpm w! 10-12k ft Ibs of torque. Note: Hole took 25 bbls while runnin /reamin in the hole. 14:15 16:15 2.00 14,489 14,489 PROD2 DRILL CIRC P Displace f/ 8.4+ ppg MOBM to 8.4 ppg SFOBM, Pumping 500 gpm w/ 1740 psi. Rotate 70 rpm w/ 1740 psi. PU wt 225k, S0 wt : none, rot wt 125k. 16:15 16:30 0.25 14,489 14,489 ~ PROD2 DRILL OWFF P Monitor well, install stripping rubbers. ~ + 08/08/2007 16:30 00:00 7.50 14,489 290 PROD2 DRILL TRIP P POOH on e4evators. Record PU and SO wPs every 5 stands in open hole, every 10 stands inside of casing. Note: Depth 9899': Rotating weight 135k, rotating 30 rpm w/ 13-13.5k ft Ibs of torque. Depth 4954': Rotating weight 120k, rotating 30 rpm w/ 5-7 k ft Ibs of tor ue. 08/09/2007 00:00 0130 1.50 290 0 PROD2 DRILL PULD P Lay down BHA # 14. Calculated displacement for the trip is 125.64 bbls, actual 152 bbls. 0130 02:00 0.50 0 0 PROD2 DRILL OTHR P Lay down subs and handfing e ui ment.Clean and clear ri floor. 02:00 02:45 0.75 0 0 COMPZ CASINC RURD P Rig up to run 4-1/2" L-80 BTC 11.6 ppf liner f/ the "D" lateral. 02:45 03:00 0.25 0 0 COMPZ CASIN( SFTY P Pre job safety meeting on liner run. 03:00 05:45 2.75 0 4,236 COMPZ CASIN( RNCS P PU/MU 4-1/2" 11.6 ppf L-80 BTC liner (slots and blanks) per running order. Record PU and SO wYs per Rig en ineer startin on 't # 60. 05:45 06:15 0.50 4,236 4,304 COMPZ CASIN OTHR P Rig down 4-1/2" handling equipment. RU 5-1/2" equipment. MU Baker settin sleeve. 06:15 06:30 0.25 4,304 4,304 COMPZ CASIN RNCS P Rig down all casing tools. 06:30 11:00 4.50 4,304 10,676 COMPZ CASIN( RUNL P Run 4-1/2" sloUblank liner f/ the "D" lateral on 5" drill pipe. Liner PU wt 100k, SO wt 95k( liner only). PU wt 180k, SO wt 75k Note: Depth 9915' (above the window) Rot wt 130k, 30 rpm w/ 6k ft Ibs of torque. Note: Depth 10000' ( just outside of the window) Rot wt 130k, 30 rpm 6k ft Ibs of tor ue. 11:00 12:00 1.00 10,676 11,152 COMPZ CASIN RUNL P Rotate liner in the hole w/ 30 rpm, 8500 ft Ibs of torque, Rot wt 115k. No down wt. 12:00 16:15 4.25 11,152 14,489 COMPZ CASIN RUNL P Continue to rotate liner in the hole w/ 30 rpm, no down wt. On bottom rotating torque 12-15k ft Ibs. Rot wt 16~k, PU wt 260k. Calculated displacment 118.5 bbls, actual 113 bbls, loss of 5.37 bbls. 16:15 16:30 0.25 14,489 14,476 COMPZ CASIN RUNL P PU and set liner on depth ( shoe @ 14476', liner to 10185'. 16:30 18:45 225 14,476 10,151 COMPZ CASIN CIRC P Drop a 29/32" ball, circ @ 3 bpm w/ 290 psi till 1200 strokes pumped, slow to 2 bpm w/ 140 psi. Ball on seat @ 1534 strokes. Pressure to 3000 psi, hold f/ a minute. Bleed off pressure. Released from liner. Prior to release PU wt 260k, after release PU wt 245k. Pressure to 4000 psi to blow ball seat. ~ ~ 08/09/2007 18:45 23:30 4.75 10,151 30 COMPZ CASIN RUNL P pOOH w/ liner running tool. Record PU and SO wYs every 10 stands. With one stand pulled back: Down weight was 105k, Rotating torque 13k ft ibs of tor ue. 23:30 00:00 0.50 30 0 COMPZ CASIN OTHR P Break and lay down Baker liner runnin tools. 08/10/2007 00:00 00:15 0.25 0 0 COMPZ FISH SFTY P PJSM on PU/MU BHA #15 {Retrieve the whi stock . 00:15 01:30 1.25 0 333 COMPZ FISH PULD P PU/MU BHA # 15. 01:30 05:45 4.25 333 9,895 COMPZ FISH TRIP P Trip in the hole w/ BHA # 15 to retrieve the whipstock. Fill pipe every 25 stands. Monitor the hole on the trip tank.Calculated displacement 95 bbls, actual 90.5 bbis. 05:45 06:00 0.25 9,895 9,895 COMPZ RIGMN SFTY P P~SM on slip and cutting the drilling line. 06:00 07:30 1.50 9,898 9,898 COMPZ RIGMN SVRG P Slip and cut the 137' of 1-3/8" drilling line. 07:30 08:15 0.75 9,898 9,898 COMPZ RIGMN SVRG P Service the rig. 08:15 08:30 0.25 9,898 9,954 COMPZ FISH TRIP P Make a top drive connection. RIH to top of whipstock @ 9954'. PU wt 230k, SO wt 105k. 08:30 10:30 2.00 9,954 9,967 COMPZ FISH WASH P Establish circualtion, pumping 300 gpm w/ 1200 psi. PU wt 230k, SO wt 100k. Wash down to the key slot on the whipstock. Rotate pipe in 1/8 turns to the right to hook whipstock. Pump pressure increased to 3000 psi while workin 9965' and 9955'. 10:30 11:00 0.50 9,967 9,960 COMPZ FISH FISH P Continue working string from 9954' to 9962', again turning pipe 1/8 turn to the right to hook whipstock.. Hooked 1100 hrs, ullin 50k over PU wt. 11:00 13:00 2.00 9,960 9,960 COMPZ FISH JAR P Jar on whipstock f/ the "D" lateral, ullin 80k over PU wt of 230k. 13:00 13:30 0.50 9,960 9,700 COMPZ FISH PULL P POOH to 9910' (pulled 50k over), jar w/ 50 k overpull, POOH to 9850' (pulled 50k over), POOH to 9810' (pulling 40 k over), then fell off to PU wt of 250k. Continue POOH w! 250k PU wt Hole swabbin 2 bbls . 13:30 15:00 1.50 9,700 9,700 COMPZ FISH CIRC NP Circulate 15:00 15:30 0.50 9,700 9,626 COMPZ FISH TRIP NP POOH. PU wt 250k. Swabbed 4 bbls. 15:30 17:00 1.50 9,626 9,626 COMPZ FISH OTHR NP Monitor well via trip tank. Static. 17:00 18:00 1.00 9,626 10,042 COMPZ FISH TRIP P Trip in the hole and tag up @ 10042' 2' above to acker of the "B" lateral. 18:00 18:45 0.75 10,042 9,716 COMPZ FISH TRIP P POOH w/ the whipstock. Hole is not swabbing. Hole is taking a little extra fill. After 4 stands pulled, drop a 1-7/8" rabbit w/ 100' of slickline tail. i r 08/10/2007 18:45 00:00 5.25 9,716 0 COMPZ FISH TRIP P Continue to POOH w/ the whipstock. Hole is not swabbing. Ca{culated displacement 102 bbls, actual 124 bbls. Note: Lost 5 bbls of mud on trip in the hole, lost 7 bbls while circ and trying to pull whipstock free, the~ 22 bbls on trip out = total loss of 34 bbis for the da . 08/11/2007 00:00 00:15 0.25 0 0 COMPZ FISH PULD P Lay down BHA # 15- hook and jars. Did not recover whi stock. 00:15 01:00 0.75 0 0 COMPZ FISH OTHR P Clean floor. 01:00 01:15 0.25 0 Q COMPZ FISH PULD T PU subs to make up Box Tap BHA to retrieve the whi stock. 01:15 02:15 1.00 0 338 COMPZ FISH PULD T MU Baker box tap and string magnet assembly to retrieve the "D" lateral whi stock. 02:15 03:00 0.75 338 2,332 COMPZ FISH TRIP T Trip in the hole w! BHA # 16 on 5" drill pipe. Fill pipe. Pumping 42 gpm w/ 680 si. 03:00 04:30 1.50 2,332 6 COMPZ FISH TRIP T POOH w/ BHA # 16 to check the float installed in the bit sub. 04:30 04:45 0.25 6 6 COMPZ FISH OTHR T Install the float to the proper direction, so that fluid will pump through it. Tor ue connection to 18k ft Ibs. 04:45 05:00 0.25 6 333 COMPZ FISH TRIP T MU BHA #16, RIH 3 stands of HWDP. MU stand #4 and noticed the torque was still set 18k ft Ibs. 05:00 05:15 0.25 333 333 COMPZ FISH TRIP T POOH to the first HWDP, re-torque HWDP to 28k ft Ibs, R{H 3 stands of HWDP. 05:15 06:15 1.00 333 2,332 COMPZ FISH TRIP T RIH w/ BHA # 16 on 5" drill pipe. Fill i e. Pum in 300 m w/ 210 si. 06:15 12:30 6.25 2,332 9,401 COMPZ FISH TRIP T Continue to RIH w/ BHA # 16 (Box tap). Filled pipe @ 6518', 8235', and 9356' 12:30 14:30 2.00 9,401 9,940 COMPZ FISH TRiP T Tagged whipstock @ 9401', continue in the hole rotating 20-40 rpm and 10-13k ft Ibs of torque, pumping 127 gpm w/ 100 psi, 300 gpm w/ 630 psi to 9905'. PU wt 220k, SO wt 90k, Rot wt145k. Set 10k down on whipstock @ 9940', torque increased to 17k ft Ibs and stalled against torque limit. PU wt 260k. Calc dispaicment 100 bbls, actual 99.5 bbls. 14:30 18:00 3.50 9,940 3,575 COMPZ FISH TRIP T POOH w/ the whipstock for the "B" lateral. 18:00 20:30 2.50 3,575 425 COMPZ FISH TRIP T Continue to POOH w/ the whipstock. Calculated fill 99 1/4 bbls, actual 109.5 bbls. 20:30 20:45 0.25 425 425 COMPZ FISH SFTY T PJSM on laying down the whipstock and fishin assembl . 20:45 21:15 0.50 425 97 ~ COMPZ FISH PULD T Lay down BHA # 16. ~ i 08l11/2007 21:15 23:00 1.75 97 0 COMPZ FISH PULD P Lay down whipwhipstock, debris sub, drain sub, safety disconnect, bottom trip anchor, blank sub, 1 jt 5" HWDP, two 5" pup jts, unioader, stop sub and seal assembl .stock assembl : 23:00 00:00 1.00 0 0 COMPZ FISH PULD P Lay down and remove subs and BHA from the ri floor. Clear and clean floor. 08/12/2007 00:00 01:15 1.25 0 0 COMPZ FISH PULD T Lay down and remove subs and BHA from the ri floor. Clear and clean floor. 01:15 02:00 0.75 0 0 COMPZ FISH OTHR T Drift 3 stands of 5" drill pipe w/ 2.46" rabbit in the derrick. Looking to locate a 1-7/8" rabbit from the box tap recove run of the whi stock. 02:00 02:15 0.25 0 0 COMPZ FISH SFTY T PJSM on PU/MU BHA # 17. 02:15 04:00 1.75 0 1,620 COMPZ FISH PULD T PU/MU BHA # 17. 04:00 05:00 1.00 1,620 2,600 COMPZ FISH TRIP T Trip in the hole w/ BHA #17. 05:00 06:30 1.50 2,600 62 COMPZ FISH TRIP T Drop a 2.33" rabbit w/ 140' of .092 wire tail. POOH w/ 5" dp And 17 stands of 5" HWDP. 06:30 07:45 1.25 62 0 COMPZ FISH TRIP T Lay down BHA # 17. 07:45 10:00 2.25 0 398 COMPZ FISH PULD T PU/MU BHA # 18. 10:00 16:45 6.75 398 10,103 COMPZ FISH TRIP T Trip in the hole w/ BHA # 18. Locate w/ mule shoe @ 10103', stop sub @ 10044.26' on the C2 packer f/ the "B" lateral. PU wt 130k, SO wt 100k. 16:45 2130 4.75 10,103 398 COMPZ FISH TRIP T Drop a 2.33" OD rabbit w/ 140' of .092" tail wire. Trip out of the hole. PU wt 215k, SO wt 85k. 21:30 21:45 0.25 398 398 COMPZ FISH SFTY T PJSM on Laying down BHA #18. 21:45 23:15 1.50 398 0 COMPZ FISH PULD T Lay down BHA # 18. Clean and clear floor. 23:15 00:00 0.75 0 0 COMPZ CASIN RURD P Rig up to run Hook hanger f/ the "D" later. PU Baker tools and RU GBR tools. 08/13/2007 00:00 00:15 0.25 0 0 COMPZ CASINC RURD P RU to run the "D" lateral hook hanger. 00:15 00:30 0.25 0 0 COMPZ CASIN SFTY P PJSM on running "D" lateral Hook Han er. 00:30 01:30 1.00 0 244 COMPZ CASINC RNCS P PU MU Hook hanger assembly 01:30 03:15 1.75 244 244 COMPZ CASIN RNCS P PU Hook Hanger, MU inner string. 03:15 03:30 0.25 244 244 COMPZ CASINC RURD P Rig down Baker sma~l tongs used for the inner strin . 03:30 04:00 0.50 244 285 COMPZ CASIN OTHR P MU Hook hanger. Orient MWD to Hook Hanger. Also note bentjoint orientation. 04:00 04:15 0.25 285 377 COMPZ CASIN OTHR P MU a stand of 5" drill pipe. Shallow test Sperry Sun MWD. 115 gpm w/ j 540 qsi. I ~ U 08/13/2007 04:15 05:15 1.00 377 2,663 COMPZ CASINC RUNL P Trip in the hole w/ the Hook Hanger on 5" drill pipe. Record PU and SO wt's eve 10 stands. 05:15 06:15 1.00 2,663 2,663 COMPZ CASIN OTHR P Shallow test MWD. 110 gpm w/ 550 si. 06:15 12:30 6.25 2,663 10,218 COMPZ CASIN( RUNL P Continue RIH w/ Hook hanger on 5" drill pipe. Oriented 4-1/2" bent joint to exit the window while @ 9930'. Exit the window @ 9954' -9970'.Record PU and SO wYs every 10 stands, fill pipe every 25 stands. Running speed 120 fUmin. 12:30 14:00 1.50 10,218 10,226 COMPZ CASIN( OTHR P Run stand # 105, PU a single and establish circulation w/ 112 gpm w/ 700 psi. PU wt 240k, SO wt 100k. Orient to 52 deg right, slack off and hook window and set 20k on hook hanger. PU and orient the hook to exit the window, slack off to 10234' (8 1/2' past the window) ( did not locate), PU and orient to hook window, Slack off and set 25k on hook. Final MWD when hooked is 27 ri ht. 14:00 15:15 1.25 10,226 10,027 COMPZ CASIN CIRC P Drop a 3/4" ball to release and inflate the ECP. Pump down @ 2.5 bpm w/ 630 psi for 1000 strokes, then reduce rate to 2 bpm w/450 psi. Ball on seat w/ 1591 strokes. Pressure to 1100 psi (1700 psi w/ 1594 strokes, 2000 psi w/ 1596 strokes, 2170 psi w/ 1597 strokes, 2400 psi w/ 1599 strokes. Began to inflate packer @ 2530 psi. Pressure was 3020 psi w/ 1603 strokes. Bleed off pressure, POOH 2 stands to clear inner string from the hook hanger. Note: Lost 10 bbls of fluid to the formation on tri in the hole. 15:15 15:30 0.25 10,027 10,027 COMPZ CASINC OTHR P Monitor well. Static. 15:30 15:45 0.25 10,027 10,027 COMPZ CASIN SFTY P PJSM f/ POOH laying down drill pipe. Monitor well on the tri tank. ' 15:45 18:00 2.25 10,027 9,203 COMPZ CASINC RUNL P Drop the Haggard Mud Dog ID wiper inside of the drill pipe. POOH w/ Hook Hanger running tool, laying down 5" HWDP and 5" drill pipe. Monitor well , on the tri tank. ' 18:00 00:00 6.00 9,203 3,711 COMPZ CASIN RUNL P Continue to POOH w/ Hook Hanger running tool, laying down 5" drill pipe. Monitor well on the trip tank. Note: Lost 10 bbls of mud to the formation as of midni ht on the ti out. 08/14/2007 00:00 04:45 4.75 3,711 110 COMPZ CASIN( RUNL P Continue to POOH w/ Hook Hanger running tools, laying down 5" drill pipe. Monitor well on the trip tank. s • 08/14/2007 04:45 06:00 1.25 110 0 COMPZ CASIN RUNL P Service break and lay down Baker running tools and inner string w1 Sperry Sun MWD. Tools were run w/ the hook hanger f/ the "D" lateral. Crew Chan e 06:00 07:00 1.00 0 COMPZ DRILL PULD P Continue POOH, break and lay down Baker running tools and inner string w1 Sperry Sun MWD. Tools were run w/ the hook han er fi the "D" lateral. 07:00 07:45 0.75 0 0 COMPZ CASIN RUNL P Ciean rig floor of tools and OBM. Send out pups, XO's and lift subs. SIMOPS: Cieanin its. 07:45 09:45 2.00 0 0 COMPZ DRILL PULD P Instail mousehole into rotary table for taying down DP. Lay down 27 stands of 5" drill pipe from the derrick. Leaving 35 stands in the derrick f/ the next well. SIMOPS: Cleanin its. 09:45 11:00 1.25 0 0 COMPZ WELCT BOPE P Drain BOP stack. BOLDS, Pull wear bushing. make up 4 1/2" test joint & plug. Rig up test equipment to test BOP"s. Fi~l BOP stack & choke manifold with water. Held PJSM, Discuss safety & hazard recognition issues. Discuss procedure to test BOP's. 11:00 15:30 4.50 0 0 COMPZ WELC BOPE P Test BOP stack rams, valves & HCRS. Test all choke manifold valves & lines. Test all floor safety valves. AI test to 250/ 3000 PSI. All tests passed. Witness of test waived bu AOGCC re Jeff Jones. 15:30 16:30 1.00 0 0 COMPZ WELC BOPE P Pull test plug & joint, lay down same. Rig down a{I test equipment. Remove & inspect drillers side fairlead for fastline on tu er. Blow down all lines. 16:30 18:00 1.50 0 0 COMPZ RPCOh PULD P Pull completion running equipment to rig floor. Rig up GBR casing equipment. Rig up Centrilift e ui ment. Crew chan e 18:00 19:00 1.00 0 0 COMPZ RPCO PULD P Continue rig up GBR casing equipment. Rig up Centrilift e ui ment. 19:00 19:15 0.25 0 0 COMPZ RPCO SFTY P Held PJSM with crew, GBR rep, Centrilift rep, and Halliburton slickline reps. Discuss safety & hazard recognition issues. Discuss procedure to make u and run ESP com letion. 19:15 21:00 1.75 0 0 COMPZ RPCOti RCST P Make up Perforated crossover intake with joints 1& 2. Insert lower tandem pump into intake. Install clamp. Make up upper tandem pump assembly and insert into tubing. Rig up Halliburton slickine & sheaves. RIH to seat pump, set acker, and test lu . 21:00 23:00 2.00 0 0 COMPZ RPCO RCST P Rig up Halliburton slickine & sheaves. RIH to seat pump, set packer, and test plua. ~ • 08f14/2007 23:00 23:30 0.50 0 0 COMPZ RPCOh RCST P Rig up test equipment. Pump down tubing to pressure to 1000 PSI -15 minutes. Observed 40 PSI bleed. Good test. Rig down test equipment & lines. 23:30 00:00 0.50 0 0 COMPZ RPC06 RCST P WLIH & pull test plug. Set tubing stop. WLOH rig down Halliburton slickline unit. 08/15l2007 00:00 01:45 1.75 0 0 COMPZ RPCOh RCST P Make up Unique discharge sub. Puli 2 joints of tubing, and intake with installed pump & rack back in derrick. Make up Centrilift Motor assembly, fill with oil & check rotation. Make up A well pump sensor & centralizer as per Centrilift re & Weatherford re . 01:45 02:15 0.50 0 0 COMPZ RPCOh RCST P Rig up Centrilift sheave & hang off ESP cable. 02:15 05:00 2.75 0 0 COMPZ RPCO RCST P Make up stainless steel control line & ESP cable. Attach & perform continuity tests. Install cable gaurds on motorassembly. Used 11 SS bands, 1 Cannon Clam . 05:00 06:00 1.00 0 310 COMPZ RPCOh RCST P Run 4 1/2" Tbg installing Cannon clamps on each collar to 310'. Observed proper displacement in hole. Crew chan e 06:00 12:00 6.00 310 4,421 COMPZ RPCO RCST P Continue run 4 1/2" tbg installing Cannon Clamp on each collar from 310' - 4421'. Perform continuity test every 35 joints ran. Record T& D parameters as per rig engineer. Observed proper displacement. Make u tor ue = 3000 ft/Ibs 12:00 17:30 5.50 4,421 7,440 COMPZ RPCOh RCST P Continue run 4 1/2" tbg installing Cannon Clamp on each collar from 4421' - 7440. Perform continuity test every 35 joints ran. Record T& D parameters as per rig engineer. Observed proper displacement. Make u tor ue = 3000 ft/Ibs 17:30 18:00 0.50 7,440 7,480 COMPZ RPCO RCST P Make up tubing hanger with landing joint. Tubing hanger made up with loaded BPV. Crew Chan e 18:00 22:30 4.50 7,480 7,480 COMPZ RPCOh RCST P Rig up and perform ESP cable splice to penetrator in tubing hanger. Rig down ESP cable & sheave. Rig down GSR tubing running equipment. Clean floor of tools and OBM. PerForm continui test on s lice. Good test. 22:30 23:15 0.75 7,480 7,480 COMPZ RPCOh RCST P Drain BOP stack. Blow down choke & kill lines. Bfow down mud pumps. Clamp off ESP cable & perform continuity test on top side of ~enetrator. aood test. ~ ~ 08/15/2007 23:15 00:00 0.75 7,480 7,512 COMPZ RPCOh RCST P Continue RIH to land tubingh hanger on depth at 7512' MD. Verify properly landed as per Vetco Gray rep. RILDS. UP WT = 135K, SO WT = 78K. 08/16/2007 00:00 00:45 0.75 7,512 7,512 COMPZ RPCOh OTHR P Continue RILDS. Rig up and test upper & lower packoff seal in hanger to 5000 PSI -10 minutes each. Good test. Bleed pressure. Pull and lay down {andin 'oint. 00:45 05:00 4.25 0 0 COMPZ WELC NUND P Nipple down BOP stack & lines. Rig down Choke & kill lines. Install Moving braces in pipe shed. Continue cleaning pits. Clean drip pan under rig floor. Move 20 stands of DP over to drillers side of ri floor for ri move. 05:00 06:00 1.00 0 0 COMPZ WELC NUND P Nipple up Tree as per Vetco Gray rep. Make up production valves. Continue cleaning pits. Disconnect flow line to complex. Disconnect manifold lines to com lex. Crew Chan e 06:00 07:00 1.00 0 0 COMPZ WELCT NUND P Continue nipple up tree. pressure test void to 5000 PSI. Good test. Close alt valves & secure tree. 07:00 10:15 3.25 Q 0 COMPZ MOVE DMOB P Continue with demobing rig disconnecting lines in between complexes. Disconnect & move rockwasher. Ri down Handi-berms. 10:15 11:00 0.75 0 0 COMPZ MOVE DMOB P Tilt Beaver slide into moving position. Prep rig floor for skid. Lift work latform. 11:00 12:00 1.00 0 COMPZ MOVE DMOB P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuus skidding floor & rig move. Skid rig floor into moving position. Rig released @ 1100 hrs. Note: Set up returns tanks, portable choke manifold, and rigged up lines with Little Red Services to freeze protect 1J-162 out of the critical path. Pumped a total of 550 BBLS of freeze protect diesel at 1 BPM - 500 PSI observing a 41 BBt loss to the formation. A BPV was not installed as per wells group. Shut in pressures = IA -340 PSI, OA -140 PSI. All o~erations took ~lace on 8/17f07 v ~;. ~ S ~a.. :',:, ~,~: API I tlWl SurFace Legal Location Field Name BUIJV Latitude (DMS) Longitude (DMS) 5002923360 11 N 10E 35 WEST SAK Alaska 70° 15' 43.726" N 149° 31' 43.288" W Well Type ~ Well Conflguration Type Original KB Elevation (ft) KB-Ground Distance ~ft) KB-CF (ft) ConocoPhillips WI (%) Development 121.80 43.81 ~ : ~ ~.. ~ti!