The URL can be used to link to this page

Home My WebLink About206-180Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 V-205 206180 500292333800 2 12/31/2023 3URSHUW\'HVLJQDWLRQ/HDVH1XPEHU 2SHUDWLRQV 3HUIRUPHG 2SHUDWRU1DPH $GGUHVV :HOO&ODVV%HIRUH:RUN3HUPLWWR'ULOO1XPEHU $3,1XPEHU :HOO1DPHDQG1XPEHU /RJV/LVWORJVDQGVXEPLWHOHFWURQLFGDWDSHU$$&)LHOG3RROV $EDQGRQ 6XVSHQG 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 3HUIRUDWH 3OXJ3HUIRUDWLRQV 5HHQWHU6XVS:HOO 2WKHU6WLPXODWH )UDFWXUH6WLPXODWH $OWHU&DVLQJ 3XOO7XELQJ 5HSDLU:HOO 2WKHU &KDQJH$SSURYHG3URJUDP 2SHUDWLRQVVKXWGRZQ 3UHVHQW:HOO&RQGLWLRQ6XPPDU\ &DVLQJ /HQJWK 6L]H 0' 79' %XUVW &ROODSVH ([SORUDWRU\ 6WUDWLJUDSKLF 'HYHORSPHQW 6HUYLFH $WWDFKPHQWVUHTXLUHGSHU$$& :HOO6WDWXVDIWHUZRUN ,KHUHE\FHUWLI\WKDWWKHIRUHJRLQJLVWUXHDQGFRUUHFWWRWKHEHVWRIP\NQRZOHGJH 2,/ *$6 :,1- :$* *,1- :'63/ *6725 6XVSHQGHG 63/8* $XWKRUL]HG1DPHDQG 'LJLWDO6LJQDWXUHZLWK'DWH $XWKRUL]HG7LWOH &RQWDFW1DPH &RQWDFW(PDLO &RQWDFW3KRQH 3%89 'XPS%DLO&HPHQW +LOFRUS1RUWK6ORSH//& &HQWHUSRLQW'U6XLWH$QFKRUDJH$. &RQGXFWRU 6XUIDFH ,QWHUPHGLDWH 3URGXFWLRQ /LQHU &U 6WUXFWXUDO %DNHU3UHPLHU3DFNHU 6WDQ*ROLV 6U$UHD2SHUDWLRQV0DQDJHU %URGLH:DJHV 'DYLG:DJHV#KLOFRUSFRP 358'+2(%$<6&+5$'(5%/8))2,/25,21322/ 7RWDO'HSWK (IIHFWLYH'HSWK PHDVXUHG WUXHYHUWLFDO IHHW IHHW IHHW IHHW PHDVXUHG WUXHYHUWLFDO PHDVXUHG PHDVXUHG IHHW IHHW IHHW IHHW PHDVXUHG WUXHYHUWLFDO 3OXJV -XQN 3DFNHU 0HDVXUHGGHSWK 7UXH9HUWLFDOGHSWK IHHW IHHW 3HUIRUDWLRQGHSWK 7XELQJVL]HJUDGHPHDVXUHGDQGWUXHYHUWLFDOGHSWK 3DFNHUVDQG6669W\SHPHDVXUHGDQGWUXHYHUWLFDOGHSWK 6WLPXODWLRQRUFHPHQWVTXHH]HVXPPDU\ ,QWHUYDOVWUHDWHGPHDVXUHG 7UHDWPHQWGHVFULSWLRQVLQFOXGLQJYROXPHVXVHGDQGILQDO 5HSUHVHQWDWLYH'DLO\$YHUDJH3URGXFWLRQRU,QMHFWLRQ'DWD 2LO%EO *DV0FI :DWHU%EO &DVLQJ3UHVVXUH 7XELQJ3UHVVXUH 3ULRUWRZHOORSHUDWLRQ 6XEVHTXHQWWRRSHUDWLRQ :HOO&ODVVDIWHUZRUN ([SORUDWRU\ 'HYHORSPHQW 6HUYLFH 6WUDWLJUDSKLF'DLO\5HSRUWRI:HOO2SHUDWLRQV &RSLHVRI/RJVDQG6XUYH\V5XQ (OHFWURQLF)UDFWXUH6WLPXODWLRQ'DWD 6XQGU\1XPEHURU1$LI&2([HPSW $'/ 1R6669,QVWDOOHG LQ7XELQJ 'XPS%DLOJDOORQVSSJ1HR&HPHQWRQWRSRI,%3 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 5(32572)681'5<:(//23(5$7,216 6U3HW(QJ 6U3HW*HR )RUP5HYLVHG6XEPLW:LWKLQGD\VRU2SHUDWLRQV 6U5HV(QJ By Anne Prysunka at 8:52 am, Oct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y Samantha Carlisle at 1:04 pm, Jun 08, 2022 'LJLWDOO\VLJQHGE\6WDQ*ROLV '1FQ 6WDQ*ROLV RX 8VHUV 'DWH 6WDQ*ROLV '65 ; 0*5-81'/% GWV Jeremy Price Digitally signed by Jeremy Price Date: 2022.06.24 13:33:21 -08'00' RBDMS JSB 063022 WƌŽĚƵĐĞKŽŶůǇ sͲϮϬϱ ͬsͲϮϬϱ>ϭ Wd͗ϮϬϲͲϭϴϬ ͬϮϬϲͲϭϴϭ tĞůůEĂŵĞ͗sͲϮϬϱ ͬsͲϮϬϱ>ϭ W/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϯϯϴϬͲϬϬ ;ϲϬͿ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗KƉĞƌĂďůĞ :d WƌŽĚƵĐĞƌ ZŝŐ͗^ůŝĐŬůŝŶĞͬŽŝů ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗:ƵŶĞ ϮϬϮϮ ƐƚŝŵĂƚĞĚƵƌĂƚŝŽŶ͗ϱĚĂǇƐ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ďďŝĞĂƌŬĞƌ &ŝƌƐƚĂůů ŶŐŝŶĞĞƌ͗ƌŽĚŝĞtĂŐĞƐ ;ϳϭϯͿϯϴϬͲϵϴϯϲ;ĐͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗tǇĂƚƚZŝǀĂƌĚ ;ϱϬϵͿϲϳϬͲϴϬϬϭ;ĐͿ &EƵŵďĞƌ͗ϮϮϱͲϬϮϭϬϵ ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗ ϭϯϴϱ ƉƐŝΛ ϰϮϱϬ͛ ds ϲ͘ϯ WW'ͮ dĂŬĞŶ ϴͬϮϬϭϴ DĂǆŝŵƵŵǆƉĞĐƚĞĚ,W͗ϮϬϬϬ ƉƐŝΛ ϰϰϬϬ͛ds DĂǆ͘ŶƚŝĐŝƉĂƚĞĚ^ƵƌĨĂĐĞWƌĞƐƐƵƌĞ͗ϭϱϲϬ ƉƐŝ ;ĂƐĞĚŽŶϬ͘ϭƉƐŝͬĨƚ͘ŐĂƐŐƌĂĚŝĞŶƚͿ >ĂƐƚ^/t,W͗ϭϱϱ ƉƐŝ DŝŶ/͗Ϯ͘ϱϬ͟ŵĂǆĚƌŝĨƚƚŚƌŽƵŐŚ >ϮũƵŶĐƚŝŽŶ ŶŐůĞ͗ϳϬĚĞŐΛ ϱϰϮϱ͛ KďũĞĐƚŝǀĞ͗ /ƐŽůĂƚĞKůĂƚĞƌĂůƚŽĨůŽǁ ĂŶĚWKW sŽůƵŵĞƐ͗ ƚŽƉDďŽƚD^ŝǌĞ /ďďůͬĨƚ Ĩƚ ǀŽů͕ďďůƐ ƚƵďƚŽ>Ϯ ǁŝŶĚŽǁ Ϭ ϱϬϭϯ ϰͲϭͬϮΗϭϮ͘ϲη ϯ͘ϵϱϴ Ϭ͘ϬϭϱϮ ϱϬϭϯ ϳϲ͘Ϯ ƚƵďƚŽ>ϭǁŝŶĚŽǁ ϱϬϭϯ ϱϭϱϭ ϰͲϭͬϮΗϭϮ͘ϲη ϯ͘ϵϱϴ Ϭ͘ϬϭϱϮ ϭϯϴ Ϯ͘ϭ ƚƵďƚŽŵĂŝŶďŽƌĞ >dW ϱϭϱϭ ϱϮϮϴ ϰͲϭͬϮΗϭϮ͘ϲη ϯ͘ϵϱϴ Ϭ͘ϬϭϱϮ ϳϳ ϭ͘Ϯ ϳϵ͘ϱ >ŝŶĞƌƐ >Ϯ ϱϬϭϯ ϭϭϯϰϲ ϰͲϭͬϮΗϭϮ͘ϲη ϯ͘ϵϱϴ Ϭ͘Ϭϯϵϴ ϲϯϯϯ ϵϲ͘ϯ >ϭ ϱϭϱϭ ϭϭϯϰϰ ϰͲϭͬϮΗϭϮ͘ϲη ϯ͘ϵϱϴ Ϭ͘Ϭϯϵϴ ϲϭϵϯ ϵϰ͘ϭ ŵĂŝŶďŽƌĞ ϱϮϮϴ ϵϲϮϱ ϰͲϭͬϮΗϭϮ͘ϲη ϯ͘ϵϱϴ Ϭ͘Ϭϯϵϴ ϰϯϵϳ ϲϲ͘ϴ ;ϲ͘ϳϱΗŚŽůĞͲϰ͘ϱΗůŝŶĞƌĚŝƐƉůͿ Ϯϱϳ͘Ϯ dŽƚĂůƚƵďнůŝŶĞƌƐ ϯϯϲ͘ϳ ƌŝĞĨtĞůů^ƵŵŵĂƌǇ͗ sͲϮϬϱŝƐĂƚƌŝͲůĂƚĞƌĂůƉƌŽĚƵĐĞƌĐŽŵƉůĞƚĞĚŝŶϮͬϬϳǁŝƚŚƚŚƌĞĞůĂƚĞƌĂůƐƚĂƌŐĞƚŝŶŐƚŚĞ^ĐŚƌĂĚĞƌůƵĨĨƌĞƐĞƌǀŽŝƌƐĂŶĚƐ͘ sͲϮϬϱĚĞĐůŝŶĞĚǀĞƌǇƌĂƉŝĚůǇǁŚĞŶŝŶŝƚŝĂůůǇK>ĂŶĚŚĂƐƉƌŽĚƵĐĞĚĂƚĂůŽǁƌĂƚĞŽĨΕϱϬϬKWĨŽƌŵŽƐƚŽĨŝƚƐůŝĨĞ Ͳ ǁĞůůďĞůŽǁĞǆƉĞĐƚĞĚƌĂƚĞƐ͘/ƚŚĂƐďĞĞŶƐƵƐƉĞĐƚĞĚĨŽƌƐŽŵĞƚŝŵĞƚŚĂƚŽŶĞŽƌŵŽƌĞŽĨƚŚĞůĂƚĞƌĂůƐŝƐŶŽƚƉƌŽĚƵĐŝŶŐ͘ x tĞůůƉŽƉƉĞĚĂƚϯϬϬϬďŽƉĚĂŶĚƋƵŝĐŬůǇĨĞůůŽĨĨƚŽΕϭϬϬϬ ďŽƉĚ o WůĂŐƵĞĚǁŝƚŚŚǇĚƌĂƚĞŝƐƐƵĞƐǁŚŽůĞůŝĨĞ͕ůŽƚƐŽĨ,KdƐ x Žŝů ϱͬϮϬϬϴ ʹ ƐŚĂůůŽǁŝĐĞƚŚĂǁ͕ƚĂŐŐĞĚƌŝŐŚƚĂƚĂŶĚďĞůŽǁ>ϭǁŝŶĚŽǁ͕ǁŝůůďĞĨƵƚƵƌĞƉƌŽďůĞŵĂƌĞĂ͕ŐŽƚ ƉĂƐƚĂŶĚĚƌŝĨƚĞĚŵŽƚŚĞƌďŽƌĞƚŽϵϮϱϯ͛ƚĂŐ͘ZĂŶWWZK&ƐŚŽǁŝŶŐϵϬйK͕ϭϬйKďĂ;tĂŐĞƐŝŶƚĞƌƉƌĞƚĂƚŝŽŶͿ͘ o KŶůǇŵŽƚŚĞƌďŽƌĞĚƌŝĨƚĞĚ x Žŝů ϭϬͬϮϬϬϴ ʹ ƐŚĂůůŽǁŝĐĞƚŚĂǁƚŚĞŶĐŽŶƚƚŽŵŽƚŚĞƌďŽƌĞ&K͕ƚƌŽƵďůĞĂƚ>ϭĂŐĂŝŶ͕ ͬK,ĂŶĚ &KƚŽ ϱϮϬϬ͛ƚŚĞŶǁĞůůƋƵŝƚĨůŽǁŝŶŐ͘ ƚƚĞŵƉƚƚŽD>dŝŶƚŽKĂŶĚŝŶŶĞƌƌĞĞůǀĂůǀĞƐƚĂƌƚĞĚůĞĂŬŝŶŐ͕D>dĂŶĚ&K ŝŶƚŽK ĂŶĚĚƌǇĚƌŝĨƚƚŽϵϵϱϬ͛͘&KŚĞĞůƐĞĐƚŝŽŶ͕ĚĞƐƉŝƚĞĚƌǇĚƌŝĨƚ͕ǁĞǁĞƌĞŐĞƚƚŝŶŐƐŽůŝĚƐďĂĐŬĚƵƌŝŶŐ &K͘:Žď^ĨŽƌŽƚŚĞƌĐƌŝƚŝĐĂůǁĞůů͘D>dŝŶƚŽKĂŶĚ&KƚŽΛϭϬ͕Ϯϯϴ͛ƚŚĞŶƉƌŽďůĞŵƐĂƚ'ϮĂŶĚǁĞůůŚĂĚ ƚŽďĞƐŚƵƚŝŶ͘ĨƚĞƌ'Ϯ^͕Z/,ĂŶĚĂƚƚĞŵƉƚŝŶƚŽKďĂ ;ǁĂƐĂďůĞƚŽǁŽƌŬĨƌĞĞůǇĂƌŽƵŶĚϱϭϳϬ͛>ϭ ũƵŶĐƚŝŽŶ ǁŝƚŚŶŽƚĂŐƐͬŽǀĞƌƉƵůůƐͿ ǁŝƚŚŶŽůƵĐŬƐŽǁĞŶƚĂŚĞĂĚƚŽǁĂƌĚƐŵŽƚŚĞƌďŽƌĞ;KĚͿ͕ŵĂĚĞŝƚƚŽϱϰϲϬ͛ƚŝůD>d ĨŝůƚĞƌƐƚĂƌƚĞĚƉůƵŐŐŝŶŐ͘WKK,ĨŽƌE^ZΘZƚŽŽů͘tŚĞŶZ/,ƚŚĞďƌŝĚŐĞǁĂƐŐŽŶĞĂŶĚĚƌǇĚƌŝĨƚĞĚƚŽKĚd͘ '/% WƌŽĚƵĐĞKŽŶůǇ sͲϮϬϱ ͬsͲϮϬϱ>ϭ Wd͗ϮϬϲͲϭϴϬ ͬϮϬϲͲϭϴϭ dƌŝĞĚƚŽZΘZŝŶƚŽKďĂǁŝƚŚŶŽůƵĐŬ͘WK,͕ƐĞƚKďĂ ĚŝǀĞƌƚĞƌ͕ĂƚƚĞŵƉƚƚŽŐĞƚŝŶǁŝƚŚ Ϯ͘ϱ͟:^EďƵƚŚĂĚŵĂƌŬƐ ŽŶĞŶĚ͕ǁĞŶƚǁŝƚŚϯ͟ŶŽǌǌůĞĂŶĚǁĂƐĂďůĞƚŽŐĞƚŝŶǁŚŝůĞƉƵŵƉŝŶŐ͘&KKĨŽƌϯĚĂǇƐ͕ƉƵůůĚŝǀĞƌƚĞƌ͕ ZDK o K&KͬƌŝĨƚĞĚƚŽϭϬ͕Ϯϯϴ ;ϭϭϬϬ͛ƐŚŽƌƚͿ o KďĂ&KƚŽϭϬ͕ϯϬϬ͛;ϭϬϬϬ͛ƐŚŽƌƚͿ ʹ ƉƌŽĚƵĐƚŝŽŶŐĂŝŶŵŽƐƚůǇĨƌŽŵKďĂ&K͕ŵŽƐƚǁŽƌŬĚŽŶĞŚĞƌĞ o KĚ&KƚŽd x ^ůŝĐŬůŝŶĞϭϭͬϮϬϬϴ ʹ ͬKǁĂƐŚĞĚŽƵƚŽƌŝĨŝĐĞ x ϭϴ,KdƐďĞƚǁĞĞŶůĂƐƚĐŽŝůĂŶĚƚŚŝƐŽŶĞ͕ƚƵďŝŶŐƉƌĞƐƐƵƌĞƵƉŽŶĐĞ x ŽŝůϭϬͬϮϬϬϵ ʹ Z/,&K,͕ĐĂŶ͛ƚŐĞƚƉĂƐƚ>ϭ͕ ηϮ ĂŐĂŝŶ͕ ηϯ ĂŐĂŝŶ͕ ηϰ ĂŐĂŝŶ͕ ηϱ ĂŐĂŝŶ͕ƐĂĨĞƚǇƐƚĂŶĚĚŽǁŶ ĨŽƌĨŝĞůĚ͕ηϲ&K,ƚĂŐƵƉĂŐĂŝŶ͕ŐŽƵŐĞƐĞĞŶŽŶƐŝĚĞŽĨŶŽǌǌůĞ͕,ηϳƚĂŐŐĞĚƵƉĂŐĂŝŶ͕ηϴƚĂŐŐĞĚĂŐĂŝŶ͕ ƉƵŵƉĞĚĂĐŝĚ͕ƚĂŐŐĞĚĂŐĂŝŶ͕ŵŽƌĞĂĐŝĚ͕ƚĂŐŐĞĚĂŐĂŝŶ͕ηϵ ǀĞŶƚƵƌŝƌƵŶǁŝƚŚŝŶĚĞǆŝŶŐƚŽŽů͕ƚĂŐŐĞĚƵƉĂŐĂŝŶ͕ ĐĂŵĞďĂĐŬǁŝƚŚϭͬϴĐƵƉƉĞĂƐŝǌĞĚƌŽĐŬƐ;ƐŚƌŽƵĚǁĂƐ>E͕ŶŽŐŽƵŐĞƐͿ͗ ĞĐŝƐŝŽŶŵĂĚĞƚŽƌƵŶĐĂŵĞƌĂ͕ƚǁŽƚƌŝĞƐĂŶĚĂůůĚĂǇƐƉĞŶƚƌƵŶŶŝŶŐĐĂŵĞƌĂ͗ ƉƉĞĂƌƐƐŽŵĞƚŚŝŶŐŵŽǀĞĚŝŶĂƚƚŽƉŽĨ>D͕ƚŚŝƐĐŽƵůĚďĞϱͲϭͬϮ͟ǆϰͲϭͬϮ͟yKƚŚŽƵŐŚ͘dŚĞŝƐƐƵĞŝƐƚŚĞKďĂ ŝƐǀĞƌǇůŝŬĞůǇƚŚĞŚŝŐŚĞƐƚW/͕ƐŽǁŚĞŶǁĞƉƵŵƉŝŶƚŽƚŚĞǁĞůůĂƚƐƵƌĨĂĐĞ͕ŵŽƐƚŽĨƚŚĞŝŶũĞĐƚĞĚĨůƵŝĚǁĂŶƚƐ ƚŽŐŽŝŶƚŽƚŚĞKďĂ͕ǁŚŝĐŚŵĞĂŶƐǁĞŶĞǀĞƌŐŽƚĐůĞĂŶĨůƵŝĚĨŽƌŽƵƌĐĂŵĞƌĂƚŽǁŽƌŬŝŶďĞůŽǁƚŚĞďŽƚƚŽŵŽĨ >ϭ>DǁŝŶĚŽǁ͘ >ŽǁĞƐƚĚĞƉƚŚĂĐŚŝĞǀĞĚǁĂƐ ϱϭϲϳ͛;ƚŝĞĚŝŶƚŽϱͲϭͬϮ͟ǆϰͲϭͬϮ͟yKĂƚƚŽƉŽĨ>DͿ ĞĐŝƐŝŽŶŵĂĚĞƚŽŵŝůů͕ŵĂĚĞŝƚƚŽϱϭϳϬ͛dD;ůŝŬĞůǇƐĂŵĞƐƉŽƚĐĂŵĞƌĂŵĂĚĞŝƚƚŽͿ͘DŝůůǁĂƐϯ͘ϱϲ͟K ďŝƚĂŶĚϯ͘ϭϮ͟ĂďŽǀĞ͕ŶŽĐĞŶƚƌĂůŝǌĞƌƐ͘͞DŝůůŚĞĂĚĂŶĚƐŚĂŶŬŚĂǀĞ ϭͬϭϲ͟ĐŝƌĐƵŵĨĞƌĞŶƚŝĂůŐƌŽŽǀĞƐƚŽƉƚŽ ďŽƚƚŽŵ͗͟ WƌŽĚƵĐĞKŽŶůǇ sͲϮϬϱ ͬsͲϮϬϱ>ϭ Wd͗ϮϬϲͲϭϴϬ ͬϮϬϲͲϭϴϭ Z/,ǁŝƚŚ ƐĂŵĞŵŝůůŝŶŐĂƐƐĞŵďůǇ͕ŵŝůůĞĚƚŽϱϭϳϱ͕͛ƐƚĂůůĞĚϴƚŝŵĞƐ͕ďƌŽŬĞŽĨĨŵŝůůĂŶĚŽƵƚƉƵƚƐŚĂĨƚ͗ o ŝĚŶŽƚĞŶƚĞƌĂƐŝŶŐůĞůĂƚĞƌĂů x ^ůŝĐŬůŝŶĞϭϭͬϮϬϬϵ ʹ ƚƌŝĞĚƚŽďĂŝƚ͕ŶŽůƵĐŬ͘ϭ Ɛƚ ƚĂŐ͗ϱϭϯϱ͛^>D͕ϮŶĚ ǁͬϯ͘ϱ͟ĐĞŶƚĂŶĚϯ͟>/ϱϭϰϭ͛^>D͕ďĂŝůĞĚ ƚŽϱϭϱϱ͛^>D x ^ůŝĐŬůŝŶĞ ϯͬϮϬϭϬ ʹ Θ&ƚŽϰϵϲϯ͛ x ^ůŝĐŬůŝŶĞϯͬϮϬϭϭ ʹ Θ&ƚŽϰϵϵϬ͛ x ^ůŝĐŬůŝŶĞϴͬϮϬϭϭ ʹ ͬKĂůů'>sƐ x ^ůŝĐŬůŝŶĞϮͬϮϬϭϮ ʹ ƐĞƚĂŬĞƌ/ƐŽ^ůĞĞǀĞŝŶ>Ϯ ǁͬ<ƉĂĐŬĞƌŽŶƚŽƉ ĂŶĚƉůƵŐŝŶďŽƚƚŽŵ o KŶůǇKĂďůĞƚŽĨůŽǁĂƚƚŚŝƐƚŝŵĞ x ^ůŝĐŬůŝŶĞϮͬϮϬϭϯ ʹ /ŶƐƚĂůůĞĚĨŝƌƐƚũĞƚƉƵŵƉ x >ŽƚƐŽĨΘ&ƐĂŶĚũĞƚƉƵŵƉĐŚĂŶŐĞŽƵƚƐ sͲϮϯϰ ƵƉĚĂƚĞ͗ǁŚŝůĞĚƌŝůůŝŶŐƚŚĞůĂƚĞƌĂůŽĨsͲϮϯϰ͕ƚŚĞ>ϭůĂƚĞƌĂůŽĨsͲϮϬϱǁĂƐŝŶƚĞƌĐĞƉƚĞĚ͘WƌŝŽƌƚŽƌĞƐƵŵŝŶŐsͲϮϯϰ ůĂƚĞƌĂů͕ ϰϱďďůƐ ŽĨĐĞŵĞŶƚǁĂƐƉƵŵƉĞĚŝŶsͲϮϯϰWϭƚŽWΘƚŚĞ>ϭůĂƚĞƌĂůŽĨsͲϮϬϱ͘dŚŝƐĐĞŵĞŶƚƉůƵŐĂůŽŶŐǁŝƚŚ ƚŚĞĨŝƐŚĂŶĚĨŝůůŽǀĞƌƚŚĞ>ϭũƵŶĐƚŝŽŶŝƐ ƚŚĞWΘĨŽƌďŽƚŚ>ϭĂŶ ĚƚŚĞŵŽƚŚĞƌďŽƌĞŽĨsͲϮϬϱ͘ sĂƌŝĂŶĐĞZĞƋƵĞƐƚ͗ϮϬϮϱ͘ϭϭϮ;ĐͿ;ϭͿ;Ϳ͗ZĞƋƵĞƐƚƚŽƐĞƚŝƐŽůĂƚŝŶŐ ƉůƵŐ ĂŶĚĚƵŵƉďĂŝůĞĚĐĞŵĞŶƚĂďŽǀĞ>ϭ ũƵŶĐƚŝŽŶďƵƚǁŝƚŚŝŶƚŚĞ^ŚƌĂĚĞƌŝŶƚĞƌǀĂů͘,ŝůĐŽƌƉ͛ƐĂƐƐĞƐƐŵĞŶƚŽĨƚŚĞĨŝƐŚŝŶƚŚĞũƵŶĐƚŝŽŶĂůůŽǁŝŶŐĂĐĐĞƐƐƚŽƚŚĞ ŵŽƚŚĞƌďŽƌĞĂŶĚ>ϭŝƐƚŚĂƚǁĞǁŽƵůĚďĞƵŶĂďůĞƚŽƌĞƚƌŝĞǀĞ͘dŚĞŶ͕ĞǀĞŶŝĨǁĞĚŝĚŐĞƚƚŚĞĨŝƐŚŽƵƚ͕ƉƌĞǀŝŽƵƐĐŽŝů WƌŽĚƵĐĞKŽŶůǇ sͲϮϬϱ ͬsͲϮϬϱ>ϭ Wd͗ϮϬϲͲϭϴϬ ͬϮϬϲͲϭϴϭ ŝŶƚĞƌǀĞŶƚŝŽŶƐŚĂǀĞƐŚŽǁŶƚŚĂƚŐĞƚƚŝŶŐƉĂƐƚƚŚĞũƵŶĐƚŝŽŶŚĂƐďĞĞŶƉƌŽďůĞŵĂƚŝĐĞŶŽƵŐŚƚŚĂƚǁĞǁĞƌĞĂďůĞƚŽ ƚǁŝƐƚŽĨĨĂďŝƚ͘ dŚĞĐĞŵĞŶƚƉƵŵƉĞĚĚƵƌŝŶŐsͲϮϯϰĚƌŝůůŝŶŐǁŝůůƐĞƌǀĞĂƐŽƵƌ>ϭͬKďĂWΘĂŶĚƐŚŽƵůĚƉƌŽǀŝĚĞƐŽŵĞ ďĂƌƌŝĞƌƚŽĨůŽǁďĞƚǁĞĞŶƚŚĞŵŽƚŚĞƌďŽƌĞĂŶĚ>ϭ͘dŚĞͲůŝŶĞƉůƵŐĂŶĚĚƵŵƉďĂŝůĞĚĐĞŵĞŶƚǁŝůůŝƐŽůĂƚĞƚŚĞ ŵŽƚŚĞƌďŽƌĞĂŶĚ>ϭĨƌŽŵ>Ϯ ƉƌŽĚƵĐƚŝŽŶ͘ ^ůŝĐŬůŝŶĞ KDW>dϱͬϭϴͬϮϮ ϭ͘ ƌŝĨƚ Ϯ͘ WƵůů:ĞƚƉƵŵƉ ϯ͘ ůŽƐĞ<Z^^Λϰϴϳϭ͛ ϰ͘ ƌŝĨƚ ϱ͘ WƵůů<ƉĂĐŬĞƌ ϲ͘ WƵůů ƐůŽƚƚĞĚ /ƐŽůĂƚŝŽŶƐůĞĞǀĞŽǀĞƌ>ϮůĂƚĞƌĂů ϳ͘ ƌŝĨƚǁŝƚŚϮ͘ϱ͟ďĂŝůĞƌƚŽϱϬϱϬ͛ ͲůŝŶĞ ϴ͘ ^Ğƚ /W ŝŶ>DηϮƚĂŝů ďůĂŶŬũŽŝŶƚ ΛϱϬϳϱ͛ ŽƌĂƐĚĞĞƉĂƐƉŽƐƐŝďůĞǁŚŝůĞĂǀŽŝĚŝŶŐĐŽůůĂƌƐ ĂŶĚĂůůŽǁŝŶŐĨŽƌ Ϯϱ͛ŽĨĚƵŵƉďĂŝůĞĚĐĞŵĞŶƚ͘ Ă͘ ^ůŝĐŬůŝŶĞǁĂƐĂďůĞƚŽĚƌŝĨƚϮ͘ϱ͟ǆϭϬ͛ŽŶϱͬϭϴͬϮϮ͕ƚŚĞǇǁĞƌĞƵŶĂďůĞƚŽŐĞƚĂ/WĚƌŝĨƚ ď͘ ^ĞĂůĂƐƐĞŵďůǇƐƚĂďďĞĚŝŶƚŽ>DηϭƐŚŽƵůĚƐƚŽƉĨůŽǁĨƌŽŵϰͲϭͬϮ͟ďĂĐŬƐŝĚĞĨƌŽŵŝŶƚĞƌĨĞƌŝŶŐǁŝƚŚ ƉƌŽĚƵĐƚŝŽŶ͕ /W ƐƚŽƉƐĨůŽǁĨƌŽŵƵƉϰͲϭͬϮ͟ůŝŶĞƌ ϵ͘ ƵŵƉďĂŝůΕϮϱ͛ŽĨĐĞŵĞŶƚŽŶƚŽƉŽĨ/W ^ůŝĐŬůŝŶĞ ϭϬ͘ ƌŝĨƚĂŶĚƚĂŐdK͕ ƚŝĞŝŶĂƐďĞƐƚǁĞĐĂŶ ϭϭ͘ /ŶƐƚĂůů'>sƐƉĞƌ'>ĞŶŐŝŶĞĞƌ͘ dĞƐƚĞƌƐ͗ ϭϮ͘ WKWǁĞůůǀŝĂ^>hƉƌŽĐĞĚƵƌĞ ďĞůŽǁ WƌŽĚƵĐĞKŽŶůǇ sͲϮϬϱ ͬsͲϮϬϱ>ϭ Wd͗ϮϬϲͲϭϴϬ ͬϮϬϲͲϭϴϭ ƵƌƌĞŶƚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ ĞŵĞŶƚĨŝůůĞĚKďĂůĂƚĞƌĂůĨƌŽŵsͲϮϯϰĚƌŝůůŝŶŐ &ŝůůĐŽǀĞƌŝŶŐĨŝƐŚŝŶ>ϭũƵŶĐƚŝŽŶ WƌŽĚƵĐĞKŽŶůǇ sͲϮϬϱ ͬsͲϮϬϱ>ϭ Wd͗ϮϬϲͲϭϴϬ ͬϮϬϲͲϭϴϭ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ /W^ĞƚΛ ϱϬϳϱ͛ dKĂďŽǀĞ ϱϬϱϬ͛ ĞŵĞŶƚĨŝůůĞĚ KďĂůĂƚĞƌĂůĨƌŽŵsͲϮϯϰĚƌŝůůŝŶŐ &ŝůůĐŽǀĞƌŝŶŐĨŝƐŚŝŶ>ϭũƵŶĐƚŝŽŶ WƌŽĚƵĐĞKŽŶůǇ sͲϮϬϱ ͬsͲϮϬϱ>ϭ Wd͗ϮϬϲͲϭϴϬ ͬϮϬϲͲϭϴϭ ^>hWƌŽĐĞĚƵƌĞ͗ WƌŽĚƵĐĞKŽŶůǇ sͲϮϬϱ ͬsͲϮϬϱ>ϭ Wd͗ϮϬϲͲϭϴϬ ͬϮϬϲͲϭϴϭ KůĚ >DŝǀĞƌƚĞƌ͗ EĞǁŝǀĞƌƚĞƌƚŽďĞƵƐĞĚƚŽƌƵŶƐĐƌĞĞŶ;ǁŝůůďĞĂǀĂŝůĂďůĞDĂƌĐŚϭƐƚ͕ϮϬϮϮͿ WƌŽĚƵĐĞKŽŶůǇ sͲϮϬϱ ͬsͲϮϬϱ>ϭ Wd͗ϮϬϲͲϭϴϬ ͬϮϬϲͲϭϴϭ >Dηϭ dĂůůǇ͗ >DηϮ dĂůůǇ͗ WƌŽĚƵĐĞKŽŶůǇ sͲϮϬϱ ͬsͲϮϬϱ>ϭ Wd͗ϮϬϲͲϭϴϬ ͬϮϬϲͲϭϴϭ >D&ƵƌƚŚĞƌĞƚĂŝů͗ KůĚĚŝǀĞƌƚĞƌĐŽůůĞƚƐĞƚƐŝŶ >DƐĞĂůďŽƌĞƉƌŽĨŝůĞ ůŽĐĂƚĞĚŚĞƌĞ͕ŶĞǁĚĞƐŝŐŶ ǁŝůůƐĞƚŝŶďŽƚƚŽŵŽĨ>D WƌŽĚƵĐĞKŽŶůǇ sͲϮϬϱ ͬsͲϮϬϱ>ϭ Wd͗ϮϬϲͲϭϴϬ ͬϮϬϲͲϭϴϭ dǇƉŝĐĂů>DŝĂŐƌĂŵ͗ WƌŽĚƵĐĞKŽŶůǇsͲϮϬϱ ͬsͲϮϬϱ>ϭWd͗ϮϬϲͲϭϴϬ ͬϮϬϲͲϭϴϭƌŽƐƐͲ^ĞĐƚŝŽŶ͗79'662$ 2:& 66/ZU 2%D :87" 662%G 2:& 662%E 2:& 662%G RXW RI SODQHa 0'3HUPHDELOLW\ JHQHUDOO\PG3HUPHDELOLW\ JHQHUDOO\!PG6Z !99 0XOWLODWHUDO&VJ 0'2$7RWDO )RRWDJH 'ULOOHG 0'7RWDO +LJK$QJOH )RRWDJH 0'7RWDO 6ORWWHG /LQHU 5XQ 0'7RWDO 1HW 3D\ 0'99/2%D2%E2%F2%G7' 0'/HQJWK 7' 0'/HQJWK 7' 0'/HQJWK 1(2%H2%I6ZHOO 3NUV 6ROLG 3LSH 0'6ZHOO 3NUV 6ROLG 3LSH 0'9/6ZHOO 3NUV 6ROLG 3LSH 0'6ZHOO 3NUV 6ROLG 3LSH 0'6ZHOO 3NUV 6ROLG 3LSH 0'6ZHOO 3NUV 6ROLG 3LSH 0'6ZHOO 3NUV 6ROLG 3LSH 0'"" +LOFRUS 1RUWK6ORSH//&+LOFRUS 1RUWK6ORSH//&Changes to Approved Work Over Sundry Procedure'DWH -XQH 6XEMHFW &KDQJHVWR$SSURYHG 6XQGU\3URFHGXUHIRU :HOO 99/6XQGU\ $Q\PRGLILFDWLRQVWR DQ DSSURYHGVXQGU\ ZLOOEHGRFXPHQWHGDQGDSSURYHGEHORZ &KDQJHVWRDQDSSURYHG VXQGU\ ZLOOEHFRPPXQLFDWHGWRWKH$2*&& E\WKH ZRUNRYHU:2³ILUVWFDOO´HQJLQHHU $2*&&ZULWWHQDSSURYDORIWKHFKDQJHLVUHTXLUHGEHIRUHLPSOHPHQWLQJWKHFKDQJH6WHS3DJH'DWH 3URFHGXUH&KDQJH+163UHSDUHG%\,QLWLDOV+16$SSURYHG%\,QLWLDOV$2*&&:ULWWHQ$SSURYDO5HFHLYHG3HUVRQDQG'DWH$SSURYDO$VVHW7HDP2SHUDWLRQV0DQDJHU 'DWH3UHSDUHG)LUVW&DOO 2SHUDWLRQV (QJLQHHU 'DWH Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:206-180 6.50-029-23338-00-00 PRUDHOE BAY, SCHRADER BLUFF OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 9625 9621 4700 4915 5173 None 4366 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 32 - 112 32 - 112 Surface 3015 10-3/4" 32 - 3047 32 - 2856 5210 2480 Intermediate 5664 7-5/8" 29 - 5693 29 - 4670 6890 4790 Production Perforation Depth: Measured depth: 5697 - 9621 feet True vertical depth: 4671 - 4700 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 27 - 4990 27 - 4410 4915 4366Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker Premier Packer Liner 4395 4-1/2" 5228 - 9623 4534 - 4700 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 278184275240 2908 2064 9 174 325 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Brodie Wages David.Wages@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.564.5006 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured4700 Sundry Number or N/A if C.O. Exempt: N/A No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Pull XXN Plug Operations shutdown Change Approved Program 5 N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028240 PBU V-205 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:53 am, Jun 23, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.06.23 07:54:09 -08'00' Stan Golis (880) SFD 6/23/2021RBDMS HEW 6/24/2021 DSR-6/24/21MGR26JUL2021 ACTIVITY DATE SUMMARY 6/12/2021 ***WELL S/I ON ARRIVAL*** (jet pump) RIGGED UP POLLARD UNIT #58 ***WSR CONTINUED ON 6/13/21*** 6/13/2021 T/I/O= 350/225/250. LRS unit 70 Assist Slickline with Brush and Flush (JET PUMP). Pumped 80 bbls of 180* F diesel into the TBG. Final T/I/O= 200/125/300. 6/13/2021 LRS Well Test Unit 6, Well Test. Begin WSR 06/13/21. Unit Move, RU, Continue RU. Inlet Well V-205, Outlet Well V-08. Continue on WSR 06/14/21 6/13/2021 ***WSR CONTINUED FROM 6/12/21*** (jet pump) PULLED 4-1/2" JET PUMP FROM 4,871' MD. (lower packing stack gone) ATTEMPTED TO PULL 2-7/8" XXN FROM 5,035' MD. MADE 3 BAILER RUNS TO 2-7/8" XXN PLUG @ 5,035' MD. (recovered chunks of v pkg & gravel) PULLED 2-7/8" XXN PLUG FROM 5,035' MD. RAN 3.80" GAUGE RING, 4-1/2" BRUSH TO SSD @ 4,871' MD. (very slow & sticky from 4,000') RAN 4-1/2" 42 BO SHIFTING TO SSD @ 4,871' MD. (confirmed open) BRUSH & FLUSH TO 4,950' SLM w/ 80 bbls 180* DIESEL. SET 4-1/2" JET PUMP IN CMD @ 4,871' MD. ***JOB COMPLETE, WELL LEFT S/I*** 6/14/2021 ***WELL S/I ON ARRIVAL***(jet pump) PULL & RESET JET PUMP IN CMD @ 4,871' MD NOTE: correct spacing of lower pkg bore measured from 90° shoulder of X-key is 39.02" top of lower pkg bore & 42.84" bottom of lower pkg bore ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU V-205 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:206-180 6.50-029-23338-00-00 PRUDHOE BAY, SCHRADER BLUF OIL BP Exploration (Alaska), Inc 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 9625 5035 4435 4915 5173 5035 4366 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" x 34" 32 - 112 32 - 112 Surface 3015 10-3/4" 32 - 3047 32 - 2856 5210 2480 Intermediate 5664 7-5/8" 29 - 5693 29 - 4670 6890 4790 Production Perforation Depth: Measured depth: 5697 - 9621 feet True vertical depth: 4671 - 4700 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 27 - 4990 27 - 4410 4915 4366Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker Premier Packer Liner 4395 4-1/2" 5228 - 9623 4534 - 4700 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 36221527541086 350 2700 Shut-In 300 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Peru, Cale Cale.Peru@bp.com Authorized Name:Peru, Cale Authorized Title: Authorized Signature with Date:Contact Phone:+1 9075644522 Treatment descriptions including volumes used and final pressure: 13. Petroleum Engineer Operations Performed1. Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured4700 Sundry Number or N/A if C.O. Exempt: 320-044 No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Install Jet Pump Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7.Property Designation (Lease Number):ADL 028240 PBU V-205 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations Petroleum Enginee Senio 6/4/2020 By Samantha Carlisle at 8:04 pm, Jun 04, 2020 MGR05JUN2020 DSR-6/9/2020 SFD 6/10/2020RBDMS HEW 6/10/2020 ACTIVITYDATE SUMMARY 5/4/2020 ****WELL S/I ON ARRIVAL****(jet pump) SET 4-1/2" X-LOCK CATCHER IN SLD SLV NIPPLE @ 4871' MD. PULL BK-OGLV FROM STA #1(4753' MD) & BK-LGLV FROM STA #3(3327' MD) SET BK-DGLV IN STA #3(3327' MD) & STA #1(4753' MD) PULL EMPTY 4-1/2" X-LOCK CATCHER FROM 4871' MD. SET 2-7/8" XXN-PLUG @ 5035' MD. LRS PERFORM PASSING MIT-IA **(see attached LRS log for details)** ****CONT WSR ON 5-5-20**** 5/4/2020 T/I/O= 350/300/250 Temp= S/I Assist SSL / MIT IA PASSED to 2640 psi (JET PUMP) pumped 8 bbls crude down tbg as slickline ran gauge ring. Pumped 4 bbls crude as slickline set plug. Pumped 2 bbls crude down IA to MIT to 2900 psi. IAP lost 109 psi 1st 15 min, and 33 psi 2nd 15 min, Bleed IAP, Bled back 2 bbls, ***WSR Continued on 05-05-20*** 5/5/2020 ****CONT WSR FROM 5-4-20****(jet pump) SHIFT BKR CMD SLD SLV OPEN @ 4871' MD. BRUSH & FLUSH TUBING W/ KJ, 4-1/2" BRUSH, 3.80" GAUGE RING FROM SURFACE TO 4977' SLM. SET 4-1/2" JET PUMP IN BKR CMD SLD SLV @ 4,871' MD ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS*** ***DRIFTED W/ 20' x 2.70" DUMMY WHIPSTOCK TO 2,650' MD FOR SUBSIDENCE SURVEILLANCE*** Daily Report of Well Operations PBU V-205 LRS MIT-IA LOG (05/04/2020) PBU V-205 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Alex Youngmun Kuparuk and Schrader Bluff PE BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Alaska Oil and Gas Conservation Commission Re: Prudhoe Bay Field, Orion Schrader Bluff Oil Pool, PBU V-205 Permit to Drill Number: 206-180 Sundry Number: 320-044 Dear Mr. Youngmun: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. DATED this day of February, 2020. RBWS A'FEB 0 4 2920 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 JAN 2 4 2020 075 Z/3 / 2, o 1. Type of Request: Abandon ❑ Plug Perforations 0 • FractureStimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other -Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other Jet Pump Swap 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0- 5. Permit to Drill Number. 206.180 3, Address: P.O. Box 196612 Anchorage, AK 6. API Number: 50-029-23338-00-00 ' 99519-6612 Stratigraphic ❑ Service ❑ 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU V-205 ' 9. Property Designation (Lease Number): 10. Field/Pools: ADL 0028240. PRUDHOE BAY, ORION SCHRADER BLUFF OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD In): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9625 4700 9621 4617 None 5173 Casing Length Size MD TVD Burst Collapse Structural Conductor 60 20" x 34" 32-112 Surface 3015 10-3/4" 32-3047 32-2856 5210 2480 Intermediate 5664 7-5/8" 1 29-5693 1 29-4670 1 6890 4790 Production Liner 4395 4-1/2" 1 5228-9623 4534-4700 8430 1 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): 1 Tubing Size: Tubing Grace: Tubing MO (ft): 1 5697-9621 4671 - 4700 4-1/2" 12.6# 13CB0 27-4990 Packers and SSSV Type: 4-1/2" Baker Premier Packer Packers and SSSV MD (ft) and TVD (ft): 4916/4366 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 . Service ❑ 14. Estimated Date for Commencing Operations: February 7, 2020 15. Well Status after proposed work. Oil 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Youngmun, Alex be deviated from without prior written approval. Contact Email: younakilliBRoom Authorized Name: Youngmun, Alex Contact Phone: +1907 564 4864 Authorized Title: Kuparuk 8 Schrader Bluff PE Authorized Signature: tv J u � Date: I/2 -LI, )2 % COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other. ABDMSIP FEB 0 41020 Post Initial Injection MIT Req'd? Yes ❑ No 11 Spacing Exception Required? Yes ❑ No ® Subsequent Form Required: !Q r 410 y APPROVED BYTHE —f Approved by: COMMISSIONER COMMISSION Date. r� - /o #-r- ORIGINAL Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. If //L� -6( .2-7ZZ M4!k1*Q Submit Form and Attachments in Duplicate 10-403 Sundry Application for Well PBU V-205 PTD #206-180 Expected Start Date: February 7, 2020 Current condition of well: Gas Lift Producer, Operable, Online: Oil Rate: 1086 BOPD Gas Rate: 2700 Mscf/Da Water Rate: 754 BWPD Tubing Pressure: 362 psi -Flowing Shut-in Wellhead Pressure: 450 psi Reservoir Pressure: 1450 psi Program History and Objective(s): V-205 is a tri -lateral jet -pumped Orion producer that has been producing via jet pump since 2013. It was previously a gas lifted well, but had hydrate issues due to low flowrates. SL and FB thawed hydrates on 10/16/19. SL then proceeded to make multiple drifts and was able to make it past the OA lateral / KB straddle assembly. The likely MBE and sanding culprit is the OBa sand. V-205 has remained shut-in since the hydrate thaw. Due to previous challenges getting past the OBa junction, the plan is to set a plug in the OA straddle assembly isolating the lower 2 laterals, returning the well to OA only production. Proposed Program: 1)4- Set plug in XN nipple at 5035' to isolate production from the OBa and OBd laterals. 2) Open sliding sleeve at 4871'. 3) - Install WFD jet pump at 4871', size 106 w/ rock screen hung on the bottom. a. Run check set to verify jet pump is latched. BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU V-205 PTD #206-180 Current Wellbore Schematic: TFEE= 4-111VCMY V-205 WB.LICAD- 11'FW VLV AMAMR= LED Ll & L2 MML XB. ELEV= 82W x407 BE. 8" = 54.05' Dk/t K'w= 700' ON1b07 Ma Aryb • 93• C 9148' 200 GOND — 117 1Fq D$e M- $123' DOkE DMMTVD- 4/00 SS 9/Y, A43, 0527119 Minimum ID = 2205" @ 5035 2-7/8" OT13 XN NIPPLE 0=3.910• 3956• jw I SFALNG LEM 61. 0=x665 183 TMSLA w FEF LOG. AN(LEATTOPFBF- NAe: Bela b RaAa:6on W lar Nab Pod E SIZE I SW I -i CgN58L I DATE SEE PAGE2 FOR H3RFORAT M MAILS PBTD 9821• SAFETY NOTES: WELL ANOLE> -70• ®6126'. 4-12' CHROME T80 2315aIM;9XW..O.381S C.AA LFT kM� ISTI NVINDIDEVITYKI VLV LAT01 FORE DATE 1 x407 31 Ia@ Dk/t BX 0 ON1b07 3 3327 3000 70 IlBO2 DOkE BK 18 0527119 2 12632 3875 3656 32 1®G2 O•AY BLL 0 0226113 1 479 4287 46 1®G2 30 SK 20 05MM L2(OA) 7Wir 6029 TJI'IOf- - "lOflOf" -'' OE@,NDTH-337• .. AN...10L101.----1 L1(OM)LEMWNDDW60' Li (0113a) J a165-5Lfir 0P8*4 WIDTH - 337- DATE FEV BY I 00MENTS I DATE I FEV BY ICOMBOS @MAW NM IMOMALCGMKETM 0&21119 MFFP Q0. -ID SLO SLHVE(06Mn8) 112513 GEI R1lHKEM Erfl/N 111/1811 0821719 FIV LLV CIO(O 19) 01112n5 RLUDISEF.ET RAP(17H9n4) 07NBn7 CNAO RLL Fs>w: FT3°T PUW(0B28n7) WM&19 M1.A0 IPJAJDXX RAURESET.Er 03n8nB M1JLD RLIID.ErRM(W67111a) BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 SEALAS5815LY, D=ISM OAJNLNR VALL. V-205 FBMTM. 2061600(10)(20) ARM- SOMW233MM(60)(6/) BP EW4MM on (AI ka) 10-403 Sundry Application for Well PBU V-205 PTD #206-180 P9FO41ATUNSLMMRY Rf F LOG: ANGLE AT TOP PEW. N51p: We, b RP*.OB Iv Mb ical pert Amb SItE SPF I LONE NISWAL qW&V DATE 412• SLID OA 5685-6097 SLTD Gu15107 4+2• SLID 8765-8584 SLTD 02115101 41? SLID 9280-+1307 SLID 021IM7 412• SLTD OBa 5809-7949 SLTD 07108!07 4112• SLID 8463 - 9519 SLID 0770807 4+? SLID am - 1IM7 SLID 0709107 4Vr SLID cad 5687-aO39 SLID 01/J0107 41? SLID 1 9561 - SRI SLTD 01730107 V-205 L1 & L2 DA PwD 1346' 112' SWI41 IMIXFFfl.- U --] 90' 0x5019 .. 5953'. 51111�Y. 66742. 66119�L{V 9AA�9 101101_ 101101_ _ _CSLN —RIR --- JOLUL--- EM- _ L IYSW II I'AMI N9. D-J9P ® 5265. 5621'. 7965'. I~. 9538 A 9909 -IDs"---X9 --- 90--- 475161'- 11355' 8-3M• OB. LATERAL 1 a-412• LNR. 1269, L-80 ST -M_01 58 bpl, s)= 3958• I � I I soar 4ffi' SM6L MR, D-3.613- 961T 412. 5%aLPMD-3e+3• N-ZOS I 5697'-9625' 6-JN'OBA LATERAL IMd 1 4-12•LNR, 126 w'a, L_80 O3T-M 0158 Opf, I0=3959• I DAZE REV BY I L'OWANM 11 DATE REV BY OOM.BJIB o77+s07 NB ONOINALCONPLE110N 082171981IlV OA6®SLDuryBYE(DY21/+9) LEOTRP (11118'1 1125113 G� RLASEr. 0921/19 .AV GLV UO OYd/19 OV12R5P1AlIDiSET.ETRAF(12)19'14) 07px4H7 C9MAU RLL®TESET,ET RW(OSWI T) 68119/19 M9JAU R11ID XX fiLGAf5ET JtT 6811609 MrbO PLLL®.ETRAP(O3QA9 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ORON LM WELL V-205 PHMTW. 2061800(10)(20) ARM: 501029-23300-00(60)(6 L T11N R11E 4697 FSL 6 1619 R3. OP Brplomt" (Aima) 10-403 Sundry Application for Well PBU V-205 PTD #206-180 Proposed Wellbore Schematic: T;U . 4.11,6' CW V-205 VaUEAD• I'FI 11w ACTUATOR • Ll & L2 NML P3 REV • 87 09 MTF HV BF HHV- 45 26Y1 KOP= TV ]t ABX An* • 9Y 09 OM Dx+ M) S123 191".A 5] 72116F7 D.[ nTVC- 4401 'U 191'4' 3327 . 30 7.0T'GV: 24:• I M PTC?OTOTXj— A49S' CAM I tAnifnu m ID = 2.21" 05038 1 3x281.3 `2.718" OUS XN NIPPLE 3915 ICAUGED-3x0' 1 InOHM MALE PEES RE GALGE D • 3 o (1 ST a�7 - 4.1?18G.1261.17CRVAMT0P. 0152tp1 D-3WA' 5177X81A7XO.1D-39VJ' - 4995' �HwSA LOOK MNUEP A13. .1L ALM LLM t2. U - 3646' 1 BAKER HOOK WA4GER 5151. ( .15EALRG L61 tt. U • 3685 MKO 1011MAaWA 1 r6l l OG ANSLEAT'OYR2d Note AM., vk*d. , 0111a hd..,1 W". SbE i S�rIJiF3NAl - OpHgt--D111 iEEPAGE 2 r0R R33OW 7101 CETA2 S.-. . I rsr aA uc uos AWCSG.2024.L80S7CM0^683' I 5693' I ; ,V 20 1111u 5621' \i Oed i SUVY NOTES: WELL AI4LE>-70'g5426' ! 4.1YCMOMETSG C.AS I FT 1MmmY Si M) TVD 11w ttK VI V IIAOKWI MTF 4 26Y1 7137 ]t I®GT OM 9K 0 72116F7 3 3327 3009 30 MM CAM 3K0 3x281.3 2 3915 7 65E 32 MW OW BK 0 322&13 1 4753 4263 48 KBW O✓/ 3K O 381161.1 In alis•--' ,1 W 41, BKt MDA" C-3.826' 17P �-(7�`J6 x11.7 BKR Z1lPLIPr/T[91C D•49C0- TND' 4-I!l MAL `S[i, U-XfN 4U7X2 7SKBRMASS",0.245' - - RR . .... L2;OA'L9JV COW56' L.2 (ON :0,0 - W29' E7Td--•RIb7•''• OPE'VG VAO7 •33T X> R... R&.. U I06a-Ia VAQDW66 Ll (ON) JI M'- 5146 oPewsMTw. �r 3__6177' tSi127? IADIOIpt 0.5"m— Ic;i BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 DNONUM Val V 205 FOW P6 20618001101000 ARM `-0.7AZS38O30160X61T SP Tiplaxbn 1ALattal 10-403 Sundry Application for Well PBU V-205 PTD #206-180 PEWO ATM SI FTNRy 14EY LOG: ANGLE AT TOP19iF: Nbl Rab, b Rodmkan 05 for 11ib,tol port Cad SIZE SPF IZCNEI tMWAL OMVSW GATE 412' SLm CA 5895-6087 SLm 07/1507 412' SLm - 8785 - 8884 SLm 07/15107 4V2' SLm - 5260-11307 SLm 02/1507 472' SLID 06a 5649 - 7919 SLm MOW 412' SLm ' 6183-9519 SLm 02/0807 41? SLm ' 8832 - 11307 SLm 071000] 412' SLm 090 5607 - 8059 SLm 011.1007 412' SLm ' 8561 9821 SLm Oln"? V-205 L1 & L2 oA PeTD . t2' SVAI I. 1'AOOR9. D • 3 B0' ®w9e•. 5ssz•. s11s. s74z.11s61• a 9259 ' aea lsm 11844• i 1% 4 VC 9'M 1I IMIXI M9. U•3B6' 99 719p8�5�,N40'. 951]p6�Iap9909 N I---IOlbl--_ - 516T - 11355' 63/4' 00a LATERAL 412' LNR, 1260. L-80 IBT,M. 0158 bpf, U) = 3 958' 412'SN9L MR D-3Ai3' 861] 412-SVA3LFKRD-3.843' V-205 r 5693'-9625' 6-3//'060 LATERAL :OBd I 4A2' LNR, 12.6#, LAO U3T-fA 0158 bpf. ID = 1958' DATE MIST OOM 3M DATE REVBY COMM 92N1M7 On ICMC1MLC=KMM 0621719 0- EDSLOSLf£7E(G521/19) 11/25713 GEY R1.18XSET.ET P(AP(11/18ft 0621119 JWAC GLV 00(05=19) 01/12/15 KXLEU MET.ET R/.P(12119714 070017 CN•AD KILLED SET,ET RAP(0828'1T) 0118/19 WAD RLLID)0( R.lrAf5ff .ET 011019 Mi•AO RLLID ET PUP 0301119 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 cfiON LMT NAL V-205 PBVATfb. 2081800 00) (20) AR No: 5042423380.00 (600 I. T11N R1 1E 4692' FSL 81619' iH BP 6pbrali (Alaska) Rixse, Melvin G (CED) From: Youngmun, Alex <younak@BP.com> Sent: Thursday, January 30, 2020 4:19 PM To: Rixse, Melvin G (CED) Subject: Re: V-205, PTD206-180, Plug and Jet Pump Swap, Sundry 320-044 Mel, Per our phone discussion, will add a MIT -IA to V -205's program to conduct prior to wireline setting a new jet pump. Will target a passing MIT -IA pressure of 2640 psi (10% over max supply pressure). V -205's power fluid source is from the produced water system and have confidence BP should not be exceeding a power fluid injection pressure down the IA of more than 2400 psi. Thanks, Alex From: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Sent: Thursday, January 30, 2020 3:53 PM To: Youngmun, Alex <younak@BP.com> Subject: RE: V-205, PTD206-180, Plug and Jet Pump Swap, Sundry 320-044 Alex, 7 years ago ...... I think we need a 2880 ( or 20% over 2400) psi test on the inner casing. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCQ, State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231) or (Melvin.Rixserdalaska.gov). From: Youngmun, Alex <younak@BP.com> Sent: Thursday, January 30, 2020 2:02 PM To: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: RE: V-205, PTD206-180, Plug and Jet Pump Swap, Sundry 320-044 Mel, Please see comments below in blue. Regards, Alex From: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Sent: Thursday, January 30, 2020 1:48 PM To: Youngmun, Alex <younak@BP.com> Subject: RE: V-205, PTD206-180, Plug and Jet Pump Swap, Sundry 320-044 Alex, Thanks for the reply. A couple other questions: 1. When was the last IC pressure test (above the packer at 4915' MD)? • 2/28/13: MIT -IA to 3019 psi. IA lost 175 psi in 1s' minutes followed by 65 psi in the 2nd 15 minutes passing to 2779 psi. Final T/1/0's were 775/2779/244 psi. 2. What will be the maximum annular surface pressure when producing? • Maximum surface annular pressure is 2400 psi. Past 24 month plot is shown below. J ,J --4 _ , I Ga , Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231) or( Melvin. RixseP a laska. go). From: Youngmun, Alex <younak@BP.com> Sent: Thursday, January 30, 2020 1:25 PM To: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: RE: V-205, PTD206-180, Plug and Jet Pump Swap, Sundry 320-044 Mel, There is currently not a jet pump set in V-205. The jet pump was pulled on 3/1/19 to allow for troubleshooting of the lower 2 laterals. Let me know if you have any additional questions. Thanks, Alex Youngmun BP Exploration (Alaska)Inc. Kuparuk & Schrader Bluff PE Office: (907) 564-4864 Cell: (907) 250-1228 From: Rixse, Melvin G (CED) <melvin.rixse@alaska.eov> Sent: Thursday, January 30, 202012:46 PM To: Youngmun, Alex <vounak@BP.com> Subject: V-205, PTD206-180, Plug and Jet Pump Swap, Sundry 320-044 Alex, Is there currently a jet pump in V-205? If so, how will a plug be set in the XN nipple at 5035' MD without pulling the jet pump? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231) or (Melvin.Rixse@alaska.Rov). STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WFI 1 nPFRATIni 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Soap Well ❑ Other: Pull XXN Plug 9 2. Operator Name: BP Exploration (Alaska), Inc 14, Well Class Before Work Development 0 Exploratory ❑ 1 5. Permit to Drill Number: 206-180 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 1 6. API Number: 50-029-23338-00-00 7. Property Designation (Lease Number). ADL 028240 8. Well Name and Number. PBU V-205 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, SCHRADER BLUF OIL 11. Present Well Condition Summary: Total Depth: measured 9625 feet Plugs measured None feet true vertical 4700 feet Junk measured 5173 teat Effective Depth: measured 9621 feet Packer measured 4915 feet true vertical 4617 feet Packer true vertical 4366 feet Casing: Length. Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" x 34" 32-112 32-112 Surface 3015 10-3/4" 32-3047 32-2856 Intermediate 5664 7-5/8" 29-5693 29-4670 6890 4790 Production Liner 4395 4-1/2" 5228-9623 4534-4700 8430 7500 Perforation Depth: Measured depth 5697-9621 feet True vertical tlepth. 4671 -4700 feet Tubing (size, grade, measured and true vertical depth) 4-1/2' 12.6# 13Cr80 23-4990 23-4410 Packers and SSSV (type, measured and 4-1/2' Baker Premier Packer 4915 4366 true vertical depth) No SSSV Installed 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 Casing Pressure Tubing Pressure Prior to well operation: 103 6 124 2109 353 Subsequent to operation: No Test Available 650 360 14. Attachments (required per2tl MC 2s 07(1.25071, s 25289) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 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: N/A Authorized Name: Youngmun, Alex Contact Name: Youngmun, Alex Authorized Title: & Schrader Bluff PE Contact Email: younakABRoom �^Kuparuk Authorized Signature: At K ` v✓A L Date3 ( Contact Phone: a1 907 564 4864 Form 10-404 Revised 042017 mc1 4%'ewlfl RBDMSINMAR 201019 Submit Onginal Only Daily Report of Well Operations PBU V-205 Ar.TiViTVn&Tr 2/23/2019 ****WELL FLOWING UPON ARRIVAL**** (Jet Pump) R/U SWCP #4522 FOR JET PUMP REPLACEMENT LRS FREEZE PROTECTED POWER FLUID LINE & IA W/ CRUDE ****CONT JOB ON 2/24/19**** ****CONT. JOB FROM 2/23/19**** (Jet pump) LRS FREEZE PROTECTED FLOWLINE (See LRS log) B&F W/ 4-1/2" BRUSH, 3.80" G -RING TO JET PUMP @ 4,848' SLM / 4,871' MD (Fiberous material in brush) RAN KJ, 4-1/2" GR, 20'x 3.70" DMY WHIPSTOCK (Heavy style), SID @ 1' SLM (300 lbs overpull to get free) B&F W/ 4-1/2" BRUSH (stiff), 3.84" G -RING TO 50' SLM (Brushed tree & tbg hanger 20 min) LRS PUMPED -70 BBLS HOT CRUDE DURING B&F's RAN KJ, 4-1/2" GR, 20'x 3.70" DMY WHIPSTOCK (Heavy style), SID @ 1' SLM (300 lbs overpull to get free) RAN 4-1/2" GR, 20'x 3.70" DMY WHIPSTOCK TO JET PUMP @ 4,855' SLM / 4,871' MD PULLED 4-1/2" WFD JET PUMP (Serial # MO -1132) W/ ROCK SCREEN FROM 4,871' MD MADE 3 RUNS W/ 2-1/4" BAILERS TO XX -PLUG @ 5,015' SLM / 5,035' MD (1.5 qts fine silt/sand) RAN 2.20" CENT, 2-7/8" X -CHECKER EQ PRONG TO XX PLUG @ 5,015' SLM 15,035, MD (Sheared & metal ring) RAN 2-7/8" GR, SID & LATCHED PLUG @ 5,015' SLM 15,035' MD (Sheared GR) RAN 2-7/8" GS, SID & LATCHED PLUG @ 5,015' SLM 15,035' MD (Plug came free from nipple) PARTED WIRE WHILE POOH W/ GS (Small amount of wire left in hole) RAN KJ, 3.625" CENT, X x 1-7/8", 3.75" CENT, 3.70" LIB, SID @ 4,968' SLM (Hung up slightly w/ wire, Impression of wire) ***CONT JOB ON 2/25/19*** ***DRIFTED TO 4,871'W/ 3.70" x 20' FOR SUBSIDENCE SURVEILLANCE 2/24/2019 ***NOTE -- RIH 150 FPM W/ 4-1/2" GR & DMY WHIPSTOCK TO PASS TBG HANGER ****CONT. JOB FROM 2/24/19**** (Jet pump) RAN 3-1/2" BAIT SUB, 4-1/2" BRUSH, 3.0" CENT, 3.0" LIB, SID @ 4,970' SLM (Partial impression of rope socket & wire) RAN 3-1/2" BAIT SUB, 4-1/2" BRUSH, 2.60" BELL GUIDE W/ 1.75" LIB TO 4970' SLM (No impression) RAN 3-1/2" BAIT SUB, 4-1/2" BRUSH, 3.50" BLIND BOX TO 4,970' SLM RAN 3-1/2" BAIT SUB, 4-1/2" BRUSH, 3.50" LIB TO 4,970' SLM (Impression of clean rope socket) RAN 3-1/2" BAIT SUB, 4-1/2" BRUSH, 3.50" WIRE GRAB TO 4,971' SLM (No recovery) RECOVERED 1-1/2" TOOLSTRING FROM 4,970' SLM (GS sheared, Parted wire & plug still in hole) RAN 3-1/2" BAIT SUB, 4-1/2" BRUSH, 3.50" WIRE GRAB TO 4,985' SLM (No recovery) RAN 3-1/2" BAIT SUB, 4-1/2" BRUSH, DUAL MAGNETS (M10 & M11), SID @ 4,993' SLM (Recovered -5" pc of wire) MADE 2 RUNS W/ 2-3/8" BAIT SUB, 2-7/8" BRUSH, MAGNET (M10), 2.25" WIRE GRAB TO 4,993' SLM (Recovered remaining T pc of wire) RAN 2-3/8" BAIT SUB, Tx 1-1/2", 2.25" TAPERED LIB, SID @ 4,993' SLM (Impression of 2-7/8" FIN) p.1u i r=n �_�ia" xx_pl i ir• W/FILL EXT FROM 4 993' SLM (2 cups fill, Partially equalized) LRS PUMPED 38 BBLS OF CRUDE WHILE PULLING XX -PLUG (See LRS log) RAN 2.0" CENT, 1-3/4" S -BAILER, SID NEAR CMD SSD @ 4,862' SLM (Lost spangs, Sample of silt/fine sand) LRS PUMPED 15 BBLS CRUDE DOWN TBG (T/I pressures increased -800 psi ..... slowly bleading off) RAN 10' x 3" DD BAILER, SID ON 45 KB PKR @ 4,985' SLM / 4,994' MD (Bailer empty) 2/25/2019 ****CONT JOB ON 2/26/19**** Daily Report of Well Operations PBU V-205 ****CONT. JOB FROM 2/25/19**** (Jet pump) DRIFTED W/ 2.0" CENT, 1-3/4" S -BAILER, S/D @ 5,010' SLM (-5 above xn nipple, Unable to work past) RAN 4-1/2" BRUSH, 3.80" G -RING TO SSD @ 4,871' MD (Brushed 15 min while LRS pumping crude) SET 4-1/2" JET RESEARCH/NS D+7 JET PUMP W/ CHECK (PN: 201231 B) IN CMD SSD @ 4,856' SLM / 4,871' MD RAN 4-1/2" CHECK SET TO JET PUMP (Sheared) 2/26/2019 ****WELL LEFT S/I & PAD -OP NOTIFIED OF STATUS UPON DEPARTURE**** ***WELL S/I ON ARRIVAL***(jet pump) SET WCS ON JET PUMP AT 4855' SLM. PULLED DGLV FROM STA#3 AT 3327' MD. LRS BEGIN PUMPING DIESEL DOWN IA TAKING RETURNS UP TBG. 2/28/2019 ***CONT ON 3-1-19 WSR*** ***CONT FROM 2-28-19 WSR***(jet pump) SET BK-DGLV IN ST#3 @ 3327' MD. PULLED 4-1/2" WHIDDON CATCHER SUB FROM 4848' SLM.(empty) PULLED 4-1/2" JET PUMP ASSY FROM BKR CMD SSD @ 4871' MD.(plugged w/ sand/schmoo) TAGGED KB PKR ASSY @ 4994' MD W/ 3.00" BAILER.(sample of schmoo) LRS FLUSHED IA W/ 30 BBLS OF CRUDE. 3/1/2019 ***WELL S/I ON DEPARTURE, PAD -OP NOTIFIED OF WELL STATUS*** 7REE=__ 4-1/16"CfW V�LFEAD= FMC' ACTUATOR= LC -0 IJTIAL KB. ELEV BE. ELEV = _ 54.05'I I KOP=lar 2632 Max Angk = 93' @ 9148' 20# COND J 112" Datum MD DMY Datum TVD=44W'SS 191.4#,A-53,iI 10-3/4' CSG. 45.5#, L -80. D = 9.95' ✓8' CSG, 29.7#, L-80 BTC XO TO TCI -C Minimum ID = 2205" @ 5035' 2-7/8" OTIS XN NIPPLE PHOS D( DtSCHARGE PRFSS -= GAUGE. D = 3.940' AUGF, D = 3.948' 7-5/8" RA TAf TBG, 12.6#, 13CR VAM TOP, bpf, D = 3.958' JAW- X 4-12" XO, D = 3.960. 1 BAKER HOOK HANGER w/SEALNGLEM#2, 0=3.688' 2-7/8' MUI ESHOF, D=2.44' 7-5/8' RA TAG M* -fid IAK'R DNGB SEA NLMi,D2 -3688. R3TORATIDN SLmmARY REF LOG ANGLEAT TOP FE3RF: Note: Refer to Reduction DB for historical perf INTERVAL OpNSgz SEE PAGE 2 FOR PERFORATION DETALS 17-5/8' RA TAG I 17-5/8' CSG 29.7#, L-80 BTC -M, D = 6.875' 5037' 5105' V-205 L1 81 L2 L AFETY NOTES: WELL ANGLE> -70°5426. 