@Ci~ , i €~ ~ ~ F;: t3~t~i~~ .,, j . £; , .,~:. ~. ` , - z~~ ~ ~ ~~~... tu.,. . ~~ ~ ;E ,~ ~.. : ~, , . ~ .~.. ~ ::.: Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Cement 7/18/2007 17:00 7/18/2007 2130 1J-162 Comment Turn over to Dowell. Pump 10 BBLS CW 100. Pressure test lines to 3500 PSI. Continue pump 65 BBLS of CW 100. Pump 71.7 BBLs of MudPush II. Reciprocate casing string in 40' increments with no movement issues.Drop bottom plug. Continue pump a total of 302.5 BBLS of Tail cement. Drop Top plug. Pump 5 BBLS of water spacer. Observed full returns during pumping and no losses. Reciprocate casing string in 40' increments with no movement issues.Turn over to rig pumps. Displace cement with MOBM at 7 BPM - 260 PSI. Observed bottom plug land and show increase of 350 PSI to rupture disk at 512 BBLS, slowing pump to 3 BPM at 652 BBLS pumped away, continue to pump a total of 6714 stks ( 797.6 BBLS) as calculated. Did not bump plug. FCP = 3 BPM - 330 PSI. Held Pressure 10 minutes and bled off. Check floats - floats held. CIP @ 21:33 HRS, with casing set ob depth as planned at 10399'. We reciprocated casing string during cement job until a total of 712 BBLS pumped away.Set in place as free movement ceased. ~,: ~li~BCl~ ~S`G~ ~....~.. ~`„ ~~~` ~ E ~ ~ ' ' , ~. e.. ~_ ! ; .~ ~..~,. , :: ~%a,~ , ,e ,: ,~ sl ~~...... ~ ~, i . , '. ~ ;''~. }.~ , / .r '~ u l .. '.....G.....v (~..i . :.:: :... :.: : .., ~1i1 ~..a.._ ~ ....~.~~~~, . ~E~.• ~.......... E? . ,..a,st e: „,„',.i~ .« ~,,= ,~j,~,^ Description Objective Top (ftKB) Bottom (ftKB) Fu~l Return? Cmnt Rtrn ... Top Plug? Btm Plug? Intermediate Cement Cement 9 5/8" x 10 3/4" 6,600.0 10,399.0 Yes 0.0 Yes Yes Casing in place. Q (start) (bbl/min) Q (end) (bbllmin) Q (avg) (bbllmin) P (flnal) (psi) P (bump) (psi) Recip7 Stroke (ft) ~ Rotated? ; Pipe RPM (rpm) 5 3 7 330.0 Yes 42.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Dril{ Out Diameter (in) Comment Turn over to Dowell. Pump 10 BBLS CW 100. Pressure test lines to 3500 PSI. Continue pump 65 BBLS of CW 100. Pump 71.7 BBLs of MudPush II. Reciprocate casing string in 40' increments with no movement issues.Drop bottom plug. Continue pump a total of 302.5 BBLS of Tail cement. Drop Top plug. Pump 5 BBLS of water spacer. Observed full returns during pumping and no losses. Reciprocate casing string in 40' increments with no movement issues.Tum over to rig pumps. Displace cement with MOBM at 7 BPM - 260 PSI. Observed bottom plug land and show increase of 350 PSI to rupture disk : at 512 BBLS, slowing pump to 3 BPM at 652 BBLS pumped away, continue to pump a total of 6714 stks ( 797.6 BBLS) as calculated. Did not bump plug. FCP = 3 BPM - 330 PSI. Held Pressure 10 minutes and bled off. Check floats - floats held. CIP @ 2133 HRS, with casing set ob depth as planned at 10399'. We reciprocated casing string during cement job until a total of 712 BBLS pumped away.Set in place as free movement ceased. y.;.. ~ . ~E~ : - : . E ' `. .. ~. . ~~~.. ,.,~ ...... . .. . ~.....: , ,.~,,. , . ~ ~ : ~' ~.. .. . , . .. : ... .., ._,_':, . ~~ .,. .. .~-.. . ...,...~ E .,~ . Ceri'f '~ Ftuids ~ t~itl5,t~ . ~ s : e.: ~# _ [ i. ~IU~~ ,~j~..... .~ ~,...~~ : / . ..... ~ ~~ Y;. ~ ~S~ ~ ~-..~~ RER ~' ,R ..n..... , .: .' . ..... ..~. . .. .~,_..: : .._.: - .......,~ .... . . . .. ~ ..... . ~. ~ ~ . , . ;: . _ . ~; ~: ~ Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 6,600.0 10,399.0 735 G 302.5 Yield (ft'/sack) Mix H20 Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1(psi) 2.26 7.74 12.50 6.37 , ~4~ 1ti~ ;, ~ % ~ ~ ~ ~ :.. ~ E ;:,- , ;: ~: ;~ - ......... ........ E€ x. . ~ .:::.~ : ~.. .. ~.._. %. ~< ~ .......... y~,, ~.r. ~..r:: ~ ._.,..... (E, F~_= `F t.: ~.... Additive Type Concentration Conc Unit label D046 ;ANTIFOAM %BWOC Addltive Type Concentration Conc Unit label D047 ANTIFOAM %BWOW Additive Type Concentration Conc Unit label M045 ANTIFOAM Additive Type Concentration Conc Unit label D031 ; BARITE I %BWOC Additive Type Concentration Conc Unit Iabei D827 CHEMICAL WASH %BWOC Additive Type Concentration Conc Unit label D185 DISPERSANT %BWOW Additive IType Concentration Conc Unit label D962 LITECRETE %BWOW ` Additive Type ConcentraUon Conc Unit label D970 MUDPUSH II %BWOW Additive Type Concentration Conc Unit label D110 RETARDER °/aBWOW " Additive ~Type Concentration Conc Unit label D167 UNIFLAC %BWOC ~ r r ~~~~~ r ~~- ~,~ ~u ~~~ ~ s . ~ ~~ 's ~~v ¢>;~'~. ~ ~ . ,~`~ .ti ~' ~ ~ E ^~. .ys ~a~ \\~.,, ~. ~... - -,;, , . ._~ .: Daily Operations Summary Report 1 J-162 Job: DRILLING ORIGINAL s~2si2oo~ 6/29/2007 7/1 /2007 Demob from Summer m Continue MU spud BHA. Spud w BHA. RIH, Continue drill to 1415' 0150 HRS. 1328' TVD Drill 16" Surface hole to 252' MU Directional drill 16" surface hole as planned to 3460' MD. TVD = 2131' hole BROOH f/ 833' to 643', blow down top drive, POOH on elevators f/ 643' to 73', UD BHA @1, clean floor, RU to run 13-3/8" surFace sasing, run 13-3/8" casing to 3832', t to work dee er while circulatin , POOH 2 jts, install centralizers on jt 88 & 89, RI , anger, an casmg, dowell cementing head, circulate while holding PJSM on cementing casing. PU drill pipe and stand back 5 stands of 5" dp w/ super sliders in the derrick, PU/MU/ stand back 13 stands slick 5" dp, then 5 stands of 5" HWDP, remove mousehole, RU to test BOPE, test, RlD, install wear bushing, clear floor, PJSM, PU/MU BHA #2, upload, con't PU/MU BHA #2, PU/MU/RIH w/ 5" dp to 2360' fill pipe, circ, shallow test MWD, con't PU/MU/RIH w/ 5" dp to 2360' fill pipe, con't RIH to tag @ 3717', circ BU, UD single, RU to test casing. ce. Move rig to 1J-162. Rig up. to 6310', monitor weli, short trip 5 stands to 5792', RIH, continue drilling to 7/1 7/12/2007 /14/2007 /16/2007 7/13/2007 7/17l2007 Obtain SPR's, BROOH f/ 7999' to 3785' (shoe @ 3820'), pump Hi-vis hi-weight sweep to surface + BU, monitor well, pull 2 stands, monitor well, pump dry job, POOH, UD Ghost reamer, con't POOH, work BHA, PU/MU BHA #3, RIH to 1785', shallow test mwd, continue RIH to 2235', pipe stopped„ PU 75k over, slack off, inspect drilling line, pull free w/ 97k over pull dragging up hole, UD single, change saver sub MU BHA #5 (12-1/4" hole opener), RIH to 5621', circ, continue RIH to 7991', pump a sweep-Circ, POOH to 7300' pump a dry job, POOH to 3815', pump a sweep-circ, POOH to 3408', pump a sweep-circ, pump a dry job, POOH w/ hole opener, PU/MU/start in the hole w/ Baker impression block and HOWCO 13-3/8" RTTS to test the casing @ 3407.64'. Continue CBU @ 5350', RIH to 6216', PU to 6165', Ream to 6261', RIH to 7460', Ream 7400' to 7500', RIH to 7878', Precautionary ream to TD @ 7999', Drill 12-1/4" intermediate hole to 8256', acquire Cassandra survey's, drill to 9300', replace Pressure relief on #1 mp, drill to 9773'. BROOH f/ 7685' to 3880', pull to 3785', pump a 40 bbls hi vis/ high wt sweep, circ, BR~OH to 3310', pump a weighted/ hi vis sweep, circ, pump a 6% steel lube pill, spot in the casing, displace w/ dry job, slip and cut drilling line, POOH, UD BHA #8, clear floor of tools. Circulate & condition mud. Load shed with 38 joints of 10 3/4" casing. Continue run 9 5/8" x 10 3/4" casing, perform 797 BBL cement job. Did not bump plug. Nipple down BOP's & set emergency slips. !, Page 1/3 Report Printed: 9/13/2007, Daily Operations Summary Report 1 J-162 Job: DRILLING ORIGINAL same. NU BOP"S. test 7/21 /2007 7/23/2007 7/24/2007 the B lateral to 13472' MD. ND = 3243'.Total Bit HRS = 18.9. well with SFMOBM, and POOH. Run 5 1/2" liner. MU /2007 8/2/2007 8/8/2007 7/30/2007 8i1 8/3/2007 8/9/2007 set same rvvi ~, mv v uc uinwiy aaacinuiy. ~ n~. vnc~.iwnai wm n~in ivvw -~w<+ inv. vn Out of zone. POOH. Lay down bit 8~ MWD assmy. MU 8 1/2" Security bit & assembly. Directional Drill D lateral to 13002'. MD. Repair shock hose on rig. MD. ND = 3167'. ilalJstee~~r~ng difficulC drili D lateral to Complete circulating 5 bottoms up above the window @ 9954'. Trip back to 10812', washing & reaming in hole f/ 10812' to 12050', trouble shoot Varco TDS-8SA Top drive. POOH on elevators to 9862'. Continue to troubleshoot the top drive. POOH to 8150'. Continue to work on the top drive. Pump 20 bbl dry job. POOH to test BOPE (14 day test). Note: Still working to fix the Varco TDS-8SA top drive. Locating electrical parts from Varco. Circulate @ 900 gpm w/ 3420 psi. recip 60'. Circulate surface to surface + 7 BU's. Waiting on parts for the V~ TDS-8SA top drive (capacitors 8 electrical service loop). Trouble shooting the top drive adjustable frequency controller. Prepare and install ends on the new electrical service loop. Cleaning on the rig. Cleaning and painting on the rig. Change the liners in both mud pumps to 6-1/2". Circ 4 BU @ 725 gpm w/ psi. Preparations are being made for service tech's and parts to arrive to fix top drive. Cleaning and painting on the rig. Preparations were made for service tech's and parts to arrive to fix top drive. Function tested top drive on auto checkout, ok. While rotating pipe and then using the torque release button to let the torque out of the string, a capacitor failed in the inverter section of the top drive house. Re trouble shooting. install another capacitor. ' Electricians continue to repair Varco top drive house, function test top drive, RIH f/ 9895' to 10690', ream hole f/ 10690' to 14489', displace to SFOBM, monitor well, POOH on elevators to 290'. PJSM, PU/MU RIH w/ whipstock retrieval BHA #15 to 9885'. PJSM, slip and cut drilling line, service rig, make top drive connection, RIH and wash slot, hook whipstock, jar free, POOH ro 9850', started dragging, jar up and pull to 9700' -swabbing, CBU, POOH to 9626'- swabbing, RIH to 10042', POOH (not swabbing), drop 1-7l8" rabbit w1 100' of tail wire, continue POOH w/ BHA # 15. Did not retrieve the whipstock. Page 2J3 Report Printed: 9i13/2007' Daily Operations Summary Report 1 J-162 Job: DRILLING ORIGINAL MU BHA # 17, RIH to 2600', POOH, L/D BHA, MU BHA # 18, RIH w/ 4-1/2" jt of BTC into the SBE of the "6 lateral ( mule shoe 10103', stop on C2 zxp @ 10044'), POOH, UD BHA #18, RU to run the "D" lateral Hook Hanger. ue laying down drill pipe, Test BOPE, RU/Run 4-1 up tree & test. Prep rig & move to 'i Page 3/3 Report Printed: 9/13/2007'i . • ~` 1J-962LinerDetail Weu: ~~-~sz ConocoPhillips 5-1/2", 15.5 ppf, BTC-Mod, L-80 Casing Date: 7/23/2007 Ala4ka, Ine. ~ ~ ~ Rig: Doyon 15 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN OD(in) Max OD(in) ID(in) LENGTH TOPS ~ P ~1 nominal actual actual '~-~~i _ . Liner Rannin Tool 5" Does not sta in hole MLZXP Liner To Packer 9-5/8" 7.50" X 8.32" FlexLock Liner Hanger 7" x 9-5/8" 6.09" X 8.30" XO Bushing 4.95" ID, 7.63" OD 7"- M563 x 5 1/2" H563 190~7 Seal Bore Ext. (Hydril 563) 4.75" ID x 6.28" OD XO Pu Joint 5 1/2", L-80 H563 box x 5/12" BTC Pin 5-1/2'; BTGMod, L-80, 15.5 LinerPu Joint ~ts sa to ~oo ~~ts ~:;~~. BT~.1Vt~d, L::~U;:1a:5 fBlaii[c Casr " w!1°R.; ; ~ts sz to ss 2~ts 5-1/2" BTC-Mod, L-80, 15.5 ppf Slotted Casing w/ TR ~ts s5 to s1 7.lts a=~/2 .STC;It?1etd, L,8[i;:'15;~ ~ Bfa.rih:~zsin vx[TE2.;_:. :: Jts 45 to 84 40 Jts 5-1/2" BTC-Mod, L-80, 15.5 f Slotted Casing w/ TR .lts za to aa z1 Jts 5-1/2" BTC-Mod, L-80, 15.5 pf Slotted Casing Jts 19 to 23 5 Jts ...._ :::... ..:.: :.::.;. , ,; .: ....:::.:..:..::.: ....:..: .:::.:. ::....::::_:::::. ::::::. ._:::::::. ~=~tz . ~~`c~l~fod .L-Ba, ~~ ~::p . ~ a1~nk :cas~ng . . ;.::.. . ;:; Jts 1 to 18 ia ~ts 5-1/2" BTC-Mod, L-80, 15.5 f Slotted Casin 5-1/2" BTC-M x 4-1/2" BTC-M Crossover 4-'1/2", BTC, L-80, 11.6 f Blank Casing - 4-1/2", BTC, L-80, 11.6 pf Blank Casing 4=1/2" Silver Bullet Shoe Bttm of Shoe = To Of Window lanned 9953' _???' above TOL TD 8-1/2" hole 14,490.00' MD! 3218.37' ND 5-1/2" Shoe 14,480.00 MD./ 3218.51' ND (10.0' RatHole Run 1 S iroGlider per joint floating gn the BTC On 'ts 1-93 Jts. 100-40 have Torque Rinqs installed Ran total of 102 jts Csg 100 ~ts 5-1/3", 2 jts 4-1/2" Ran Total 93 S irogliders Used Run-N-Seal thread eompound on all connections. brifted casing to 4.825" w/ teflon rabbit. Tor ue i~ings Instalted in joints 40 7'hru 100 = 60 tor ue rings Supervisors: Fred Herbert / Scoit Heim 10042.95 10042.95 11.30 10042.95 21.25 10054.25 5.25 10075.50 1.44 1008075 19.65 10082.19 2.04 10101.84 3.80 10103.88 285.47 10107.68 86.75 10393.15 303 92 : i144799€3 1713.50 `:::;::9Q78382 905.67 12497.32 217.94 > .334E3~.,93 770.41 :::::;138~(3 9~ _.._ 1.43 14391.34 41.90 14392.77 43.64 14434.67 1.69 . 14478.31 14480:00 14480.00 14480,.00 4 4480.00 14480.00 14480.00 14480.00 14480; 00 14480:00 14480:00 ,14480,00 14480.00 1448.0.00 144380"00 14480.00 U Wt Rl; 280K Dn Wt R7~ OK Block Wt 70K Rot Wt OK ~ ~ 30-Aug-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-162 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 10,497.30' MD Window / Kickoff Survey 10,550.00' MD (if applicable) Projected Survey: 14,490.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date r ~ ~a'''~''° ~ Signed ~ Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) a.~Z-~go ~ ~ 30-Aug-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-162PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and '`.PDF files. Tie-on Survey: 41.00' MD Window / Kickoff Survey 0.00' MD (if applicable) Projected Survey: 3,998.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ) oZ ~~4-~-7 Signed ~~t~rar~ ~~~~ - Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) o~-~~~`"O~~ • • 30-Aug-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-162PB2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 3,805.42' MD Window / Kickoff Survey 3,820.00' MD (if applicable) Projected Survey: 11,035.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ) ~. d~ ~c~ ~ Signed V Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ao ~yv~~ 1J-162PB2 Sidetrack ~ ~ Maunder, Thomas E (DOA) Page 1 of 1 From: Reilfy, Patrick J [PatrickJ.Rei{!y@conocophiUips.com] Sent: Monday, July 23, 2007 1:39 PM To: Maunder, Thomas E (DOA) Subject: 1J-162PB2 Sidetrack Attachments: Patrick.J.Reifly@conocophiilips.cam.vc€ Tom, The details of the sidetrack are as folfows: • Weli: 1J-162 • Rig: [7ayon 15 • Date: 7120/07 • T"rme: 2215 hrs • Last Casing: Intermediate ~a 10,399' • MD af abandaned section: 10,527' - 11,0'i1' ~o`~, -~~~ We exited the formation after crossing a down thrown fault. We made a low side sidetrack. We are p{anning to isolate the sidetrack by allowing it to collapse. If you need any additional information ptease eontact me. Pat Reitly ConocoPhiltips Alaska Drilling & Wefts (907) 265-6048 WORK (907) 244-5558 CELLULAR (918) 662-8284 FAX TO E-MAlL Patrick. J. Reilly@conocophil(ips.com «Patrick.J.Reilly~a conocophitlips.com.vcf» 8/1/2007 . • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA} Sent: Friday, Jufy 't3, 2007 2:36 PM To: 'McKeever, Steve'; Re~gg, James B(~OA) Cc: Thomas, Randy L; Allsup-Drake, Sharon K; Harlwig, Dennis D; Reilly, Patrick J; Doyon 15 Company Man Subject: RE: Well 1J-162 Operations Update Operations tast night Steve, ~O~ ~ O ~~ I appears that you have successfully verified that you can continue forward with your originally plannect operations. One for the home team! Tom Maunder, PE AOGCC -----Original Message----- From: McKeever, Steve [mailto:Steve.McKeever@conocophillips.com] Sent: Friday, July 13, 2007 2:18 PM To: Maunder, Thomas E(DOA); Regg, James B(DOA} Cc: Thomas, Randy L; Allsup-Drake, Sharon K; Hartwig, Dennis D; Reilly, Patrick J; Doyon 15 Company Man Subject: FW: Well 1J-162 Operations Update Operations last night Good Afternoon - We11, today things are not so discouraging with our operation on 2J-162. Last night we tripped in the impression block (to 3470, below the suspected bacl spot at 3428) and test packer (to 3407, above the suspected bad spot)without the string ever taking weight. We tested the casing above 3407 successfully to 3,000 psi, and tripped out of the hole, finding no concerning marks on the impression block. We then picked up 4 joints of 9-5/8" casing and ran it to the 13-3/8" casing shoe at 382Q'with no indications of any problems. We plan to go back in wi~h a drilling assembly and drill to our intermediate casing point. Please let me know if you have any concerns about this course of action. Thanks kindly, Steve McKeever -----Original Message----- From: McKeever, Steve Sent: Thursday, July 12, 2007 5:08 PM To: Tom Maunder (tom maunder@admin.state.ak.us}; James Regg (jim regg@admin.state.ak.us) Cc: Thomas, Randy L; Har~wig, Dennis D; Allsup-Drake, Sharon K; Reilly, Patrick J Subject: Well 1J-162 Operations Update Tom & Jim: Following up on my conversation earlier this afternoon with Jim, here is a summary of our operations to date on West Sak well 1J-162, and our planned operations: For past operations, please see the attached report of daily operation summaries. In short, in the process of drilling our 12-1/4 intermediate hole, we've found evidence of possible prob].ems with our 13-3/8" surface casing. We are going to do a diagnostic trip tonight to gain more information about the nature and extent of the potential problem. The potential problein is at +/- 3,428 MD (+/- 2130 TVD), 392 feet abave the casing shoe at 3820 MD (2207 TVD). Late yesterday a 12" OD shoe on a globe basket needed to be worked and rotated to pass some sort of obstruction at that depth. Tonight we will run an impression block and test packer to gain more information about the obstruction. Should 1 ~ ~ the casing test above the problem area, we will next run a few joints of 9-5/8" casing in the well on drill pipe as a large drift, the goal being to gain confidence that we can run our intermediate casing string past the obstruction. Should that run be successful, our plan is to next run a drilling assembly, drill to our intermediate casinq point, and run and cement the in~ermediate casing. I will call or email you fellows in the morning with more information about what we find out with our run tonight. Steve McKeever Staff Drilling Engineer ConocoPhillips Alaska, Inc. phone: 907.265.6526 cell: 907.351.5004 fax: 907.265.1535 Units of Conversion: 1 million bicycles = 2 megacycles 2 • i 1J-162 Daily Operations Summaries Start Date Last 24hr Sum 6/28/07 Demob from Summer maintenance. Move ri to 1J-162. Ri u. 6/29/07 Pick up 5" DP & HWDP. Load pits with spud mud. RU Gyro unit. MU BHA. 6/30/07 Continue MU spud BHA. Spud well @ 0150 HRS. Continue Directional Drill 16" SurFace hole to 252' POOH, MU BHA. RIH, Continue drill to 1415' MD. 1328' TVD 7/1/07 Directional drill 16" surtace hole, wiping excessive doglegs of more than 5 de . as er DD. Av ROP = 103' /hr. 7/2/07 Directional drill 16" surface hole as planned to 3460' MD. ND = 2~31'. Trou h hole for excessive do le s. 7/3/07 Directional drill 16" surface hole as planned to TD @ 3998' (2237.61' ND), Circ 3BU while pulling to 3650', RIH to TD, , BROOH to 833'. 