12" CHROME TBG 14-12-HES X NP, D=3.813" 1 GAS LFT MANTRR C ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 2632 2497 31 DMY BK 0 02/18/(17 3 3327 3099 30 g DMY BK 0 02/28/13 2 3975 3658 32 DMY BK 0 02/28/131 4753 4263 48 DMY BK O 0826/11 4871' I-14-12• BKR GrD SLDNG SLV, 17-5/8' X 4-12' BKR PREM PKR D = 3.870" I 14-12- HES X NP, D = 3.813' 1 4963 J-14-12' HES X NP, D = 3.813' l 4976' 7-5/8'X4-12'BKR ZXP LTP w/I'®K. D= 4VVU- 1 -t412 -MULE SHDE, D=3.958 �Jp 4-12' X 2-7/8' KB PKR ASSY, D - 2.45' L2 (OA) LEM WINDOW 56- L2 (ON 5018' - 5029' 1prp� 1prp� OPENNG WATH = 3.33" ISI Id _ _ I01 IpI _ 503V 71W OT15 XN NP, D = 2205" --1/-S/e'X5-12'BKR ZXP LTPw R1FBK D=4.950' 5121' 4-12'SEAL ASSEMBLY, D=3.89' L1 (OBa) LRM WNDOW 60° L1(OBa) 5155'- 5166' _ - OPENING WIDTH = 3.33" 5173' HFISH: 2-7/8' MIA MOTOR ELEMENTS tm/75m91 data I 522W 7-5/8" X 5-12' BKR ZXP LTP, D = 5.75' DATE 5266' 4-3/4' BKR SEAL ASSEMBLY, D=3.870' 5276'5' X 4-12' XO, 15= 3.960' I I � I ,V-2051 PBTD sszl• � OBd --- i — -1 um 10 02/18/07 N9l$ ORIGINAL COMPLETION _1125/13 I L]A IE I HEV BY I COMMBd15 GIBIJMD RLL�Ef JET PUYP(it/18/13 042 /TLH GLV 0'0(04/17/07) .�Ir —RFC 5 Vdffi' RLLEIYREiET JET R -W(12/19/14 04/18A8 JCANTLH RLL PLUG(04!17/07)7 CJWJMD RLL�ETJET RAVP(06/26/17 0S2� '?/PJC DRLG DRAFT COF42E(,'f1pN$ 9 WJMD RLLEDXX IiUGIF2ESETET TVNPJC DRLG DRAFT COfRRECT10N5�9 MWJMD RLL® JET RAP(03(01119) 03A4/13ISWC/ GLV G08SET JET AImp(0228/1 ORION LUT I WELL: V-205 I PEFW W: 2061800 (10) (20) I AR No: 50-029-23380-W (60x61) SEC 34, TI 1 N, R11 E, 4692' FSL 8 1619' FEL BP Exploration (Alaska) PB WKMTDN SU AMITY RIF LOG: ANGLEAT TOP PERF: Note: Fifer to Production DB for historical perf data SEE SPF IZONEI HTERVAL OpnISgz DATE 4-12' SLID OA 5695-6097 SLTD 02/15107 4-12" SLTD " 6765-8664 SLTD 02/15/07 4-12' SLTD I I I I I I 9280-11307 SLTD 02/15/07 4-12" SLTD OBa 5649-7949 SLTD 02/06/07 4-12' SLID " 8463-9519 SLTD 02/08/07 4-12' SLTD 9932- 11307 SLTD 02/08/07 4-12' SLTD OBd 5697-8039 SLTD 01/30/07 4-12' SLTD 8561 - 9621 SLTD 01130/07 V-205 L1 & L2 CIA PBTO 1134F 4-1/2'SWELL PACKERS, D= 3.90' �@ 550-9988, 5652', �611r133'',, 6747, 7866811' _& 9259' _ 5030'- 11370' 6-3/4" OA LATERAL 4-12- LNR, 12.6#, L-80 IBT-M, .0158 bpf, ID = 3.958" • r �I 1 �9 gI �1 I i.n • 0 1 c •� U@ DATE REV BY I OOMrH"!f9 1125113. GB/JMO RLLEYMESET JET RAP (11/18/12 5265', 5621', 7965', 0440', 9536' & 9909' 101112I15�V1A�/ FU.LEDII�.SET JET RItiP(12119/14 04/18108 JCM'iLH FILL RRC PLt1G (04/17/07) 07106117' CJWJMD R=MMSETJET RAP (0626/17 06/23/08 ?/PJC DING DfiAf7 OOR}�CilOh15 03/18/19 Mi�JMD RLL®XX PLIJC2RFSET JLT F'lMp 0726/08 IVI/PJC ORLG OWIFT OOF�EOilONS 03/18/19 WJM7 PML®JETRMP(03/01/19) 03/04/1 3 SVuCJ GLV C/O & SET JET RMP (0228/13) 5167' - 11355' 6-3/4" OBa LATERAL 4-12- LNR, 12.6#, L-80 IBT-M, .0158 bpf, ID I I I I I I 8057' 4-12' SWELL PKR, D=3.813' 8517' 4-12' SWELL PKR D=3.813' V-2015: 5693'- 9625' 6-3/4" OBd LATERAL I OBd I 4-12" LNR, 12.6#, L-00 IBT-M, .0158 bpf, ID = 3.958" u DATE I REL/ BY l'X. MMENM 02118W N9ES ! ORIGINALCOMPLEITON Iii DATE REV BY I OOMrH"!f9 1125113. GB/JMO RLLEYMESET JET RAP (11/18/12 0426107 /TLH ,GLV C/O (04117107) 101112I15�V1A�/ FU.LEDII�.SET JET RItiP(12119/14 04/18108 JCM'iLH FILL RRC PLt1G (04/17/07) 07106117' CJWJMD R=MMSETJET RAP (0626/17 06/23/08 ?/PJC DING DfiAf7 OOR}�CilOh15 03/18/19 Mi�JMD RLL®XX PLIJC2RFSET JLT F'lMp 0726/08 IVI/PJC ORLG OWIFT OOF�EOilONS 03/18/19 WJM7 PML®JETRMP(03/01/19) 03/04/1 3 SVuCJ GLV C/O & SET JET RMP (0228/13) WELL: V-205 PEFW No: 2061800 (10) (20) AR No: 50-029-23380-00(60)(61) SEC 34, T11 N, R11 F- 4692' FSL & 1619' FEL EIP Exploration (Alaska) RECEIVED STATE OF ALASKA AIRKA OIL AND GAS CONSERVATION COMMIS ION S E P 0 6 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon 11 Repair Well L] Plug Perforations 'Z Perforate Lf Other Li Set Isolation Sleeve Performed: Alter Casing ❑ Pull TubingD Stimulate - Frac ❑ Waiver ❑ Time Extension❑ $ f- p I v Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Wee J 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development 19 Exploratory ❑ 206 -180 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23338 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028240 v V -205 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, SCHRADER BLUF OIL 11. Present Well Condition Summary: Total Depth measured 9625 feet Plugs measured None feet true vertical 4700.21 feet Junk measured None feet Effective Depth measured 4988 feet Packer measured See Attachment feet true vertical 4408.69 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# A -53 30 - 110 30 -110 0 0 Surface 3029 10 -3/4" 45.5# L -80 29 - 3058 29 - 2865.31 5210 2480 Intermediate None None None None None None Production 5667 7 -5/8" 29.7# L -80 26 - 5693 26 - 4670.24 6890 4790 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 23 - 4990 23 - 4409.84 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: A 'App Intervals treated (measured): SCANNED !AAR 0 1 20 13 Treatment descriptions including volumes used and final pressure: vw�- 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 670 295 75 861 414 Subsequent to operation: 20 69 34 1586 404 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExpioratorE Development 0 " Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil— El Gas ❑ WDSPIJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron --��--�� Title PDC PE Signature jjaAir, 0d . Phone 564 -4424 Date 9/6/2012 V e if,* RBDMS SEP102012J 2 0 R1G1 AL 9 i I I Form 10-404 Revised 10/2010 Submit Original Only • • Packers and SSV's Attachment ADL0028240 SW Name Type MD TVD Depscription V -205 PACKER 4915 4282.85 4 -1/2" Baker Premier Packer V -205L1 PACKER 5,094 4,467.18 5 -1/2" BAKER ZXP PACKER V -205L1 PACKER 9,909 4,595.54 4 -1/2" SweII Packer V -205L1 PACKER 9,536 4,587.86 4 -1/2" SweII Packer V -205L1 PACKER 8,440 4,580.10 4 -1/2" SweII Packer V -205L1 PACKER 7,959 4,554.20 4 -1/2" SweII Packer V -205L1 PACKER 5,621 4,541.93 4 -1/2" SweII Packer V -205L1 PACKER 5,265 4,545.55 4 -1/2" SweII Packer V -205L2 PACKER 4,976 4,401.78 5 -1/2" BAKER ZXP PACKER V -205L2 PACKER 9,259 4,534.91 4 -1/2" SweII Packer V -205L2 PACKER 8,681 4,519.23 4 -1/2" SweII Packer V -205L2 PACKER 6,742 4,476.79 4 -1/2" SweII Packer V -205L2 PACKER 6,113 4,486.85 4 -1/2" SweII Packer V -205L2 PACKER 5,652 4,481.16 4 -1/2" SweII Packer V -205L2 PACKER 5,098 4,466.29 4 -1/2" SweII Packer Casing / Tubing Attachment ADL0028240 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# A -53 30 - 110 30 - 110 LINER 4395 4 -1/2" 12.6# L -80 5228 - 9623 4534.47 - 4700.2 8430 7500 PRODUCTION 5667 7 -5/8" 29.7# L -80 26 - 5693 26 - 4670.24 6890 4790 SURFACE 3029 10 -3/4" 45.5# L -80 29 - 3058 29 - 2865.31 5210 2480 TUBING 4967 4 -1/2" 12.6# 13Cr80 23 - 4990 23 - 4409.84 8430 7500 LINER L1 6201 4 -1/2" 12.6# L -80 5145 - 11346 4493.77 - 4592.31 8430 7500 LINER L2 6372 4 -1/2" 12.6# L -80 4976 - 11348 4401.78 - 4536.07 8430 7500 • • • Perforation Attachment ADL0028240 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base V -205 1/30/2007 SL 5697 8039 4670.67 4700.93 V -205 1/30/2007 SL 8561 9621 4703.35 4700.19 V -205L1 2/8/2007 SL 5649 7949 4540.46 4553.28 V -205L1 2/8/2007 SL 8463 9519 4581.32 4587.94 x205L1 _ 2/8/2007 L _ 9932 _ _11307 _ 4596.83 _ _93 V- 05L x/19/1012 MIS 569 .097 447 786 4487.21 V -205L2 2/19/2012 MIS 6765 8664 4476.37 4517.93 • V -205L2 2/19/2012 MIS 9280 11307 4534.86 4534.71 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • Daily Report of Well Operations ADL0028240 ACTIVITYDATE .. x DRIFT W/ 3.74" GAUGE RING AND TAG BKR HOOK HANGER /SEALING LEM #2 @ 4992' SLM. BRUSH & FLUSH TO 5024' SLM W/ BLB & 3.50" GAUGE RING. DRIFT TO 5012' SLM W/ 3.50" CENTRALIZER AND 2.50" SIDE MAGNET, SOME METAL SHAVINGS DRIFT W/ 20'x3.69" DMY WHIPSTOCK, TAG BKR HOOK HANGER /SEALING LEM #2 @ 4992' SLM. DRIFT TO 5018' SLM W/ 20' OF 3 -3/8" DMY GUNS. RIH W/ 24.67'x3.675" BAKER ISOLATION SLEEVE (min id 2.21 " /xn nip). 2/18/2012 ***JOB CONTINUED ON 2/19/12 * ** ** *JOB CONTINUED FROM 2/18/12 * ** SET 24.67'x3.675" BAKER ISOLATION SLEEVE (min id 2.21"/xn nip) @ 5018' S LM. SET 2 -7/8" XXN PLUG IN ISOLATION SLEEVE @ 5014' SLM SET 45 KB PACKER cD 4988' S LM 2/19/2012 ** *WELL S/I ON DEPARTURE, PAD OP NOTIFIED OF STATUS * ** • TREE _ ° 4-1/16" CIW WELLHEAD= 11'FMC • v -205 SAFZTYNOTES:4- 112 " CHROME TBG 1 ACTUATOR = LEO L 1 & L2 KB ELEV = 82.89' BF ELEV 54.5' I I LI KOP= ... _. 700' Max Angle = 93° @ 9179' 20# CONDUCTOR, H 80' , , I 2318' H4-1/2" HES X NIP, ID = 3.813" 1 Datum MO = 5123' 91.4#, A -53, GAS LIFT MANDRELS Datum TV D = 4400' SS ID =1 9.124'" ST AID TVD DEV TYPE VLV LATCH PORT DATE 110 -3/4" CSG, 45.5 #, L -80, ID = 9.95° H 3047' 4 2632 2497 31 KBG2 DMY BK 0 02/18/07 3 3327 3099 30 KBG2 DOME BK 16 08/26/11 17 -5/8" CSG, 29,7 #, L -80 BTC XO TO TCII �— 4465 5C * 2 3975 3658 32 KBG2 SO BK 20 08/26/11 1 4753 4263 48 KBG2 OMY BK 0 08/26/11 Minimum ID = 2.21" @ 5035' 2 -7/8" OTIS XN NIPPLE I I I I 4871' -- 14 -1/2" BKR CND SLIDING SLV, ID = 3.813" PHOENIX DISCHARGE PRESS —1 4861' 4915' 1- 17 -5/8" X 4 -1/2" BKR PREM PKR, ID = 3.870" GAUGE, ID = 3.940" PHOENIX INTAKE PRESSURE —1 4893' 4942' H41/2 HES X NIP, ID = 3.813 "' 1 GAUGE, ID = 3.948" ' ' ii 1 463 9' I —14 -1 /2"' HES X NIP, ID = 3.813" 1 17 -5 /8" RA TAG 1 49 73' I 4976' 1-- 17 -5/8" X 4-1/2" BKR ZXP LIP w1T1EBK, ID = 4.950" I 4-1/2" TBG, 12.6 #, 13CR VAM TOP, —1 4990' 0 .0152 bpf, ID = 3.958" - 1 4990' H41 /2" MULE SHOE, ID = 3.958 1 15 -1 /2" X 4 -1 /2" X0, ID = 3.960" H 4995' 1- ----------- 2 /.1 4994' — {4 -1/2' X 2 -7/8 KB PKR ASSY, ID = 2.45" III! 6a 6a _ _ _ RR_ _ _ e e - - - - L2 (OA) LEM WINDOW 56" BAKER HOOK HANGER —I_ 5013' U (OA) �I 5018' - 5029' i'/' w !SEA LING LEM #2, ID = 3.688" OPENING WIDTH = 3.33" 12 -7/8" NAJL.ESHOE, ID = 244" H 5037' 1— �, - - - �� - - - �� - - 5035' 2-7/8" 0 XN NAP, ID = 2.21" 7 -5/8" RA TAG 5 105' H 1 '111 1.-: 5 2 -718" XXN PLUG (02/19/12) �'-- 5094' 7 -5/8" X 5-1/2" BKR ZXP LTPw /TIEBK, ID = 4.950" 15 -12" X 4-1/2" X0, ID = 3.960" H 5133' I 5121' H4112" SEAL ASSEMBLY, ID = 3.89" 1 BAKER HOOK HANGER -1 5151' IA tgl - - - 1811a_ - - ►•1 4 - - - - L1 (0Ba) LE1ut WINDOW 60° w/ SEA LINGLEM #1,ID= 3.688" p' Ll (a3a) - �1 5155' -5166' _ OPENING WIDTH = 3.33" PERFORATION SUMMARY ' /:4 e - - - NE- - - - �g REF LOG: ANGLE AT TOP PERF: ®--1 FISH: 2 -7 /8" MD MOTOR ELEMENTS (1025/09) 1 Note: Refer to Ftoductan DB for historical pert data II 5228' —1 7 5!8" X 5-1/2" BKR ZXP LTP, ID = 5.75" 1 SIZE I SFF I I INTERVAL I Opn/Sgz I DATE I SEE PAGE 2 FOR PERFORATION DETAILS 5266' H4 -314" BKR SEAL ASSEMBLY, ID = 3.870" I I I I I . 5276' H5" X 4-1/2" XO, ID = 3.960" 1 [7 -5/8" RA TAG H 5405' V 17 -5/8" CSG, 29.7 #, L -80 BTC -M, ID = 6.875" H 5693' 1 I I I I I I V -205 IPBTD 1 9621' OBd DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNT 02118107 N9ES ORIGINAL COMPLETION 09/30/09 TW /SV PERF CORR (DATES) WELL V -205 04/26/07 /TLH GLV C/O (04/17/07) 12/19/09 JKD'SV FISH (10/25/09) PERMIT No: 2061800 (10) (20) 04/18/08 JCNYTLH PULL RHC PLUG (04/17/07) 08/29/11 CDJ/ PJC GLV GO (8/26/11) API No: 50- 029 - 23380 -00 (60)(61) 06/23/08 7 /PJC DRLG DRAFT CORRECTIONS 02/23/12 CDJ/ PJC KB PKR w / XXN PLUG (2/19/12) SEC 34, T11 N, R11 E, 4692' FSL & 1619' FEL 07/26/08 TW /PJC DRLG DRAFT CORRECTIONS 12/04/08 DAV /PJC GLV GO (11/27/08) BP Exploration (Alaska) • V -205 • L1 &L2 I 1 1 1 iJ 11111 1 I 1 • t a (OA PBTD I M � 1 �I 4 SWELL PACKER'S, ID = 3,90" '.,,,oAmo, @ 5098', 5652', 6113', 6742', 8681' & 9259' • 5030' - 11370' 6 -3/4" OA LATERAL 4-1/2" LNR, 12.6#, L -80 IBT -M, .0 158 bpf, ID = 3.958" PERFORATION SUMMARY A. REF LOG: ANGLE AT TOP PERF: ( OBa PBTD I MEMO Note: Refer to Rroduction DB for historical perf data - - - �®.- - - pl Iq I�t - - - - SIZE SPF ZONE INTERVAL Opn /Sqz DATE � 4-12"' SLTD OA 5695 - 6097 SLTD 02/15/07 4 - 1/2" SWELL PACKER'S, 10 = 3.90" 4-1/2' SLTD 6765 - 8664 SLTD 02/15/07 @ 5265', 5621', 7965, 8440', 9535 & 9909' 4-1/2' SLTD 9280 - 11307 SLTD 02/15/07 e - - - 4-1/2" SLTD OBa 5649 - 7949 SLTD 02/08/07 4-1/2' SLTD " 8463 - 9519 SLTD 02/08/07 5167' - 11355' 6 -3/4" OBa LATERAL 4-1/2' SLTD " 9932 - 11307 SLTD 02/08/07 4-1/2" LNR, 12.6 #, L -80 IBT -M, 0158 bpf, ID = 3.958" 4-1/2' SLTD OBd 5697 - 8039 SLTD 01/30/07 4-1/2' SLTD " 8561 - 9621 SLTD 01130/07 • 41 i I i I 8057' H4 -1 SWELL PKR, ID = 3.813 " I ►1 L8517' I— I4 -1/2 " SWELL PKR, ID = 3.813" I V-2051 5693' - 9625' 6 -3/4" OBd LATERAL 4-1/2" LNR, 12.6 #, L -80 IBT -M, .0158 bpf, ID = 3.958" 'O u DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 02/18107 N9FJ; ORIGINAL COMPLETION 09/30/09 TW /SV PERF CORR (DATES) WELL: V -205 04/26/07 /TLH GLV C/O (04/17/07) 12/19/09 JKD/SV FISH (1025/09) PERMIT No: 2061800 (10) (20) 04/18/08 JCM'TLH PULL RHC PLUG (04/17/07) 0829/11 CDJ/ PJC GLV GO (8/26/11) AIR No 50- 029 - 23380 -00 (60)(61) 06/23/08 ? /PJC DRLG DRAFT CORRECTIONS 02/23/12 CDJ/ PJC KB PKR w / XXN PLUG (2/19/12) SEC 34, T11 N, R11 E, 4692' FSL & 1619' FEL 07/26/08 TW /PJC DRLG DRAFT CORRECTIONS 12/04/08 DAV /PJC GLV CJO (11/27/08) BP Exploration (Alaska) Wells with ice plugs during to shut -do. • Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator @bp.com] Sent: Saturday, January 15, 2011 1:40 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) 1 Cc: AK, D &C Well Integrity Coordinator 6 fu- In Subject: Wells with ice plugs during to shut -down Jim, The following wells were found to have ice plugs in the tubing. They are all artificially lifted producers that are stacked out with aas lift on the IA. The plan forward is to have a pumping unit thaw the ice plugs by pumping down the backside. We will keep you informed of the progress and any other wells with ice plugs as they are discovered. V -05 (PTD # 2080930) /V -205 (PTD #2061800) 5V9V4E0 FE 0 i ZD1 °E Z -46A (PTD #2052030) Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 1/24/2011 a ~~ ~? ~u ~a.~ ~~ t ~~ ~~~ fi; 3 ~~ ~~: ~ m ~~~~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • BP Exploration (Alaska) Inc. Attn: Well Integriry Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 c~+~i~`'~~'ti~'' % ~,~'+. •! y ~# ~,~v~ August 14, 2009 C~ bp ~~~~f~~~ OCT 0 5 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB V-Pad Dear Mr. Maunder, Al~lc~ Oil ffi Gas Con~. ~ammi~~ion Anchor~pe ~o (~ -~ L ~o ~f ~ ~os+ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB V- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • . BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date V-pad 8/13/2009 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls ft na al V-01 2040900 50029232100000 NA 2 NA 17 6/30/2009 V-02 2040770 50029232090000 NA 3 NA 43.4 7/11/2009 V-03 2022150 50029231240000 surface NA NA NA NA V-04 2061340 50029233220000 NA 1.5 NA 20.4 6/29/2009 V-05 2080930 50029233910000 NA 1.75 NA 20.4 5/10/2009 V-07 2071410 50029233720000 NA 0.25 NA 1.7 6/29/2009 V-100 2010590 50029230080000 NA 1.5 NA 20.4 5/9/2009 V-1ot 2020560 50029230740000 NA 3.75 NA 32.3 7/10/2009 V-102 2020330 50029230700000 NA 7.75 NA 98.2 8!7l2009 V-103 2021860 50029231170000 NA 0.5 NA 9.4 7/12/2009 V-104 2021420 50029231030000 NA 1.5 NA 21.3 7/11/2009 V-105 2021310 50029230970000 NA 2.25 NA 23.8 6/29/2009 V-106A 2041850 50029230830100 NA 1.75 NA t7 6/29/2009 V-107 2021550 50029231080000 NA 1.75 NA 13.6 7/11/2009 V-108 2021660 50029231120000 NA 1.5 NA 14.5 7/10/2009 V-1o9 2022020 50029231200000 NA 1.2 NA 10.2 6/30/2009 V-111 2031030 50029231610000 NA 1.5 NA 11.9 7/12/2009 V-112 2060200 50029233000000 NA 1.5 NA 15.3 5/10/2009 V-113 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009 V-114A 2031850 50029231780100 NA 2.5 NA 34 6/30/2009 V-115 2040270 50029231950000 NA 1.5 NA 13.1 5/9/2009 V-117 2030900 50029231560000 NA 1.25 NA 22.1 5/10/2009 V-119 2040410 50029232010000 NA 2 NA 18.7 6/30/2009 V-120 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009 V-121 2070360 50029233480000 NA 1.9 NA 17 6/30/2009 V-122 2061470 50029233280000 NA 1.5 NA 6.8 5/10/2009 V-2o~ 2012220 50029230540000 SCleak NA 4 NA 90.6 8/7/2009 V-202 2030770 50029231530000 NA 1.75 NA 12.8 7/11/2009 V-203 2051680 50029232850000 NA 2 NA 12.8 7/10/2009 V-204 2041310 50029232170000 NA 2 NA 22.1 6/30/2009 V-205 2061800 50029233380000 NA 1.8 NA 13.6 6/30/2009 V-207 2080660 50029233900000 NA 1.75 NA 18.28 1/9/2009 V-210 2042100 50029232310000 NA 2 NA 18.7 7/11/2009 V-211 2042200 50029232320000 NA 1.5 NA 13.6 7/10/2009 V-2i2 2051500 50029232790000 NA 12 NA 11.9 6/29/2009 V-213 2041160 50029232130000 NA 1.75 NA 6.3 5/9/2009 V-214 2051340 50029232750000 NA 0.5 NA 9.4 7/11/2009 V-215 2070410 500292335t0000 NA 2.8 NA 30.6 6/30/2009 V-216 2041300 50029232160000 NA 1.5 NA 13.6 6l29/2009 V-2t7 2061620 50029233340000 NA 2.3 NA 25.5 6/30/2009 V-218 2070400 50029233500000 NA 2 NA 17.9 7/12/2009 V-219 2081420 50029233970000 NA 1 NA 16.2 7/12/2009 ~9 2080200 50029233830000 NA 1.75 NA ~b 3/9l2008 V-221 2050130 50029232460000 NA 0.8 NA 8.5 6/29/2009 V-222 2070590 50029233570000 NA 2.5 NA 21.3 7/11/2009 V-223 2080220 50029233840000 NA 2 NA 20.5 9!7/2008 1g~~ DATA SUBMITTAL COMPLIANCE REPORT 11!18/2008 Permit to Drill 2061800 Well Name/No. PRUDHOE BAY UN ORIN V-205 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23338-00-00 MD 9625 TVD 4700 Completion Date 2/18/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey es DATA INFORMATION Types Electric or Other Logs Run: MWD / GR, MWD / GR / RES / AZI DEN / NEU / PWD, MWD / GR / R (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 0 9625 Open 3/13/2007 ppt Directional Survey 0 9625 Open 3/13/2007 / ~ .l~D C Lis 15663+ Induction/Resistivity 110 9624 Open 11/9/2007 LIS Veri, GR, ROP, FET, RPS, DRHO, NPHI w/PDS graphics wog Induction/Resistivity 2 Blu 110 9625 Open 11/9/2007 MD Vision Service 29-Jan- 2007 ~g InductionlResistivity 2 Blu 110 9625 Open 11/9!2007 TVD Vision Service 29-Jan- ' 2007 ~ ~~ !Cog Production 5 Col 4590 5397 Case 6/4/2008 PPL, MPL, Pres, GR, CCL, Temp, ILS, Spin 18-May- / , ~/ I " 2008 CED C Las 16359 See Notes 0 0 6/4/2008 PPL and Stop Counts in LAS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comme nts ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? ~ N Chips Received? Y-HMI-- ( ~~ ~ Formation Tops ~'Y~'~ Analysis Received? • Comments: DATA SUBMITTAL COMPLIANCE REPORT 11 /18/2008 Permit to Drill 2061800 Well Name/No. PRUDHOE BAY UN GRIN V-205 Operator BP EXPLORATION (ALASKA) INC MD 9625 TVD 4700 Completion Date 2/18/2007 Completion Status 1-OIL Current Status 1-OIL Compliance Reviewed By: API No. 50-029-23338-00-00 UIC N Date: 9 • LL ~_~ ~ / /~ ~ ~~~, - - - -;,- ProActive Diagnostic Services, Iac. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hote/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by retul^ning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907 245-8952 1) Production Profile 2] Signed Print Name: 18-May-08 V-205 Date PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 98518 PHONE: (907245-8951 FAX: (907245-88952 E-MAIL . ., . .. ~~~.: ,~~ _-, WEBSITE _ ., .. c70Co ~ /l36 i G~~~ 1 Color Log / EDE 50-029-23338-00 C:\DocumenLs and Settings\Owne~Desktop\Transmit_BP.doc 11/08/07 r Schlamberger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 4487 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Aurora Orion Date BL Color CD S-201 11676972 LDL 17/07107 1 S-126 11594528 ISOLATION SCANNER 11101107 1 V-205 40014729 OH MWDILWD EDIT / 01129107 2 1 V-205L1 40014729 OH MWDILWD EDIT / 02103/07 1 1 V-205L2 40014729 OH MWDILWD EDIT 02112/07 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH T0: BP Exploration (Alaska) Inc. Petrotechnical Dala Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 ~ Dale Delivered: - Schlumberger-DCS 2525 Gambell St SUItA, 4gfr Anchorage, AK 99503. 2E3°38 ' ATTN: Beth - - Received by: (gl°'Gd~ /, ~~~ ~)I~t~'' ~- , ~9, '' a 6"~~ ~ STATE OF ALASKA ~ ~~~ ~ 8 2007 ALASKA~L AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons~~L~i~@~IAPLETION OR RECOMPLETION REPORT AND LOG Anchorage 06/08/07: Revised, Put on Production 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 20AAC 25.105 zoAAC zs.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Abag~,/ 02/18/2007 ~~~~ 12. Permit to Drill Number 206-180 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 1 /19/2007. 13. API Number 50-029-23338-00-00 4a. Location of Well (Governmental Section): Surface: 4 ' S ' 7. Date T.D. Reached 1/28/2007 14. Well Name and Number: PBU V-205 692 F L, 1619 FEL, SEC. 11, T11N, R11E, UM Top of Productive Horizon: 2680' FSL, 1198' FEL, SEC. 11, T11 N, R11 E, UM (OBd) 8. KB (ft above MSL): 82.89' Ground (ft MSL): 54.39' 15. Field /Pool(s): Prudhoe Bay Field / Orion Total Depth: 85' FSL, 252' FWL, SEC. 01, T11 N, R11 E, UM 9. Plug Back Depth (MD+TVD) 9625 4700 Schrader Bluff 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 590684 y- 5969941 Zone- ASP4 10. Total Depth (MD+TVD) 9625 4700 16. Property Designation: ADL 028240 TPI: x- 591131 y_ 5967934 Zone- ASP4 Total Depth: x- 592546 y- 5970636 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submi el ctroni and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1786' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD / GR, MWD / GR /RES / AZI DEN /NEU /PWD, MWD / GR /RES / AZI DEN /NEU /AIM /PWD 22. CASING, LINER AND CEMENTING RECORD (;,ASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM ' `.SIZE CEMENTING REGORD PULLED 20" x 34" 21 .5# A5 Surface 110' Surface 110' 48" 260 sx Arcti Se A r x. 10-3/4" 45.5# L-80 29' 3047' 29' 2856' 13-1/2" 575 sx AS Lite 400 sx Class'G' 7-5/8" 29.7# L-80 26' 5693' 26' 4670' 9-7/8" 248 sx Class 'G' 181 sx Class'G' 4-1l2" 12.6# - 0 5228' 9623' 4534' 4700' 6- /4" n m n d Slotted Liner 23. Open to production or inject ion? ®Yes ^ No 24. Tuelroc RECORD If Yes, IISt each i (MD+TVD of Top & Bottom; Pe nterval Open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 4-1/2" Slotted Section 4-1/2", 12.6#, 13Cr80 4990' 4915' MD TVD MD TVD 5697 - 8039' 4671' - 4701' 8561' - 9621' 4703' - 4700' 25. ACID, FRACTURE,. CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT He KIND OF MATERIAL USED 2650' Freeze Protect w/ 110 Bbls of Diesel 26. PRODUCTION TEST Date First Production: May 30, 2007 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date Of Test: 6/3/2007 HOUrS Tested: 6 PRODUCTION FOR TEST PERIOD OIL-BBL: 2g2 GAS-MCF: 711 WATER-BBL: -0- CHOKE SIZE: 92 GAS-OIL RATIO: 2,432 Flow Tubing Press. 340 Casing Press: 1,200 CALCULATED 24-HOUR RATE OIL-BBL: 1,169 GAS-MCF: 2,843 WATER-BBL: -0- OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD 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 results p~ensr 20 AAC~~250.071. taVi~i -Ii01V { None ~~- {~1N 1.$ ~Q~7 ~. ~'~~ '. !.' Form 10-407 Revised 02/2007 ~r 'i ~ ~ ~ i ~ n ~ONTINUED ON REVERSE SIDE I ly ~ 28. ~xEOLOGIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested . ^ Yes No Permafrost Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base 1815' 1786' detailed test information per 20 AAC 25.071. Ugnu 3131' 2929' None Ugnu MA 4469' 4061' Ugnu MB1 4538' 4112' Ugnu M62 4643' 4188' Ugnu MC 4730' 4248' Schrader Bluff NB 4792' 4289' Schrader Bluff NC 4842' 4321' Schrader Bluff NE 4853' 4328' Schrader Bluff NF 4953' 4388' Schrader Bluff OA 5027' 4431' Schrader Bluff OBa 5156' 4499' Schrader Bluff OBb 5240' 4540' Schrader Bluff OBc 5386' 4600' Schrader Bluff OBd 5606' 4659' Schrader Bluff OBd 9217' 4700' Schrader Bluff OBd 9365' 4699' Formation at Total Depth (Name): Schrader Bluff OBd 9365' 4699' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Rubble/ Title Technical Assistant Date ~ ~~(~ PBU V-205 206-180 Prepared ey NameMumber. Terrie Hubble, 564-4628 Drilling Engineer: Scott Kolstad, 564-5347 Well Number Permi No. / A royal No. INSTRUCTIONS GeweRAL: 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 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 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. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 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. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submlt detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL APK Y Y 2007 Alaska Oil & Bas Cons. Commission) Ancfiorago 1. Operator: 4a. Well Class: Stratigraphic Service 6. Permit to Drill Number: 205-180 FEX L.P. Development ^ Exploratory Q 7. Well Name: AKLAQ #2 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^ 8. API Number: 3601 C Street, suite 370, Anchorage, AK 99503 GINJ ^ WINJ ^ WDSPL ^ 50- 279-20014 3. (Check one box only) 5a. Sundry Number: 5b. Sundry approval date: 9. Field: Wildcat Initial Disposal ^ Continuation Q Final ^ 306-387 12/15/2006 10 (h)(1) drilling mud, drilling (hx2) drill rig wash fluids (hx3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids and drill rig domestic waste approved substances (include days Beginning Dates: Ending cement-contaminated drilling water descriptions in block 12) disposal Dates: mud, completion fluids, occurred: formation fluids and any necessary water added. Previous 4850 611 60 5521 13 04!04/06 04/17!06 AKLAQ #2 totals (bbls): 2006/04 0 0 0 0 0 2007/01 4759 790 278 5$27 6 03108/07 03/30/07 AMAGUQ #2, AKLAOYAAO #1 YYYY/Q# YYYY/O# Total 9609 1401 338 11348 19 Re ort is due on the 20th P Ending Volume of the month following the final month of the quarter. Ex: (bbls): April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test [] October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Diesel for freeze protect. Description(s): I hereby certify that the foregoing is true and correct to the best of my knowledge. '/~ ~ ~ 4/10/2007 Signature: ~ Q~ f"'/Q-~---- Date: Printed Paul Mazzolini Title: Operations Manager Phone g07-771-1923 Name: Number: Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate ~~C. v -_ i _ v 1t ia: u. 1, tAC~~UC7L IV1 iR1~.. ;4UU;c: Subject: Re: V _ ~ ~rariance Request for flow paddle From: Tho as Maunder <tom_maunder~aadmin.state.ak.us> Date: Fri, 30 Mar2007 14:31:01 -0800 To: "Peltier, Brandon" ~Brandon.Peltier~bp.com> CC: "Tirpack. Robert B" ~Robert.Tirpack~~BP.com> Brandon. Thanks for the reply. I have not had a chance to look in at your attachment. Having good lift pressure does help the case for isolation. As I indicated, the files I could examine did not have that information. If I need anything else, I will get back to you. Tom Maunder, PE AOGCC Peltier, Brandon wrote, On 3/30/2007 2:09 PiVI: Tom ( have been on the slope; so (was not able to respond earlier this week. V-01: Returns were minimal aster 75 bbls were outside the shoe. With 75 bbls out; the TOC would be in the CM2, therefore the Kuparuk would be covered. The question is if the Schrader Bluff was covered after returns diminished. I reviewed the actual pump pressures (see attached file) and it does show good lift after the pack-off occurred. The actual lift pressure trends do correspond with modeled lift pressure trends, they show about a 1200 psi increase from the time the cement first rounds the corner till pumping is completed (with the actual pressure adjusted for the 1000 psi pack-off pressure increase). That being the case, the cement calculations submitted 4vere for the total volumes pumped. ._.~ V-205: (attached the cement plot. It shows good lifting pressure during the cement placement. With the plot showing good lifting pressures, the cement calculations used the total volumes pumped. I hope this is helpful. Let me know if you want additional information. Brandon Peltier BP Exploration (Alaska), Inc. Operations Drilling Engineer GPB Rotary Drilling (907) 564-5912 (Direct) (907) 748-7838 (Mobile) Brandon.Peltier(c~bp.com From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, March 27, 2007 2:20 PM To: Peltier, Brandon Cc: Tirpack, Robert B Subject: Re: V-215 Variance Request for flow paddle ~'~ 1 of 4 4/2/2007 11:30 AM i . _._ .~. _.,.,~.. ,_~...~.,~_., uu~., Brandon. I am continuing m~ work on this permit application. In ~~orkin~ to confirm thz l ~'=I mite information I have developed some questions. 1. I concur with your assessment of V-119. 2. On V-20~, the 7" cementing operations report from 1'26107 indicates that 60 bbls of fluid were lost during the cementing operation. Do you have information that shows pumping pressure increasing throughout the job? Since there is no mention of a "loss of returns", it is probable that the Schrader is isolated. 3. I cannot verify your assessment of V-O1 w-ith the file information I have available. The report of the 7" cementing operations from 6,'29'04 indicates that "returns were minimal" with 7~ bbls of lead slurry out of the shoe and that a total of 165 bbls of cement was lost during the cement. job. 7~ bbls of slurry is not sufficient to give the top of cement you list. Do you have additional information that shows pumping pressure rising as the job proceeds? Your comments will be appreciated. Thank in advance. Call or message with any questions. Tom Maunder, PE AOGCC Peltier, Brandon wrote, On 3; 26/2007 10:09 Ati'1: f agre hat you are correct in regard to the pressures listed in block 17 ,The pressures shown are surface h e pressures and they should be the intermediate pressure . I have also atta ed the as-staked for you. it was not done when submitted the permit application Brandon Peltier BP Exploration (Alaska), Inc. Operations Drilling Engineer GPB Rotary Drilling (907) 564-5912 (Direct) (907) 748-7838 (Mobile) Brandon.Peltier(ct7bp.eom },, From: Thomas Maunder [mailto:to _maunder~~admin.state.a Sent: Friday, March 23, 2007 4:4 PM To: Peltier, Brandon Subject: Re: V-215 Variance equest for flow paddle Brandon, >~ Your statement will fit the need. Would you please check your calculations on t surface 2 of 4 4/2/2007 11:30 ANI Schlamberger Wef! d-205 Field GPB Engineer Gary Giersdorf Country United States --- - Time - Pressure 03:30:35 i 03:41:00 03:51:00 04:01:00 04:11:00 04:21:00 04:31:00 '~ '. 04:41:00 ~' 04:51:00 i ~ ~~lerttl~~ ~®~ ~ep®1°t CemCATvLO Client B.P.Exploration SIR No. Z20I073624 ]ob Type 7 5/8 Intermediate lob Date 01-26-2007 _ __ _ . -Rate Density Wellhead Pressu Messages Start Job Start Pumping Water -----.-_.- Pressure Test lines ~. Reset Total, Vol = 4.83 bbl End Water '.. Start Pumping Spacer End Spacer '~ Drop Bottom Plug '. Reset Total, Vol = 49.66 bbl , Start Mixing Tail Slurry , + 1 ~ Durostone ~r 05:01:00 I~ Il ~'.. ` `_ 06:13:04 I hh:mm:55 ~, o.o0 1000 2000 3000 4000 5000 0.00 2.~ 4.0 6.0 8.0 10.0 5.0 10.0 15.0 30.0 Z5.0 0.00 933 366] 2500 3333 416] 5000 ov=m~aoo os..m~. PSI 8/M LB/G PSI I End Tail Slurry ~~, Drop Top Plug ~, Start Pumping Water '.. Reset Total, Vol = 92.26 bbl End Water '~. Reset Total, Vol = 5.21 bbl ~. Mudpush At Shoe ~. i Cement Turning the corner i I I DuraSTONE at Shoe ~. Bump Top Plug 3580 Strokes, 253 bbls mud End Job 01/26/2007 13:47:53 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1~~D'' ~:~~~ ~ 4 2007 WELL COMPLETION OR RECOMPLETION REPORT AND LOG,~~ ~~ ~~ ~~~, Cornmissi0q 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAACZS.~os zoAACZS.»o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Ab 02/18/2007 ~ 'b 12. Permit to Drill Number 206-180 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 1/19/2007 ~ 13. API Number 50-029-23338-00-00 4a. Location of Well (Governmental Section): Surface: 4 ' S ' 7. Date T.D. Reached 1/28/2007 14. Well Name and Number: PBU V-205 692 F L, 1619 FEL, SEC. 11, T11N, R11E, UM Top of Productive Horizon: 2680' FSL, 1198' FEL, SEC. 11, T11 N, R11 E, UM `(OBd) 8. KB Elevation (ft): 82.89' 15. Field /Pool(s): Prudhoe Bay Field / Orion Total Depth: 85' FSL, 252' FWL, SEC. 01, T11N, R11E, UM ~ 9. Plug Back Depth (MD+TVD) 9625 ' + 4700 Ft Schrader Bluff 4b. Location of Well (State Base Plane Coordinates): Surface: x- 590684 y- 5969941 Zone- ASP4 10. Total Depth (MD+TVD) 9625 ~ + 4700 Ft 16. Property Designation: ADL 028240 ~ TPI: x- 591131 y_ 5967934 Zone- ASP4 Total Depth: x- 592546 y- 5970636 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD / GR, MWD / GR /RES / AZI DEN /NEU /PWD, MWD / GR /RES / AZI DEN /NEU /AIM /PWD 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT SIZE WTc PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 215.5# A53 Surface 110' Surface 110' 48" 260 sx Arctic Set A rox. 10-3/4" 45.5# L-80 29' 3047' 29' 2856' 13-1 /2" 575 sx AS Lite 400 sx Class 'G' 7-5/8" 29.7# L- 26' S6 26' 4670' 9-7/8" 248 sx Class 'G' 1 1 sx Class 'G' 4-112" 12.6# L-80 5228' 9623' 4534' 4700' 6-3/4" Uncemented Slotted Liner 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SEr MD PACKER SET MD 4-112" Slotted Section 4-1/2", 12.6#, 13Cr80 4990' 4915' MD TVD MD TVD 5697 - 8039' 4671' - 4701' 8561' - 9621' 4703' - 4700' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT St KIND OF MATERIAL USED 2650' Freeze Protect w/ 110 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Production Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO FIOW TUbing Press. CaSing PreSSUre CALCULATED 24-HOUR RArE.• OIL-BBL - GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet; if necessary). Submit core chips; if none, state "none". MAi~ ;~ #~ 20D7 ~/~G~ None }Yr~ lid /~5~ Form 10-407 Revised 12/2003 ~"''t t T TIUED ON REVERSE SIDE /J r ~~ ~e i 5 ~ ~' ~ I l pis 28 GEOLOGIC MARKS 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAtvte MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 3131' 2929' None Ugnu MA 4469' 4061' Ugnu MB1 4538' 4112' Ugnu M62 4643' 4188' Ugnu MC 4730' 4248' Schrader Bluff NB 4792' 4289' Schrader Bluff NC 4842' 4321' Schrader Bluff NE 4853' 4328' Schrader Bluff NF 4953' 4388' Schrader Bluff OA 5027' 4431' Schrader Bluff OBa 5156' 4499' Schrader Bluff OBb 5240' 4540' Schrader Bluff OBc 5386' 4600' Schrader Bluff OBd 5606' 4659' Schrader Bluff OBd 9217' 4700' Schrader Bluff OBd 9365' 4699' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. ~~~ Signed Terrie Hubble ~ Title Technical Assistant Date 13 d PBU V-205 206-180 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A r val N Drilling Engineer: Scott Kolstad, 564-5347 INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 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. IreM 4b: TPI (Top of Producing Interval). ITenu 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. Irenn 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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). IreM 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only gp Page 1 of 1 Leak-Off Test Summary Legal Name: V-205 Common Name: V-205 ___ __ Test Date Test Type 1 /22/2007 LOT 1/27/2007 FIT - - _ _ __-, Test Depth (TMD) I Test Depth (TVD) AMW Surtace Pressure Leak Off Pressure (BHP) EMW - ___ _ _ 3,047.0 (ft) 2,856.0 (ft) 8.90 (ppg) 740 (psi) 2,060 (psi) 13.89 (ppg) 5,393.0 (ft) 4,671.0 (ft) 9.20 (ppg) 560 (psi) 2,792 (psi) 11.51 (ppg) Printed: 2/19/2007 1:08:46 PM BP Operations Summary Report Page 1 of 23 ~ Legal Well Name: V-205 (Common Weli Name: V-205 Spud Date: 1/19/2007 ,Event Name: DRILL+COMPLETE Start: 1/18/2007 End: 'Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/18/2007 Rig Name: NABOBS 9ES Rig Number: Date ~ From - To Hours Task ~ Code~PT Phase Description of Operations 1/18/2007 ~ 07:00 - 15:00 8.010 MOB P ~ ~ PRE Move Rig On Same Well Row, V-2171 => V-205 15:00 - 22:00 I 7.001 RIGU I P I I PRE 22:00 - 00:00 2.00 RIGU P PRE 1/19/2007 00:00 - 02:00 2.00 RIGU P PRE 02:00 - 02:30 0.501 RIGU P PRE 02:30 - 06:00 3.50 RIGU P PRE 06:00 - 07:00 1.00 RIGU P PRE 07:00 - 07:30 0.50 RIGU P PRE 07:30 - 08:00 0.50 RIGU P PRE 08:00 - 18:30 I 10.501 DRILL I P 18:30 - 19:00 0.50 DRILL P 19:00 - 00:00 5.00 DRILL P ~ 1/20/2007 100:00 - 01:30 1.501 DRILL P Set wellhead equipment and diverter behind rig. Lay herculite, spot rig over well. Install rig mats under rig and set down rig. Level sub base. Position and spot mud pits to rig. Level mud pits. Accepted Rig ~ 15:00 hrs 1/18/2007 Nipple up Diverter line, Hydril, Riser & Flowline Install 4" Dump valves in conductor Take on Water and Mix Spud Mud Place DP and HWDP in Pipe Shed P/U 4" DP Singles From Pipe Shed, M/U Stands and set back P/U 4" DP &HWDP Singles From Pipe Shed, M/U Stands and set back Test Diverter Perform Accumlator test Low - 1800 psi, @00 Psi build 22 secs., Full recovery 2:02 minutes - 6 Nitrogen Bottles -Avg 2050 psi Test Witness by BP WSL, Dave Newlon, NAD TP Roy Hunt Witness of test waived by Chuck Shieve, AOGCC PJSM, P/U BHA#1 as per Anadrill Directional Driller Service Rig & TDS Rig up HES slick line unit for Gyro Surveys Conduct Pre-Spud meeting with NAD TP & rig Crews, Service personel, BP WSL Test lines to 3000 psi Spud V-205 @ 08:00 1/19/2007 Drill 108' - 915' 80 Rpm , 2k Tq off / 3 Tq On 600 gpm, 1050 psi / 1500 on 10-25k WOB PUW= 65k, SOW=55k, RtWt= 60k 8.9 ppg & 350+ vis. SURF 8 GYRO Surveys , 100',200',300',400',500',600',700',800' SURF Rig Down Gyrodata sheaves and equipment SURF Dri11 Directionally as per Anadrill Directional Driller, 915' - 1294' (1289') 80Rpm,2kTgoff/3TgOn 660 gpm, 1950 psi / 2150 on 10-25k WOB PUW= 77k, SOW=69k, RtWt= 71k 9.1 ppg & 350+ vis. SURF Drill Directionally as per Anadrill Directional Driller, 1294' - 1349' 80Rpm,2kTgoff/3TgOn 660 gpm, 1950 psi / 2150 on 20-35k WOB PUW= 77k, SOW=69k, RtWt= 71k Printed: 2/19/2007 1:08:51 PM 1 ~ ~ BP Operations Summary Report Page 2 of 23 ~ Legal Well Name: V-205 Common Well Name: V-205 Spud Date: 1/19/2007 Event Name: DRILL+COMPLE?E Start: 1/18!2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/18/2007 Rig Name: NABOBS 9ES Rig Number: i Date From - To '. Hours ~ Task Code , NPT Phase i Description of Operations 1/20/2007 00:00 - 01:30 1.50 DRILL P SURF 01:30 - 02:00 0.50 DRILL N SFAL SURF 02:00 - 05:30 I 3.501 DRILL I P I I SURF 05:30 - 06:00 0.50 DRILL P SURF 06:00 - 08:30 2.50 DRILL P SURF 08:30 - 15:30 I 7.001 DRILL I P ( ~ SURF 15:30 - 17:00 1.50 DRILL P SURF 17:00 - 18:00 1.00 DRILL P SURF 18:00 - 18:30 0.50 DRILL P SURF 18:30 - 19:00 0.50 DRILL P SURF 19:00 - 19:30 0.50 DRILL P SURF 19:30 - 21:00 1.50 DRILL P SURF 21:00 - 00:00 3.00 DRILL P SURF 11/21/2007 100:00 - 02:30 I 2.501 DRILL I P 02:30 - 04:30 2.001 CASE P 9.1 ppg & 300+ vis. Repair Drag Chain - Reduced pump rate C~ 250 gpm /reciprocate pipe while repairing drag chain Drill Directionally as per Anadrill Directional Driller, 1349' - 1676' 80Rpm,3kTgoff/5TgOn 660 gpm, 2150 psi / 2350 on 20 - 35k WOB PUW= 80k, SOW=70k, RtWt= 75k 9.1 ppg & 300+ vis. CBU 3x ~ 650 gpm 12225 psi 80 rpm / 3k TO, 75 RtWt Short trip 1676 - 271', -Some minor tight tight spots w/10-15k overpulls Drill Directionally as per Anadrill Directional Driller, 1676' - TD / 3058' (2865' tvd) 80 Rpm , 4k Tq off / 7 Tq On 680 gpm, 3200 psi / 3350 on 20 - 35k W OB PUW= 100k, SOW=90k, RtWt= 95k Intermittent Hydrates present from 2150' to TD 9.6 ppg & 300+ vis. CBU 3x C~ 700 gpm / 3325 psi 100 rpm / 3k TO, 95 RtWt Monitor hole, static Mud Wt. 9.6 ppg in/out POH from 3058' to 2058', experiencing 20-25k overpulls Backream from 2048' to 1581', no problems 656 gpm / 2350 psi 80 rpm / 3k tq. RIH (/1581 - 1782' ,taking 30k more than normal drag Work tight area down with 80 spm / 230 gpm / 550 psi 30 rpm /3ktq Worked 1780 =>1866', Backream up ~ full rate, worked area without pump, no problems, O.K. continue RIH t/3000', no problems CBU 2x C~ 700 gpm / 3325 psi 100 rpm / 3k TO, 95 RtWt Monitor hole, static Mud Wt. 9.6 ppg in/out POH from 3058' to 1880', experiencing 10-15k overpulls Work pipe f/1880 = 1581' with 90 spm(260 gpm)/650 psi, 35 rpm / 2k tq continued POH to BHA seeing Intermittent overpulls ~ 1150' to 700' Stand Back Jars & DC's in derrick L/D BHA #1 Lay down UBHO sub, XO sub, Stab, MWD, Stab, NMLC, Mud Motor, and break bit PJSM, Clear floor and Rig up casing running equipment for 10 3/4" casing Made Dummy Run with Landing Joint SURF SURF Printed: 2/19/2007 1:08:51 PM ~ ~ BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date i From - To 1 /21 /2007 04:30 - 14:00 14:00 - 15:00 15:00 - 18:00 18:00 - 21:00 21:00 - 22:30 22:30 - 00:00 1 /22/2007 00:00 - 01:00 01:00 - 03:00 03:00 - 06:00 06:00 - 08:00 08:00 - 12:30 V-205 V-205 DRILL+COMPLETE NABOBS ALASKA DRILLING NABOBS 9ES ~. Hours ~ Task ~ Code ~ NPT ~_ 9.50 ~ CASE ~ P Start: 1 /18/2007 Rig Release: 2/18/2007 Rig Number: Phase Page 3 of 23 Spud Date: 1/19/2007 End: Description of Operations SURF PJSM -Run 75 jts of 45.5# L-80 10 3/4" BTC surface casing. -Bakerlock Shoe Track -TO to 8900 ft/Ibs / BOL 2000NM pipe dope -25 -Bow Spring centralizers ran on the first 25 joints into hole -2139' - 3047' intermittent tight spots 1.00 CEMT P SURF R/D Franks Fill up tool and M/U 10 3/4" double plug Cement Head 3.00 CEMT P SURF Circulate and condition mud to 60 s/qt funnel vis, 17 YP -Comprehensive Pre-Job meeting with D/S cementers, BP WSL, NAD TP & rig crew, -Pre-job meeting with BP WSL, VECO truck drivers, MI mud engineer and Applicable NAD rig hands 3.00 CEMT P SURF Cement surface pipe -Pump 5 bbls of water, Test line to 3500 psi, O.K. -Pump 75 bbls of MudPush II @ 10.1 ppg -Drop Bottom plug -Pump 464 bbls of Lead Arcticset Lite cement ~ 10.7 ppg Pump 82 bbls of Class "G" tail cement ~ 15.8 ppg -Drop top plug and chase with 10 bbls of water Turn over to rig pumps and displace cement with 275.5 bbls of 9.6 mud @ 8 bpm initially -Mudpush II back after 52 bbls displaced, slowed pumps to 5.5 bbls to handle clabbered mud -Good cement returns after 141 bbls displaced -134 bbls of cement returns to surface Bumped plug ~ 3916 strokes / 275.5 bbls (96% eff.) increased pressure from 750 psi to 1300 psi -Bled pressure off and check floats, O.K. CIP C~3 20:45 hrs 1.50 CEMT P SURF Rig Down Cement head, -Break out and UD Landing Joint, -Flush stack & Flow line, -Flush Hydril & Diverter Knife valve 1.50 DIVRTR P SURF N/D 20" riser, Remove 4" valves in conductor, -R/D Diverter Line, -L(D Csg. Equip. and Long Bails from rig floor 1.00 DIVRTR P SURF Set Hydril Back on stand 2.00 WHSUR P SURF Install casing head.Test metal to metal seal to 1,000 psi - 10 minutes - OK. M/U Tubing Spool and working valves 3.00 BOPSU P SURF N/U BOP's, drilling nipple & flowline 2.00 BOPSU P SURF Make up wash tool and flush stack, Function BOP Rams, Flush stack and lay down wash tool 4.50 BOPSU P SURF PJSM, Install test joint and plug, R/U test equip, fi{I stack, manifold & lines, -Test Bope, 250 low, 3500psi high, holding each test for 5 min. -Test #1 -Top Rams, Dart, HCR Kilf, and choke manifold valves 1,2&3 -Test #2 -choke manifold valves 4,5 & 6 -Test #3 -choke manifold valves 7,8 7 9 Printed: 2/19/2007 1:08:51 PM BP Page 4 of 23 Operations Summary Report Legal Well Name: V-205 Common Well Name: V-205 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES I Date ;From - To Haurs Task Code ~ NPT P ~- 1/22/2007 08:00 - 12:30 4.50 BOPSUf~ Spud Date: 1/19/2007 Start: 1 /18!2007 End: I Rig Release: 2/18/2007 Rig Number: Phase ~ Description of Operations SURF -Test #4 -hydraulic choke & manual choke -Test #5 -choke manifold valves 10,11, 14 & TIW, inner annular valve -Test #6 -choke manifold valve #15 -Test #7 -Annular, Lower IBOP, HCR Choke& Kill valves -Test #8 -Manual Choke & Kill valve, Lower IBOP -Test #9 -Lower Pipes & Upper IBOP -Test #10 -choke manifold valves 12 , 13 & Blind Rams Accumulator test Initial pressure 3050, 1,750 psi after functioning all valves, 24 sec for 200 psi, 2 min 14 sec for full recovery to 3,050 psi Average charge for 6 bottles of Nitrogen is 2,066 psi Test Witness by AOGCC Chuck Shieve, BP WSL Brian Buzby and NAD TP Kelly Cozby 12:30 - 13:00 0.50 BOPSU P SURF Remove test plug and Install wearbushing 13:00 - 15:30 2.50 DRILL P INT1 PJSM, P/U 48 jts of 4" HT40 DP and standback in derrick 15:30 - 18:00 2.50 DRILL P INT1 PJSM, Included Installing source procedure -M/U BHA #2- 9 7/8" PDC bit, PDM, XO,NM STAB, LWD/MWD, 2x NMDC's, 5"HWDP, Hyd. Jar, 5"HWDP, XO, 24 x 4" HWDP, 12 X 4" DP, XO, Ghost Reamer, XO, -Source Installed -MWD shallow hole tested ~ 997' - 604 GPM, 890 psi, -Good Test 18:00 - 19:30 1.50 DRILL P INTi RIH to 2920' 19:30 - 20:00 0.50 DRILL P INT1 CBU @ 200 spm, 492 gpm, 1360 psi, 30 rpm, 3k tq, -PUW - 102k, SOW - 75k, RtWt - 92k 20:00 - 21:00 1.00 DRILL P INT1 Test 10 3/4" casing to 3500 psi for 30 min. -10 (.6 bpm)spm, 74 (4.2 bbls) total. strokes to pressure 21:00 - 22:30 1.50 DRILL P INT1 Wash down and tag cement 20' above float collar ~ 2940', -clean out cmt down to FC, Tag ~ 2962', -Drill Shoe track @ 588 gpm, 1958 psi, 65 rpm, 4k tq Pump High Vis pill and displace to new 8.8 LSND mud, Continued to drill Float Shoe ,rat hole & 20' of new hole 22:30 - 23:00 I 0.501 DRILL I P 23:00 - 23:30 I 0.501 DRILL I P 23:30 - 00:00 I 0.50 I DRILL I P 1/23/2007 100:00 - 11:00 I 11.001 DRILL I P INT1 CBU @ 240 spm / 588 gpm! 1138 psi / 65 rpm 3k tq 8.9 ppg / in & out INT1 Perform LOT with 8.9 ppg mud -Pumped ~ 10 spm (.58 bpm) -Pressued built to 840 psi before leaking off a 740 psi -3.0 bbls pumped / 2.4 returned -EMW 13.88 ppg -held pressure for 10 min. - bleed off and blow out lines INT1 Circulate ~ drilling rates and estab{ish benchmark ECD readings -Perform SPR's INT1 Drill Directionally as per Anadrill Directional Driller, 3078' - 4068' (3736'tvd) -80 Rpm , 5k Tq off / 7 Tq On -588 gpm, 1400 psi off / 1550 psi on -5-20k WOB Printed: 2/19/2007 1:08:51 PM BP Operations Summary Report Page 5 of 23 ~ Legal Well Name: V-205 Common Well Name: V-205 Spud Date: 1/19/2007 Event Name: DRILL+COMPLETE Start: 1/18/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/18/2007 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours ask ,Code NPT Phase ~ Description of Operations 1/23/2007 ~ 00:00 - 11:00 11.00 ~ DRILL ~ P ~ ~ INT1 11:00 - 11:30 I 0.501 DRILL I P I I INT1 11:30 - 13:00 I 1.501 DRILL I N I HMAN I INT1 13:00 - 14:00 1.00 DRILL N HMAN INT1 14:00 - 15:00 1.00 DRILL N SFAL INT1 15:00 - 15:30 0.50 DRILL N HMAN INT1 15:30 - 02:00 10.50 DRILL P INTi 11/24/2007 100:00 - 15:00 I 15.001 DRILL I P I I INT1 15:00 - 22:00 I 7.001 DRILL I P I I INT1 22:00 - 00:00 I 2.001 DRILL I P I I INT1 1/25/2007 100:00 - 01:30 I 1.501 DRILL I P I I INT1 01:30 - 02:00 0.50 ~ DRILL P INT1 02:00 - 03:30 1.50 DRILL P INT1 -PUW= 116k, SOW=88k, RtWt= 100k -CECD = 9.04 /AECD = 9.29 Backream full stand each connection, reduced pump rates to 75% of drlg. rate on down stroke Pumped High Vis pill ~ 3550'md, 0% increase in return cuttings AST=4.2 hrs /ART=4.94 hrs. CBU 1 x -Reciprocating full stand 590 gpm = 1580 psi, 80 rpm / 6k tq MW = 8.9 ppg in/out Pulled 4068 - 3500', started to swab & pull 10k over Backream from 3500' to 3015' (shoe) 279 gpm 1560 psi, 65 rpm / 4k tq. Change pump liners from 5" to 5 1/2" Change out Link Tilt directional valve on TDS RIH f/3015 - 4068' Tight at 3541' worked through without problems Drill Directionally as per Anadrill Directional Driller, 4068' - 4545' (4123'tvd) - 80 Rpm , 4k Tq off / 7 Tq On - 711 gpm, 2400 psi off / 2580 psi on - 5-15k WOB -PUW= 122k, SOW=95k, RtWt= 110k -CECD= 9.20/AECD=9.45 - Backream full stand each connection full drilling rates, - reduced pump rates to 75% of drlg. rate on down stroke AST=4.81 hrs /ART=1.43 hrs. Drill Directionally as per Anadrill Directional Driller, 4545' - 5700' (4673' tvd) - 80 Rpm , 4k Tq off 16 Tq On - 711 gpm, 2650 psi off / 2900 psi on - 10-20k WOB -PUW= 116k, SOW=96k, RtWt= 107k - CECD = 9.331 AECD = 9.69 - Backream full stand on each connection at full drilling rates, - reduced pump rates to 75% of drlg. rate on down stroke -AST=8.89 /ART=2.75/ADT=11.64 Backream @ 225'/hr for MAD pass log from 5700 - 4600' - 665 gpm / 2440 psi - 104 rpm / 3.5k tq. Continued Backreaming ~ >1000'/hr - 665 gpm / 2040 psi - 80 rpm / 3k tq. no problems Backreaming out Continued Backreaming to shoe ~ >1000'/hr - 665 gpm / 2040 psi - 80 rpm / 3k tq. no problems Backreaming out CBU 1x ~ 680 gpm 1 1900 psi - 80 rpm / 3k tq / 90k RtWt Monitor well, static MW 9.2ppg in/out Printed: 2/19/2007 1:08:57 PM BP Operations Summary Report Page 6 of 23 ~ Legal Well Name: V-205 Common Well Name: V-205 Spud Date: 1/19/2007 Event Name: DRILL+COMPLETE Start: 1/18/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/18/2007 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours ~ Task I Code NPT Phase Description of Operations 1/25/2007 02:00 - 03:30 1.50 DRILL P INT1 POH to BHA 03:30 - 04:00 0.50 DRILL P INT1 PJSM, L/D BHA -Safety meeting with Schlumberger Anadrill MWD hands safety issues handling LW D source -Remove Source from LW D -L/D DC's, MWD/LWD, XO's PDM Break Bit and clear floor of BHA 04:00 - 04:30 0.50 DRILL P INT1 VD BHA down to LWD ~', -HWDP,JARS, HWDP, 2xNMDC's 04:30 - 06:00 1.50 DRILL N SFAL INT1 Remove Source from LWD - Removal tool failure, tool unable to grasp source - Removed source with secondary tool I~ 06:00 - 07:30 1.50 DRILL P INT1 Continued Laying down BHA -L/D LWD, MWD, Stab, Mud Motor & Bit Bit Grade 2-2-WT-N-X-I-CT-TD 07:30 - 08:00 0.50 BOPSU P INT1 Clear Floor and pull Wear Bushing 08:00 - 10:00 2.00 BOPSU P INT1 PJSM ', Flush Stack, Install -Test Plug & 7 5/8" test joint -Change out 3 112" variab{es to 7 518" rams 10:00 - 10:30 0.50 BOPSU P INT1 Test 7 5/8" rams to 250 psi low / 3500 high held each test for 5 min. & charted, good test BP WSL Alan Madsen &NAD TP Kelly Cosby witness of test R/D test equip. & UD test Joint 10:30 - 13:00 2.50 CASE P INT1 PJSM, Rig up casing running equipment -Install Long Bails, Franks fill up tool, Elevators, Slips, Power Tongs, Stabbing Board, ect. 13:00 - 18:30 5.50 CASE P INT1 PJSM w/BP WSL, NAD TP & Rig Crews, Service Hands -Ran 7 5/8" intermediate casing as per running detail. ', Bakerlocked connections to 1 jt above float collar. -check floats. O.K. -Ran 28 jts. 7 5/8" 29.7# BTC-M casing using Best-O-Life 2000 pipe dope, Torque to 8200 ft/Ibs ~ -M/U TCII Box xBTC-M XO jt I -continued to running in to shoe with 7 5/8" 29.7# TCII casing. Torqued Turn to 9000 fUlbs, doped with Jet Lube Seal Guard, -Fill each joint & Break circ. every 10 jts. -record up & down weights every 10 jts i Ran 2 centralizer per joint except for joints where whipstock windows are located 76 centralizers ran & 38 stop rings I 18:30 - 19:30 1.00 CASE P INT1 CBU 1.5x @ 10 3/4" shoe I -253 gpm (6 bpm), 346 psi, PUW 116k, SOW 100k "'CIO Franks Swab Cup 19:30 - 00:00 4.50 CASE P INT1 -continued to running to 5344" with 7 5/8" 29.7# TCII casing. Torqued Turn to 9000 ft/Ibs, doped with Jet Lube Seal Guard, -Fill each joint & Break circ. every 15 jts., circ f/20 minutes -record up & down weights every 10 jts 1/26/2007 00:00 - 01:00 1.00 CASE P INT1 -continued to running to 5693" with 7 5/8" 29.7# TCII casing. -Torqued Turn to 9000 fVlbs, doped with Jet Lube Seal Guard, Printed: 2/19/2007 1:08:51 PM BP Operations Summary Report Page 7 of 23 ~ Legal Well Name: V-205 Common Well Name: V-205 Spud Date: 1/19/2007 Event Name: DRILL+COMPLETE Start: 1/18/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/18/2007 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task ~ Code NPT Phase Description of Operations 1/26/2007 00:00 - 01:00 1.00 CASE P INT1 -Fi11 each joint & Break circ. every 15 jts.& circ f/20 minutes -record up & down weights every 10 jts PUW = 170K /SOW = 125K No Problems & Full Returns when RIH 01:00 - 01:30 0.50 CEMT P INT1 Pulled Slips, Laydown Franks tool, R/U cement head, and cement lines 01:30 - 03:30 2.00 CEMT P INT1 Circulate & Condition Mud for cement job Staged Pumps up 2 bpm f/10 min, 4 bpm f/5 min, 6 bpm f/ bottoms up Circ. one full circulation C~ 7 bpm No Losses during Circulation PJSM with DS, NAD TP & Rig Crew, BP WSL 03:30 - 05:30 2.00 CEMT P INT1 Pump 5 bbls of water, Test lines to 3500 psi, Pump 50 bbls of 11 ppg Mud push Il, Drop Bottom plug, Pump 52 bbls of 15.8 ppg "G" cement, Pumped 38 bbls of 16.3 ppg "G" cement with Durastone @ 5 bbls /min, Drop Top Plug and chase with 5 bbls of water, Turn over to Rig and displace with mud @ 5 bpm, reciprocated throughout job, slowed pumps, to 2 bbl/min 700 psi, the last 100 strokes, bumped plug with 3575 strokes (96% eff) -Riciprocrated anti! 200 strokes from bumping -Lost 60 bbl during the displacement, no other losses throughout job, -Landed casing with 120k down -check floats, O.K. -CIP @ 05:15 hrs 05:30 - 07:00 1.50 CEMT P INT7 Rig down cement head & cement line, -Lay Down Landing Joint -L/D Elevators and long bales -clear floor of all casing & cementing tools 07:00 - 07:30 0.50 CASE P INT1 Install 7 5/8" packoff & Test to to 5000 psi for 10 min., Good Test Out of the critical path activity; Perform LOT ~ 290 psi, Injected 1 bpm, 11.15 ppg EMW 07:30 - 09:30 2.00 BOPSU P INT1 Flush stack and drain -Install Test Plug Change out 7 5/8" Rams to 3 1/2" x 6 variables 09:30 - 11:00 1.50 BOPSU P INT1 PJSM, R/U and test Rams with 4" and 4 1/2" test Joint -Test to 250 psi low & 3500 psi high ,held each test for 5 min. Good Test, No Failures Witness of test by NAD TP Kelly Cosby 11:00 - 15:00 4.00 DRILL P PROD1 Pick up 4 HT40 15.7# DP and stand back in derrick Out of the critical path activity; -Injected 117 bbls of mud down 7 5/8 x x10 3/4 annulus -Injection rate of 3 bpm / 900 psi 15:00 - 16:00 1.00 DRILL P PROD1 PJSM, Schlumberger Source handling safety procedures discussed P/U BHA #3; 6 34" PDC, PDM, BP Sub, NM Stab, MWD/LWD, 2x NM Flex DC,Circ. Sub, XO 1 x DP, Jars, Printed: 2/19/2007 1:08:51 PM i ~Il gp Page 8 of 23 ~ Operations Summary Report Legal Well Name: V-205 ,Common Well Name: V-205 Spud Date: 1/19/2007 Event Name: DRILL+COMPLETE Start: 1/18/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/18/2007 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task ;Code I! NPT Phase Description of Operations i - - __ 1/26/2007 15:00 - 16:00 I 1.00 DRILL I P I PROD1 I RA Source Installed in LWD 16:00 - 22:30 6.50 DRILL P PROD1 RIH P/U DP 1 x 1 Out of the critical path activity; -R/U Little Red Services to inject down OA, Freeze Protected 10 3/4" x 7 5/8" annulus with 95 bbls of "Dead Crude" ICP ~ 1 bpm = 250 psi, FCP @ 2 bpm = 1200 psi 22:30 - 00:00 1.50 DRILL P PROD1 RIH with Stands to 5401' '.1/27/2007 00:00 - 01:30 1.50 DRILL P PROD1 Service TDS and Rig, -Slip and cut Drilling Line 01:30 - 03:00 1.50 DRILL P PROD1 PJSM, Rig up and test 7 5/8 casing to 3500 for 30 min. -Pressured up ~ 10 spm (0.6 bpm), charted test, -Good Test 03:00 - 04:00 1.00 DRILL P PROD1 Wash Down from 5497' to Float Collar, Tag on Depth ~ 5609' 285 gpm / 1190 psi, 60 rpm 3k tq 04:00 - 05:00 1.00 DRILL P PROD1 Drill cement, Shoe Tract, Shoe (5693') and rat hole to 5700' 285 gpm / 1190 psi off / 1280 on ii -60 rpm 3k tq off / 4k on ~ WOB-5-15k ~ PUW - 116k /SOW - 88k / RtWt - 98k 05:00 - 07:00 2.00 DRILL P PROD1 PJSM on Handling and displacing to MOBM, -Pumped 35 bbl High -Vis pill, -50 bbls of Hot water (100deg F) & soap pill, -268 gpm / 1260 psi - 80 rpm / 4k tq. -Displace well to 9.2 ppg Versa-Pro MOBM -300 gpm ! 