7/4/07 BROOH f/ 833' to 643', blow down top drive, POOH on elevators f/ 643' to 73', UD BHA @1, clean floor, RU to run 13-3/8 surface sasing, run 13 3/8" casing to 3832', try to work deeper while circulating, POOH 2 jts, install centralizers on jt 88 & 89, RIH, MU hanger, tand casing, RU dowell cementing head, circulate while holding PJSM on cementing casin ." 7/5/07 Circ prior to cementing, Dowell cement surFace casing (225 bbls cement returns), R/D cementing equip, UD landing joint, R/D casing tools, N/D diverter, NU Vetco Gray Multibowl wellhead (MB222A), NU 13-3/8 BOP stack, install VWVf super sliders on 120 joints of 5" dp, load pipe shed with drill pipe, changing liners on mud pumps to 6-1/2", PU driH pipe and stand back 35 stands of 5" dp w/ super sliders in the derrick." 7/6/07 PU drill pipe and stand back 5 stands of 5 dp w/ super sliders in the derrick, PU/MU/ stand back 13 stands slick 5" dp, then 5 stands of 5" HWDP, remove mousehote, RU to test BOPE, test, R/D, install wear bushing, clear floor, PJSM, PU/MU BHA #2, upload, con't PU/MU BHA #2, PU/MU/RIH w/ 5" dp to 2360' fill pipe, circ, shallow test MWD, con't PU/MU/RIH w/ 5" dp to 2360' fill pipe, con't RIH to tag @ 3717', circ BU, UD sin le RU to test casin ." 7/7/07 Test 13-3/8 surface casing to 3000 psi, POOH 4 stands, slip and cut drilling line, service rig, PJSM, perform stripping drill w/ both crews, blow down choke an kilt lines and manifold, RIH to 3700', move 4 stands of HWDP in the derrick, inspect grabbbers on top drive, PU 3 singles f/ the shed, tag Float collar, drill plugs, FC, shoe track, shoe, then drill 50' below shoe to 3870', POOH to 3795', circ, displace to new 9.0 ppg LSND mud. RU and perform LOT ( EMW 14.9 ppg), RIH to 3870'. Drill 12-1/4" intermediate hole to 4241', POOH to 4080', change out geopilot skid RIH drill to 4458'." ~ ~ 1J-162 Daily Operations Summaries 7/8/07 Directional driil 12-1/4 f/ 4458' to 6310', monitor weli, short trip 5 stands to 5792', RIH, continue drillin to 6481'." 7/9/07 Directional drill 12-1/4 f/ 6481' to 7910', POOH a stand, work on #2 mud um , RIH, Directional drill 12-1/4" hole to 7999'." 7/10/07 Obtain SPR's, BROOH f/ 7999' to 3785' (shoe @ 3820'), pump Hi-vis hi- weight sweep to surface + BU, monitor well, pull 2 stands, monitor well, pump dry job, POOH, UD Ghost reamer, con't POOH, work BHA, PU/MU BHA #3, RIH to 1785', shallow test mwd, continue RIH to 2235', pipe stopped„ PU 75k over, slack off, inspect drilling line, pull free w! 97k over pull dragging up hole, UD single, change saver sub 7/11/07 C/O the saver sub, C/O jt of 5 dp, CBU x3, POOH w/ BHA #3, service rig, MU BHA #4, RIH to 2240', tagged up, dropped 1-7/8" steel ball f/ reverse circ basket, wash and work basket to 2463', trip to 3428', Work basket f/ 3428' to outside of casing to 3845', pull back up to 3815', CBU, monitor well, pump dry job, POOH- 70k overpull @ 3428', work free, POOH UD BHA #4, inspect recovery, service rig, remove tools f/ the floor. Prepare to make a 12-1/4" hole opener run." CPAI - West Sak Updates ~ ~ Page 1 af 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, July 05, 2007 3:01 PM To: 'Hartwig, Dennis D' Cc: Jerome Eggemeyer; Randy Thomas Subject: RE: CPAI - West Sak Updates Dennis, As we discussed, ~~ JO.,,I ~ 0,~~ 1. With regard to 1J-162, the requirement at 20 AAC 25.030 (fl is conduct test to a predetermined EMW, leak-off or fracture pressure as specified [and approved~ in the permit. The test results must demonstrate that the integrity of the casing shoe is sufficient to contain anticipated welibore pressures ... Jerome and 1 had discussed LOT/FIT procedures. I have not seen what I understand is a new procedure. The practice of 3 barrels past pump-in came from annular disposal issues where 20 AAC 25.080(e)(2) requires that the downhole disposal pressure may not exceed the downhole pressure obtained during the formation integrity test ... Actually pumping in was the requirement to clearly demonstrate what was occurring proximate to the shoe. Where AD is not planned, so long as the 030 requirements are met, FIT or LOT with 3 points past appears sufficient. Where annular disposal is planned, 3 points may not be sufficient. Proof will be when an AD application is received and is determined not to have sufficient information. 2. Stopping short of TD is not a problem. The actual depth drilled will be reported on the 407. Call or message with any questions. Tom Maunder, PE AOGCC From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips,com] Sent: Thursday, July 05, 2007 2:31 PM To: Maunder, Thomas E (~OA) Subject: CPAI - West Sak Updates Importance: High Tom, I am covering West Sak for Pat Reilly over the next couple of days and thought I would updafe you on a few items of note. Doyon__15 _ -_Drilling_Dual Lat Producer 1J-162 The 16" surface hole was drilled to approximately 3,998'MD. 13 3/8" surface casing was run and could not pass beyond 3,832'MD - the casing was cemented in place approximately 178` off bottam. The cement job went well - 226 bbls back to surface with plugs bumped. Considering the possibility that we have 178' of open hole below the 13 3/8" shoe, we are more biased to pump longer to obtain an accurate LOT. The current plan is to obtain 3 additionat points (approximately $/." bbl) beyond 7/5/2007 CPAI - West Sak Updates ~ ~ Page 2 of 2 the break-over point. The initial plan also involves sidetracking the well shortly after drilling out the shoe. A LOT witl be conducted once it is confirmed that we have drilled ~20' of new formation. Doyon_141_-__Dril_ting_Tri-lat Injector 7J-_1_22 We have just finished drilling the lower A-lateral and will be running a USIT log across the intermeciiate casing in the next few hours. The permitted Total depth of the 1 J-122 was 18,054'. After drilling to approximately 15,109'MD it was decided to end drilting prematurely due to water contact. Please contact me if 1 can provide any further information...Regards Dennis Hartwig Drilling Engineer ConocoPhillips Alaska, Inc. Office : 907•265-6862 Cell : 907-980-1433 Fax :907-265-1535 7/5/2007 Re: Casing Ram Requirements . ~ Subject: Re: Casing Ram Requirements From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Wed, 13 Jun 2007 13:26:42 -0800 To: "McKeever, Steve" <Steve.McKeever@conocophillips.com> CC: "Hartwig, Dennis D" <Dennis.D.Hartwig@conocophillips.eom>, "Reilly, Patrick J" <Patrick.J.Reilly@conocophillips.com>, AOGCC North Slope Office <aogcc~rudhoe_bay a~admin.state.ak.us> Steve, My colleagues and I have discussed your message. It is our opinion that rams to fit tize casing sizes should be employed. Please call or message with any questions. Tom Maunder, PE AOGCC McKeever, Steve wrote, On 5/25/2007 4:46 PM: Hello Tom - I'm writing to request an "off the record", informal opinion from you with regard to the need for casing rams for some upcoming West Sak wells. We are planning on running tapered casing strings: roughly 6,000 feet of 9-5/8" 40# pipe, followed by ±3,000 feet of 10-3/4" 73.2# pipe on top. We are doing this to overcome drag and friction in high angle holes - the heavy 10-3/4" pipe will be used to "push" the 9-5/8" pipe to bottom. We're planning to use our normal stack (ARRSR) with 10-3/4" casing rams in the lower cavity. The question for you is do we need to additionally put 9-5/8" rams in the upper cavity, given the regulation requiring "..pipe rams that fit the size of drill pipe, tubing, or casing being used,..."? We feel that we can safely run the tapered casing string with only the 10-3/4" rams given the following: -AOGCC regulations require only 3,000 psi BOPE for West Sak wells. -while the West Sak sands will be exposed in the well bore as we run the casing string, they will be at initial reservoir pressure, having not been exposed to any injection or withdrawal. -we have had no well control problems during West Sak drillinq on both lE and 1J. -in the past, when West Sak wells were constructed without surface casing, casing strings were run into the exppsed West Sak formation while only a diverter was rigged up. Similarly, the surface casinq of Kuparuk wells is run across the West Sak with only a diverter for well control. -in the remote chance that it is necessary to close in the well with the 9-5/8" casing across the preventers, the annular could be used. -the tapered casing string will be run with a Frank's casing fill up and circulation tool rigged up on the Top Drive, allowing immediate circulation of the string, should a well control incident occur. If your informal opinion is that the AOGCC would approve running such a tapered casing string without a set of 9-5/8" rams installed, I will prepare and submit a formal request for a waiver from the requirement for "..pipe rams that fit the size of drill pipe, tubing, or casing being used,..." Thanks for you help with this matter - Steve McKeever Staff Drilling Engineer ConocoPhillips Alaska, Inc. phone: 907.265.6826 1 of 2 6/13/2007 1:27 PM ~ ~ a a ~ a ~ SARAH PAUN GOVERN , 1R ~~A ~aa~ ~~p~ 333 W. 7th AVENUE, SUITE 100 C~~FjRQ~~~~ CQ~II~"si~~ ANCHORAGE, ALASKA 99501-3539 PHONE (90n 279-1433 FAX (90~ 27&7542 Randy Thomas Drilling Team Leader ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 1J-1 E2 ConocoPhillips Alaska Inc. Permit No: 207-080 Surface Location: 1958' FSL, 2527' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 1611' FSL, 87' FWL, SEC. 3, T10N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to c~mply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the filaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. VJhen providing notice for a representative of the Commission to witness an~~ required test, contact the Commission's petroleum field inspector at (90~'`6y59-3607 (pager). n DATED this ~ day of June, 200'7 cc: Department of Fish & Game, Habitat Section w/o enc1. Department of Environmental Conservation w/o encl. ~ • ~ Canoco h ~ I I ~ s p Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone(907)265-6830 Email: Randy.L.Thomas@conocophillips.com RECEIVED June 5, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Producer, 1J-162 and 1J-162 L1 Dear Commissioners: JUN 0 6 ?_007 A{aska Oil & Gas Cnns. Carmmissien Rncharage ~ ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore producer well, a horizontal well in the West Sak ~~B" and "D" sands. The main bore of the well will be designated 1J-162, and the lateral bore of the well will be designated 1J-162L1. We draw your attention to this well as it is different than wells in the immediate area. This well has a 10.75" x 9-5/8" tapered casing string. `~ Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1]-162 is July 2, Z007. If you have any questions or require any further information, please contact Pat Reilly at 265-6048. Sincerely, ~-°-_-•e_ ~c~~ Randy Thomas Greater Kuparuk Area Drilling Team Leader ~ STATE OF ALASKA ~ ALASKA OI~ AND GAS CONSERVATION COMMISSION~ PERMIT TO DRILL ~~~ 20 AAC 25.005 ~E~EIVEa ~~» a s 2007 ~y~sk~ t~ii & Gas Cans. Commissian I-..nl~nrhna 1a. Type of Work: Drill Q/ ~ Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ~ Development Oil ~, Stratigraphic Test ^ Service ^ Development Gas ~ Multiple Zone^ Single Zone ~ tc. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ~ Shale Gas ^ 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 ' 11. Well Name and Number: 1J-162 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 14259' ~ TVD: 3218' ~ 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Govemmentat Section): SurFace: 1958' FSL, 2527' FEL, Sec. 35, T11N, R10E, UM ' 7. Property Designation: ADL 25661, 25660, 25663 West Sak Oil Pool ~ Top of Productive Horizon: 144' FSL, 53' FWL, Sec. 34, 711 N, R10E, UM 8. Land Use Permit: ALK 471, 470, 472 13. Approximate Spud Date: ~~2~2Q0~ Total Depth: 1611' FSL, 87' FWL, Sec. 3, T10N, R10E, UM ' 9. Acres in Property: 2560 14. Distance to ~3 ~i h(C~~(,~, Nearest Property: ~avu .0 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558683 ~ y- 5945769 ~ Zone- 4 10. KB Elevation (Height above GL): 'I Z'I' AMSL ~ teet 15. Distance to Nearest Well within Poot: 1J-~o9 , 16. Deviated wells: Kickoff depth: 300' ' ft. Maximum Hole Angle: 92° de9 17. Maximum Anticipated Pressures in psig (see 20 ,anC zs.os5) Downhole: 1436 psig ~ Surtace: 1076 psig ~ 18. Casing Program ti S ifi Setting Depth Quantity of Cement Size ons pec Ca Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD TVD (including stage data) 40" 20" 62.5# H-40 Welded 80' 40' 40' 120' 120' 360 sx AS 1 16" 13-3/8" 68# L-80 BTC 4572' 40' 40' 4612' - 2303' - 770 sx AS Lite, 220 sx DeepCRETE 12.25" 10.75" 73.2# L-80 BTCM 3405' 40' 40' 3445' 2105' 690 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 7000' 3445' 2105' 10445'- 3251' • see above 8.5" 5.5" 15.5# L-80 BTCM 4167' 10091', 3251' 14258' ~ 3218' ~ slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD ND Cond uctor/Structu ra I SurFace Intermediate Production Liner PerForation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee o BOP Sketch ~ Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q/ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. ContaCt Pat Reilly @ 265-6048 Printed Name Randy Thomas Titte Drilling Team Leader Signature ~` ~'~-~~_ Phone ~S- G~3a Date ~~S ~~ 7 -~ haron Alf u -D k Commission Use Only Permit to Drill Number: zj~~ .-^~ API Number: 50- ~2.~~ Z~~.~o~ ~~ Permit Approvai Date: ~• i3' O See cover letter for other requirements Conditions of app~oval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: \ Samples req'd: Yes ^ No u I g req'd: Yes ^ No ~ Other: ~ Qgt ~~~~ ~S "~"' (~ H2S measures: Yes ~ No Dire vy req'd: Yes [~'~ No ^ K \ ~5~~ ~ `~~ f y" ~Gv~S ~U i~CCJ ~r~ „~ ~ ROVED BY THE COMMISSION ~i DATE' , COMMISSIONER ~~ Form 10-401 Revised 12/2005 ~ ~~ ~ ~ ~ ~ ~ ~ ~ v ~~ Submit in Duplicate ~ ~~ ~ ~ Q~ ~ ~ation for Permit to Drill, Well 1 J-162 Revision No.O Saved: 5-Jun-07 Permit It - West Sak Well #1J-162 Application for Permit to Drill Document Table of Contents 1. Well Name .................................................................................................................. 2 Requirements of 20 AAC 25. 005 (n ............................................................................................................. 2 2. Location Summary ..................................................................................................... 2 Requirements of 20 AAC 25. 005(c)(2) ......................................................................................................... 2 Requirements of 20 AAC 25.050(b) ............................................................................................................. 3 3. Blowout Prevention Equipment Information ............................................................... 3 Requirements of 20 AAC 25.005(c)(3) ......................................................................................................... 3 4. Drilling Hazards Information ..................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ........................................................................................................ 3 5. Procedure for Conducting Formation Integrity Tests .................................................. 3 Requirements of 20 AAC 25.005 (c)(5) ........................................................................................................ 3 6. Casing and Cementing Program ................................................................................. 4 Requirements of 20 AAC 25.005(c)(6) ......................................................................................................... 4 7. Diverter System Information ...................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ......................................................................................................... 4 8. Drilling Fluid Program ............................................................................................... 4 Requirements of 20 AAC 25.005(c)(8) ......................................................................................................... 4 Surface Hole Mud Program (e,xtended bentonite) ......................................................................................... 4 Intermediate Hole Mud Program (LSND) .................................................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) B, D sand laterals .................................................... 5 9. Abnormally Pressured Formation Information ........................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ........................................................................................................ 5 10. Seismic Analysis ......................................................................................................... 5 Requirements of 20 AAC 25. 005 (c)(10) ...................................................................................................... 5 11. Seabed Condition Analysis .......................................................................................... 5 Re uirements o 20 AAC 25.005 c 11 ............... 5 9 .f ~~~ ~ ....................................................................................... 1J-162 PERMIT IT Page 1 of 7 Printed: 5-Jun-07 . Ap~on for Permit to Drill, Well 1 J-162 Revision No.O Saved: 5-Jun-07 12. Evidence of Bonding ................................................................................................... 5 Requirements of 20 AAC 25. 005 (c)(12) ...................................................................................................... 5 13. Proposed Drilling Program ......................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ...................................................................................................... 