1700 psi - 80 rpm / 4k tq. -reciprocating pipe 5693 - 5700' 07:00 - 10:00 3.00 DRILL P PROD1 Shut down on MOBM back to surface, pulled into shoe & blow down !, -Clean mud pit, flush mud lines, flush mud cleaning equipment, -ready pit room and Rig for MOBM operations 10:00 - 11:00 1.00 DRILL P PROD1 Drill 20' of new 6 1/8" hole to 5720' (4674' tvd) Conduct FIT to 11.5ppg EMW, 9.2ppg mud, surface pressure = 560 psi hold for 10 minutes and bleed off Conduct Benchmark ECD readings, 10.1 ppg ~ 290 gpm, 60 rpm Conduct SPR's fps 5698 (4672' tvd) 11:00 - 00:00 13.00 DRILL P PROD1 Drill Directionally as per Wellsite Geologist, 5720' - 7184'(4690' tvd) -60Rpm,3.4kTgoff/4.3TgOn - 300 gpm, 2600 psi off / 2900 psi on - 3-10k WOB -PUW= 119k, SOW=71 k, RtWt= 95k - CECD = 9.99 / AECD = 10.47 - Backream full stand on each connection - 30' surveys Printed: 2/19/2007 1:08:51 PM gp Page 9 of 23 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ; Name: ell Name: e: Name: From - To V-205 V-205 DRILL+C NABOBS NABOB Hours ~ OMPLE ALASK S 9ES Task TE A DRI Code LING NPT Start I Rig Rig Phase Spud Date: 1/19/2007 : 1/18/2007 End: Release: 2/18/2007 Number: Description of Operations _ 1/27/2007 11:00 - 00:00 _- 13.00 DRILL P PROD1 -___ - -AST = 4.65 /ART = 2.27 /ADT = 6.92 HSE Meeting. BP W SL Alan Madsen, NAD TP Kelly Cozby, Kelly Haug crew, NAD Support Crew, DD, and MI Mud Man -Discussed the feedback results from the investigative team regarding the allegations reported on 9ES. 1/28/2007 00:00 - 18:30 18.50 DRILL P PROD1 Drill Directionally as per Wellsite Geologist, 7184'-9625' (4701 tvd) TD well @ end of target polygon, TD @ 18:15 1-28-2007 - 70 Rpm , 5k Tq off / 6 Tq On - 300 gpm, 2950 psi off / 3150 psi on - 5-15k WOB - PUW= 136k, SOW=63k, RtWt= 100k - CECD = 10.25 / AECD = 10.97 - Backream 60' on each connection, - 30' surveys AST-4.38 /ART-4.81 /ADT- 9.19 18:30 - 19:00 0.50 DRILL P PROD1 Circulate for 15 min. 290 gpm / 2850 psi, 70 rpm / 5k tq Monitor well for 10 min., static Mud Wt 9.2 in/out 19:00 - 00:00 5.00 DRILL P PROD1 Mad Pass &Backream from 9625'-8647 -300 gpm / 2700 psi, 70 rpm 4k tq Backream ~ 600'/hr except 8647'-8527' Logged @ 200'/hr 1/29/2007 00:00 - 10:00 10.00 DRILL P PROD1 Mad Pass &Backream from 6500' - 5800' (100' below shoe) Pump back into shoe without rotation, -300 gpm / 2250 psi, 70 rpm 3k tq Backream ~ 600'fhr except 8248'-8128' Logged C~2 200'Jhr -~ 6750' hole drag, torque and pressure increased, -Ran in with stand and wipe area without problems, did not see it RIH 10:00 - 11:00 1.00 DRILL P PROD1 Pumped 25 bbl Hi-vis weighted sweep around 300 gpm, 2100 psi / 60 rpm, 3k tq. Reciprocrated full stand during circulation Sweep brought up 5-10% increase in cuttings 11:00 - 11:30 0.50 DRILL P PROD1 Sevice Rig and Top Drive System 11:30 - 14:00 2.50 DRILL P PROD1 RIH 5684' - 9625' -No problems running in -Filled Pipe 1x RIH ~ 14:00 - 14:30 0.50 DRILL P PRODi Break Circ. & CBU 1 x , ', -300 gpm, 2700 psi / 70 rpm, 4k tq PUW - 130k /SOW - 85k Reciprocate pipe full stand during circulation 14:30 - 16:00 1.50 DRILL P PROD1 Displaced over to Solids Free MOBM -300 gpm, 2700 psi / 70 rpm, 5k tq -Reciprocate pipe full stand during circulation !, 16:00 - 20:00 4.00 DRILL P PROD1 Monitor for 10mins. / 9.2 ppg in/out POH f / 9625 - 5452' ', Obtained up & Down weights every 5 stands in open hole 20:00 - 21:00 1.00 DRILL P PROD1 Backream/MAD pass, 5452 - 5020' -300 gpm, 2300psi / 70 rpm, 3k tq Verified RA tag depths on depth Printed: 2/19/2007 1:08:51 PM gp Page 10 of 23 Operations Summary Report Legal Well Name: V -205 Common W ell Name: V -205 Spud Date: 1/19/2007 Event Nam e: DRILL+C OMPLE TE Start : 1/18/2007 End: Contractor Name: NABOBS ALASK A DRI LLING I Rig Release: 2/18/2007 Rig Name: NABOBS 9ES Rig Number: Date ~ From - To Hours ~ Task Code ~ NPT ~hase Description of Operations 1/29/2007 21:00 - 00:00 3.00 DRILL P PROD1 POH to 5020 - 396' 1/30/2007 00:00 - 02:30 2.50 DRILL N RREP PROD1 Repaired Link tilt actuator valve on topdrive. 02:30 - 04:30 2.00 DRILL P PROD1 PJSM on nuclear source. Laydown Jars, stand back NM DC's, {aydown remainder of BHA. 04:30 - 05:00 0.50 DRILL P PROD1 Clear and clean rig floor. 05:00 - 06:30 1.50 CASE P RUNPRD Pick up 12 ea 4 3/4" Steel DC's for liner run and rack back in derrick. 06:30 - 08:00 1.50 CASE P RUNPRD Rig up to run 4.5" OBd Mother Bore liner. 08:00 - 14:30 6.50 CASE P RUNPRD PJSM on running liner. Pick up, make up and run in hole with 4.5" 12.6# L-80 BTC slotted, IBT solid liner to 4,341' ~ 90 fpm. Checked up and down weights every 25 joints. Make up torque - 3,500 ft/Ibs, used Best-O-Life NM 2000 pipe lubricant. 14:30 - 15:30 1.00 CASE P RUNPRD Pick up and make up SBE, 7 5/8" x 5 1/2" HMC liner hanger, and 7 5/8" x 5 1/2" HRD ZXP liner top packer with 11.03' x 5.75" ID Tieback. 'Ran total of 86 joints of slotted liner. 20 joints total of solid liner, 10 joints between Swell packers, 10 joints under packer tea 4.5" x 6.4" Swell Packers 110 centralizers - 1 locked in 5 ft above guide shoe 105 free floating on remainder of joints tea on each side of both Swell Packers 15:30 - 20:00 4.50 CASE P RUNPRD Run in hole with 4.5" liner on 4" drill pipe, 4" HWDP, and 4 3/4" steel drill collars from 4,406' to bottom @ 9,625', PU - 170k, SO - 60k. Checked up and down weights every 10 stands and prior to exiting 7 5/8" shoe. No mud lost and no other problems on trip in. 20:00 - 21:00 1.00 CASE P RUNPRD Pick up 2 ft off bottom. Circulate one drill pipe volume @ 4 bpm, 477 psi. Break out topdrive and drop 1.75" Baker Lite Ball. Make up topdrive and circulate down ball @ 4 bpm, 475 psi. Seat ball and pressure up to 1800 psi to set hanger. Set down 20k to confirm hanger set. Pressure up to 3,000 psi and hold for 5 min. Pressure up to 3,800 psi to set packer and hold for 2 min. Bleed pressure to 0 psi. Pick up 1 ft, close annular and pressure test packer to 2,000 psi for 5 min - OK. Pick up 6 ft then slack off while rotating and set 20k on liner. Pressure ~ up to 1,000 psi. Pick up 21 ft to pull out of seals. *Float shoe ~ 9,623'. Tops: Swell Packer #1 - 8,516' Swell Packer #2 - 8,057' ZXP Liner top Packer - 5,227' 21:00 - 21:30 0.50 CASE P RUNPRD Circulate bottoms up @ 300 gpm, 1,485 psi. 21:30 - 00:00 2.50 CASE P RUNPRD Monitor well - OK. Pump dry job and POH from 5,206' to 3,125'. 1/31/2007 00:00 - 01:30 1.50 CASE P RUNPRD Continue POH from 3,128' to surface. Inspect and laydown running tool. (Dogs out) 01:30 - 02:00 0.50 CASE P RUNPRD Clear and clean rig floor. 02:00 - 04:30 2.50 STWHIP P WEXIT Pick up and make up OBa whipstock assembly. 04:30 - 05:30 1.00 STW HIP P WEXIT Run in hole with 4 stands of 4 3/4" steel DCs and 8 stands of Printed: 2/19/2007 1:08:51 PM gp Page 11 of 23 Operations Summary Report Legal Well Name: V-205 Common Well Name: V-205 Spud Date: 1/19/2007 Event Name: DRILL+COMPLETE Start: 1/18/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/18/2007 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task ~ Code' NPT Phase ~ Description of Operations 1/31/2007 04:30 - 05:30 1.00 STWHIP P WEXIT HWDP to 1,276'. 05:30 - 09:00 3.50 STWHIP P WEXIT Run in hole with whipstock assembly, at 90 FPM from 1,276'to 09:00-09:30 I 0.501STWHIPIP I IWEXIT 13:30 I 4.OOISTWHIPIP I IWEXIT ~~~ 13:30 - 14:00 I 0.501 STWHIPI P I IWEXIT 14:00-17:30 3.50 STWHIP P WEXIT 17:30-18:30 1.00 STWHIP P WEXIT 18:30-19:00 0.50 STWHIP P WEXIT 19:00-00:00 5.00 STWHIP N WAIT WEXIT 2/1/2007 100:00 - 06:30 I 6.501 STWHIPI N I WAIT IWEXIT 06:30 - 07:00 0.50 STW HIP N WAIT WEXIT 07:00 - 09:00 2.00 DRILL P PROD2 09:00 - 09:30 0.50 DRILL P PROD2 09:30 - 11:30 2.00 DRILL P PROD2 11:30 - 12:00 0.50 DRILL P PROD2 12:00 - 13:00 1.001 DRILL I P I I PROD2 13:00 - 13:30 0.50 DRILL P PROD2 13:30 - 14:00 0.50 DRILL P PROD2 14:00 - 00:00 I 10.001 DRILL I P I I PROD2 5120. Screw into string with topdrive and orient whipstock to 18 left while working down to tag up on top on liner top packer at 5227. Observe several repeats from MWD indicating 18 left orientation. Record P/U ~ 125K and slack off ~ 90K. Tag liner top packer and slack off 10K on anchor and observe setting. P/U 10K over up wt. and confirm anchor is holding. Slack back off and set 45K down on brass lug and observe shear. Pick string back up to neutral position and rotate string free with 6,000 ft. pds. of tq. Swap out current SFMOBM with 9.2 MOBM ~ 300 GPM Mill window from 5155 to 5177 with: GPM=300, SPM=123 ~ 1840 PSI, RPM=95, WOB=3-5, TO=7,000 on and 5600 off. Continue to drill from 5177 to 5184 while letting upper watermelon mill dress window and ramp. ~ ~ ~ Pump 25 bbl. weighted sweep ~ 1.5 pounds over while working window from 5184 to 5150. Window looks good. Work mills in and out with no pumping or rotation. 145K up and 100K down with no pumps.Pump dry job and observe well for 5 minutes. Static. POH racking back DP to app. 1000 ft. Hole taking proper fill. Rack back 4 stands of 4 3/4 DC and 8 stands of 4" HWDP. Break, gauge and lay down mills. Upper watermelon mill full gauge. Clear floor of all excess vendors equipment. Pick up perforated stack flushing sub and flush stack while operating BOP equipment and valves. Wait on weather due to white out conditions with 40-50 MPH wind gusts. Equipment unable to support drilling operations due to emergency only travel. Conserve,fuel water and manpower. Continue waiting. Weather conditions improved but Phase 2, Level 3 still in place as of 03:00 hr. Crews able to change out at midnight with permission of Allen Graft. inspect derrick prior to operations due to previous high winds. Pick up and make up BHA #5: 6.75" DSX146H+GJNW bit # RR4, 1.5 deg AIM/PDM, bypass sub, NM Stab, MWD/LWD, VPWD, ADN, tea NM Flex DCs, Circ sub, XO, 1ea 4" DP, JAR. Run in hole with BHA #5 on drill pipe from 236' to 1,193': Shallow hole test MWD @ 275 gpm, 1,407 psi - OK. Continue running in hole from 1,193' to 5,116'. Fill pipe. Obtain ECD benchmark ~ 300 gpm, 0-60 rpm, CECD - 8.87 ppg. Cut and slip drilling line 84 ft. Inspect and clean under drawworks. Service topdrive and crown. Obtain benchmark ECDs ~ 300 gpm, 0-70 rpm, CECD - 10.01 ppg. Orient 18 deg left of high side and slide through window to bottom @ 5,184'. Directionally drill 6.75" OBa Li from 5,184' to 6,233'. 300 gpm, 2,380 psi off, 2,460 psi on, 70 rpm, 4.1 k TO off, 4.2k TO on, '~ Printed: 2/19/2007 7:08:51 PM ~ ~ gp Page 12 of 23 Operations Summary Report Legal Well Name: V-205 Common Well Name: V-205 Spud Date: 1/19/2007 Event Name: DRILL+COMPLETE Start: 1/18/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/18/2007 Rig Name: NABOBS 9ES Rig Number: Date From - To ~' Hours Task Code L NPT Phase -- - - 2/1/2007 14:00 - 00:00 10.00 DRILL P PROD2 2/2/2007 00:00 - 12:00 12.00 DRILL P PROD2 12:00 - 23:30 I 11.501 DRILL I P I I PROD2 23:30 - 00:00 I 0.501 DRILL I P I I PROD2 2/3/2007 100:00 - 04:30 I 4.501 DRILL I P I I PROD2 04:30 - 06:00 I 1.50 I DRILL l P I I PROD2 06:00 - 12:00 I 6.001 DRILL I P f I PROD2 12:00 - 19:00 I 7.001 DRILL I P I I PROD2 19:00 - 19:30 I 0.501 DRILL I P I I PROD2 19:30 - 20:30 I 1.001 DRILL I P I I PROD2 20:30 - 21:30 I 1.001 DRILL I P I I PROD2 21:30 - 22:00 I 0.501 DRILL I N I RREP I PROD2 22:00 - 23:00 I 1.001 DRILL I N I RREP I PROD2 23:00 - 00:00 I 1.001 DRILL I N I RREP I PROD2 Description of Operations PU - 109k, SO - 83k, RWT - 93k, WOB - 5/15k, AST - 5.05 hrs, ART - 0.94 hrs, CECD - 10.21 ppg, AECD - 10.40 ppg. Backream 60' at drilling rate prior to connections, 75% of rate on down stroke. Pumped a 25 bbl 1.5 ppg over sweep @ 5,846', 25% increase in cuttings observed on surface. Directionally drill 6.75" OBa L1 from 6,233' to 7,859'. 300 gpm, 2,750 psi off, 2,950 psi on, 70 rpm, 4.7k TO aff, 5.5k TO on, PU - 115k, SO - 75k, RWT - 95k, WOB - 5/15k, CECD - 10.27 ppg, AECD - 10.63 ppg, AST - 2.78 hrs, ART - 2.80 hrs. Backream 60' at drilling rate prior to connections, 75% of rate on down stroke. Directionally drill 6.75" OBa L1 from 7,859' to 9,198'. 300 gpm, 2,960 psi off, 3,080 psi on, 70 rpm, 5.8k TO off, 6.2k TO on, PU - 129k, SO - 73k, RWT - 97k, WOB - 5/15k, CECD - 10.49 ppg, AECD - 11.39 ppg, AST - 2.65 hrs, ART - 2.66 hrs. Backream 60' at drilling rate prior to connections, 75% of rate on down stroke. Circulate bottoms up for ECDs. 300 gpm, 2,925 psi, 70 rpm, 5.5k TO. IECD - 11.39 ppg, FECD - 11.08 ppg. Directionally drill 6.75" OBa Li from 9,198' to 9,677'. 300 gpm, 2,960 psi off, 3,160 psi on, 70 rpm, 6.3k TO off, 7.Ok TO on, PU - 129k, SO - 70k, RWT - 99k, WOB - 5l10k, CECD - 10.42 ppg, AECD - 11.39 ppg. Backream 60' at drilling rate prior to connections, 75% of rate on down stroke. Circulate bottoms up for ECDs. 300 gpm, 2,975 psi, 70 rpm, 6.3k TO. IECD - 11.39 ppg, FECD - 11.17 ppg. Circulate 1.5 ppg over weighted sweep surface to surface. FECD - 11.10 ppg. 10% increase in cuttings with sweep at surface. Directionally drill 6.75" OBa L1 from 9,677' to 10,441'. 300 gpm, 2,960 psi off, 3,160 psi on, 70 rpm, 6.3k TO off, 7.Ok TO on, PU - 129k, SO - 60k, RWT - 99k, WOB - 5/10k, CECD - 10.53 ppg, AECD - 11.33 ppg, AST - 1.88 hrs, ART - 2.51 hrs. Backream 60' at drilling rate prior to connections, 75% of rate on down stroke. Directionally drill 6.75" OBa L1 from 10,441' to TD C~ 11,335' MD, 4,592' TVD. 300 gpm, 3,130 psi off, 3,290 psi on, 70 rpm, 7.1 k TO off, 8.9k TO on, PU - 140k, SO - 54k, RWT - 96k, WOB - 5/10k, CECD - 10.61 ppg, AECD - 11.27 ppg, AST - 0.99 hrs, ART - 2.21 hrs. Backream 60' at drilling rate prior to connections, 75% of rate on down stroke. Circulate 15 minutes Q 300 gpm, 3,157 psi, 70 rpm, 7k TO. Obtain slow pump rates. Downlink data to MWD by using pump to adjust and speed data frames from drilling mode (300 fph) to logging mode (600 fph). MadPass log from 11,335' to 11,196'. 300 gpm, 2,595 psi, 70 rpm, 6.9k TO. Topdrive pipe handler would not lock. Trouble shoot problem. Pipe handler positioning pin disconnected from ram. Circulate bottoms up prior to working on topdrive. 300 gpm, 2,960 psi. Reciprocate pipe while circulating. Change out hydraulic cylinder and pin for pipe handler lock. Circulate @ 2 bpm, 500 psi. Printed: 2/19/2007 1:08:51 PM i ~ gp Page 13 of 23 ~ Operations Summary Report Legal Well Name: V-205 Common Well Name: V-205 Spud Date: 1/19/2007 Event Name: DRILL+COMPLETE Start: 1/18/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/18/2007 Rig Name: NABOBS 9ES Rig Number: Date ~, From - To Hours a Task Code ~ NPT ( Phase I Description of Operations 2/4/2007 ~ 00:00 - 11:30 11.50 ~ DRILL ~ P ~ROD2 Continue MadPass logging from 11,196' to 8,146'. 300 gpm, 11:30 - 13:30 I 2.001 DRILL I N I DFAL I PROD2 13:30 - 16:00 2.501 DRILL N DFAL PROD2 16:00 - 17:00 1.001 DRILL I N I DFAL PROD2 17:00 - 19:30 I 2.501 DRILL I N I DFAL I PROD2 19:30 - 21:00 1.50 DRILL N DFAL PROD2 21:00 - 21:30 0.50 DRILL N DFAL PROD2 21:30 - 22:00 0.50 DRILL P PROD2 22:00 - 00:00 2.00 DRILL P PROD2 12/5/2007 100:00 - 03:00 3.00 DRILL P I PROD2 03:00 - 03:30 I 0.501 DRILL I P I I PROD2 03:30 - 04:30 1.00 DRILL P PROD2 04:30 - 06:30 2.00 DRILL N DFAL PROD2 06:30 - 07:00 0.50 DRILL N DFAL PROD2 07:00 - 08:30 1.50 DRILL N DFAL PROD2 08:30 - 09:00 0.50 DRILL N DFAL PROD2 09:00 - 10:30 I 1.501 DRILL I N I DFAL I PROD2 10:30 - 12:00 I 1.501 DRILL I P I I PROD2 12:00 - 22:30 10.50 DRILL P PROD2 22:30 - 23:00 0.50 DRILL P PROD2 23:00 - 00:00 1.00 DRILL P PROD2 2/6/2007 00:00 - 02:30 2.50 DRILL P PROD2 02:30 - 03:30 I 1.001 DRILL I P I I PROD2 2,830 psi, 70 rpm, 5k TO. 600 fph except through Swell Packer sections done ~ 200 fph. Re-shot surveys @ 10,596', 10,243', 10,212', and 10,181'. Lost signal from MWD tool. Trouble shoot MWD with various pump rates. Lost 300 psi. Test surface circulating equipment - OK. POH wet for MWD failure and looking for possible washout from 8,146' to 5,116'. 9.2 ppg MW. Attempt to regain MW D signal without success. Compare s{ow pump rate with prior slow pump rates. 2 bpm - 40 psi difference. 3 bpm - 70 psi difference. Drilling rate @ 300 gpm - 530 psi difference Continue POH wet for MW D failure and looking for possible washout from 5,116' to 435'. PJSM on nuclear source. Laydown JAR, stand back NM DC's, and laydown remainder of BHA. No indication of any washouts on pipe or BHA. Clear and clean floor of MOBM. PJSM. Pull wear bushing and jet BOP stack. Rig up to test BOPE. Start pressure testing BOPE to 250 low psi and 3,500 high psi for 5 min each test. Continue pressure testing BOPE to 250 low psi and 3,500 high psi for 5 min each test. Tested Swaco Super Choke with same pressures. Test manual choke to 1,500 psi. Tested 2 flanged connections to 5,000 psi. All tests good. Performed accumulator test. Witnessing of test waived by AOGCC rep Jeff Jones. Test Witnessed by BP WSL R. French and NAD TP B. Tiedemann. Rig down BOP test equipment. Blow down surface lines. Install wear bushing. Change out topdrive quill and saver sub. Service topdrive. PJSM on nuclear source. Pick up BHA #6. Picked up new MWD, remainder of BHA the same. Run in hole 8 stands to 1,000'. Shallow hole test MWD ~ 308 gpm, 1,695 psi - OK. Continue running in hole from 1,000' to 5,114'. Fill drill pipe. Orient high side. Check pump pressure against previous run - OK. Slide through window and continue running in hole to 8,240'. 10-20k down drag from 6,220' to 8,145'. MadPass log from 8,240' to 7,880' ~ 600 fph, 400 fph in Swell Packer intervals. 300 gpm, 2,880 psi, 70 rpm, 4.5k TO. Mad Pass log from 7,880' to 5,230' ~ 600 fph, 400 fph in Swell Packer intervals. 