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .................................. 7 Requirements of 20 AAC 25. 005 (c)(14) ...................................................................................................... 7 15. Attachments ............................................................................................................... 7 Attachment 1 Directional Plan .................................................................................................................. 7 Attachment 2 Drilling Hazards Summary ................................................................................................... 7 Attachment 3 CemCADE Summary ............................................................................................................. 7 Attachment 4 Well Schematic .................................................................................................................... 7 1. Well Name Requirements of 20 AAC 25.005 (~ Each wel[ must be idertified by a unigue name desigiaaied by the operator m~d a Ui~ique API number• assig~~ed by the commission under 20 AAC 25.040(b). For a ivell i~~itla multiple weld branches. each braneH must sinailarly be idendfred by a unique i~am~e and API number by adding a suffix to the nan2e designatea! for the 1~~e11 by lhe operator and to the nu~nbe~• assigned to the ~+ ell by the comnzission. The well for which this Application is submitted will be designated as 1J-162. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An applieatioiz for a Permit to Drill must be accompanied by each of the follo~~~ing items, except for ma item already on file ivith the comnzission arrd identifted irr the applieation: (2) a plat ident~ing tlie property and the property's oia~ners and shoia~ing ~ (A)the coordinates of the p~•oposed location of the irell at the surface, at tlie top of each objective formation, and at Xotal depth, refererzced to govervrmental seetion lines. (B) the coordinates of the proposed location of the ivell at the surface, referenced to the state plane coordana~e system for this state as maintair~ed by the National Geodetic Suryey ii~ the Natiorral Oceanic and Atmospheric ~dmir~ish•ation; (C) t7ae proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 1958' FSL, 2526' FEL, Section 35; T11N, RlOE ASP Zone 4 NAD 27 Coordinates RKB Elevation 121' AMSL ~ Northings: 5,945,769 Eastings: 558,683 ~ Pad Elevation 81' AMSL ~ Location at Top of Productive Interval (West 144' FSL, 53' FWL, Section 34, T11N; R10E Sak "B" Sandl ASP Zone 4 NAD 27 Coordinates Northings: 5,943,897 Eastings:550,719 Measured De th, RKB: 10,44` Total Vertical De th, RKB: 3,251 Total Vertical De th, S5: 3,130 Location at Total Depth 1611' FSL, 87' FWL, Section 3, T10N, R10E Measured De th, RKB: 14,259 ~ ASP zone 4 NAD 27 Coordinates SSO 787 Total Vertical Depth, RKB: 3,218 , Northings: 5,940,086 Eastings: Total Vertical De th, SS: 3,097 and (DJ other inforniation required by 20 AAC 25.050(b); 1J-162 PERMIT /T Page 2 of 7 Printed: 5-Jun-07 ~ ., s ~,~ , ~ #+y~ ~ ~..a~ ~ ~ ~ ~ ~ ~ ~ation for Permit to Drill, Well 1J-162 Revision No.O Saved: 5-Jun-07 Requirements of 20 AAC 25.OSO(8) If a ivell is to be inte~7tio~~ally deviated, the application for a Permit to Drill (Forne 1 D-401) nsust (1) include a plat, drm~~n to a suitable scale, showing the path of the proposed tivellbore, including all adjacent wellbores within 200 feet of any portion of the pr•oposed ivell,- Please see Attachment 1: Directional Plan avrd (2) for all ~~ ells ivithin 200 feet of the proposed wellbore (A) list the nanzes of the operato~•s of tl~ose wells, to the extent that those rranzes are known or discoverable an public records, and sho~v that each named operator has been furnished a copy of the applicatron by certif ed mail; or (B) state that the applicant is tlae o~zly affected oivner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Pennit to Drill must be accompm~ied by each of dze following items, except for an item already ovr frle ~cith the coni~nission and ident~ed in the application: ~ (3) a diagram and descriph'on of the bloivout prevention eguipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA} will be utilized to drill and complete well 1J-162. Please see information on the Doyon Rig 15 blowout prevention equipment placed on file with the Commission. If required, 10 3/4" and 9 5/8" rams will be installed while running the tapered intermediate string. 4. Drilling Hazards Information ~~v~ ~- i Q\~ ~rtiS c-~~v ~ c~~ ~ ~1~ ~-3 Requirements of 20 AAC 25.005 (c)(4) Arr applicatio» for a Permit to Drill must be accompanied by each of the folloiving items, exeept for an item already on fi7e ivitFr the com~nission and zdent~ed i~a the application: (4) i~lformation on drillirtg ha_ards, indudirrg ~ (A) the mcz~ imum doirnhole p~•essure that rnay be encounte~~ed, criteria used to determine it, m~d maximum potential susface pressure based ois a metharre gradient; The expected reservoir pressure in the West Sak sands in the IJ-162 area is 0.44 psi/ft, or 8.4 ppg EMW (equivalent mud weight). - The maximum potential surface pressure (MPSP) Based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak A2 sand formation is 1,076 PSI, calculated as follows: --- The MPSP is: MPSP =(3,263 ft)(0.44 - 0.11 psi/8) i =1,076 psi ~ (B) dafa on potential gas =ones,- ~ The well bore is not expected to penetrate any gas zones. m~d (C) data cor~cerning potential causes of hole problems szrch as abr~ormally geo pressur~ed strata, lost circulation=ones, and soraes that have a propelasiry for d~erential sticking; ~ Please see Attachment 2: 1J-162 Drilling Hazards Suimnary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.OOS (c)(S) An a~plicatioia for a Permit to Drill must be acco~n~anied by each of tJ~e folloi4~ing items, except for an item ah•eady on file with the commission and identrfzed in the applicatrola: (5) a desc~•iption of the procedure for conductiiag formation integrity tests, as reguired under 20 AAC 25. 030(~; ~ 1J-162 PERMIT IT Page 3 of 7 Printed: 5-Jun-07 ~?~~~~~~-L ~ Ap~on for Permit to Drill, Well 1J-162 Revision No.O Saved: 5-Jun-07 1J-162 will be completed with 9-5i8" casing landed at the top of the West Sak "B" sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integity Test Procedure" that ConcocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompa»ied by each of the folloiving items, exceptfor ara iiem already onfile ~+~ith the commission and ident~ed irz the ap,olicatioia: (6) a complete proposed casing and cementir~g program as reqt~ired by 20 AAC 25.030, arrd a description of arzy slotted liner, pre perforated liner, or screen to be ir,stalled~~ ~~. Casing and Cementing Program See also Attachment 3: Cement Summ Hode Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (lb/ft) Grade Connection (ft) (ft) t) Cement Program 20" 40" 62.5 H-40 Welded 80 40' / 40' 120' / 120' Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 13-3/8" 16" 68 L-80 BTC 4,572 40' / 40' 4,612' / 2,303' 770 sx ArcticSet Lite Lead, 220 sx Dee CRETE Taii 10-3/4" 12-1/4" 73.2 L-80 BTCM 3,405 40' / 40' 3,445' / 2,105' Top oftapered 10'/<" x 9 5/8" See 9 5/8" Program in next row Cement Top planned @ 6,600' 9-5/8" 12-1/4" 40 L-80 BTCM 7,000 3,445' / 2,105' 10,445' / 3,251' MD / 2,640' TVD. Cemented w/ 690 sx Dee CRETE 5-1/2 8-1/2" B Sand Lateral 15.5 L-80 BTCM 4,167 10,091 / 3,251' 14,258' / 3,218' Slotted-no cement d (1J-162) 4-1/2 8-1/2" D Sand Lateral 11 6 L-80 BTC CSG 4,263 9,991' / 3,186' 14,254' / 3,146' 5lotted- no cement slotted (1J-162L1~ . 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An applicatio~z for a Permit to Drill must be accompa~~ied by eaclt of Ihe folloiring i/enzs, exceptfor an item ab•eady on file i+~ith the commission and identified in the applicatiori: (7) a diagram and desc~•iption of tbe diver•ter system as required by 20 AAC 2~.035, unless this requireme~at !s i~~aived by the comrrzission under 20 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 1J- 162. Please see diagrams of the Doyon 15 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25. 005(c) (8) A~a application for a P~e~~mit to Drill naust be accompanied by each of the follo~rirag iter~is, except for an item already on frle ivith the com~nissiovr and identrfied i~z the applicatian: (8) a drillingfluid program, including a diagram and description of the drilln~gfluid system, as reqUired by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Surface Casing Point Initial Value Final Value Initial Value Fdnal yalue Densiry (pp~ 8.5 9.2 9.2 9.6 Funnel Viscosiry 150 250 200 300 (seconds) Yield Point 50-70 50-70 30-50 30-50 (~PJ 1J-162 PERMIT IT Page 4 of 7 Printed: 5-Jun-07 ... {., ~ ~°' ~~ ~~~~~~p~~~~ ~ ~ation for Permit to Drill, Well 1 J-162 Revision No.O Saved: 5-Jun-07 Plasric viscostiy (lb/100 s 20-45 20-45 15-20 15-20 PH 8.5-9.0 8.5-9.0 8.5-9.0 8.5-9.0 API Filtrate (cc /30 minJ) NC-8.0 NC-8.0 5.0-7.0 5.0-7.0 *9.6 ppg if hydrates are encountered Intermediate Hole Mud Program (LSND) 10-3/4 " Casing Shoe 1a Intermediate Casin Point Initial Value Densi ppgJ 9.0-9.1 Funnel Viscosity (seconds 45-60 Plastic Viscostiy (lb/100 s~ 12-18 Yield Point ~~P~ 26-35 API Filtrate (cc / 30 min) 4-6 Chlorides mg/1 <500 H 9.0-9.5 MBT <20.0 Lateral Mud Program (MI VersaPro Mineral Oil Base) B, D sand laterals Value Densi ( p 9.0 Plastic Viscostiy (Ib/100 s~ 15-25 Yield Point ~~P~ 1 g-2g HTHP Fluid loss (ml/30 min @ <4.0 200psi & I50° Oil / Water Ratio 80:20 Electrical Stabili >600 .--- Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25. 005 (c)(9) Arz applicatio~a for a Permit to Drill mz~st be accompmzied by each of t1~e folloirii~g items, except for a~7 itena already on fi~le i~-itla the com»:ission and identified in the applicatio~a: (9) for an explorato~y o~• str•atigraphic test x~ell, a tabulafron setting ozrt the deplhs of predicted abnorrnally geo ~ressured strata as required by ~0 A ~C 25.033(fl; Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) Aia application for a Pernzit to Drill must be accompanied by each of the follo~tiing items, except for an i~ern already o~x file witlz the commission mid identified i~z the application: (10) for a~~ exploratory or stratigraphic test i1 elZ, a seisrnic refractio~z or reflectio~a m~alysis as reguired by 20 AAC 25.061(aJ; Not applicable: Application is not for an explaratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be acconapanied by each of the followi~ag items, except for m~ item already o~a file with the conznzission a~vd identifred in d~e application: (11) for a well drilled fi•om an offshore platform, nzobile bottons founded sbzrcture, jack-up rig, or floatirrg drilling vessel, an analysis of seabed coizditions as required by 20 AAC 25.061(b); Not applicable: Application is not fQr an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Pern~it to Drill must be accompa~lied by each of the following items, except for an item already oiz file ivith the conznaission m1d identified in the application: ~ ~ (12) evidence shoiving that fhe requirements of 20 AAC 25.02~ {Bonding~bave been nset; 1J-162 PERMIT IT Page 5 of 7 Printed: 5-Jun-07 ~~~~~~~L • Ap~n for Permit to Drill, Well 1J-162 Revision No.O Saved: 5-Jun-07 Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25. 005 (c)(13) An application for a Permit to Drill must be accompa~aied by each of the follox~ivrg itenzs, except for ara item already on file ivith the commission and ident fed in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematics. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 108' RKB. Installlanding ring on conductor. 2. Move in / rig up Doyon Rig 15. Insta1121-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 4,612' MD / 2,303' TVD as per directional plan. Run MWD tools as required for directional monitaring. 4. Run and cement 13-3/8", 68#, L80, BTC casing to surface~ Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi) Notify AOGCC 24 hrs before test. 6. PU 12-1/4" drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment. Pressure test casing to 2500 psi for 30 minutes and record results. '1. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. , ~ 8. Directionally drill to intermediate casing point at 10,445' MD / 3,251' TVD, the prognosed top of the B sand. 9. Run 10-3/4" 73.2# x 9-5/8" 40# tapered, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 6,600' MD, 500' above the Ugnu C 10. Install wellhead x 10-3/4" packoff and test to 5000 psi. 11. Flush 13-3/8" x(10-3/4" x 9-5/8" tapered) annulus with water, followed by diesel. 12. PU 8-1/2" drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Pressure test casing to 3,000 psi for 30 minutes and record results. 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. 14. Directionally drill 8-1/2" hole to TD at +/- 14,258' MD / 3,218' TVD as per directional plan. 15. POOH, back reaming out of lateral. POOH. 16. PU and run 5-1/2" slotted liner. 17. Land liner, set liner hanger @+/- 10,091' MD / 3,251'. POOH. Note: Remaining operations are covered under the IJ-162 LI Application for Permit to Drill, and are provided here for information only. 18. Run and set Baker WindowMaster whipstock system, at window point of 9,991' MD / 3,186' TVD, the top of the "D" sand. 19. Mill 8-1/2" window. POOH. 20. Pick up 8-1/2" drilling assembly with LWD and MWD and PWD. RIH. 21. Drill to TD of "D" sand lateral at 14,254' MD / 3,146' TVD, as per directional plan. 1J-162 PERMIT IT Page 6 of 7 Printed: 5-Jun-07 . ~~'~~~~~~:~_~! : ~~ ~~ ~ 22. POOH, back reaming out of lateral. POOH. 23. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. A~ion for Permit to Drill, Well 1J-162 Revision No.O Saved: 5-Jun-07 24. PU and run 4-1/2" slotted liner. 25. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 26. Release hanger running tool. POOH. 27. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. 28. POOH, laying down drill pipe as required. 29. PU ESP completion as required and RIH to depth. Land tubing. Set BPV. 30. Nipple down BOPE, nipple up tree and test. Pull BPV. 31. Freeze protect well with diesel by pumping into 4-1/2" x(10-3/4" x 9-5/8" tapered) annulus, taking returns from tubing and allowing to equalize. 32. Set BPV and move rig off. 33. Rig up wire line unit. Pull BPV. 34. Flowback well with ESP to cleanup. Place well on production. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) ~?n application for a Permit to Drill mustc be accompm7ied by each of the follo~~~ing itenzs, exceptfor an item already on file with the con2mission an~d idenz~ed in the applicatioia: (14) a general description of how the operator plans to dispose of drilling nsud and cuttings and a statemznt of u~hether the operator intends to request authori~atron unden 20 AAC 25.080 for an m~~~ular disposal ope~•ation in the ivell.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a ~ permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on lE Pad, hauled to the Prudhoe Bay Grind and Inject Facility for .- temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 CemCADE Summary Attachment 4 Well Schematic 1J-162 PERMIT IT Page 7 of 7 ~ ~ ~ ~ ~ ~ ~ ~ Printed: 5-Jun-07 ~ ~' . . Cor~c~coPh ~ I I ~ ps Alaska i Plan: 1J-162 (wp09) Sperry Drilling Services Proposal Report - Geographic 16 May, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-162 - Slot 1J-162 1J-162 Local Coordinate Origin: Centered on Well Plan 1J-162 - Slot 1J-162 Viewing Datum: Doyon 15 @ 121.OOft (Doyon 15 (40+g1)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet LL~~w~~TQ~ 3perry ~ritting Ssrvtce~ ~~~4..J~~~~1L... ~ V I ~ .!~" ~ 9~ALL1 ~ tJ F~'T'O N Sperry Drilling Services -300 300 600 1200 Pfrost 1500 '---------- I SHL @ 1958'FSL,2526'FEL-Sec35-T11N-R10E soo 1000 1500 DETAIIS: PIan1J-162 NAD 1927(NADCONCONUS) WF~ ~ AlaskaZone04 Project: Kuparuk River Unit - • Site: Kuparuk 1J Pad ~°~a~"ec 8100 Sl i d Well: Plan 1J-162 +N/-S +FJ-W Northing Easting l~tinude 000 000 59J576963 558683.15 70°IS'44.79N 149°3 ot Long m e 1'32149W 17-162 Wellbore: 1J-162 Plan: 1 J-162 (wp09) FORMATION TOP DETAILS No. TVDPath NDSS MDPath Formation 1 1525.44 1404.44 1720.56 Pfrost 2 1650.95 1529.95 1965.66 t3 3 1935.72 1814.72 2845.28 k15 4 2148.15 2027.15 3695.40 csgpt 5 2726.40 2605.4 7109.94 Ugnu C 6 2906.21 278521 8180.13 Ugnu B 7 2949.83 2828.83 8448.51 Ugnu A 8 3108.79 2987.79 9468.30 K13 9 3186.14 3065.14 9991.33 Wsak D 10 3229.00 3108 10289.36 Wsak C 11 3248.00 3127 10422.11 Wsak B CASING DETAILS No MD ND TVDss Name Size 1 4612.00 2303.38 2182.38 13 3f8" 13-3/ 2 10445.12 3251.29 3130.29 9 5/S" 9-5/8 3 14259.00 3218.40 3097.4 51/2" 5-1/2 1800 t3 2500 gegin Pump Tangent @ 7454' MD, 2785' ND ~,( i ----'~------------------------------ -------------------------- --------------- . ~. ~ 3000 ~ k15 . -------------------------------- 2100 ---~`'~------~~---------------------------------- 4000 csgpt 4500 End Pump Tangent @ 7654' MD, 2819' TVD 2400 5000 ,,~" BHL @ 14259' MD, 3218' ND: 1344' FSL, 89' FWL - Sec03-T10N-R10E ~ 5500 - ~ Ugnu C 6000,' , ~ ~ , ` 6506 , ' ~ ~ ----- 2700 _ ------ ~6B¢ =-/------------------------------------------------------------- ---------- ~ UgnuB -~po6,~o o ------------------ - --- ~ ----- -=-UgnuA------- ~ ---~----D -----$-------------------------o------o ------o---- a -----o`-- N---- ' ~ ----- 3000 K13 ~ ° o ° ° ° ° ° ~ ~ ~ ~ ~ - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ s _ - _ _ _ o _ - _ _ - o _ _ _ - - _~ _ - _ _ _ N - _ - _ - -M - _ O _ - _ _ - _ - _ _ - _ _ _ - - _ ~ L ~ _ _ - _ _ _ ~ ~ ~ _~.WsakD ---------------------- -- `~ ~ -------~-------------7---i'----I---,---~_--- -~___ ~--- -- 9 5/8" Casing @ 10445' MD, 3251' TVD: 144' FSL, 53' FWL-Sec 34-T11 N-R10E ~ ~ T-`' =° __ 3300 .: ________________________°=-_ - ~ ~ . _ ~ ~ ' ~ ` WsakC ~~' ' o ~~ 1J-162 (wp08) D-Top ~ 3600 ~ 1J-162 T2 (wp08) 04/18/07 ' 1J-162 T4 (wp08) 04/18/07 1J-162 T6 (wp08) 04/18/07 1J-162 Toe (wp09) 04/18/07 Wsak B ' 1J-162 T1 (wp08) 04/18/07 1J-162 T3 (wp08) 04/18/07 1J-162 TS (wp08) 04/18/07 ~~-162 T7 (wp08) 04/18/07 3900 4500 ,~~ ,~,,,,~....i....i. i i ~ -600 -300 0 300 600 900 1200 1500 1800 2100 2400 2700 3000 3300 3600 3900 4200 4500 4800 5100 5400 5700 ConocoPhillips aaska HALLlB~l~TQN Spe~ry DrEliing Services CASING DETAILS No MD ND TVDss Name Size 1 4612.00 2303.38 2182.38 13 3/6" 133/8 210445.12 3251.29 313029 9 5/8" 9-518 314259.00 3218.40 3097.4 5 1/2" 5-1/2 1J-162 (wp08) D-T p_. ~~ -1800 1J-162T1(wp08)04/18/07 ~ ' O O ^ -2400 U-162 T2 (wp08) 04/I S/07 ~ o -300o i~1-Ie2r3~..POS)oansio.'. ~ -~ u-ibz ra ~~oa~ oanaio~" ~ -3G00 0 ~ U-162 TS (wp08) 04/ I S/07 I IJ-162 T6 (wp08) 04/1 I IJ-162 7'7 (wp08) 04/1 I]-162 Toe (wp09) 04i -7200 -7800 -5400 ~ o $ N \ ~ \ \ \ \ ~ ~ ~ Begin Pump Tangent @ 7454' MD, 2785' ~ ~ E~d Pump Tangent @ 7654' MD, 2819' 0 0 0 0 ° ~ 8~ 13 39E" ^ - - ~ -~ ; ~ 2 O ~ y ~ ~ ' / SHL @ 1958' FSL, 2526' FEGSec35-'Il I N-RlOE 9 5/8" Casing @ 10445' MD, 3251' ND: 144' FSL, 53' FWL-Sec 34-T1 IN-RI OE ~ . -____ •'~~'--_ _ i ` 5 1/2" B~- @~4259' MD, 3218' TVD: 1344' FSL, 89' FWL - Sec03-TlON-RI OE i ~ IJ-162 (wp09) T M Azimuths to True North Magnetic North: 24.54° Magnetic Field Strength: 57578.9nT Dip Angle: 80.72° Date: 11 /18/2004 Model: BGGM2004 -9000~ -10200 -9600 -9000 -8400 -7800 -7200 -6600 -6000 -5400 -4800 -4200 -3600 -3000 -2400 -1800 -1200 -600 0 600 West(-)/East(+) (1500 ft/in) ConocoPhillips ~~ ~ ~ • • ConocoPhill~ps Alaska ~ Plan: 1 J-162 (wp09) Sperry Drilling Services Proposal Report - Geographic 16 May, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-162 - Slot 1J-162 1J-162 Local Coordinate Origin: Centered on Well Plan 1J-162 - Slot 1J-162 Viewing Datum: Doyon 15 ~ 121.DOft (Doyon 15 (4~+81)) ~ NDs to System: N North Reference: True Unit System: API - US Survey Feet QL { ~ Q~ Sperry Drilling Ss~wta~ ~~~~`~~~~.~~ ~ ~ __ '~ Ku aruk Ri~er~ Unit, North Slo e';Alaska, United States ~ ~ ~ ~ ~ ~ ~ ~ ' _ ~; ~ ~ : ~ '~ ~u n ' m •~~ ~ ~ - =~ ~ ~ ~' Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Audit Notes: Version: Phase: PLAN Tie On Depth: 40.00 ~~ _ u ,~~~~~ ~~~r` ~I 'a';~~ ~~I~i~ ~~~~" ,~~~ y~. . 40.00 0.00 0.00 ~ 180.00 5/16/'2007 4:52:58PM Page 2 of 10 COMPASS 2003.11 Build 48 Q~~G~NAL ~~aCO~;'~;~ Halliburton Company HALLIBU TON ~ Compass Proposal Report - Geographic gpmrry Drilling Serviaes _ ~ . a w ~ ~ , ±m _ ~ ~.~a ---- ~ i ~r~r .uwr m Plan~~ 1 J-162 - Slot 1 J-162 .__. ' ~ t~lY~.. 3.»;;;+~a911101~P,;. . tl~ti~ ~~ . ~ ~ 10&U;eii ~:: ~ ~tl;NEUi ~ ';idP;Yi~EN ~ ': ,=-" . Well Position +N/-S 0.00 ft Northing: 5,945,769.63 ft Latitude: 70° 15' 44.790" N +E/-W 0.00 ft Easting: 558,683.15 ft Longitude: 149° 31' 32.149" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft ' ! ~ / Halliburton Company HALLIBURTDi`I COIlOCO~II~~ p~5 Compass Proposal Report - Geographic Sparry Drillin9 8ervice~ ~~~~.,~ 40.00 0.00 ~~~ ~W~...~__.. 0.00 ~. 40.00 _ -81.00 0.00 0.00 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 129.00 0.00 0.00 0.00 0.00 0.00 0.00 70427 13.63 270.00 700.00 579.00 0.00 -53.77 3.00 3.00 0.00 270.00 1,677.87 52.57 270.79 1,500.00 1,379.00 5.56 -575.23 4.00 4.00 0.08 1.00 2,165.13 72.00 269.04 1,725.54 1,604.54 4.33 -1,004.50 4.00 3.99 -0.36 -5.00 3,215.13 72.00 269.04 2,050.01 1,929.01 -12.41 -2,002.97 0.00 0.00 0.00 0.00 3,454.33 80.25 270.51 2,107.33 1,986.33 -13.27 -2,234.99 3.50 3.45 0.61 10.00 7,654.33 80.25 270.51 2,818.59 2,697.59 23.53 -6,374.16 0.00 0.00 0.00 0.00 10,189.81 81.77 180.50 3,214.75 3,093.75 -1,557.52 -7,981.47 3.51 0.06 -3.55 -89.02 10,415.12 81.77 178.36 3,247.00 3,126.00 -1,780.48 -7,979.25 0.94 0.00 -0.95 -90.00 10,445.12 81.77 178.36 3,251.29 3,130.29 -1,810.16 -7,978.40 0.00 0.00 0.00 0.00 10,644.12 91.72 178.44 3,262.57 3,141.57 -2,008.51 -7,972.85 5.00 5.00 0.04 0.46 10,695.90 91.72 178.44 3,261.02 3,140.02 -2,06025 -7,971.44 0.00 0.00 0.00 0.00 10,703.98 91.40 178.40 3,260.80 3,139.80 -2,068.32 -7,971.22 4.00 -3.97 -0.48 -173.15 10,777.52 89.14 180.28 3,260.45 3,139.45 -2,141.85 -7,970.37 4.00 -3.07 2.56 140.21 10,858.54 89.14 180.28 3,261.67 3,140.67 -2,222.86 -7,970.77 0.00 0.00 0.00 0.00 10,933.78 92.09 179.69 3,260.86 3,139.86 -2,298.09 -7,970.76 4.00 3.92 -0.79 -11.35 11,283.78 92.09 179.69 3,248.10 3,127.10 -2,647.85 -7,968.86 0.00 0.00 0.00 0.00 11,380.86 91.13 179.52 3,245.37 3,124.37 -2,744.89 -7,968.19 1.00 -0.98 -0.18 -169.65 12,096.14 91.13 179.52 3,231.20 3,110.20 -3,460.00 -7,962.14 0.00 0.00 0.00 0.00 12,252.49 89.58 179.35 3,230.22 3,109.22 -3,616.33 -7,960.59 1.00 -0.99 -0.11 -173.74 13,151.47 89.58 179.35 3,236.80 3,115.80 -4,515.23 -7,950.31 0.00 0.00 0.00 0.00 13,248.98 90.17 180.68 3,237.01 3,116.01 -4,612.73 -7,950.34 1.50 0.60 1.37 66.31 13,423.50 90.17 180.68 3,236.50 3,115.50 -4,787.25 -7,952.42 0.00 0.00 0.00 0.00 13,584.96 91.33 178.56 3,234.40 3,113.40 -4,948.68 -7,951.35 1.50 0.72 -1.32 -61.46 13,757.71 91.33 178.56 3,230.40 3,109.40 -5,121.33 -7,947.00 0.00 0.00 0.00 0.00 13,838.78 91.38 179.37 3,228.49 3,107.49 -5,202.36 -7,945.53 1.00 0.06 1.00 86.41 14,259.01 91.38 179.37 3,218.40 3,097.40 -5,622.44 -7,940.88 0.00 0.00 0.00 0.00 5/16/2007 4:52:58PM Page 3 of 10 COMPASS 2003.11 Build 48 ~;'~~~~~~~~~ ~ ~ _ ~ 1 J-162 ' ~ 09 ~ ~~ ~~ ~ ~~ ~ - - „ ~, _ _ - = - - , = _ 40.00 , - ~ ~ - ~.~ ~e- ' 0.00 ; 0.00 ~ ~ ~ ~~ ~ 40.00 -- - -81.00 ~ ,~. _ 0.00 --- - ~, 0.00 ~ , ~~„ 5,945,769.63 ' 58,683.15 ' - 0.00 _- ~ - 0.00 SHL @ 1958' FSL, 2526' FEl-Sec35-T11 N-R10E 100.00 0.00 0.00 100.00 -21.00 0.00 0.00 5,945,769.63 558,683.15 0.00 0.00 200.00 0.00 0.00 200.00 79.00 0.00 0.00 5,945,769.63 558,683.15 0.00 0.00 250.00 0.00 0.00 250.00 129.00 0.00 0.00 5,945,769.63 558,683.15 0.00 0.00 300.00 1.50 ~ 270.00 299.99 178.99 0.00 -0.65 5,945,769.62 558,682.50 3.00 0.00 400.00 4.50 270.00 399.85 278.85 0.00 -5.89 5,945,769.58 558,677.26 3.00 0.00 500.00 7.50 270.00 499.29 378.29 0.00 -16.34 5,945,769.50 558,666.81 3.00 0.00 600.00 10.50 270.00 598.04 477.04 0.00 -31.98 5,945,769.38 558,651.17 3.00 0.00 700.00 13.50 270.00 695.85 574.85 0.00 -52.77 5,945,769.22 558,630.39 3.00 0.00 704.27 13.63 270.00 700.00 579.00 0.00 -53.77 5,945,769.21 558,629.39 3.00 0.00 800.00 17.46 270.22 792.21 671.21 0.06 -79.42 5,945,769.07 558,603.74 4.00 -0.06 900.00 21.46 270.37 886.48 765.48 0.23 -112.72 5,945,768.98 558,570.44 4.00 -0.23 1,000.00 25.46 270.48 978.20 857.20 0.53 -152.52 5,945,768.97 558,530.65 4.00 -0.53 1,100.00 29.46 270.55 1,066.92 945.92 0.95 -198.61 5,945,769.03 558,484.56 4.00 -0.95 1,200.00 33.46 270.62 1,152.20 1031.20 1.48 -250.78 5,945,769.16 558,432.39 4.00 -1.48 1,300.00 37.46 270.66 1,233.64 1112.64 2.13 -308.77 5,945,769.35 558,374.40 4.00 -2.13 1,400.00 41.46 270.71 1,310.84 1189.84 2.89 -372.31 5,945,769.62 558,310.87 4.00 -2.89 1,500.00 45.46 270.74 1,383.42 1262.42 3.76 -441.07 5,945,769.95 558,242.11 4.00 -3J6 1,600.00 49.46 270.77 1,451.02 1330.02 4.73 -514.72 5,945,770.35 558,168.46 4.00 -4.73 1,677.87 52.57 270.79 1,500.00 1379.00 5.56 -575.23 5,945,770.70 558,107.95 4.00 -5.56 1,700.00 53.45 270.70 1,513.32 1392.32 5.78 -592.91 5,945,770.79 558,090.27 4.00 -5.78 1,720.56 54.27 270.61 1,525.44 1404.44 5.97 -609.51 5,945,770.85 558,073.67 4:00 -5.97 Pfrost 1,800.00 57.44 270.29 1,570.03 1449.03 6.48 -675.25 5,945,770.85 558,007.94 4.00 -6.48 1,900.00 61.42 269.91 1,620.87 1499.87 6.63 -761.33 5,945,770.32 557,921.86 4.00 -6.63 1,965.66 64.04 269.68 1,650.95 1529.95 6.42 -819.69 5,945,769.66 557,863.51 4.00 -6.42 t3 2,000.00 65.41 269.57 1,665.61 1544.61 6.22 -850.74 5,945,769.22 557,832.47 4.00 -6.22 2,100.00 69.40 269.24 1,704.02 1583.02 5.25 -943.05 5,945,767.53 557,740.18 4.00 -5.25 2,965.13 72.00 269.04 1,725.54 1604.54 4.33 -1,004.50 5,945,766.13 557,678.74 4.00 -4.33 2,200.00 72.00 269.04 1,736.32 1615.32 3.78 -1,037.66 5,945,765.32 557,645.59 0.00 -3.78 2,300.00 72.00 269.04 1,767.22 1646.22 2.18 -1,132.75 5,945,762.98 557,550.52 0.00 -2.18 2,400.00 72.00 269.04 1,798.12 1677.12 0.59 -1,227.85 5,945,760.65 557,455.45 0.00 -0.59 2,500.00 72.00 269.04 1,829.02 1708.02 -1.01 -1,322.94 5,945,758.31 557,360.39 0.00 1.01 2,600:00 72.00 269.04 1,859.92 1738.92 -2.60 -1,418.03 5,945,755.98 557,265.32 0.00 2.60 2,700.00 72.00 269.04 1,890.83 1769.83 -4.20 -1,513.12 5,945,753.64 557,170.25 0.00 4.20 2,800.00 72.00 269.04 1,921.73 1800.73 -5.79 -1,608.22 5,945,751.31 557,075.18 0.00 5.79 2,845.28 72.00 269.04 1,935.72 1814.72 -6.51 -1,651.27 5,945,750.25 557,032.13 0.00 6.51 k'f 5 2,900.00 72.00 269.04 1,952.63 1831.63 -7.39 -1,703.31 5,945,748.97 556,980.11 0.00 7.39 3,000.00 72.00 269.04 1, 983.53 1862.53 -8.98 -1, 798.40 5, 945, 746.64 556, 885.05 0.00 8.98 3,100.00 72.00 269.04 2,014.43 1893.43 -10.57 -1,893.49 5,945,744.30 556,789.98 0.00 10.57 3,200.00 72.00 269.04 2,045.33 1924.33 -12.17 -1,988.59 5,945,741.97 556,694.91 0.00 12.17 3,215.13 72.00 269.04 2,050.01 1929.01 -12.41 -2,002.97 5,945,741.61 556,680.53 0.00 12.41 3,300.00 74.93 269.57 2,074.16 1953.16 -13.39 -2,084.32 5,945,740.00 556,599.20 3.50 13.39 5/16/2007 4:52:58PM Page 4 of 10 COMPASS 2003.11 Build 48 ~~~~1N~L ~`'~ Halliburton Company AL~IBliRTON ~~~~~~'~~~ Compass Proposal Report - Geographic Alaska Sperry DrilEing Serv[ce~ ~ COtlOCO~'11~~Ip5 Alaska Halliburton Company Compass Proposal Report - Geographic ~ HALLI'BURTOtV Bperry Drilling E3e~vices .~ ~...__ 3,400.00 78.37 _ 270.18 2,097.25 1976.25 -13.59 -2,181.60 5,945,739.04 556,501.93 3.50 13.59 3,454.33 80.25 270.51 2,107.33 1986.33 -13.27 -2,234.99 5,945,738.94 556,448.55 3.50 13.27 3,500.00 80.25 270.51 2,115.06 1994.06 -12.87 -2,279.99 5,945,738.99 556,403.55 0.00 12.87 3,600.00 80.25 270.51 2,131.99 2010.99 -11.99 -2,378.54 5,945,739.10 556,305.00 0.00 11.99 3,695.40 80.25 270.51 2,148.15 2027.15 -11.16 -2,472.57 5,945,739.20 556,210.98 0.00 11.16 csgpt 3,700.00 80.25 270.51 2,148.93 2027.93 -11.12 -2,477.10 5,945,739.21 556,206.45 0.00 11.12 3,800.00 80.25 270.51 2,165.86 2044.86 -10.24 -2,575.65 5,945,739.32 556,107.91 0.00 10.24 3,900.00 80.25 270.51 2,182.80 2061.80 -9.37 -2,674.20 5,945,739.43 556,009.36 0.00 9.37 4,000.00 80.25 270.51 2,199.73 2078.73 -8.49 -2,772.75 5,945,739.53 555,910.82 0.00 8.49 4,100.00 80.25 270.51 2,216.67 2095.67 -7.61 -2,871.30 5,945,739.64 555,812.27 0.00 7.61 4,200.00 80.25 270.51 2,233.60 2112.60 -6.74 -2,969.85 5,945,739.75 555,713.72 0.00 6.74 4,300.00 80.25 270.51 2,250.54 2129.54 -5.86 -3,068.41 5,945,739.86 555,615.18 0.00 5.86 4,400.00 80.25 270.51 2,267.47 2146.47 -4.98 -3,166.96 5,945,739.97 555,516.63 0.00 4.98 4,500.00 80.25 270.51 2,284.41 2163.41 -4.11 -3,265.51 5,945,740.08 555,418.09 0.00 4.11 4,600.00 80.25 270.51 2,301.34 2180.34 -3.23 -3,364.06 5,945,740.18 555,319.54 0.00 3.23 4,612.00 80.25 270.51 2,303.38 2182.38 -3.13 -3,375.89 5,945,740.20 555,307.71 0.00 3.13 13 3!8" Casing @ 4672' MD 2319' ND: 1954'FSL, 622' FEL-Sec 34-T11 N-R10E -13 3/8" 4,700.00 80.25 270.51 2,318.28 2197.28 -2.36 -3,462.61 5,9A5,740.29 555,220.99 0.00 2.36 4,800.00 80.25 270.51 2,335.21 2214.21 -1.48 -3,561.16 5,945,740.40 555,122.45 0.00 1.48 4,900.00 80.25 270.51 2,352.15 2231.15 -0.60 -3,659.72 5,945,740.51 555,023.90 0.00 0.60 5,000.00 80.25 270.51 2,369.08 2248.08 0.27 -3,758.27 5,945,740.62 554,925.36 0.00 -0.27 5,100.00 80.25 270.51 2,386.02 2265.02 1.15 -3,856.82 5,945,740.72 554,826.81 0.00 -1.15 5,200.00 80.25 270.51 2,402.95 2281.95 2.03 -3,955.37 5,945,740.83 554,728.26 0.00 -2.03 5,300.00 80.25 270.51 2,419.89 2298.89 2.90 -4,053.92 5,945,740.94 554,629.72 0.00 -2.90 5,400.00 80.25 270.51 2,436.82 2315.82 3.78 -4,152.47 5,945,741.05 554,531.17 0.00 -3.78 5,500.00 80.25 270.51 2,453.76 2332.76 4.65 -4,251.03 5,945,741.16 554,432.62 0.00 -4.65 5,600.00 80.25 270.51 2,470.69 2349.69 5.53 -4,349.58 5,945,741.26 554,334.08 0.00 -5.53 5,700.00 80.25 270.51 2,487.63 2366.63 6.41 -4,448.13 5,945,741.37 554,235.53 0.00 -6.41 5,800.00 80.25 270.51 2,504.56 2383.56 7.28 -4,546.68 5,945,741.48 554,136.99 0.00 -7.28 5,900.00 80.25 270.51 2,521.50 2400.50 8.16 -4,645.23 5,945,741.59 554,038.44 0.00 -8.16 6,000.00 80.25 270.51 2,538.43 2417.43 9.04 -4,743.79 5,945,741.70 553,939.89 0.00 -9.04 6,100.00 80.25 270.51 2,555.37 2434.37 9.91 -4,842.34 5,945,741.81 553,841.35 0.00 -9.91 6,200.00 80.25 270.51 2,572.30 2451.30 10.79 -4,940.89 5,945,741.91 553,742.80 0.00 -10.79 6,300.00 80.25 270.51 2,589.24 2468.24 11.66 -5,039.44 5,945,742.02 553,644.26 0.00 -11.66 6,400.00 80.25 270.51 2,606.17 2485.17 12.54 -5,137.99 5,945,742.13 553,545.71 0.00 -12.54 6,500.00 80.25 270.51 2,623.11 2502.11 13.42 -5,236.54 5,945,742.24 553,447.16 0.00 -13.42 6,600.00 80.25 270.51 2,640.04 2519.04 14.29 -5,335.10 5,945,742.35 553,348.62 0.00 -14.29 6,700.00 80.25 270.51 2,656.98 2535.98 15.17 -5,433.65 5,945,742.45 553,250.07 0.00 -15.17 6,800.00 80.25 270.51 2,673.91 2552.91 16.05 -5,532.20 5,945,742.56 553,151.53 0.00 -16.05 6,900.00 80.25 270.51 2,690.85 2569.85 16.92 -5,630.75 5,945,742.67 553,052.98 0.00 -16.92 7,000.00 80.25 270.51 2,707.78 2586.78 17.80 -5,729.30 5,945,742.78 552,954.43 0.00 -17.80 7,100.00 80.25 270.51 2,724.72 2603.72 18.67 -5,827.85 5,945,742.89 552,855.89 0.00 -18.67 7,109.94 80.25 270.51 2,726.40 2605.40 18.76 -5,837.65 5,945,742.90 552,846.09 0.00 -18.76 Ugnu C I 7,200.00 80.25 270.51 2,741.65 2620.65 19.55 -5,926.41 5,945,743.00 552,757.34 0.00 -19.55 7 300 00 80 25 270 51 2 758 59 2637 59 20 43 -6 024.96 5 945 743.10 552 658.80 0.00 -20.43 5/16/2007 4:52:58PM Page 5 of 10 COMPASS 2003.11 Build 48 ~~~'~~~~~~. ~ ~ , , 1 J-162 ~ 09 7,400.00 80.25 270.51 2,775.52 2654.52 21.30 -6,123.51 5,945,743.21 552,560.25 0.00 -21.30 7,454.29 80.25 270.51 2,784.71 2663.71 21.78 -6,177.01 5,945,743.27 552,506.75 0.00 -21.78 Begin Pum p Tangent @ 7454' M D, 2785' TVD 7,500.00 80.25 270.51 2,792.46 2671.46 22.18 -6,222.06 5,945,743.32 552,461.70 0.00 -22.18 7,600.00 80.25 270.51 2,809.39 2688.39 23.06 -6,320.61 5,945,743.43 552,363.16 0.00 -23.06 7,654.33 80.25 270.51 2,818.59 2697.59 23.53 -6,374.16 5,945,743.49 552,309.61 0.00 -23.53 End Pump Tangent @ 7654' MD, 2819' ND 7,700.00 80.28 268.89 2,826.32 2705.32 23.30 -6,419.17 5,945,742.90 552,264.61 3.50 -23.30 7,800.00 80.34 265.34 2,843.15 2722.15 18.33 -6,517.60 5,945,737.17 552,166.23 3.50 -18.33 7,900.00 80.40 261.79 2,859.88 2738:88 7.28 -6,615.55 5,945,725.36 552,068.38 3.50 -7.28 8,000.00 80.46 258.24 2,876.51 2755.51 -9.82 -6,712.65 5,945,707.50 551,971.43 3.50 9.82 8,100.00 80.52 254.69 2,893.04 2772.04 -32.90 -6,808.52 5,945,683.68 551,875.75 3.50 32.90 8,180.13 80.57 251.84 2,906.21 2785.21 -55.65 -6,884.21 5,945,660.34 551,800.25 3.50 55.65 Ugnu B 8,200.00 80.58 251.14 2,909.46 2788.46 -61.88 -6,902.79 5,945,653.97 551,781.71 3.50 61.88 8,300.00 80.64 247.59 2,925.78 2804.78 -96.64 -6,995.11 5,945,618.49 551,689.68 3.50 96:64 8,400.00 80.70 244.04 2,942.00 2821.00 -137.06 -7,085.10 5,945,577.37 551,600.01 3.50 137.06 8,448.51 80.73 242.32 2,949.83 2828.83 -158.67 -7,127.83 5,945,555.44 551,557.46 3.51 158.67 uy~-~, a 8,500.00 80.76 240.49 2,958.11 2837.11 -182.99 -7,172.44 5,945,530.77 551,513.04 3.50 182.99 8,600.00 80.82 236.94 2,974.12 2853.12 -234.24 -7,256.79 5,945,478.87 551,429.11 3.50 234.24 8,700.00 80.88 233.39 2,990.03 2869.03 -290.63 -7,337.81 5,945,421.85 551,348.54 3.51 290.63 8,800.00 80.94 229.84 3,005.83 2884.83 -351.94 -7,415.19 5,945,359.95 551,271.64 3.51 351.94 8,900.00 81.00 226.29 3,021.53 2900.53 -417.93 -7,488.65 5,945,293.40 551,198.71 3.51 417.93 9,000.00 81.06 222.74 3,037.13 2916.13 -488.35 -7,557.89 5,945,222.44 551,130.03 3.51 488.35 9,100.00 81.12 219.19 3,052.62 2931.62 -562.94 -7,622.64 5,945,147.36 551,065.86 3.51 562.94 9,200.00 81.18 215.64 3,068.01 2947.01 -641.41 -7,682.66 5,945,068.43 551,006.46 3.51 641.41 9,300.00 81.24 212.09 3,083.30 2962.30 -723.46 -7,737.72 5,944,985.96 550,952.05 3.51 723.46 9,400.00 81.30 208.54 3,098.48 2977.48 -808.77 -7,787.60 5,944,900.27 550,902.84 3.51 808.77 9,468.30 81.34 206.11 3,108.79 2987.79 -868.76 -7,818.59 5,944,840.06 550,872.32 3.51 868.76 K13 9,500.00 81.36 204.99 3,113.56 2992.56 -897.03 -7,832.11 5,944,811.68 550,859.02 3.51 897.03 9,600.00 81.42 201.44 3,128.53 3007,53 -987.88 -7,871.07 5,944,720.54 550,820.77 3.51 987.88 9,700.00 81.48 197.89 3,143.40 3022.40 -1,080.99 -7,904.34 5,944,627.18 550,788.23 3.51 1,080.99 9,800.00 81.54 194.34 3,158.17 3037.17 -1,175.99 -7,931.79 5,944,531.98 550,761.53 3.51 1,175.99 9,900.00 81.60 190.79 3,172.84 3051.84 -1,272.52 -7,953.30 5,944,435.29 550,740.77 3.51 1,272.52 9,991.33 81.66 187.55 3,186.14 3065.14 -1,361.71 -7,967.69 5,944,346.00 550,727.07 3.51 1,361.71 Wsak D -1J-1fi2 (wp0&} D-Top 10,000.00 81.66 187.24 3,187.40 3066.40 -1,370.22 -7,968.80 5,944,337.48 550,726.04 3.50 1,370.22 10,100.00 81.72 183.69 3,201.86 3080.86 -1,468.71 -7,978.22 5,944,238.94 550,717.39 3.51 1,468.71 10,189.81 81.77 180.50 3,214.75 3093.75 -1,557.52 -7,981.47 5,944,150.11 550,714.83 3.52 1,557.52 10,200.00 81.77 180.40 3,216.21 3095.21 -1,567.60 -7,981.54 5,944,140.03 550,714.83 0.94 1,567.60 10,289.36 81.77 179.55 3,229.00 3108.00 -1,656.04 -7,981.51 5,944;051.60 550,715.55 0.94 1,656.04 Wsak C 10,300.00 81.77 179.45 3,230.52 3109.52 -1,666.57 -7,981.42 5,944,041.08 550,715.73 0.94 1,666.57 5/16/2007 4:52:58PM Page 6 of 10 COMPASS 2003.11 Build 48 a~~~i~A~ COt10CQ~'1l~~IpS Halliburton Company HAL 1 URT N a~ Compass Proposal Report - Geographic gperry Driiling 8ervices ~ ~ ~-' Halliburton Company HALL1 URTOI~f ~OI'lOCO~'ll~~a~5 Compass Proposal Report - Geographic €3pere~y Driilit~g ~~rwfoes ~ a ae a _ ~ ~ ~, ~,~ ,: .. =~.Sperry EDM~ .11 ~ -- ~ ~ ~,~ ~' ~ ~ ~ __ ~,, ConocoPhillips'Alaska, Inc. Well Plan 1J-162 - Slot 1J-162 ~L ~ ~ Do on 15 121.OOft Do on 15 40+81 ~ y @ ( Y { )) , Kuparuk River Unit - ~„E,,, ' ~ Doyon 15 @ 121'.OOft (Doyon 15 (40+81)) ~ ~ -_- Kupatuk aJ Pad ~ True '~ - _= Plan ~1J-162 Minimum Curvature , 1 J-162 ~ 1 J-162 (wp09} ', _ _ -- „~ . ~ ~ ~ _~ ~ 10,400.00 81.77 178.50 3,244.84 3123.84 -1,765.52 -7,979.66 10,415.12 81.77 178.36 3,247.00 3126.00 -1,780.48 -7,97925 10,422.11 81.77 178.36 3,248.00 3127.00 -1,787.4~ -7,979.05 Wsak B 10,445.12 81.77 178.36 3,251.29 3130.29 -1,810.16 -7,978.40 9 5/8" Casing @ 10445' MD, 3251 ' ND: 144' FSL, 53' FWL-Sec 34-T11 N- R10E - 9 5 10,500.00 84.51 178.38 3,257.84 3136.84 -1,864.62 -7,976.85 10,600.00 89.51 178.42 3,263.05 3142.05 -1,964.41 -7,974.06 10,644.12 91.72 178.44 3,262.57 3141.57 -2,008.51 -7,972.85 10,695.90 91.72 178.44 3,261.02 3140.02 -2,060.25 -7,971.44 10,700.00 91.56 178.42 3,260.90 3139.90 -2,064.35 -7,971.33 10,703.98 91.40 178.40 3,260.80 3139.80 -2,068.32 -7,971.22 1J-162 T1 (wp08) 04/1 8l07 10,777.52 89.14 180.28 3,260.45 3139.45 -2,141.85 -7,970.37 10,800.00 89.14 180.28 3,260.79 3139.79 -2,164.33 -7,970.49 10,858.54 89.14 180.28 3,261.67 3140.67 -2,222.86 -7,970.77 10,900.00 90.76 179.96 3,261.71 3140.71 -2,264.32 -7,970.86 10,933.78 92.09 179.69 3,260.86 3139.86 -2,298.09 -7,970.76 11,000.00 92.09 179.69 3,258.45 3137.45 -2,364.26 -7,970.40 11,100.00 92.09 179.69 3,254.80 3133.80 -2,464.19 -7,969.86 11,200.00 92.09 179.69 3,251.16 3130.16 -2,564.12 -7,969.32 11,283.78 92,09 179.69 3,248.10 3127.10 -2,647.85 -7,968.86 1J-162 T3 (wp08) 04/1 8/07 11,300.00 91.93 179.66 3,247.53 3126.53 -2,664.06 -7,968.77 11,380.86 91.13 179.52 3,245.37 3124.37 -2,744.89 -7,968.19 11,400.00 91.13 179.52 3,244.99 3123.99 -2,764.02 -7,968.03 11,500.00 91.13 179.52 3,243.01 3122.01 -2,864.00 -7,967.18 11,600.00 91.13 179.52 3,241.03 3120.03 -2,963.98 -7,966.34 11,700.00 91.13 179.52 3,239.05 3118.05 -3,063.95 -7,965.49 11,800.00 91.13 179.52 3,237.07 3116.07 -3,163.93 -7,964.65 11,900.00 91.13 179.52 3,235.09 3114.09 -3,263.91 -7,963.80 12,000.00 91.13 179.52 3,233.10 3112.10 -3,363.88 -7,962.96 12,096.14 91.13 179.52 3,231.20 3110.20 -3,460.00 -7,962.14 1J-162 T4 (wp08) 04/1 8l07 12,100.00 91.10 179.51 3,231.12 3110.12 -3,463.86 -7,962.11 12,200.00 90.10 179.40 3,230.08 3109.08 -3,563.85 -7,961.16 12,252.49 89.58 179.35 3,230.22 3109.22 -3,616.33 -7,960.59 12,300.00 89.58 179.35 3,230.57 3109.57 -3,663.84 -7,960.05 12,400.00 89.58 179.35 3,231.30 3110.30 -3,763.83 -7,958.90 12,500.00 89.58 179.35 3,232.03 3111.03 -3,863.82 -7,957.76 12,600.00 89.58 179.35 3,232.77 3111.77 -3,963.81 -7,956.62 12,700.00 89.58 179.35 3,233.50 3112.5~ -4,063.80 -7,955.47 12,800.00 89.58 179.35 3,234.23 3113.23 -4,163.79 -7,954.33 12,900.00 89.58 179.35 3,234.96 3113.96 -4,263.78 -7,953.19 13,000.00 89.58 - 179.35 3,235.69 3114.69 -4,363.78 -7,952.04 13,100.00 89.58 179.35 3,236.42 3115.42 -4,463.77 -7,950.90 5,943,942.15 550,718.26 0.94 1,765.52 5,943,927.19 550,718.79 0.94 1,780.48 5,943,920.28 550,719.04 0.00 1,787.40 5,943,897.52 550,719.87 0.00 1,810.16 5,943,843.08 550,721.84 5.00 1,864.62 5,943,743.32 550,725.40 5.00 1,964.41 5,943,699.24 550,726.96 5.00 2;008.51 5,943,647.53 550,728.77 0.00 2,060.25 5,943,643.43 550,728.91 4.00 2,064.35 5,943,639.45 550,729.06 4.00 2,068.32 5,943,565.94 550,730.47 4.00 2,141.85 5,943,543.47 550,730.54 0.00 2,164.33 5,943,484.94 550,730.71 0.00 2,222.86 5,943,443.48 550,730.94 4.00 2,264.32 5,943,409.72 550,731.31 4.01 2,298.09 5,943,343.56 550,732.18 0.00 2,364.26 5,943,243.64 550,733.50 0.00 2,464.19 5,943,143.73 550,734.82 0.00 2,564.12 5,943,060.02 550,735.93 0.00 2,647.85 5,943,043.81 550,736.15 1.00 2,664.06 5,942,963.00 550,737.36 1.00 2,744.89 5,942,943.86 550,737.67 0.00 2,764.02 5,942,843.91 550,739.29 0.00 2,864.00 5,942,743.95 550,740.92 0.00 2,963.98 5,942,643.99 550,742.54 0.00 3,063.95 5,942,544.03 550,744.17 0.00 3,163.93 5,942,444.08 550,745.79 0.00 3,263.91 5,942,344.12 550,747.42 0.00 3,363.88 5,942,248.02 550,748.98 0.00 3,460.00 5,942,244.16 550,749.04 0.99 3,463.86 5,942,144.19 550,750.77 1.00 3,563.85 5,942,091.72 550,751.75 1.00 3,616.33 5,942,044.22 550,752.66 0.00 3,663.84 5,941,944.25 550,754.58 0.00 3,763.83 5,941,844.28 550,756.51 0.00 3,863.82 5,941,744.31 550,758.43 0.00 3,963.81 5,941,644.35 550,760.35 0.00 4,063.80 5,941,544.38 550,762.27 0.00 4,163.79 5,941,444.41 550,764.20 0.00 4,263.78 5,941,344.44 550,766.12 0.00 4,363.78 5,941,244.47 550,768.04 0.00 4,463.77 5/16/1007 4:52:58PM Page 7 of 10 COMPASS 2003.11 Build 48 ; ,: ~ ~ ~ ~ ~ ~ ~ ~ '~ l ~ ~ COI'lOCO~'ti~~IpS Halliburton Company HQLLI~URTC?N ~~ Compass Proposal Report - Geographic gp~rry Dritling Ssrvfcea 13,151.47 89.58 179.35 3,236.80 3115.80 -4,515.23 -7,950.31 5,941,193.02 550,769.03 0.00 4,515.23 1J-162 T5 (wp08) 04/1 8/O7 13,200.00 89.87 180.01 3,237.03 3116.03 -4,563.76 -7,950.04 5,941,144.49 550,769.68 1.50 4,563.76 13,248.98 90.17 180.68 3,237.01 3116.01 -4,612.73 -7,950.34 5,941,095.52 550,769.76 1.50 4,612.73 13,300.00 90.17 180.68 3,236.86 3115.86 -4,663.75 -7,950.95 5,941,044.50 550,769.55 0.00 4,663.75 13,400.00 90.17 180.68 3,236.57 3115.57 -4,763.75 -7,952.14 5,940,944.52 550,769.14 0.00 4,763.75 13,423.50 90.17 180.68 3,236.50 3115.50 -4,787.25 -7,952.42 5,940,921.02 550,769.04 0.00 4,787.25 1J-162 T6 (wp08) 04l1 8(07 13,500.00 90.72 179.68 3,235.91 3114.91 -4,863.74 -7,952.66 5,940,844.53 550,769.39 1.50 4,863.74 13,584.96 91.33 178.56 3,234.40 3113.40 -4,948.68 -7,951.35 5,940,759.61 550,771.37 1.50 4,948.68 13,600.00 91.33 178.56 3,234.05 3113.05 -4,963.71 -7,950.98 5,940,744.59 550,771.86 0.00 4,963.71 13,700.00 91.33 178.56 3,231.73 3110.73 -5,063.65 -7,948.46 5,940,644.68 550,775.16 0.00 5,063.65 13,757.71 91.33 178.56 3,230.40 3109.40 -5,121.33 -7,947.00 5,940,587.02 550,777.06 0.00 5,121.33 1J-162 T7 (wp08) 04/1 8l07 13,800.00 91.35 178.98 3,229.41 3108.41 -5,163.59 -7,946.09 5,940,544.77 550,778.30 1.00 5,163.59 13,838.78 91.38 179.37 3,228.49 3107.49 -5,202.36 -7,945.53 5,940,506.01 550,779.16 1.00 5,202.36 13,900.00 91.38 179.37 3,227.02 3106.02 -5,263.56 -7,944.86 5,940,444.83 550,780.32 0.00 5,263.56 14,000.00 91.38 179.37 3,224.62 3103.62 -5,363.52 -7,943.75 5,940,344.88 550,782.20 0.00 5,363.52 14,100.00 91.38 179.37 3,222.22 3101.22 -5,463.49 -7,942.64 5,940,244.94 550,784.09 0.00 5,463.49 14,200.00 91.38 179.37 3,219.82 3098.82 -5,563.45 -7,941.54 5,940,144.99 550,785.97 0.00 5,563.45 r 14,259.01 91.38 179.37 3,218.40 ` 3097.40 -5,622.44 -7,940.88 5,940,086.02 550,787.09 0.00 5,622.44 BHL ~ 14255' MD, 32 18' ND: 1fi11' FSL, 87' FWL - Sec03 -T10N-R10E - 5 1/2" -1J-1 62 Toe (wp09) 04/18/07 5/16/2007 4:52:58PM Page 8 of 10 COMPASS 2003.11 Build 48 1.~~~l.d~~~L ~ ~ , , Halliburton Company COIlOCO~'ll~~aa~ Compass Proposal Report - Geographic 3,236.80 1J-162 T5 (wp08) 04/18/07 - Point 3,264.50 1J-162 T2 (wp08) 04/18/07 - Point 3,186.14 1J-162 (wp08) D-Top - Point 3,236.50 1J-162 T6 (wp08) 04/18/07 - Point 3,230.40 1J-162 T7 (wp08) 04/18/07 - Point 3,218.40 1J-162 Toe (wp09) 04/18/07 - Point 3,254.80 1J-162 T1 (wp08) 04/18/07 - Point 3,268.30 1J-162 MB_Heel 04/18/07 - Polygon Point 1 Point 2 3,248.10 1J-162 T3 (wp08) 04/18/07 - Point 3,23120 1J-162 T4 (wp08) 04/18/07 - Point ~ HALL.iBURTO ~parry Drilling Bervic~ -4,515.23 -7,950.31 5,941,193.02 550,769.03 -2,199.77 -7,971.39 5,943,508.02 550,729.91 -1,359.97 -7,965.91 5,944,347.76 550,728.84 -4,787.25 -7,952.42 5,940,921.02 550,769.04 -5,121.33 -7,947.00 5,940,587.02 550,777.06 -5,622.44 -7,940.88 5,940,086.02 550,787.09 -2,068.75 -7,971.37 5,943,639.02 550,728.91 -1,359.70 -7,965.88 5,944,348.03 550,728.87 0.00 0.00 5,944,348.03 550,728.87 -709.16 -5.49 5,943,639.02 550,728.91 -2,647.85 -7,968.86 5,943,Q60.02 550,735.93 -3,460.00 -7,962.14 5,942,248.02 550,748.98 4,612.00 2,303.38 13-3/8 16 10,445.12 3,251.29 9-5/8 12-1/4 14,259.00 3,218.40 5-1/2 8-1/2 5/16/2007 4:52:58PM Page 9 of 10 COMPASS 2003.11 Build 48 ~~~~~~~~~ ~ ~ 1,720.56 54.27 270.61 1,525.44 5.97 -609.51 ~~ ~ Pfrost 1,965.66 64.04 269.68 1,650.95 6.42 -819.69 Y3 2,845.28 72.00 269.04 1,935.72 -6.51 -1,651.27 k15 3,695.40 80.25 270.51 2,148.15 -1L16 -2,472.57 csgpt 7,109.94 80.25 270.51 2,726.40 18.76 -5,837.65 Ugnu C 8,180.13 80.57 251.84 2,906.21 -55.65 -6,884.21 Ugnu B 8,448.51 80.73 242.32 2,949.83 -158.67 -7,127.83 Ugnu A 9,468.30 81.34 206.11 3,108.79 -868.76 -7,818.59 K13 9,991.33 81.66 187.55 3,186.14 -1,361.71 -7,967.69 Wsak D 10,289.36 81.77 179.55 3,229.00 -1,656.04 -7,981.51 Wsak C 10,422.11 81.77 178.36 3,248.00 -1,787.40 -7,979.05 Wsak B 40.00 SHL @ 1958' FSL, 2526' FEL-Sec35-T11N-R10E 4,612.00 2,303.38 -3.13 -3,375.89 13 3!8" Casing @ 4612' MD 2319' Tl/D: 1954'FSL, 622' FEL-Sec 34-T11 N-R1 7,454.29 2,784.71 21.78 -6,177:01 Begin Pump Tangent @ 7454' MD, 2785' TVD 7,654.28 2,818.58 23.53 -6,374.11 End Pump Tangent @ 7654' MD, 2819' TVD 10,445.12 3,251.29 -1,810.16 -7,978.40 9 5/8" Casing @ 10445' MD, 3251' TVD: 144' FSL, 53' FWL-Sec 34-T11N-R10 14,259.00 3,218.40 -5,622.43 -7,940.88 BHL @ 14259' MD, 3218' TVD: 1611' FSL, 87' FWL - Sec03-T10N-R10E I ° 5/162007 4:52:58PM Page 10 of 10 COMPASS 2003.11 Build 48 ~,,~ ~ ~ ~ ~ ~l ~ ~ C0110C~~"il~~I~JJS Halliburton Company H LIBURTt~ AlaSka Compass Proposal Report - Geographic gperry Drilling Servicros ~ • Plan: 1 J-162 (wp09) Sperry Drilling Services Anticollision Summary 11 May, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1 J-162 1J-162 Local Coordinate Origin Viewing Datum: TVDs to System: North Reference: Unit System: Centered on Well Plan iJ-162 - Slot 1J-162 Doyon 15 @ 121.Oft (Doyon 15 (40+g1)) N True API HALLIBURTQRI ~pee~ry Drilflng 8ervice~ ~i ~ +,,,,~ : a ''~ ~ ~ ,.u..,. ~~ ~~~~~~~~ SIBVET PROGIt~~t Date: 2007-OS03T00:00:00 Validated: Yes Version: Depth Froro Depth To Survey/1'lan Tool 40.0 900.0 1J-162 (wp09) C~GYRO-SS 900.0 14259.0 1J-1G2 (wp09) MWD+IFR-AK-CA~SC 2~0 COMPANY DETAILS: ConocoPhillips Alaska, Inc. Engineering Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surtace: Elliptical Conic Warning Method: Rules Based 1J-158 L1 (v~~~,'iuj 1J-152 7J-154 ~~ 1J•107 (wp04) 1E-170 ~ 1J-G9 ~~ 1J-10 ~` 1J-159 i 1J-03 ~ ~~ ~ i ' i^ ~~~~ n W ~'-~'~ ~ Ii L ,~ 1J-118 3~ \\~ ~ ~ , ~,; / , ~ ~ ~~'`~~ ti2q'~ ¢. ~c~ -~^-~ i ~ ~ ~ ~~ ~\ _.. .~ ~ . ~bC ~~ - . ~~ 1 \ ~i ~ \._ ~ ~ ~.~ i i ~ ~ ~~\ ~'~ ~ fi,Dt ` '' 1J-23 flot(wpot) ~ ;. \~._ 3i9" 11 ; . '~~ .~i ~ ~ ~ ~ i ~ "~ i~~~ ~ ~ i ~ ~n ~~ ' i 1J-23 E Lat (wp01) 270 ~~~~- -' ,,+ I i i 1\{ , 150i ~ i ~~'~~` `' 140 ~~~~ ,' ~' 1J-122 (wp06) 1J-168 ~eo, -' 1J-173 Pilot (wp06) ' ~ 1J-160 1J-170 L1 Rig Surveys 1J-166 Travelling Cylinder Azimuth (TFO+AZI) ~°J vs Centre to Centre Separation ~200 ft/inJ ~ REFERENCE INFORMATION I Co-ordinate (N/E) Reference: Well Plan 1J-162 • Slot 1J-162, True NoRh Vertical (ND) Reference: Doyon 15 ~ 121.Oft (Doyon 75 (40+81~) Section (VS) Reference: Slot - 1J-162(O.ON, O.OE) Measured Depth Reference: Doyon 15 @ 121.Oft (Doyon 15 (40+81~) Calculation Method: Minimum Curvature °~-^. ` ~ ~ i ~ 'IJ-109 ,~ v. ~ ~ ~, ~ ~ WSP-1 ~ 3Q ~ 1 I ~ ~ ~ / ~'~ ~\ 1 1 ~ ~ I ' =i~ . ~~ i i i ~ WSP-OZ f.~.\\ ' ~. ~~~ ~~~ \ 1 ~ ~ ~ // ~p~ 1 I~ ~Ir" . ~_<~ ~\ili~~-'-t1N## .`.~ i ~ ~ ~ ~ ~ WSP-05 i From Colour To MD 0 13 113 213 413 613 813 1813 2813 3813 4813 5813 7313 8813 10313 11813 13313 14813 - 13 - 113 - 213 - 413 - 613 - 813 1813 _- 2813 - 3813 --- 4813 - 5813 - 7313 - 8813 - 10313 11813 - 13313 - 14813 - 16313 90 TravelGng Cylinder Azimuth (TFO+AZI) ~°~ vs Centre to Centre SeparaNon ~30 ftlin] ~ NAD 27 ASP Zone 4: WELL DETAILS: Plan 1J-162 ~ Ground Level: 81.0 ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: 100Stations Depth Range From: 40.0 To 14259.0 Maximum Range:1621.90351961195 Reference: Plan: 1J-162 (wp09) secnaa oetni~s 5~< MO Ir~c hv TVD HJlS ~EI-W DLep TFace VSec Target i aoo aoo o.ao aoa o0 00 o.ao oao 00 ~ xso.o aao ooa l ]00] 1]61 IJ000 zso.a "l00.0 oa oa 00 -SlB ooa 3.00 o00 3]0.00 0.0 00 ~ 16~1.9 51.5] 3i0.19 1500.0 5.8 -S152 9.00 100 -5.8 5 1165.1 1300 369.04 1Tt5.5 1.3 -1ro05 400 ~50p <.3 6 3215.1 )I.00 ]6B.OC 10A.0 ~1]4 -X1030 0.00 000 12< 1 3150.] 80.25 2]0.51 a ~csa.c ao.zs nosi 11013 zate5 -13.3 -Y1350 x3s s»az J50 oao 1000 o.oo 1J.] -z35 B 10189.8 Bt.i] 180.50 321<8 -155]5 -]9815 J.51 -0903 155]5 io iais.i ei.n ~~e.as ax~~o -i~eos -~e~s.3 o.sa ao.ao t~eos n iaas.i etn ne.ae 3zsi3 amoz -is~e.a o.oo 00o iaio.z 11 106M.1 81.)2 1]8M J2626 -3009.5 -19]39 500 0.46 1W8.5 13 tOfi95.9 91 ]2 1 ~B M 10I0.10 91a0 i)040 JZ61.0 J2509 -20fi0.3 -]8]1.5 ~20683 ~I9]12 0.00 4W O. W -I]]15 HG0.2 3068J 1J-163T~~wpOO~Gd~1B.0i 15 10Tl1.5 0.9.11 1t0.]8 3260.5 -31<1.9 -18)0< 4W 140.I1 if11.9 18 108588 89.11 180.]B 3Zfi11 .I2]2.9 -i8]0.8 OOD OOJ Y2129 1] 10833.8 82.OB 1]9.69 32fi0.8 -1]88.1 -]9)0.8 O.OU -1135 Y298.1 1B 1128J8 9 9 I)969 19 11~lOB 91.1~ ti9.52 ]2481 3245< .26<).9 -]958.9 -11N.8 -M88.2 000 1.00 000 .1G9.85 26i)9 IJ-153iJlwpOB10.Y1fl~0) 3IM.9 Zo izosal s~~3 ~~ssz ]1 1]251.5 69.SE 1]8.J5 ~z~i1 3330.2 aosoo -~sez.z -38183 -]980.8 oao 1.00 00o -1]).)9 aasoo i~-~ezr<~wpoeloa~aro~ 381fi.3 23 IJI515 8959 I]935 33JG8 ~45151 -]950.~ 000 000 <515.] IJ-161i5(wpOB~0011A~0) ]] 192/9.0 90.1] 1BO.fie 921~0 J812.] -]950.< t.SU 8831 ~812.'! 3C iJ<3J5 90.1] 1BO6B ]5 13585.0 Btlt 1]D.% 3]]65 3234.4 -0IB).3 -1951.0 d8/8.~ -]95fA 000 1.50 000 EtA6 4l8].3 11162T6(wpO8~0Y1B10) 99N.~ ]6 1JJ5>] 91JJ I18.56 ]] 19E38.6 91.96 11H.3] ]3J0< 9]38.5 .5121.3 -]9C]0 -520I.~ -]815.5 000 1.W 0.00 86~1 5111J 11182TI1~+~AB1W16~0] 52tYl.9 1B I<]590 91.30 119.J] 3I18< ~56234 -]9C09 000 0.00 5633.G 1J-162Tw~wp09~ON18/0) 180 WSP-20 •Halliburton Com an ~ p Y Anticollision Report Company. GonocoPhiliips Alaska Inc. - Date, ~ 5/15/2007 Time. 10:39;15 ~ ~Page: ~~ 1 Fietd:~ ~ ReferenceSite: Kuparuk River t3nit Kuparuk 1J Pad : ~ ~ ': ~ ~ ~ ~ Co-ordinate(N~)Reference: WeIG Plari 1J-~62,;Trus Nott#t ': ~. ` ' Refere~ce WeIl: Plari iJ-162 ~ ~~ Vertical (TYD)!Reference: DOyor~ 15 ~4(l~$1j 12'i.0 ~~ Reference Wellpath: Plan 1.1-i62 ~Db: Or~CIe= GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Refere nce: Plan: 1 J-162 (wp09) & NOT PLANNED P Interpolation Method: MD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 40.00 to 14259.01 ft Scan Method: Trav Cylinder North Maximum Radius: 1621.90 ft Error Surface: Ellipse + Casing Casing Points Mp T~'D ; Diamefer ' Hole Size NAme ! ft ft. , in in 4612.00 2303.38 13.375 16.000 13 3/8" 10445.12 3251.29 9.625 12.250 9 5/8" 14259.01 3218.40 5.500 8.500 51/2" Plan: 1J-162 (wp09) Date Composed: 1/26/2005 Version: ~ 2 Principal: Yes Tied-to: From Well Ref. Point Summary ~ "~ ~ ------- <- ~~ -----~--- (}ffset Wellpath --- -----------------> ~ Refexence bf£set Ctr-Ctr No-Go ' Aifowabl~ ~ ~ Site Well Welipath MD ' Ml) Distance Area Deviation Warnin~ ft i ft ft ft ft Kuparuk 1 E Pad 1 E-117 1 E-117 V1 7720.35 15450.00 , 625.92 122.88 503.04 Pass: Major Risk Kuparuk 1 E Pad 1 E-117 1 E-117L1 V4 7636.24 15400.00 496.00 119.62 376.39 Pass: Major Risk Kuparuk 1 E Pad 1 E-117 1 E-117L2 V3 7652.68 15450.00 424.01 118.82 305.20 Pass: Major Risk Kuparuk 1E Pad 1E-170 1E-170 L1 V8 9310.63 15756.00 229.65 184.48 45.17 Pass: Major Risk Kuparuk 1E Pad 1E-170 1E-170 L2 V3 ~ 9303.25 15748.00 195.01 40.98 154.02 Pass: Minor 1/200 Kuparuk 1 E Pad 1 E-170 1 E-170 V3 9464J6 15940.00 268.39 136.66 131.74 Pass: Major Risk Kuparuk 1J Pad 1J-03 1J-03 V10 154.88 150.00 184.40 2.92 181.48 Pass: Major Risk Kuparuk 1J Pad 1J-03 1J-03L1 V2 155.00 15~.00 184.40 2.93 181.48 Pass: Major Risk Kuparuk 1J Pad 1J-03 1J-03L2 V1 155.00 150.00 184.40 2.93 181.48 Pass: Major Risk Kuparuk 1J Pad 1J-03 1J-03L2PB1 V1 155.00 150.00 184.40 2.93 181.48 Pass: Major Risk Kuparuk 1J Pad 1J-09 1J-09 V7 358.66 350.00 200.52 5.92 194.59 Pass: Major Risk Kuparuk 1J Pad 1J-10 1J-10 V7 506.83 500.00 38.93 8.56 30.37 Pass: Major Risk Kuparuk 1J Pad 1J-109 1J-109 V1 199.16 200.00 178.12 4.32 173.80 Pass: Major Risk Kuparuk 1J Pad 1J-109 1J-109P61 V3 199.16 200.00 178.12 4.32 173.80 Pass: Major Risk Kuparuk 1J Pad 1J-109 Plan 1J-109a L1 VO Pla 211.98 200.00 178.46 4.55 173.91 Pass: Major Risk Kuparuk 1J Pad 1J-109 Plan 1J-109a L2 V0 Pla 211.98 200.00 178.46 4.44 174.02 Pass: Major Risk Kuparuk 1J Pad 1J-109 Plan 1J-109a V0 Plan: 211.98 200.00 178.46 4.59 173.86 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115 V2 261,14 250.00 147.59 4.55 143:04 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L1 V1 261.14 250.00 147.59 4.42 143.17 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L1P61 V1 261.14 250.00 147.59 4.66 142.93 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L1PB2 V1 261.14 250.00 147.59 4.66 142.93 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L2 V2 261.14 250.00 147.59 4.42 143.17 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L2P61 V4 261.14 250.00 147.59 4.66 142.93 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L2P62 V3 261.14 250.00 147.59 4.66 142.93 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115PB1 V1 261.14 250.00 147.59 4.66 142.93 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115P62 V1 261.14 250.00 147.59 4.66 142.93 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115P63 V1 261.14 250.00 147.59 4.66 142.93 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115P64 V1 261.14 250.00 147.59 4.66 142.93 Pass: Major Risk Kuparuk 1J Pad 1J-118 1J-118 V7 261.07 250.00 166.06 5.48 160.58 Pass: Major Risk Kuparuk 1J Pad 1J-118 1J-118L1 V4 261.07 250.00 166.06 5.35 160.71 Pass: Major Risk Kuparuk 1J Pad 1J-118 1J-118L2 V3 261.07 250.00 166.06 5.35 160.71 Pass: Major Risk Kuparuk 1J Pad 1J-118 1J-118PB1 V2 261.07 250.00 166.06 5.59 160.47 Pass: Major Risk Kuparuk 1J Pad 1J-118 1J-118PB2 V1 261.07 250.00 166.06 5.59 160.47 Pass: Major Risk Kuparuk 1J Pad 1J-152 1J-152 V3 416.54 400.00 238.74 6.65 232.10 Pass: Major Risk Kuparuk 1J Pad 1J-152 1J-152L1 V2 416.54 400.00 238.74 6.38 232.36 Pass: Major Risk Kuparuk 1J Pad 1J-152 1J-152L2 V1 416.54 400.00 238.74 6.38 232.36 Pass: Major Risk Kuparuk 1J Pad 1J-152 1J-152L2PB1 V1 416.54 400.00 238.74 6.75 231.99 Pass: Major Risk Kuparuk 1J Pad 1J-152 1J-152P61 V3 416.54 400.00 238.74 6.65 232.10 Pass: Major Risk Kuparuk 1J Pad 1J-152 1J-152P62 V4 416.54 400.00 238.74 6.65 232.10 Pass: Major Risk Kuparuk 1J Pad 1J-154 1J-154 V5 565,00 550.00 182.29 10.27 172.02 Pass: Major Risk Kuparuk 1J Pad 1J-154 1J-154L1 V5 565.00 550.00 182.29 10.15 172.14 Pass: Major Risk Kuparuk 1J Pad 1J-154 1J-154L2 V3 565.00 550.00 182.29 10.11 172.18 Pass: Major Risk Kuparuk 1J Pad 1J-156 1J-156 V3 414.92 400.00 141.55 7.65 133.90 Pass: Major Risk Kuparuk 1J Pad 1J-156 1J-156L1 V1 414.92 400.00 141.55 7.52 134.03 Pass: Major Risk Kuparuk 1J Pad 1J-156 1J-156L1PB1 V3 414.92 400.00 141.55 7.76 133.79 Pass: Major Risk Kuparuk 1J Pad 1J-156 1J-156L2 V1 414.92 400.00 141.55 7.52 134.03 Pass: Major Risk ~GRAM C~R~~~~~r~~,.A * Halliburton Com any ~ P Anticollision Report Company, ConocoPhiilips Alaska Inc. Date: 5/15/2007 Time: 1b:3~,15 Page: 2 Fieid; ~~~~ Kuparuk River UnY ~ ~~ ' ` ` ~ ~ ~ ~ Referene~ Site: Kuparuk 1 d Pad : Caorclinat~(NE) Referenee: Wel#: Pl~n '#J-162~ True NortM Refere~ce Well: Plan 1J-162 Vertical(TI'D) ReCerence: (7oy0r~ 15 (4d~$1} 12 1.Q ' Reference Wellpafh: Plan 1J-'162 Db:. Qracle Summary ~-. --. -- ---- Offset Wellpath ---------------_--> Referenet Qffset Ctr-Ctr ' l~"u-Go - Allowable ~ ~ ~ Site Well WellpatL MD ~ MII ~~~Distance~ Area Devi~tron Warning; ;ft i ft ' ft ft ~ Kuparuk 1J Pad 1J-159 1J-159 V2 462.97 450.00 77.32 7.54 69J8 Pass: Major Risk Kuparuk 1J Pad 1J-159 1J-159L1 V5 462.97 450.00 77.32 7.41 69.91 Pass: Major Risk Kuparuk 1J Pad 1J-159 1J-159L1PB1 V1 462.97 450.00 77.32 7.65 69.67 Pass: Major Risk Kuparuk 1J Pad 1J-159 1J-159L1PB2 V1 462.97 450.00 77.32 7.65 69.67 Pass: Major Risk Kuparuk 1J Pad 1J-159 1J-159L2 V2 462.97 450.00 77.32 7.41 69.91 Pass: Major Risk Kuparuk 1J Pad 1J-159 1J-159P61 V2 462.97 450.00 77.32 7.65 69.67 Pass: Major Risk Kuparuk 1J Pad 1J-160 1J-160 V4 1471.13 ~1450.00 70.76 30.05 40.71 Pass: Major Risk Kuparuk 1J Pad 1J-160 1J-160L1 V5 1471.13 1450.00 70.76 29.91 40.85 Pass: Major Risk Kuparuk 1J Pad 1J-160 1J-160L1P61 V2 1471.13 1450.00 70.76 30.06 40.69 Pass: Major Risk Kuparuk 1J Pad 1J-160 1J-160L2 V1 1471.13 ~1450.00 70.76 29.91 40.85 Pass: Major Risk Kuparuk 1 J Pad 1 J-164 1 J-164 V3 361.34 