300 gpm, 2,550 psi, 70 rpm, 4.7k TO. Re-take surveys @ 10 stations. Pull through window without pumping from 5,230' to 5,114'. Service topdrive and crown section. Cut and slip drilling line 65'. Inspect brakes and drum. Run in hole from 5,114' to 11,300' without problem. Washed last stand down to 11,355' - OK. Circulate a 1.5 ppg over weighted sweep surface to surface. Printed: 2/19/2007 1:08:51 PM • gp Page 14 of 23 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: From - To ate '', _ - 2/6/2007 ~ 02:30 - 03:30 03:30 - 05:00 05:00 - 09:30 09:30 - 11:00 11:00 - 13:30 13:30 - 15:00 15:00 - 15:30 15:30 - 16:30 16:30 - 17:00 17:00 - 17:30 17:30 - 20:30 20:30 - 22:00 22:00 - 00:00 2!7/2007 00:00 - 00:30 00:30 - 01:00 01:00 - 02:30 02:30 - 04:30 04:30 - 05:00 05:00 - 06:30 V-205 V-205 DRILL+COMPLE NABOBS ALASK NABOBS 9ES Hours :, Task ~ TE A DRI Code ~ LING NPT 1.00 DRILL P 1.50 DRILL P 4.50 DRILL P 1.50 DRILL P 2.50 DRILL P 1.50 DRILL P 0.50 DRILL P 1.00 WHIP P 0.50 WHIP P 0.50 WHIP P 3.00 WHIP P 1.50 WHIP P 2.00 WHIP P 0.50 WHIP P 0.50 WHIP P 1.50 WHIP P 2.00 WHIP P 0.50 WHIP P 1.50 WHIP P 06:30 - 07:00 0.50 WHIP P 07:00 - 07:30 0.50 CASE P 07:30 - 10:00 2.50 CASE P 10:00 - 18:00 8.00 CASE P Spud Date: 1 /19/2007 Start: 1/18/2007 End: I Rig Release: 2/18/2007 Rig Number: Phase Description of Operations PROD2 304 gpm, 3,060 psi, 70 rpm, 6.7k TO, CECD - 10.61 ppg, AECD - 10.70 ppg. No increase in cuttings with sweep back to surface. PROD2 Displace hole from 9.2 ppg MOBM to 9.2 ppg SFMOBM. 290 gpm, 2,980 psi, 70 rpm, 7k TO, PU - 145k, SO - 65k, RWT - 95k. PROD2 Observe well -static. POH to retrieve whipstock from 11,355' to 5,497'. Pumped dry job C~ 10,537'. Record PU and SO weights every 5 stands in open hole. PROD2 MadPass log from 5,497' to 5,260' @ 300 fpm. 300 gpm, 2,280 psi, 40 rpm, 3k TO, 95k RWT. Pull up through window without rotation to 5,114'. Pump dry job. PU - 115k, SO - 90k. PROD2 Continue POH from 5,114' to 331'. Recorded PU and SO weights every 10 stands in cased hole. PROD2 PJSM on nuclear source. Laydown JAR. Stand back NM DC's and laydown remainder of BHA. PROD2 Clear and clean rig floor. RUNPRD Make up Whipstock retrieval assembly. Hook, 1 joint 3.5" drill pipe, float sub, bumper sub, oil jars. RUNPRD Run in hole with whipstock retrieval assembly on 4" drill pipe 11 stands to 1,152'. RUNPRD Run in hole with 4 stands of steel DC's to 1,518'. RUNPRD Pick up 39 steel drill collars out of pipeshed and run in hole to 2,720'. RUNPRD Run in hole with 8 stands HWDP and continue running in hole on 4" drill pipe to 5,082'. Make up topdrive. PU - 153k, SO - 112k. RUNPRD Fill pipe and orient 18 deg. left of high side. 225 gpm, 1,350 psi. Attempt to hook whipstock without success. Wash out slot on whipstock. Continue fishing for whipstock by turning pipe in small increments before each pick up. RUNPRD Continue fishing for whipstock. PU - 155k, SO - 110k. 240 gpm, 1,705 psi. Turn pipe in 10 deg increments looking for whipstock. Hooked whipstock on 2nd time around ~ high side. Jar several times @ 200k to pull free. Lost 2 bbls after pulling seals free. RUNPRD Pull up to 5,120'. Circulate bottoms up @ 290 gpm, 2,375 psi. 9.2 PP9 MW. RUNPRD Monitor well -static. Pump dry job and POH from 5,120' to 2,718'. RUNPRD Stand back drill collars from 2,718' to 1,152'. RUNPRD Stand back HWDP and remainder of drill pipe from 1,152' to 99'. RUNPRD Laydown whipstock and retrieval assembly. Whipstock looked good. 9 ft from top of whipstock to wellbore exit indication. *Lost 20 bbls of mud on trip out. RUNPRD Clear and clean rig floor. RUNPRD Pick up and stand back 6 additional 4.75" steel DC's for liner run. RUNPRD Rig up to run L1 OBa slotted liner. RUNPRD PJSM. Pick up 4.5" 12.6# L-80 IBT slotted bent joint with shoe. Run in hole from surface to 5,155' @ 90 fpm. Make up TO - 3,800 ft/Ibs using Best-O-Life 2000 NM. Installed 4.5" x 6.125" Printed: 2/19/2007 1:08:51 PM gp Page 15 of 23 Operations Summary Report Legal Well Name: V -205 Common W ell Name: V -205 Spud Date: 1/19!2007 Event Nam e: DRILL+C OMPLE TE Start : 1/18/2007 End: Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 2/18/2007 Rig Name: NABOB S 9ES Rig Number: Date From - To Hours I Task Code ~~ NPT ~ Phase Description of Operations 2/7/2007 10:00 - 18:00 8.00 CASE P RUNPRD Volant centralizers, free floating on every joint starting with joint #3. Run swell packer as per detail Record PU and SO weights every 1,000' 18:00 - 22:00 4.00 CASE P RUNPRD Exit shoe on first try without any weight indications. PU - 86k, SO - 72k. Run in open hole from window to 6,202' ~ 60 fpm. Record PU and SO weights every 500'. Ran total of: 1 Bent 4.5" 12.6# L-80 IBT solid liner joint w/ float shoe. 121 ea 4.5" 12.6# L-80 IBT slotted liner joints. 26 ea 4.5" 12.6# L-80 IBT solid liner joints. 6 ea 4.5" x 6.4" Swell Packers with tea straight blade centralizers on each side of element (12 total centralizers) 10 ea 4.5" space out pup joints. 146 Volant centralizers. Baker Flanged Hook Hanger assembly with swivel. 22:00 - 23:30 1.50 CASE P RUNPRD Run in hole with liner on 20 stands 4" drill pipe, 7 stands HWDP from 6,202' to 8,851'. Record PU and SO weights every 500' 23:30 - 00:00 0.50 CASE P RUNPRD Run in hole with liner on 4.75" drill collars from 8,851' to 9,125'. `No mud losses after trip out with whipstock. 2!8/2007 00:00 - 01:30 1.50 CASE P RUNPRD Continue running in hole with 4.5" slotted liner on drill collars from 9,125' to 10,604'. Total of 19 stands of DC's. 01:30 - 02:00 0.50 CASE P RUNPRD Run in hole with 8 stand of drill pipe from 10,604' to 11,274'. Make up topdrive and run in hole with hook assembly missing window to 11,354'. PU - 220k, SO - 55k. 02:00 - 04:00 2.00 CASE P RUNPRD Pick up and start turning pipe in 270 deg increments, picking hook hanger assembly up appx 30' each try. Attempted to hang liner appx 20 times without success. After the initial pipe pick up, the down weight decreased to less than topdrive weight. Had to work down by bouncing brake. Finally hung liner off ~ calculated depth. Pick back up and slack back off with slack off weight increasing to 65k. Confirmed liner hang off by landing, picking up and turning pipe 180 deg and going past window. Repeat process twice with the same positive results. Land liner. PU - 220k SO - 65k 04:00 - 04:30 0.50 CASE P RUNPRD Drop 29/32" ball and pump down drill pipe ~ 3 bpm, 660 psi, slowing down to 2 bpm, 380 psi prior to seating ball. Seat ball and pressure up to 3,000 psi to release the HR running tool. Pressure up to 4,200 psi to shear the ball seat. Pick up and release from liner. PU - 150k. Shoe depth - 11,346'. Solid bent joint - 11,307' to 11,344' 35 jts Slotted liner - 9,932' to 11,307'. Swell Packer # 1 (element) - 9,909' to 9,919'. 8 jts Solid liner - 9,558' to 9,892'. Swell Packer # 2 (element) - 9,536' to 9,546'. 27 jts Slotted liner - 8,463' to 9,519'. Swell Packer # 3 (element) - 8,440' to 8,450'. 10 jts Solid liner - 8,009' to 8,424'. Swell Packer # 4 (element) - 7,965' to 8,475'. 59 jts Slotted liner - 5,649' to 7,949'. Printed: 2/19/2007 1:08:51 PM gp Page 16 of 23 Operations Summary Report Legal Well Name: V-205 Common Well Name: V-205 Spud Date: 1/19/2007 Event Name: DRILL+COMPLETE Start: 1/18/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/18/2007 ,Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task ~ Code NPT ~ Phase Description of Operations -- _ _ _ -- 12/8/2007 104:00 - 04:30 0.50 CASE P RUNPRD Swell Packer # 5 (element) - 5,621' to 5,631'. 7 jts Solid liner - 5,313' to 5,604' Swell Packer # 6 (element) - 5,265' to 5,275'. 1 jt Solid liner.- 5,206' to 5,248' Top of liner - 5,151' 04:30 - 05:00 0.50 CASE P RUNPRD Circulate bottoms up @ 252 gpm, 1,550 psi. 9.2 ppg MW. 05:00 - 05:30 0.50 CASE P RUNPRD Observe well -static. Pump dry job and POH from 5,144 to 4,409'. 05:30 - 07:30 2.00 CASE P RUNPRD POH standing back 19 stands of drill collars from 4,409' to 2,657'. 07:30 - 08:30 1.00 CASE P RUNPRD Continue POH standing back HW DP and drill pipe from 2,657' to running tool. 08:30 - 09:00 0.50 CASE P RUNPRD Make service breaks and laydown running tool. 09:00 - 10:00 1.00 CASE P RUNPRD Service topdrive and drawworks. 10:00 - 10:30 0.50 TIEBAC P OTHCMP Pick up LEM and 2 3/8" equipment to rig floor. 10:30 - 11:00 0.50 TIEBAC P OTHCMP Rig up to run L1 LEM #1. 11:00 - 13:00 2.00 TIEBAC P OTHCMP Pick up and make up LEM assembly. Baker non-locating Seal Assembly (spaced out for 10.3' entry into OBd Mother Bore Seal Bore Extension) XO joint 4.5" 12.6# L-80 IBT box X STL pin 1 joint 4.5" 12.6# L-80 IBT liner Hook Hanger LEM Baker 190-47 Seal Bore Extension 19.62' x 4.75" ID throat Baker "HRD" ZXP Liner Top Packer w/ 11.00' x 5.75" ID throat Total length - 172' Hydraulic setting tool & pup jt. 13:00 - 14:30 1.50 TIEBAC P OTHCMP Run in hole with LEM on drill pipe 20 stands and 8 stands of HW DP from 183' to 2,833' @ 90 fpm. 14:30 - 16:30 2.00 TIEBAC P OTHCMP Run in hole with 19 stands of 4 3/4" drill collars from 2,833' to 4,747'. 16:30 - 17:00 0.50 TIEBAC P OTHCMP Continue running in hole with LEM on drill pipe from 4,747' to 5,065'. PU - 150k, SO - 125k. 17:00 - 18:00 1.00 TIEBAC P OTHCMP Make up topdrive and lower pipe into top of L1 liner @ 5,151'. Continue slacking off. Set down @ 5,237'. Pick up 3 ft and pump @ 2 bpm, 600 psi. Wash down and enter Seal Bore Extension @ 5,256'. Slack off for 10 more feet to tag L1 liner. PU - 160k, SO - 118k in SBE. Latched LEM on top of L1 liner on depth @ 5,151', set down 100k. Drop and pump down 1.5" ball to seat @ 3 bpm, 795 psi. Slow rate to 2 bpm, 520 psi prior to ball seat. Seat ball and pressure up to 2,500 psi and hold to set ZXP liner top packer. Increase pressure to 4,200 psi to release running tool. Bleed off pressure, close pipe rams and test packer to 1,500 psi for 5 minutes - OK. Pick up and pull inner string seals out of LEM assembly. Tops: Seal Bore Extension - 5,113' Liner top Packer - 5,094' 18:00 - 19:30 1.50 TIEBAC P OTHCMP Circulate bottoms up @ 5 bpm, 920 psi. Shut down and monitor well -static. Pump dry job and blow down topdrive. 19:30 - 20:00 0.50 TIEBAC P OTHCMP POH standing back drill pipe from 5,075' to 4,414'. 20:00 - 23:30 3.50 TIEBAC P OTHCMP POH laying down 45 drill collars from 4,414' to 3,027'. 23:30 - 00:00 0.50 TIEBAC P OTHCMP POH standing back 4 stands of dril{ collars from 3,027' to Printed: 2/19/2007 1:08:51 PM gp Page 17 of 23 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: V ell Name: V e: Name: From - To -205 -205 DRILL+C NABOBS NABOBS Hours OMPLE ALASK 9ES Task ; TE A DRI Code LING NPT Spud Date: 1/19/2007 Start: 1/18/2007 End: I Rig Release: 2/18/2007 Rig Number: Phase Description of Operations 2/8/2007 23:30 - 00:00 0.50 TIEBAC P OTHCMP 2,662'. 2/9/2007 00:00 - 00:30 0.50 TIEBAC P OTHCMP Continue POH with LEM running tool, standing back HWDP from 2,662'to 1,927'. 00:30 - 01:30 1.00 TIEBAC P OTHCMP Cut & slip drilling line 85 ft. Clean out from under drawworks and inspect same. 01:30 - 02:00 0.50 TIEBAC P OTHCMP Continue POH from 1,927' to running tool. Running tool came out normal. 02:00 - 03:00 1.00 TIEBAC P OTHCMP Laydown running tool and inner string. 03:00 - 03:30 0.50 TIEBAC P OTHCMP Clear and clean rig floor. 03:30 - 04:00 0.50 STWHIP P WEXIT Pick up whipstock tools to rig floor. 04:00 - 07:00 3.00 STW HIP P WEXIT Pick up and make up L2 OA whipstock assembly. Spaced out for cutting top of window C~ 5,018'. 07:00 - 08:00 1.00 STWHIP P WEXIT Run in hole from 539' to 1,279' C~ 90 fpm. Shallow hole test MWD @ 255 gpm, 1,100 psi - OK. 08:00 - 10:00 2.00 STWHIP P WEXIT Continue running in hole with whipstock assembly from 1,279' to 5,039' ~ 90 fpm. PU - 125k, SO - 96k. 10:00 - 11:00 1.00 STWHIP P WEXIT Make up topdrive. Fill pipe and orient whipstock to 26 deg left of high side. 290 gpm, 1,920 psi, PU - 122k, SO - 90k. Lower pipe and tag up on depth with NO-GO on bottom of L1 packer seal bore extension ~ 5,094'. Set down 47k and set trip anchor. Pick up 10k over string weight to verify. Set down 70k to shear lug. Pick up free with 122k PU weight. Rotate at 15 rpm to verify release. Close annular and pressure test seals to 1,000 psi - OK. 11:00 - 12:00 1.00 STWHIP P WEXIT Displace well from 9.2 ppg SF MOBM to 9.2 ppg MOBM. 290 12:00 - 18:00 6.00 STWHIP P WEXIT Mill L2 OA window from 5,018' to 5,030'. 290 gpm, 1,725 psi, 85 rpm, 3-6k TO, 1-20k WOB. Pumped 25 bbl weighted sweep f i after mill stalled out when working pipe up 15 ft. No increase in ~ JV~ b metal cuttings with sweep back to surface. ROP increase when sweep went around mill. ~', 18:00 - 19:30 1.50 STW HIP P WEXIT Drill new hole with pilot mill from 5,030' to 5,048'. Upper 6 3/4" mill to 5,034'. 290 gpm, 1,695 psi, 85 rpm, 4-6k TO, 10k WOB. 19:30 - 20:00 0.50 STWHIP P WEXIT Circulate a 28 bbl weighted sweep surface to surface while dressing window. 290 gpm, 1,725 psi, 85 rpm, 4k TO, PU - 115k, SO - 98k. Shut down pumps and work up and down through window without rotating. Looked good. PU - 120k, SO - 100k without pumps. No increase in cuttings with sweep back to surface. 20:00 - 22:30 2.50 STWHIP P WEXIT Monitor well -static. Pump dry job and POH from 5,018' to 1,200'. 22:30 - 23:30 1.00 STWHIP P WEXIT Stand back HWDP and 4 stands of steel drill collars from 1,200'to 175'. 23:30 - 00:00 0.50 STWHIP P WEXIT PJSM. Start laying down whipstock milling assembly. 2/10/2007 00:00 - 00:30 0.50 STWHIP P WEXIT Continue laying down whipstock milling BHA. Pilot mill was flattened out. Upper mill was in gauge. 00:30 - 01:00 0.50 STWHIP P WEXIT Clear rig floor of milling tools. Jet BOP stack. 01:00 - 03:00 2.00 DRILL P PROD3 PJSM on nuclear source and BHA. Pick up and make up BHA #9: 6.75" DSX146H+GJNW bit # RR6, 1.5 deg AIM/PDM, bypass sub, NM Stab, MWD/LWD, VPWD, ADN, tea NM Flex DCs, Circ sub, XO, 1 ea 4" DP, JAR. 03:00 - 03:30 0.50 DRILL P PROD3 Run in hole with BHA #5 on drill pipe from 236' to 1,193'. Shallow hole test MWD C~3 290 gpm, 1,565 psi - OK. La Printed: 2/19/2007 7:06:51 PM .. , gp Page 18 of 23 Operations Summary Report 2/10/2007 03:30 - 05:00 1.50 DRILL P 05:00 - 05:30 0.50 DRILL P Date ~ From - To Hours ~ Task Code NPT Legal Well Name: V-205 Common Well Name: V-205 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES ~ I ~ 05:30 - 12:00 I 6.501 DRILL I P 12:00 - 00:00 12.001 DRILL P 2/11/2007 100:00 - 12:00 I 12.001 DRILL I P 12:00 - 00:00 I 12.001 DRILL I P 2/12/2007 100:00 - 06:30 I 6.501 DRILL I P 06:30 - 08:00 1.50 DRILL P 08:00 - 00:00 16.00 DRILL P 2/13/2007 100:00 - 08:00 I 8.001 DRILL I P 08:00 - 08:30 I 0.501 DRILL I P 08:30 - 09:30 I 1.001 DRILL I P Spud Date: 1/19/2007 Start: 1 /18/2007 End: I Rig Release: 2/18/2007 Rig Number: Phase Description of Operations PROD3 Continue running in hole from 1,193' to 4,924'. PROD3 Fill pipe and orient 26 deg left of high side. Obtain slow pump rates. Shut down pump and slide through window OK. Wash to bottom @ 5,048' ~ 300 gpm, 2,370 psi without rotating. PROD3 Directionally drill 6.75" OA L2 from 5,048' to 5,688'. 300 gpm, 2,390 psi off, 2,710 psi on, PU - 110k, SO - 81 k, RWT - 95k, WOB - 5/10k, CECD - 10.16 ppg, AECD - 10.62 ppg, AST - 3.07 hrs, ART - 0.35 hrs. Backream 60' at drilling rate prior to surveys and connections, 75% of rate on down stroke. PROD3 Directionally drill 6.75" OA L2 from 5,688' to 7,308'. 300 gpm, 2,590 psi off, 2,950 psi on, 70 rpm, 4.3k TO off, 5-6k TO on, PU - 110k, SO - 77k, RWT - 95k, WOB - 5/20k, CECD - 10.32 ppg, AECD - 10.87 ppg, AST - 3.33 hrs, ART - 2.68 hrs. Backream 60' at drilling rate prior to surveys and connections, 75% of rate on down stroke. Pumped a 1.5 ppg over weighted sweep @ 6,359'. No increase in cuttings with sweep back to surface. PROD3 Directionally drill 6.75" OA L2 from 7,308' to 9,293'. 300 gpm, 2,885 psi off, 3,165 psi on, 70 rpm, 4.9k TO off, 6.3k TO on, PU - 125k, SO - 71 k, RWT - 94k, WOB - 5/15k, CECD - 10.60 ppg, AECD - 11.45 ppg, AST - 1.07 hrs, ART - 4.58 hrs. Survey every 30', backream 60' at drilling rate prior to surveys and connections, 75% of rate on down stroke. PROD3 Directionally drill 6.75" OA L2 from 9,223' to 10,663'. 300 gpm, 3,040 psi off, 3,290 psi on, 70 rpm, 6k TO off, 7k TO on, PU - 132k, SO - 69k, RWT - 99k, WOB - 5/15k, CECD - 10.52 ppg, AECD - 10.70 ppg, AST - 2.58 hrs, ART - 2.20 hrs. Survey every 30', backream 60' at drilling rate prior to surveys and connections, 75% of rate on down stroke. PROD3 Directionally drill 6.75" OA L2 from 10,663' to TD ~ 11,370' MD, 4,535' TVD. 300 gpm, 3,005 psi off, 3,190 psi on, 70 rpm, 7.2k TO off, 8.1 k TO on, PU - 133k, SO - 57k, RWT - 95k, WOB - 5/15k, CECD - 10.60 ppg, AECD - 11.04 ppg, AST - 1.70 hrs, ART - 1.90 hrs. Survey every 30', backream 60' at drilling rate prior to surveys and connections, 75% of rate on down stroke. PROD3 Circulate, surrey, and attempt to downlink to MWD. Unable to downlink. PROD3 MadPass log from 11,370' to 6,932' (bit depths). 300 gpm, 2,900 psi, 70 rpm, 6.7-6.4k TO. 600 fph all depths except swell packer intervals ~ 9,440' to 9,280' and 8,890' to 8,730' (bit depths) i PROD3 MadPass log from 6,932' to 5,700' (bit depths). 