350.00 41.39 6.73 34.66 Pass: Major Risk Kuparuk 1J Pad 1J-164 1J-164L1 V1 361.34 350.00 41.39 6.60 34.79 Pass: Major Risk Kuparuk 1J Pad 1J-164 1J-164L2 V2 361.34 350.00 41.39 6.84 34.55 Pass: Major Risk Kuparuk 1J Pad 1J-164 1J-164L2P61 V1 361.34 350.00 41.39 6.73 34.66 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166 V5 311.35 300.00 81.13 5.53 75.60 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166L1 V3 311.35 300.00 81.13 5.40 75.73 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166L1P61 V3 311.35 300.00 81.13 5.40 75.73 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166L2 V1 311.35 300.00 81.13 5.64 75.49 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166L2P61 V1 311.35 300.00 81.13 5.64 75.49 Pass: Major Risk Kuparuk 1 J Pad 1 J-168 1 J-168 V5 311.13 300.00 120.78 5.88 114.90 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168L1 V3 311.13 300.00 120.78 5.75 115.03 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168L2 V2 311.13 300.00 120.78 5.75 115.03 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168L2P61 V1 311.13 300.00 120.78 5.99 114.79 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170 V2 506.80 500.00 157.67 9.32 148.35 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170L1 V1 506.80 500.00 157.67 9.18 148.48 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170L2 V1 506.80 500.00 157.67 9.18 148.48 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170P61 V1 506.80 500.00 157.67 9.42 148.24 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170P62 V1 506.80 500.00 157.67 9.42 148.24 Pass: Major Risk Kuparuk 1J Pad Plan 1J-107 Plan 1J-107 L1 VO Plan 308.77 300.00 216.64 6.28 210.36 Pass: Major Risk Kuparuk 1J Pad Plan 1J-107 Plan 1J-107 L2 VO Plan 308.77 300.00 216.64 6.28 210.36 Pass: Major Risk Kuparuk 1J Pad Plan 1J-107 Plan 1J-107 V1 Plan: 1 308.77 300.00 216.64 6.41 210.23 Pass: Major Risk Kuparuk 1J Pad Plan 1J-111 Plan 1J-111 V1 Plan: 1 308.10 300.00 158.25 6.62 151.63 Pass: Major Risk Kuparuk 1J Pad Plan 1J-112 Kuparuk Plan 1J-112 W Lat VO P 295.82 300.00 151.53 5.74 145.79 Pass: Major Risk Kuparuk 1J Pad Plan 1J-119 (M15 Ph~lan 1J-119 VO 40.00 99.00 177.05 No Offset Stations Kuparuk 1J Pad Plan 1J-120 Plan 1J-120 L1 V2 Plan 261.02 250.00 188.94 5.47 183.47 Pass: Major Risk Kuparuk 1J Pad Plan 1J-120 Plan 1J-120 L2 VO Plan 261.02 250.00 188.94 5.47 183.47 Pass: Major Risk Kuparuk 1J Pad Plan 1J-120 Plan 1J-120 V2 Plan: 1 261A2 250.00 188.94 5.62 183.32 Pass: Major Risk Kuparuk 1J Pad Plan 1J-122 Plan 1J-122 L1 VO Plan 250.00 250.00 216.62 5.43 211.19 Pass: Major Risk Kuparuk 1J Pad Plan 1J-122 Plan 1J-122 L2 V0 Plan 250.00 250.00 216.62 5.38 21124 Pass: Major Risk Kuparuk 1J Pad Plan 1J-122 Plan 1J-122 V2 Plan: 1 250.00 250.00 216.62 5.54 211.08 Pass: Major Risk Kuparuk 1J Pad Plan 1J-123 Plan 1J-123 Kuparuk Pr 295.60 300.00 232.38 6.38 225.99 Pass: Major Risk Kuparuk 1J Pad Plan 1J-158 Plan 1J-158 L1 VO Plan 753.36 750.00 102.67 14.77 87.90 Pass: Major Risk Kuparuk 1J Pad Plan 1J-158 Plan 1J-158 V3 Plan: 1 753.36 750.00 102.67 15.02 87.66 Pass: Major Risk Kuparuk 1J Pad Plan 1J-162 Plan 1J-162 L1 V2 Plan X7650.00 7650.00 0.00 0.00 0.00 FAIL: No Errors Kuparuk 1J Pad Plan 1J-173 1J-73 Kuparuk Producer 347.29 350.00 220.56 6.42 214.14 Pass: Major Risk Kuparuk 1J Pad Plan 1J-174 Plan: 1J-174 V1 Plan: 311.20 3~0.00 240.62 6.31 234.31 Pass: Major Risk Kuparuk 1J Pad Plan 1J-174 Plan: 1J-174L1 VO Plan 311.20 300.00 240.62 6.42 234.20 Pass: Major Risk Kuparuk 1J Pad WSP-02 WSP-02 V4 299.91 300.00 196.65 5.32 191.32 Pass: Major Risk Kuparuk 1J Pad WSP-03 WSP-03 V1 310.57 3D0:00 181.68 7.32 174.36 Pass: Major Risk Kuparuk 1J Pad WSP-04 WSP-04 V1 299.27 300.00 183.29 5.02 17827 Pass: Major Risk Kuparuk 1J Pad WSP-05 WSP-05 V1 294.39 300.00 206.39 6.87 199.52 Pass: Major Risk Kuparuk 1J Pad WSP-15 WSP-15 W 295.57 300.00 229.09 670 222.39 Pass: Major Risk Kuparuk 1J Pad WSP-20 WSP-20 V1 / 616.93 600.00 49.25 12.22 37.02 7 Pass: Major Risk or Risk M P Kuparuk River Un it N KUP 34-11-10-1 KUP 34-11-10-1 V1 ~[ 8615.68 3150.00 261.06 147.49 113.5 ass: aj ~ ~~~~i~~~` 1~-162 ~rilling Hazards~lummarv (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) Surface Hole Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced ~ drilling fluid temperatures, Additions of Driltreat. ~ Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip ' sheets , um in out Intermediate Hole Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud wei ht Abnormal Reservoir Low BOP training and drills, increased mud Pressure ' wei ht. Lost circulation Low Reduced um rates, mud rheolo , LCM Hole swabbing on trips Moderate Trip speeds, proper hole filiing (use of trip ~ sheets , um in out Production Hole Hazard Risk Level Miti ation Strate Abnormal Reservoir Low Stripping drills, shut-in drills, increased Pressure ~ mud wei ht. ~ Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs, decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo , LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip ~' sheets , um in out, backreamin ~~~~`~ A L 1J-162 Drilling Hazards Summary 6/4/2007 3:23:00 PM • ; CemCAbE Preliminary Jab Design ` 13 3/8":;Surface ~ ~ Preliminary Job Design based on limited input data. For estimate purposes onty. Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 5/23/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 80' MD < Base of Permafrost at 1,720' MD (1,500' TVD) < Top of Tail at 3,812' MD < 13 3/8", 72.0# casing in 16" OH TD at 4;612' MD (2,303' TVD) Mark of Schlumberger Volume Calculations and Cement Svstems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 3,812' MD. Lead Slurrv Minimum pump #ime: 340 min. (pump time plus 120 min.) ARCTICSET Lite C 10.7 ppg - 4.45 ft3/sk 1.0190 ft3/ft x(80') x 1.00 (no excess) = 81.5 ft3 0.4206 ft3/ft x(1720' - 80') x 3.50 (250% excess) = 2414.2 ft3 0.4206 ft3/ft x(3812' - 1720') x 1.35 (35% excess) = 1187.9 ft3 81.5 ft3 + 2414.2 ft3+ 1187.9 ft3 = 3683.6 ft3 3683.6 ft3 / 4.45 ft3/sk = 827.8 sks Round up to 830 sks Have 320 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurrv Minimum pump time: 250 min. (pump time plus 120 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.4206 ft3/ft x(4612' - 3812') x 1.35 (35% excess) = 454.2 ft3 0.8315 ft3/ft x 80' (Shoe Joint) = 66.5 ft3 454.2 ft3 + 66.5 ft3 = 520J ft3 520.7 ft3/ 2.47 ft3/sk = 210.8 sks Round up to 220 sks BHST = 51 ~, Estimated BHCT = 66~. (BHST calculated using a gradient of 2.6~/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time ~bpm~ (bbll (min) (min) CW100 5 50 1OA 10.0 Drop Bottom Plug 15.0 25.0 MudPUSH II 6 50 8.3 33.3 Lead Sl~rry 7 658 94A 127.3 Tail Slurry 6 97 16.2 143.5 Drop Top Plug 8A 151.5 Water 5 20 4.0 155.5 Switch to Rig Pum s 5A 160.5 Displacement 7 631 90.1 250.6 Slow Rate 3 20 6.7 257.3 MUD REMOVAL Recommended Mud Properties: 8.8 ppg, P~ < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH~ I I, P~ ~ 17-21, TY = 20-25 Centralizers Recommend 1 per joint across zones of interest for proper cement placement. ~../~~~~~~~ ~ • ~ ~ CemGADE Prel~rninary Job Design 9~625" Intermediate Casing ; ~ ~ Preliminary Job Design based on limited input data. For estimate purposes only. ~ ~ . ~ Volume Calculations and Cement Svstems Volumes are based on 25% excess. Tail slurry is designed for 500' MD above Ugnu C formation -(Ugnu C at 7110' MD, TOC at 6600' MD, 3845' MD annular length). Tail Slurrv Minfmum thickening time: 5:15 hr:min. (Pump time plus 120 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.3132 ft3/ft x 3845' x 1.25 (25% excess) = 1505.3 ft3 0.4257 fit3/ft x 80' (Shoe Joint) = 34.1 ft3 1505.3 ft3 + 34.1 ft3 = 1539.4 ft3 1539.4 ft3/ 2.25 ft3/sk = 684.2 sks Round up to 690 sks BHST = 74`F, Estimated BHCT = 60~. (BHST calculated using a gradient of 2.6~/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time ~bpm~ (bbll ~min) (minl CW 100 5 75 15.0 15.0 Drop Bottom Plug 10A 25.0 MudPUSH II 5 75 15.0 40.0 Tail Slurry 6 277 45.7 85.7 Drop Top Plug 5A 90.7 Water 5 20 4A 94.7 Switch to Rig Pum s 5A 99J Displacement 7 651.2 93A 192.7 Slow Rate 3 150 50.0 242.7 MUD REMOVAL Recommended Mud Properties: 8.8 ppg, P~ < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH* II, P~ = 19-22, TY = 22-29 Centralizers: Recommend 2 per joint across zones of interest for proper cement placement. o~1~~E~~~~ ~ ~ V / ~ ~ ~~ Insulated Conductor, 20" 94# K-55 x 34" 0.312 WT +I- 80' Wellhead I Tubing I Tree: 13318" x4112", 5,000 psi 4112" x 1" KBMG 13-3/8" C sing Shoe, 68# L-80, BTC set @ 4612' MD, 2303' D Tubing String 4-t/2" 12.6#, L-80, IB 3.958" ID, 3.833" Drift 4-112" x 1" KBMG C01'lOCO~'ll ~~I p5 West Sak Hybrid Producer 1 J-162 Dual Lateral Completion As Planned WP 09 of Motor Centralizer ft 418 HP KMHFERwith FC6000 Pump D-san window ~D' Sand Lateral at 999 ' MD, 3186' TVD - 4-112" 11.6#, BTC, ~ 2" PayZone ECP L-80 Slotted Liner 7" x 9-5/8" _ >del B HOOK anger ~ ~' \ ~o ,~ 4_ .. I 7" Tieback T' X &Sl8" ZXP Liner Top Packer T' X 9-5/8" Flex Lock Liner Hanger I Packer Assembly Liner Hanger ~ +I- 10100' MD Casing ore Receptacle I aBaw« Huqnes mw. nus a« mem ~~dy i Qi i~ rep.«m<~ V~~,o-n„~~ea' ~'~U no~ o, ~~~, na,~ ~~ ,~y iorm o~ ~y.,~~y ~~ea~~s ekaroni<«mern,nicy, inuuaioy plp~o[opying, recordin9. o~ by any infortn i s~o~aye anJ re val sys~e~ i w ki~own or ~ereaM1er inven~eJ, witl~oul wnh n pemtissian han Bake~ HYglies I~ 9-5/8" Casin~ 40.0#, L 80 BT @ 10445' MD, 1' ND (84 deg inc) ~ 15.5 #, L-80 BTCM MD, 3218' ND p~rp~~i' BNYGlES Baker Oil Tools Eauioment Snecifications 7"" X 9-5/8" HOOK Hanger Mainbore DriH: 7.00" Mainbore Drrft, with diverter. 6.T5" Latenl Drik, no diverter or LEM: 6.15" Lateral Drift, w/ diverter, no LEM: 5.17" LatenllMainbore Diverter OD: 8.50" 41/2" Guide Shce 4-1/2" Casing Shoe, 11.6#, L-80 BTCM Set @ 14254' MD, 3146' ND . 5112" 15.5 #, BTC, ~~ \ L-80 Slotted Liner 5-1/2" Eccentric Guide Shoe ~ 5-1/2" Casing ~ti~~ Set @ 1! ~ • • ~ ~ ~ Deve[o m _ p ent Service ~Yon-Coaventiona[ Welt Cercle 4ppropriate Letter 1 Pacagraphs to be tncfud~d in Transmittat Letter ` CE~CK ~ w'HAT APPLIES ;--- ~ ~ ' • ~'RANS1dII~'~'A~ I.~~"a'ER C'~iECKLIST ~YEL.L i~iAitiiE ~\Z~ ~ - ~~o ~~ PT'D# -c~(~°~~ ' ~~S ~ AUU-U ~f S (OPT[O!V S ) MliCTI LATERAL Expioratory~ Stratigraphic T'est T'EXT FOR APPROVAL LETTER i The permit i; for a new weilbore segment of existine ' I ~ ([f last two dt wel( gits in ~ Pe~it Yo. i API nurnber are , API No. ~0- . ,` between 60-69) Production shoutd continue to be repoRed as a function of the ~ ; origina! .4Pf number stated above. ~ PILOT I~fOLE ! ! ~ ' ~ ~ 1 , ~ ~ SPACIIYG ! EXCEPTION ~ ~ ~ i ; DRY D1TCH i SA.tiIPLE i ~ j 1Yon-Conventiona! i 1r4'e!1 ~ ~ i[n accocdance with 20 A.4C 2~.OU5{~, ait records, data and lo~s ; acquired far the pilot hole must be ctearly differentia,ted in both ; weti name ( PE~ and API number f~ ~~~~ ~) &om records, data and togs i acquired for well The pecmit is approved subject to full compliance with 20 AAC ; 2~•d7~. Approval to perforate ar~d oroduce / ini+ect is contingenr ± I upon issuance of a conservation order approving a spacing ' I exception. I i liabili of an assumes the ~ tY y protest to the spacing exception that may occur. ~ .~ ~ Ali dry ditch sampte sets subrnitted to the-Eommissioa musc be in ; i no greater than 30' sample intenrals &om 6etow~ che pecrnafrost or ; ( from whece samples are Fnt ca~ght and i 0' sampte interv~als ; ! through target aones. i r j Please note the fotlow~ircg. speciai condition of' this perm~r. ,~ ~ production or production testing of coa! bed methane is not atlowed ~ ~ for (riarne of well) untit after (Cocnnanv Name) has designed and ! ~~mp(emented a water well testing program to provide base(ine data ; on water quality artd quantity. (C1omn~Y N~e) must contact the I ! Commission to obtain advance approval of such wacec weit testing ; DCO¢I3m_ Rev: I '2~ia6 C:' jocly~transrnirtat_checktist ~ ~ ^^ , , , ~I ' ~ ~ ~- ; ; ; ~ ~ : , ; ~ o ! ~ ~' ; : ; ; ~ ; ; ; ; ~ ~~ , , , , , ~ i N~, c , ~, , , , y, , , ~ ~ a ~ Q o, ~ ~ ~ , ~ , , , , , , , , , , , v~ i ~, c t i 3 , , , , ~ , ~ , ~ , ~ , a ~', ; N, , 3, W; ~ , _; ~ ~ ~ ; , , , N ~, , ~ ~ ~ Q ~ c ~ -a~ ~, ~~ ~ ~, ~, , , , ~~ ~~ , ~~ ~, ~~ ~~ ~~ ~, , ~~~ ~~ ~, ~~ ~~ , ~~ , , uh C °' ~~~ `O 0 O ~ , a~, ~ ~ , , , , , , , O, m, `~ , ~ L ~ ? v ~ ; ~ U~ ~ ~, ~ fl; rn , , , , , ?, N, , , °~ ~ ~, 4 N p a, . o ~.c I ~ o, , o, ~~ ; ~ o, , a~~ ~~ .r, ~ ~ ~ ~ ~ ~ ~ ~ , , , ~ , , ~ ~ ~ ~ ~ ~ ~ ~ ~~, ~~~ , ~~ ,• , , , ~ , ~ ~ , ~ ~~ ~ c, ' ar m~ ~~ ~~ ~n~ N w 3 v~ W ~I J, , -~ U =, ~ , ~, ~, , , , , , , , , ~ a T Y, , , , ,rn ~, ~ ~ ~ y, N = o ~ c ~ ~ N ,, , , ~ , , ~ , Q ~ ° ~ ~ o E O m p ,>, a~ ~ ~ , ~ ~ ° Q NI o , `' Q' , m , ~~ , ~ ° a~, ~~= ~ ' a , Q 3 Y , , , , , c6 > C9 p a = o, ~, rn ~ Z ~ a O O~, ~ ~~ `~ (O~ O o'6~ ~~ , . , ~ ~ , , , ~ ~ ~ ~ ~ , ~ ~ ~ ~ , , ~ ~ ~ ~ ~ ~ , , , , ~ O, ~ , ~ , -~ ~ ~ ~ 7~ ~ N~ , ~~~ ~ ~ ~, ~~p~ ~ I ~ G , ~n, UNi' O'~ . ~ a I ~, ~, ~ a ~~ w ~ Y~ ~ N , ~ ~ , ~ ~ ~ ~ ~, , «~ ~' , ~ a ~ _' ~ w~ ~~ ~ ~~ ~, N ° , o U' o' ~ °: a , ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 3 ~ , ~ , , ~ ~, o; ~ ~ ~ ~, ~, ~, •3 ' ~6 c o ~ °, ~; ~~ a~ , , , , , ~ i ii ~ oi; ~ ~ ~ Q~ ~~ ~~ ~~ ~, ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , ~ , ~ , ¢~~ ~ ,C~ , m~ ~ ~~ , ~ L, N, W '~~ Vl N G L, m ~ ~ , , , , 'O ~, O. 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Q. s • a , , c~ a E, ~ a a~, , ~~ ~ a i m, ~ r~ ~, ~n, ~ u i ~, ° a~ ~, ' w-' 0' ' ~' m' m ' ' ` ' c E o ~ a a v c N N a a 'm a~ v . ~6 ~ ~.~, .. o, ~ a, ~, 'S r. o ~ ~~ o rrn , a~Q ,~ ~~ o 3 o L~ o .-, W V $ d J o c, :~, a m m > a~, m o' U ~ ~ a~ ~ a~ ° m' ~' o a o~ ~ o o ~, Y asi o' o' N' ~°' E' a°~i' ~ E t°~ o aai' °: ~'' ~' c' , ~ p; ~.6~ ~~ ~~ 4~ ~~~ ~ ~ ~ 0~ >~ ~~ Q C~ ~A O~ V ~ N ~~ fl" ~ ~ ~ - a ~ ~~ ~ ~ ~ ~ C~ U ~ ~ ~ N N~ y p ~ ~ ~+ _ t~ ~ Q. d ~ ~ E, ~6 0 0, ~ °' ~ 4 UA 4 N VD !~, fl. m ~ ~~ ~, 'c, N , oi a m . .. m' m ~ p, ~ ~ ~a' o ~', °y ' , ~ ~, ~ 3, _ ~°' ~ , p , .N; o `~ - ~ a v a ~a ~ ~, .5 a fl. - - ~ 3 x ~'~ . ~0 ~ ~ ~, a~ a 3, S ~ oD ~ ~ c a a `m c Y, ~ ~; ~; ~ ~~ ° a` a ~, ~', o', w ~ ~- o ~ o' o~ ci I , o ~, ~, >, '_', v ~, ~ 0 m~ .o~ _, o~ a a~ ~ m~ E N ~. ~. • m - ~, ~ C .n~ C , ~ -o, ~, ~ c ~ ;~~ a~, ~' a a~, a > o' .~ N:°' ~, _ 3, ~, ~ ~ o N~ ~~ I O f0 ~ ~ ca ~, N ~ C E f6 ~ Z ~ ~ N' ~°'' c' 3' c`~i' ~ ~ 4 p~ O~ ~' :~' o ~ L~ o ~' ~ ~' E „ ,,. ~' N' .o' ~' yo c`~' ~' ~' ° ~' ~' -' :?' ~' ,-~'' ~°' a~' ~ , _' ~~' I ~ p, ~ cf6i' ~' ~ ~ ~ ~' °` °' °~ a~~ m~ o~ , o~ o~ I Vi ~i ~i ~i . 3~ ~ m~ ~~ ~ '~~ rn vi~ 3~ ~~ ~~ ~ Q ~~: V' /~~-, O C~ ; ai ~; ~ ~, a . • m N i m ~ ~ Q 3~ c, ~ o> c: ~, H > H F' 'v a~ ~ `~ N ~~ ~ a o o o p ~ y m ~:° c ~ ~\ ~ ~ , . N' a> m ~ m, _ a ~~~~~; a ~ ~~ d u~' ~ O' a~ a a~ a O a~ a' c m U ~ o, ~' Q; a' z o~~' U' u~' U' ~', U ~', U a i m, a, U¢ f° v, = Q ~ = o -, O, O t m m' U; : ~ ~' `~' ~' -, a ~' <n' in' : U' ~ ~~ , , , , , , ~ ~~ ~ N M O ~ O N M tt ~ CO 1~ 00 ~ O N M V ~(O f~ 00 ~ O N M V ~ ln t~ I~ OD ~ ~\ r y U r ~~ C OO ~ I ~ ~ N N N N N N N N N N M M _ M M M, M M M M M : ~ N 1 0 N N ~ r O N N 0 R N c V O ~'^ \ r a~0 a=~ p ~ ~ ~ ~ ~ ~ ^ ~ N ~ ~: O ~ O 10 L y (O C 01 ~ I CO T p. ~ ~ ~ ~ ~~ 3~ ~~ G ~ ~ C C~ ~ ~ Q ~ U . a Q ¢ cu.n rn a _ -W- ~l' ~ Q cu'i~ ~ ' ~ • Well History File APPENDIX InioRnation of detailed nature that is not pa~ticula~iy germane to the Weli Permitting Process but is part of the history file. To improve the readability of the Wetl History file and to sirn.plify finding information, information of this naiure is accumulaied at the end of the file under APPENDIX. No special efifort has been made to chronologically organize this category of information. s ~ • ~ 1j-162.tapx sperry-Sun Drillin9 Services LIS Scan utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Oct 11 16:29:50 2007 Reel Header Service name .............LISTPE Date . ...................07/10/11 Ori in ...................5T5 Ree~ Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................sTS ~I5 writing ~ibrary. scientific Technical services Tape Header Service name .............LISTPE Date . ...................07/10/11 Origin ...................5T5 Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................5T5 ~IS writing ~ibrary. scientific Technical services Physical EOF Comment Record TAPE HEADER Kuparuk River unit west sak MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 17-162 500292336000 conocoPhillips Alaska Inc. Sperry Drilling Services 11-OCT-07 MWD RUN 2 MWD RUN 4 MWD RUN 5 706 NUMBER: w-0005034902 w-0005034902 w-0005034902 LOGGING ENGINEER: R. FRENCH B. HENNINGSE B. HENNINGSE OPERATOR WITNE55: M. THORNTON F. HERBERT F. HERBERT MWD RUN 6 ~og NUMBER: w-0005034902 LOGGING ENGINEER: B. HENNINGSE OPERATOR WITNESS: F. HERBERT # SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: lOE FNL: FS~: 1958 FEL: 2527 FWL: Page 1 ,~j-~~ =p~ ~ ~ 510~~ ~ ~ i 1j-162.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 122.00 GROUND LEVEL: 81.00 # WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 15T STRING 12.250 13.375 3820.0 2N~ STRING 8.500 9.625 10399.0 3RD STRING PRODUCTION STRING # REMARKS: l. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE IS AN OPENHOLE SIDETRACK EXITING THE 1~-162 PB2 WELLBORE AT 10550'MD/3253~TVD, WITHIN THE MWD RUN 5 INTERVAL. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,4,5,6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP). MWD RUNS 5,6 AL50 INCLUDED AT-BIT GAMMA (ABG). NO PROGRESS WAS MADE ON MWD RUN 3. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-6 REPRESENT WELL 1J-162 WITH API#: 50-029-23360-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14490~MD/3218~TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). $ File Header Service name... .......STSLIB.001 Service Sub Level Name... version -vumber...........1.0.0 Page 2 ~ 1j-162.tapx Date of ~eneration.......07/10/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPD RPS RPM FET RPX RO P $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 3785.0 3805.0 3805.0 3805.0 3805.0 3805.0 3820.5 STOP DEPTH 14456.0 14448.5 14448.5 14448.5 14448.5 14448.5 14490.0 ~ # BASELINE CURVE FOR SMIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ BIT RUN NO MERGE TOP 2 3785.0 4 7994.0 5 10401.0 6 10550.5 # REMARKS: MERGED MAIN PA55. $ MERGE BASE 7994.0 10401.0 10550.0 14490.0 # Data Format Specification Record Data Record Type... ..........0 ~ata specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. . .. .. ..... Datum specification Block sub-type...0 Name service order units size ivsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 Page 3 ~ 1j-162.tapx ~ First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3785 14490 9137.5 21411 3785 14490 RPD MwD OHMM 1.28 2000 35.083 21288 3805 14448.5 RPM MWD OHMM 4.42 2000 31.9325 21288 3805 14448.5 RPS MwD OHMM 2.88 2000 30.6387 21288 3805 14448.5 RPx Mwo OHMM 2.9 2000 26.4507 21288 3805 14448.5 FET MwD HOUR 0.08 121.52 1.63742 21288 3805 14448.5 GR MwD API 22.14 132.14 66.4828 21343 3785 14456 ROP MwD FT/H 0.06 981.13 255.382 21340 3820.5 14490 First Reading For Entire File..........3785 Last Reading For Entire File...........14490 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/11 Maximum Physical Record..65535 File Type ................LO Next File Name...........5T5LIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... Version Number. ........1.0.0 Date of Generation.......07/10/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3785.0 7963.5 RPD 3805.0 7950.0 RPM 3805.0 7950.0 RPx 3805.0 7950.0 RPS 3805.0 7950.0 FET 3805.0 7950.0 RoP 3820.5 7994.0 $ # LOG HEADER DATA DATE LOGGED: 09-JUL-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 Page 4 ~ ~ 1j-162.tapx DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7994.0 TOP LOG INTERVAL (FT): 3820.0 BOTTOM LOG INTERVAL (FT): 7994.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 77.6 MAXIMUM ANGLE: 82.1 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 77613 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER~S CASING DEPTH (FT): 3820.0 # BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 8.95 MUD VISCOSITY (S): 52.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.200 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.220 135.3 MUD FILTRATE AT MT: 2.600 72.0 MUD CAKE AT MT: 2.200 72.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format specification rtecord Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. .. ..... ~atum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 Page 5 ~ ~ 1j-162.tapx ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3785 7994 5889.5 8419 3785 7994 RPD MwD020 OHMM 7.34 2000 16.241 8291 3805 7950 RPM MwD020 OHMM 6.73 2000 15.3346 8291 3805 7950 RPS MwD020 OHMM 5.35 1746.89 13.6384 8291 3805 7950 RPx MwD020 OHMM 3.22 1293.21 11.1603 8291 3805 7950 FET MwD020 HOUR 0.11 101.2 1.02325 8291 3805 7950 GR MwD020 API 22.14 132.14 61.1613 8358 3785 7963.5 RoP MwD020 FT/H 0.06 943.37 228.861 8348 3820.5 7994 First Reading For Entire File..........3785 ~ast Reading For Entire File...........7994 File Trail~ service service version Date of Maximum Fi 1 e Tyl Next Fi ~r name... .......STSLIB.002 Sub Level Name... Number. ........1.0.0 Generation.... .07/10/11 Physical Record..65535 ~e ................LO le Name...........5T5LIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPx 7950.5 10358.0 FET 7950.5 10358.0 RPM 7950.5 10358.0 RPD 7950.5 10358.0 RP5 7950.5 10358.0 GR 7964.0 10365.5 RoP 7994.5 10401.0 $ # LOG HEADER DATA DATE LOGGED: 15-~u~-07 Page 6 i SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # # # # # # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ 1j-162.tapx BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER~S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Log~ing Direction .................Down optical log depth units...........Feet ~ata Reference Point ..............undefined Frame spacing...... ............60 .lIN ... Max frames per record .............undefined Absent value ......................-999 Depth units. . .. .. .... Datum specification Block sub-type...0 \J Insite 72.13 Memory 10401.0 7994.0 10401.0 80.4 82.8 TOOL NUMBER 132478 222163 12.250 3820.0 Fresh Water Gel 9.20 52.0 9.5 200 4.8 1.500 85.0 1.070 122.0 1.600 85.0 1.900 85.0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 Page 7 ~ ~ 1j-162.tapx RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7950.5 10401 9175.75 4902 7950.5 10401 RPD MwD040 OHMM 4.66 122.68 15.8184 4816 7950.5 10358 RPM Mw~040 OHMM 4.42 124.44 14.4247 4816 7950.5 10358 RPS MwD040 OHMM 3.94 99.11 12.8264 4816 7950.5 10358 RPx MwD040 OHMM 3.41 48.24 9.83002 4816 7950.5 10358 FET MwD040 HOUR 0.08 100.77 2.4927 4816 7950.5 10358 GR MwD040 API 22.54 122.06 75.2663 4804 7964 10365.5 RoP MwD040 FT/H 0.09 981.13 275.995 4814 7994.5 10401 First Reading For Entire File..........7950.5 ~ast Reading For Entire File...........10401 File Trail~ Service service version Date of Maximum Fi 1 e Tyl Next Fi er name... .......STSLIB.003 Sub Level Name... Number. ........1.0.0 Generation.... .07/10/11 Physical Record..65535 ~e ................LO le Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RP5 10358.5 10550.0 FET 10358.5 10550.0 RPM 10358.5 10550.0 RPx 10358.5 10550.0 RPD 10358.5 10550.0 GR 10366.0 10550.0 RoP 10401.5 10550.0 $ Page 8 ~ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # 1j-162.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ # # # # # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER~S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type... ..........0 ~ata Specification Block Type.....0 Log~ing Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 ~epth units. .. .. .. ..... Datum Specification Block sub-type...0 ~ 20-JUL-07 Insite 72 .13 Memo ry 10550.0 10401.0 10550.0 82.9 93.1 TOOL NUMBER 097054 228269 8.500 10399.0 Mineral Oil Base 8.50 59.0 .0 21000 .0 .000 .0 .000 138.2 .000 .0 .000 .0 Name Service order units Size -vsam Rep code Offset Channel DEPT FT 4 1 68 0 1 Page 9 i ~ 1j-162.tapx RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10358.5 10550 10454.3 384 10358.5 10550 RPD MWD050 OHMM 1.28 2000 417.928 384 10358.5 10550 RPM MWD050 OHMM 7.9 2000 303.768 384 10358.5 10550 RPS MwD050 OHMM 2.88 2000 292.773 384 10358.5 10550 RPx MwD050 OHMM 2.9 2000 209.557 384 10358.5 10550 FET Mw~050 HOUR 0.12 1 21.52 28.2934 384 10358.5 10550 GR Mw~050 API 25.36 90.59 62.9319 369 10366 10550 RoP MWD050 FT/H 10.89 518.4 284.053 298 10401.5 10550 First Reading For Entire File..........10358.5 ~ast Reading For Entire File...........10550 File Trail~ Service Service version Date of Maximum Fi 1 e Tyl Next Fi er name... .......STSLIB.004 Sub Level Name... Number. ........1.0.0 Generation.... .07/10/11 Physical Record..65535 ~e ................LO le Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/11 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUIV NUMBER: 6 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE RPM ROP RPX RPS RPD START DEPTH 10550.5 10550.5 10550.5 10550.5 10550.5 STOP DEPTH 14448.5 14490.0 14448.5 14448.5 14448.5 Page 10 ~ ~ 1j-162.tapx GR 10550.5 14456.0 FET 10550.5 14448.5 $ # LO G HEADER DATA DATE LOGGED: 22-JUL-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 14490.0 TOP LOG INTERVAL (FT): 10550.0 BOTTOM LOG INTERVAL (FT): 14490.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.3 MAXIMUM ANGLE: 93.5 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 097054 EWR4 ELECTROMAG. RESIS. 4 228269 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 10399.0 # BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (s): 59.0 MUD PH: .O MUD CHLORIDES (PPM): 22000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 138.2 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~ing Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... ~atum specification Block sub-type...0 Page 11 ~ 1j-162.tapx `J Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10550.5 14490 12520.3 7880 10550.5 14490 RPD MwD060 OHMM 8.22 2000 48.1629 7797 10550.5 14448.5 RPM Mw~060 OHMM 7.37 2000 47.0082 7797 10550.5 14448.5 RP5 MwD060 OHMM 7.06 2000 46.8082 7797 10550.5 14448.5 RPx MwD060 OHMM 6.98 2000 43.958 7797 10550.5 14448.5 FET MWD060 HOUR 0.12 5.23 0.449411 7797 10550.5 14448.5 GR MwD060 API 35.28 107.09 66.9427 7812 10550.5 14456 RoP Mw~060 FTjN 1.34 935.65 269.8 7880 10550.5 14490 First Reading For Entire File..........10550.5 Last Reading For Entire File...........14490 File Trailer Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of ~eneration.......07/10/11 Maximum Physical Record..65535 File Ty e ................LO Next Fi~e Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/10/11 origin ...................sTs Tape Name . .... .........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Reel Trailer Service name .............LISTPE Date . ...................07/10/11 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing ~ibrary. scientific Technical services ~ibrary. scientific Technical services Page 12 i ~ 1j-162.tapx Physical EOF Physical EOF End Of LIS File Page 13 e 4 . 1j-162pb2.tapx Sperry-Sun Drillin9 Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Oct 12 13:45:52 2007 C~ Reel Header service name .............LISTPE Date . ...................07/10/12 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................5T5 ~zs writing ~ibrary. scientific Technical services Tape Header Service name .............LISTPE Date . ...................07/10/12 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Physical EoF Comment Record TAPE HEADER Kuparuk River Unit west Sak MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MWD RUN 2 JOB NUMBER: w-0005034902 LOGGING ENGINEER: R. FRENCH OPERATOR WITNESS: M. THORNTON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD ~ibrary. scientific Technical services 1J-162 PB2 500292336071 ConocoPhillips Alaska znc. Sperry ~rilling Services 12-OCT-07 MWD RUN 4 MWD RUN 5 w-0005034902 w-0005034902 B. HENNINGSE B. HENNINGSE F. HERBERT F. HERBERT 35 11N lOE 1958 2527 122.00 81.00 Page 1 ~p~ -O Z50 ~ d S(O~~- • 15T STRING 2ND STRING 3RD STRING PRODUCTION # REMARKS: File Header OPEN HOLE BIT SIZE (IN) 12.250 8.500 STRING 1j-162pb2.tapx CASING DRILLERS SIZE (IN) DEPTH (FT) 13.375 3820.0 9.625 10399.0 L~ 1. ALL DEPTHS ARE MEASURED DEPTHS UNLE55 OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE IS AN OPENHOLE SIDETRACK EXITING THE 1J-162 PBl WELLBORE AT 3820~MD/2207'TVD. MWD RUN 1, WHICH WAS DIRECTIONAL ONLY, COMPRISED 1J-162 PBl. THIS RUN TD'D AT THE 13 3/8~~ CASING POINT. THE CASING STUCK 168~ OFF BOTTOM, NECESSITATING THE SUBSEQUENT OPEN-HOLE SIDETRACK. NO DATA ARE PRESENTED FOR MWD RUN 1/1J-162 PB1. 4. MWD RUNS 2,4,5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP). MWD RUN 5 ALSO INCLUDED AT-BIT GAMMA (ABG). NO PROGRESS WAS MADE ON MWD RUN 3. 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-5 REPRESENT WELL 1J-162 PB2 WITH API#: 50-029-23360-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11035~MD/3249'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED, SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). $ Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/10/12 Maximum Physical Record..65535 Page 2 + ~ ~ 1j-162pb2.tapx File Type.. ............LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD ~epth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3785.0 11001.5 FET 3805.0 10993.5 RPD 3805.0 10993.5 RPS 3805.0 10993.5 RPM 3805.0 10993.5 rtPx 3805.0 10993.5 ROP 3820.5 11035.0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO MERGE TOP 2 3785.0 4 7994.0 5 10401.0 # REMARKS: MERGED MAIN PASS. $ MERGE BASE 7994.0 10401.0 11035.0 # Data Format Specification Record Data Record Type... ..........0 Data Specif~cation Block Type.....0 Log~ing Direction .................DOwn optical log depth units...........Feet ~ata rteference Point ..............undefined Frame Spacing....... ............60 .1zN Max frames per record .............undefined Absent value ......................-999 Depth Units .. .. .. ..... ~atum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading Page 3 ~ 1j-162pb2.tapx • DEPT FT 3785 11035 7410 14501 3785 11035 RPD MwD OHMM 1.28 2000 29.5213 14378 3805 10993.5 RPM MwD OHMM 4.42 2000 24.8258 14378 3805 10993.5 RPS MwD OHMM 2.88 2000 20.7735 14378 3805 10993.5 RPx MwD OHMM 2.9 2000 15.9611 14378 3805 10993.5 FET MwD HOUR 0.08 121.52 2.20175 14378 3805 10993.5 GR MwD API 22.14 132.14 67.6176 14434 3785 11001.5 ROP MwD FT/H 0.06 981.13 245.443 14430 3820.5 11035 First Reading For Entire File..........3785 ~ast Reading For Entire File...........11035 File Trailer Service name... .......STSLIB.001 SerViCe Sub LeVel~Ndme... version Number. ........1.0.0 Date of Generation.......07/10/12 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3785.0 7963.5 FET 3805.0 7950.0 rtPx 3805.0 7950.0 RPS 3805.0 7950.0 RPM 3805.0 7950.0 RPD 3805.0 7950.0 ROP 3820.5 7994.0 $ # LOG HEADER DATA DATE LOGGED: 09-JUL-07 SOFTWARE SURFACE SOFTWA RE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7994.0 TOP LOG INTERVAL (FT): 3820.0 Page 4 • ! 1j-162pb2.tapx BOTTOM LOG INTERVAL (FT): 7794.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 77.6 MAXIMUM ANGLE: 82.1 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 77613 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 3820.0 # BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 8.95 MUD VISCOSITY (S): 52.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.200 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.220 135.3 MUD FILTRATE AT MT: 2.600 72.0 MUD CAKE AT MT: 2.200 72.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~ing Direction .................DOwn Optical log depth units...........Feet ~ata rteference Point ..............undefined Frame Spacing ........ ............60 .lziv Max frames per record .............undefined ,4bsent value ......................-999 Depth Units. . .. .. ..... oatum specification Block sub-type...0 Name service order units size Nsam rtep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 Page 5 ~ ~ 1j-162pb2.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3785 7994 5889.5 8419 3785 7994 RPD MWD020 OHMM 7.34 2000 16.241 8291 3805 7950 RPM MWD020 OHMM 6.73 2000 15.3346 8291 3805 7950 RPS MWD020 OHMM 5.35 1746.89 13.6384 8291 3805 7950 RPx MWD020 OHMM 3.22 1293.21 11.1603 8291 3805 7950 FET Niw~020 HOUR 0.11 101.2 1.02325 8291 3805 7950 GR MWD020 API 22.14 132.14 61.1613 8358 3785 7963.5 RoP Mw~020 FT/H 0.06 943.37 228.861 8348 3820.5 7994 First Reading For Entire File.,........3785 ~ast Reading For Entire File...........7994 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/10/12 Maximum Physical Record..65535 File TyL~ e ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.002 Comment rtecord FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 7950.5 10358.0 RPS 7950.5 10358.0 RPX 7950.5 10358.0 RPM 7950.5 10358.0 RPD 7950.5 10358.0 GR 7964.0 10365.5 ROP 7994.5 10401.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWA RE VERSION: DOWNHOLE SOFTWARE VERSION: Page 6 15-7U~-07 Insite 72.13 . DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # # # # # # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA EWR4 ELECTROMAG. $ ~ 1j-162pb2.tapx Memory 10401.0 7994.0 10401.0 80.4 82.8 TOOL NUMBER RAY 132478 RESIS. 4 222163 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 3820.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 52.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.500 85.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.070 122.0 MUD FILTRATE AT MT: 1.600 85.0 MUD CAKE AT MT: 1.900 85.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # ~ata Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~ing Direction .................DOwn optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined ,4bsent value ......................-999 Depth Units. .. .. .. ..... ~atum specification Block sub-type...0 Name Service order units size Nsam rtep code offset channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MwD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 Page 7 • ~ 1j-162pb2.tapx ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7950.5 10401 9175.75 4902 7950.5 10401 RPD MWD040 OHMM 4.66 122.68 15.8184 4816 7950.5 10358 RPM MWD040 OHMM 4.42 124.44 14.4247 4816 7950.5 10358 RPS MWD040 OHMM 3.94 99.11 12.8264 4816 7950.5 10358 RPx MWD040 OHMM 3.41 48.24 9.83002 4816 7950.5 10358 FET Mw~040 HOUR 0.08 100.77 2.4927 4816 7950.5 10358 GR MwD040 API 22.54 122.06 75.2663 4804 7964 10365.5 ROP MwD040 FT/H 0.09 981.13 275.995 4814 7994.5 10401 First Reading For Entire File..........7950.5 ~ast Reading For Entire File...........10401 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/12 Maximum Physical Record..65535 File Ty e ................LO Next Fi~e Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 10358.5 10993.5 RPx 10358.5 10993.5 RPD 10358.5 10993.5 FET 10358.5 10993.5 RPS 10358.5 10993.5 GR 10366.0 11001.5 ROP 10401.5 11035.0 $ # LOG HEADER DATA DATE LOGGED: 20-JUL-07 Page 8 ! SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # Insite 72.13 Memory 11035.0 10401.0 11035.0 82.9 93.1 1j-162pb2.tapx • TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 097054 EWR4 ELECTROMAG. RESIS. 4 228269 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 10399.0 # BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 59.0 MUD PH: ,Q MUD CHLORIDES (PPM): 21000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 138.2 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # ~ata Format specification rtecord Data Record Type... ..........0 ~ata Specification Block Type.....0 Log~ing Direction .................DOwn optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined ,4bsent value ......................-999 Depth units. . .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 Page 9 ~ ~ 1j-162pb2.tapx RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10358.5 11035 10696.8 1354 10358.5 11035 RPD MwD050 OHMM 1.28 2000 168.073 1271 10358.5 10993.5 RPM MwD050 OHMM 6.88 2000 126.15 1271 10358.5 10993.5 ttPS Mw~050 OHMM 2.88 2000 97.4299 1271 10358.5 10993.5 RPx MwD050 OHMM 2.9 2000 70.5095 1271 10358.5 10993.5 FET MwD050 HOUR 0.12 121.52 8.78694 1271 10358.5 10993.5 GR MwD050 API 25.36 123.17 81.1542 1272 10366 11001.5 RoP Mw~050 FT/H 10.89 518.4 238.625 1268 10401.5 11035 First Reading For Entire File..........10358.5 ~ast Reading For Entire File...........11035 File Trailer Service name... .......STSLIB.004 ServiCe Sub Level.Ndme... version ivumber. ........1.0.0 ~ate of Generation.......07/10/12 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/10/12 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......OZ Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Reel Trailer Service name .............LISTPE Date . ...................07/10/12 Ori 9in ...................5T5 Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comment5 .................STS LIS Writing Physical EOF ~ibrary. scientific Technical services ~ibrary. Scientific Technical Services Physical EOF Page 10 End Of LIS File ~J 1j-162pb2.tapx Page 11 ~