300 gpm, 2,350 psi, 70 rpm, 6.7-6.4k TO. 600 fph all depths except swell packer intervals C~3 6,840' to 6,680' and 6,390' to 6,230' (bit depths). Hole tried to packoff temporarily @ 6,630' and 6,555'. Lost appx 10 bbls of mud initially, then seeped appx 4 bph. Lost 26 bbls since midnight. PROD3 Orient to 20L deg. of highside, shut down pumps, Pull through windows without issues, Pulled up above 5018' ~i 117k PUW / 94k SOW PROD3 Pump Hi-Vis / 11.2 ppg Weighted sweep surface to surface ', Printed: 2/19/2007 1:08:51 PM g p Page 19 of 23 Operations Summary Report Legal Well Name: V-205 Common W ell Name: V-205 Spud Date: 1/19/2007 Event Nam e: DRILL+C OMPLE TE Start : 1/18/2007 End: Contractor Name: NABOBS ALASK A DRI LLING I Rig Release: 2/18/2007 Rig Name: NABOBS 9ES Rig Number: ate i I From - To ; ` i Hours Task ~ ~~ Code __ NPT Phase ~ Description of Operations 2/13/2007 08:30 - 09:30 1.00 DRILL P PROD3 296 gpm / 2100 psi, 60 rpm 2.3k Tq. / 94k RtWt 09:30 - 10:30 1.00 DRILL P PROD3 Slip and Cut 55' of Drilling Line -Service Drawworks 10:30 - 11:00 0.50 DRILL P PROD3 Service Top Drive and Crown 11:00 - 13:30 2.50 DRILL P PROD3 RIH to 11301', no problems running to bottom 13:30 - 15:00 1.50 DRILL P PROD3 Precautionary Ream last stand to bottom Circ. hole clean , 296 gpm / 2950 psi 70 rpm / 6k Tq. / 96k RtWt IECD = 10.9 ppg / FECD = 10.44 ppg 15:00 - 16:30 1.50 DRILL N WAIT PROD3 Continued to circ. while waiting on trucking for Solids Free MOBM changeout 16:30 - 18:30 2.00 DRILL P PROD3 Displace 9.2 ppg MOBM to 9.2 ppg Solids Free MOBM -291 gpm / 3050 psi, 70 rpm / 7k Tq, 99k RtWt 18:30 - 00:00 5.50 DRILL P PROD3 Monitor well for 10 min, Okay 9.2 ppg SF MOBM in & out POH taking up and down wts. every 10 stands into csg. No Problems POH Total MOBM losses for today 51 bbl /Total SF MOBM for today 10 bbls 2/14/2007 00:00 - 01:00 1.00 DRILL P PROD3 POH to BHA 01:00 - 02:30 1.50 DRILL P PROD3 PJSM with Schlumberger and Rig crew on handling RA sources on surface UD BHA Flex DC's, Remove sources, Download MWD/LWD data, UD MWD/LWD, Break Bit and UD mud motor -Clean Floor & laydown BHA components and tools down 02:30 - 03:30 1.00 WHIP P RUNPRD PJSM, Make Up BOT whipstock fishing BHA 03:30 - 04:00 0.50 WHIP P RUNPRD RIH to 1713' with 4" DP 04:00 - 04:30 0.50 WHIP N DFAL RUNPRD Shallow hole test Anadrills MWD -284 gpm / 857 psi Unable to get shallow hole test 04:30 - 05:00 0.50 WHIP P RUNPRD RIH with 4" HWDP to 2458' 05:00 - 05:30 0.50 WHIP P RUNPRD Shallow hole test Anadrills MWD -299 gpm / 1220 psi 76k PUW / 70k SOW Successful shallow hole test 05:30 - 08:30 3.00 WHIP P RUNPRD Pick up 1x1 - 69 jts of 4 3/4" Steel DC's RIH with 4 stands of 4 3/4" SDC's total of 81 jts of dc's 08:30 - 09:00 0.50 WHIP N DFAL RUNPRD Establish circulation 298 gpm / 2707 psi Unable to get MWD data, MWD Failed 165k PUW / 132k SOW 09:00 - 09:30 0.50 WHIP P RUNPRD Engage slot & Verified that we hooked whipstock Pick up 4x 60k over, Pick up 3x 70k over, Whipstock released 170k PUW 09:30 - 10:00 0.50 WHIP P RUNPRD Break circulation and CBU 1x 250 gpm / 2120 psi 10:00 - 15:00 5.00 WHIP P RUNPRD Monitor well, slight seepage loss 9.2 ppg SF MOBM POH, to BHA Stand back HWDP & SDC's 15:00 - 16:30 1.50 WHIP P RUNPRD PJSM, Lay Down Whipstock, UD BHA Printed: 2/19/2007 1:08:51 PM • gp Page 20 of 23 ~ Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To ~ V-205 V-205 DRILL+C NABOB NABOB Hours OMPLE S ALASK S 9ES Task ; TE A DRI Code LING NPT Start I Rig Rig ~ Phase Spud Date: 1/19/2007 : 1/18/2007 End: Release: 2/18/2007 Number: Description of Operations 2/14/2007 15:00 - 16:30 1.50 WHIP P RUNPRD -Window Mill rolled off to the right side of whipstock, Metal Shaving in cuttings Debris cup 16:30 - 17:30 1.00 CASE P RUNPRD Clear Rig floor of excess tools and equipment -clean MOBM off floor and ready rig floor for picking up 4 1/2" slotted liner 17:30 - 19:00 1.50 CASE P RUNPRD Pick up casing handling equipment and power tongs -P/U pup jts and centralizers from outside 19:00 - 19:30 0.50 CASE P RUNPRD PJSM with rig crew, NAD toolpusher, BP WSL Review job procedure, review running order and casing jewellery placement Discussed safety hazards associated with running 4 1/2" liner 19:30 - 23:00 3.50 CASE P RUNPRD PJSM. Pick up 4.5" 12.6# L-80 IBT slotted bent joint with shoe. Run in hole from surface to 2025' ~ 90 fpm. Make up TO - 3,400 fUlbs using Best-O-Life 2000 NM. Installed 4.5" x 6.125" Volant centralizers, free floating on every joint starting with joint #3. Run swell packer as per detail. Record PU and SO weights every 1,000' 23:00 - 23:30 0.50 CASE N RREP RUNPRD Rig Mechanic and Electrician diagnose problem with skate controller -Change out skate control joystick on Pipe handler 23:30 - 00:00 0.50 CASE P RUNPRD PJSM with rig crew, NAD toolpusher, BP WSL Review job procedure, review running order and casing jewellery placement Discussed safety hazards associated with running 4 1/2" liner 2/15/2007 00:00 - 00:30 0.50 CASE N RREP RUNPRD Rig Mechanic and Electrician Change out skate control joystick on Pipe handler 00:30 - 07:30 7.00 CASE P RUNPRD -Continued Picking up 4.5" 12.6# L-80 IBT slotted bent joint with shoe. Run in hole from surface to 5,018 C~ 90 fpm. Make up TO - 3,400 ft/Ibs using Best-O-Life 2000 NM. Installed 4.5" x 6.125" Volant centralizers free floating on every joint starting with joint #3. Run swell packers as per detail. Record PU and SO weights every 1,000' Exit shoe after four tries no weight indications. PU - 85k, SO - 70k. -Continue Picking up Liner in open hole from window to 6342' -M/U Hanger - 91k PUW - 68k SOW 07:30 - 08:00 0.50 CASE P RUNPRD Rig Down Liner running & handling equipment -Clear rig floor 08:00 - 12:00 4.00 CASE P RUNPRD RIH to 11290' -with 4" DP, 4 3/4" DC's and 4 1/2" slotted liner into L2 Oa Lateral -206k PUW / 100k SOW 12:00 - 12:30 0.50 CASE P RUNPRD Make up Top Drive and RIH to 11348', Hook Window on first attempt, PU and verified liner hooked, PU and turn 180 degrees, RIH past window and work compression out of Liner, PU and turn 180 degrees and Rehook window with Liner, Verified Liner hooked, Drop 29/32" ball and SO with 40k on window 12:30 - 13:00 0.50 CASE P RUNPRD Pump ball down @ 3 bpm / 650 psi, slowed to 2 bpm and seat Printed: 2/19/2007 1:08:51 PM gp Page 21 of 23 Operations Summary Report Legal Well Name: V-205 Common Well Name: V-205 Spud Date: 1/19/2007 Event Name: DRILL+COMPLETE Start: 1/18/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/18/2007 Rig Name: NABOBS 9ES Rig Number: Date From - To ~ Hours Task Code NPT~ Phase ~ Description of Operations 2/15/2007 12:30 - 13:00 0.50 CASE P RUNPRD ball @ 520 strokes, pressured up to 2800 psi released Hook liner running tool, PU and confirm release, pressure up to 3960 psi and shear ball seat, -160 k PUW, POH 1 std to 4972' 13:00 - 14:00 1.00 CASE P RUNPRD CBU at top of liner, 2257 gpm / 1960 psi -monitor well, Static -Pump Dry job 9.2 ppg in /out 14:00 - 17:00 3.00 CASE P RUNPRD POH with 4 3/4" DC's, 4" HWDP, and 4" DP 17:00 - 17:30 0.50 CASE P RUNPRD Service break BOT running tool and Lay Down 17:30 - 19:00 1.50 TIEBAC P OTHCMP Clear rig floor, clean up MOBM, Rig to make up LEM PJSM with NAD rig crew, NAD toolpusher, BOT toolhand and BP WSL on making up and running LEM for OA Lateral 19:00 - 20:00 1.00 TIEBAC P OTHCMP M/U LEM, ZXP Packer with 2 3/8" EUE inner string -BOT seat assembly -2 joints of 4.5" 12.6# L-80 tubing, -LEM -BOT "ZXP" Liner Top Packer -Hyd. setting tool 20:00 - 00:00 4.00 TIEBAC P OTHCMP RIH with LEM @ 90 FPM, -17 stands 4" Dp -8 stands 4" hwdp -27 stands 4 3/4" DC's 2/16/2007 00:00 - 02:00 2.00 TIEBAC P OTHCMP Make top Drive @ 5011' 160 PUW / 140 SOW -washdown ~ 3bpm / 800 psi -Engaged seal assembly in lower seal bore Extension top ~ 5113, cont. to 5121' -Latch up, pull out 18k overpull, relatch and verify latch up -unlatch and pull up 15' and break off, drop 1.75" ball, MU stand -Circ. ball down @ 3bpm / 750 psi, with 5 bbls left to go slowed to 2 bpm 500 psi -Seat ball and pressure up to 1200 psi, held pressure for to verify ball seat, -pressure up to 2500, visual indication pkr. set ~ 2200psi -Continued pressuring up to 3900 psi, release Liner running tool from ZXP packer Bleed off pressure and test backside to 1500 psi for 5 min, good test PU and pull dogs out on dog sub, set back down and verify dogs released from packer, pulled up 20' and line up to displace MOBM to brine 02:00 - 04:00 2.00 TIEBAC P OTHCMP Displace 9.2 ppg SF MOBM to 9.2 ppg brine -pump 24 bbl of LVT-200 base oil @ 3bpm / 770 psi -pump 25 bbl of viscosified 9.2 ppg brine ~ 3.8 bpm / 900 psi -pump 50 bbls of Safe Surf-O /Brine heated to 110 degrees ~ 4.3 bpm / 1150 psi -Pump 202 bbls of 9.2 ppg Brine, pumped until clean brine returns @ 6.1 bpm / 1400 psi 04:00 - 04:30 0.50 TIEBAC P OTHCMP Ready rig floor for laying down DP and DC's Monitor well, static - 9.2 ppg in /out Printed: 2/19/2007 1:08:51 PM • gp Page 22 of 23 ~ Operations Summary Report Legal Well Name: V-205 Common Well Name: V-205 Spud Date: 1/19/2007 Event Name: DRILL+COMPLETE Start: 1/18/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/18/2007 Rig Name: NABOBS 9ES Rig Number: i Date ~ From - To Hours ~ Task 'Code NPT Phase Description of Operations ---- - -' _ _ i_ 1 _ _ _ _ _-- 2/16/2007 104:00 - 04:30 I 0.50 TIEBAC P I OTHCMP PJSM on laying down Drill pipe Clean surface equipment in pit room 04:30 - 13:30 9.00 TIEBAC P OTHCMP Lay Down 4" drill pipe and 4 3/4" DC's 13:30 - 14:30 1.00 TIEBAC P OTHCMP Make service breaks on BOT running tool and LD 3 jts of 2 3/8" eue pipe -clean floor and UD running tools off of floor 14:30 - 16:30 2.00 TIEBAC P OTHCMP RIH with 4" DP from Derrick to 4783' 16:30 - 17:00 0.50 TIEBAC P OTHCMP Flush DP with Surf-o sweep, pump S/S -506 gpm / 1100 psi -100 rpm / 2k tq 17:00 - 21:00 4.00 TIEBAC P OTHCMP Monitor well, 9.2 ppg brine in/out Lay Down 4" drill pipe 1 x 1 21:00 - 22:30- 1.50 TIEBAC P OTHCMP RIH with 4" DP from Derrick to 4305' 22:30 - 23:00 0.50 TIEBAC P OTHCMP Flush DP with Surf-o sweep, pump S/S -534 gpm / 1100 psi -100 rpm / 2k tq 23:00 - 00:00 1.00 TIEBAC P OTHCMP Slip and cut drilling line --clean MOBM from underneath drawworks 2/17/2007 00:00 - 00:30 0.50 TIEBAC P OTHCMP Service top drive and drawworks 00:30 - 05:00 4.50 TIEBAC P OTHCMP Monitor well, 9.2 ppg brine in/out Lay Down 4" drill pipe 1 x 1 05:00 - 09:00 4.00 BUNCO RUNCMP -Clear rig floor of excess tools and equipment -clean and ready floor to run 4 1/2" completion tubing -Make Dummy run with Hanger -P/U Power tong and running equipment -RU I-Wire spool & sheaves 09:00 - 20:00 11.00 BUNCO RUNCMP PJSM on running completion with NAD drilling crew and Toolpusher, Service Hands, BP WSL Ran total of 112 jts, 4679' 4.5" 12.6# 13Cr80 Vam Top tubing joints. 64 - I-Wire Full Clamps 8 - 1-Wire Half Clamps Mule shoe C 4989.7' (8 ft inside of L2 LEM Tie Back) Tops: 4.5" TCII HES "X" Nipple 3.813" ID @ 4963' 4.5" TCII HES "X" Nipple 3.813" ID w/ RHC plug ~ 4942' 7.625" x 4.5" Baker Premier Packer @ 4915' Phoenix CST Jet Pump Gauge C 4893' 4.5" 13Cr HES CMD Sliding Sleeve @ 4871' 4.5" Phoenix Discharge Pressure Sensor ~ 4861' GLM #1 - 4.5" 1" KBG-2, 9Cr, w/ DCK-2 Shear & BEK latch @ 4753'. GLM #2 - 4.5" 1" KBG-2, 9Cr, w/ RD Dummy, SBK-2C latch ~ 3975' GLM #3 - 4.5" 1" KBG-2, 9Cr, w/ RD Dummy, SBK-2C latch ~ 3327' GLM #4 - 4.5" 1" KBG-2, 9Cr, w/ RD Dummy, SBK-2C latch ~ 2632' 4.5" TCII HES "X" Nipple 3.813" ID @ 2,317 20:00 - 21:00 1.00 BUNCO RUNCMP -RIH tag NO GO @ 4,992.7' Printed: 2/79/2007 1:08:51 PM • gp Page 23 of 23 Operations Summary Report Legal Well Name: V-205 Common Well Name: V-205 Event Name: DRILL+COMPLETE ~~,Contractor Name: NABOBS ALASKA DRILLING ~I Rig Name: NABOBS 9ES Date ~ From - To Hours Task Code ~ NPT f 2/17/2007 20:00 - 21:00 1.00 RU 21:00 - 21:30 0.50 RU 21:30 - 22:00 0.50 RU 22:00 - 00:00 2.00 RU 2/18/2007 00:00 - 01:00 1.00 RU 01:00 - 01:30 0.50 RU 01:30 - 03:30 2.00 RU 03:30 - 04:00 0.50 BUNCO 04:00 - 09:30 5.50 BOPSU P 09:30 - 12:00 2.50 BOPSU P 12:00-13:30 1.50 WHSUR P 13:30 - 14:30 14:30 - 16:30 16:30 - 17:30 17:30 - 20:00 1.001 W HSUR I P Spud Date: 1/19/2007 Start: 1 /18/2007 End: I Rig Release: 2/18/2007 Rig Number: Phase ~ Description of Operations RUNCMP Space out tubing, 2 ea , 9.83' & 5.84', 4.5" 12.6# 13Cr80 Vam Top tubing space out pups under top joint of tubing. FMC Tubing Hanger with 1 ft of Blast Rings below hanger on pup jt with 4.5" TCII lifting threads. RUNCMP Terminate I-Wire C~ Hanger RUNCMP Land Tubing C~ 4989' w/80k PUW & 77k SOW Run in Lock Down Screws and TO to 450 ft/Ibs, Gland Nuts to 350 fUlbs RUNCMP PJSM, Rig to reverse circ. Pump 207 bbls of 9.2 brine @ 3bpm / 125 psi RUNCMP continue, Reverse circulate 76 bbls of clean 9.2 ppg brine followed with -55 bbls of corrision inhibtor treated 9.2 brine followed with -70 bbls of clean 9.2 brine -3 bbls/min / 125 psi RUNCMP PJSM on setting hanger and Testing Tubing Reviewed HACL, initiated creation of an updated written procedure NAD rig crew & Toolpusher, BOT service hand and BP WSL RUNCMP Drop ball/rod assembly. Back out and lay down landing jt. Close blind rams and set the packer with 4,000 psi and hold for 30 min to test tubing. Bleed tubing pressure slowly to 2500 psi and then pressure annulus to 3500 psi and hold for 30 minute test. Bleed off pressure in annulus and then tubing. Re-pressure annulus to shear DCK valve (sheared at 1800 psi), Pump both ways to verify shear, 10 bbls down annulus 3bpm / 750 psi, pump 10 bbls ~ 3bpm / 750 psi down the tubing RUNCMP FMC dry rod TWC, test from below to 1,000 psi f/5 min. RUNCMP Thouroghly clean Derrick, rig Floor, rig floor drain system and drip pan, cellar area and mud pits of all oil based mud prior to nipple down. -Rig down all tubing running equipment -Flush and blow out all mud lines RUNCMP R/D drilling nipple, N/D BOP RUNCMP Nipple up adapter flange, terminate I-wire and test. Test adapter flange to 5,000 psi, nipple up and test double master valve to 5,000 psi. RUNCMP R/U DSM Lubricator pull TWC, R/D lubricator. 2.00 WHSUR P RUNCMP R/U Little Red, test lines to, 3,000 psi. Freeze protect tubing and annulus to 2,650' with 110 bbls diesel heated to 70 deg, ICP 950 psi ~ 2 bpm, FCP 1,250 psi @ 2 bpm. 1.00 WHSUR P RUNCMP Allow diesel to U-tube. 2.50 WHSUR P RUNCMP R/U DSM Lubricator and install BPV, test from below to 1,000 psi. Clean cellar, remove secondary annulus valves and secure well. Release Rig from V-205 @ 20:00 hrs 2/18/2007 Printed: 2/19/2007 1:08:51 PM bra ~~~ ... u:.~ ~~. ~~` r} dll"u V-205 Survey Report Schlumberger Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure /Slot: V-Pad /Plan V-205 (S-P) Well: V•205 Borehole: V-205 UWVAPI#: 500292333800 Survey Name /Date: V-205 /January 20, 2007 Tort /AHD / DDI / ERD ratio: 366.686° / 6525.92 ft / 6.690 / 1.387 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location Lat/Long: N 70.32761133, W 149.26456155 location Grid NIE Y/X: N 5969941.370 ftUS, E 590683.570 ftUS Grid Convergence Angle: +0.69251734° Grid Scale Factor: 0.99990934 Vertical Section Azimuth: 115.000° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 82.89 ft relative to MSL Sea Bed /Ground Level Elevation: 54.39 ft relative to MSL Magnetic Declination: 23.807° Total Field Strength: 57631.952 nT Magnetic Dip: 80.887° Declination Date: January 20, 2007 Magnetic Declination Model: BGGM 2006 North Reference: True North Total Corr Mag North -> True North: +23.807° Local Coordinates Referenced To: Well Head • Comments Measured Inclination Azimuth SulsSea TVD TVD Vertical Atong Hole Closure NS EW DLS Northing Easting latitude Longitude Depth Section Departure ft de de ft ft ft ft tt ft ff de 100 ft ftUS ftUS H I t U.UU V.UU U. UU -tlL.tSy V.UU U.UU U.UU U.UU U.UU U.UU U.VU byb`Jy41.3/ byUCC3.b/ N /U.3Z/OI 133 VV 14y.LU4Obl55 GYD CT DMS 100.00 0.05 244. 35 17.11 100.00 -0.03 0.04 0.04 -0.02 -0.04 0.05 5969941.35 590683.53 N 70.32761128 W 149.26456187 200.00 0.20 305 .92 117.11 200.00 -0.23 025 0.23 0.06 -022 0.18 5969941.43 590683.35 N 70.32761151 W 149.26456334 300.00 0.07 0 .94 217.11 300.00 -0.42 0.47 0.43 0.23 -0.36 0.17 5969941.59 590683.21 N 70.32761196 W 149.26456448 400.00 0.17 256. 21 317.11 400.00 -0.56 0.64 0.56 0.25 -0.50 0.20 5969941.62 590683.06 N 70.32761203 W 14926456564 500.00 0.13 294. 00 417.11 500.00 -0.79 0.89 0.80 0.26 -0.75 0.10 5969941.63 590682.82 N 70.32761206 W 149.26456765 600.00 0.12 247. 22 517.11 600.00 -0.98 1.09 0.99 0.27 -0.95 0.10 5969941.63 590682.62 N 70.32761207 W 149.26456927 700.00 0.15 263 .35 617.11 700.00 -1.16 1.33 1.20 0.21 -1.18 0.05 5969941.57 590682.39 N 70.32761192 W 149.26457111 Last GYD CT DMS 800.00 0.77 201 .39 717.11 800.00 -1.23 2.09 1.61 -0.43 -1.55 0.71 5969940.92 590682.02 N 70.32761017 W 149.26457415 MWD+IFR+MS 855.10 1.63 192 .29 772.19 855.08 -1.03 3.24 2.41 -1.54 -1.85 1.59 5969939.81 590681.73 N 70.32760713 W 149.26457660 946.78 3.11 196. 21 863.79 946.68 -0.36 7.03 5.92 -5.20 -2.83 1.62 5969936.14 590680.81 N 70.32759713 W 149.264 1042.65 4.75 196. 30 959.43 1042.32 0.63 13.60 12.42 -11.51 -4.67 1.71 5969929.81 590679.04 N 70.32757990 W 149.264 1137.52 6.45 205 .62 1053.85 1136.74 1.17 22.84 21.64 -20.08 -8.07 2.03 5969921.19 590675.74 N 70.32755647 W 149.26462702 1234.88 8.94 206 .86 1150.32 1233.21 0.87 35.87 34.65 -31.76 -13.86 2.56 5969909.44 590670.10 N 70.32752456 W 149.26467392 1329.23 11.13 207 .04 1243.23 1326.12 0.30 52.31 51.07 -46.42 -21.31 2.32 5969894.70 590662.82 N 70.32748453 W 149.26473436 1424.75 13.42 206 .04 1336.56 1419.45 -023 72.62 71.37 -64.59 -30.37 2.41 5969876.42 590653.99 N 70.32743488 W 14926480781 1519.99 17.08 206 .24 1428.43 1511.32 -0.73 97.66 96.42 -87.07 -41.41 3.84 5969853.81 590643.22 N 70.32737346 W 149.26489733 1615.28 21.17 203 .33 1518.44 1601.33 -0.53 128.87 127.62 -115.44 -54.42 4.41 5969825.29 590630.56 N 70.32729597 W 149.26500280 1710.48 21.38 200 .38 1607.15 1690.04 1.37 163.41 162.10 -147.49 -67.27 1.15 5969793.09 590618.10 N 70.32720841 W 149.26510700 1806.38 24.19 198 .13 1695.56 1778.45 5.13 200.54 199.10 -182.56 -79.47 3.07 5969757.88 590606.32 N 70.32711261 W 149.26520596 1902.25 28.71 196 .28 1781.38 1864.27 10.97 243.23 241.57 -223.35 -92.04 4.79 5969716.95 590594.24 N 70.32700116 W 149.26530792 1998.12 30.53 196 .47 1864.72 1947.61 18.07 290.61 288.73 -268.81 -105.40 1.90 5969671.33 590581.43 N 70.32687697 W 149.26541624 2093.81 30.26 196 .39 1947.25 2030.14 25.29 339.02 336.99 -315.24 -119.10 0.29 5969624.74 590568.30 N 70.32675011 W 149.26552728 2189.82 29.80 200 .59 2030.39 2113.28 30.74 387.05 384.98 -360.79 -134.32 2.24 5969579.02 590553.64 N 70.32662568 W 149.26565067 2285.08 29.43 200 .04 2113.20 2196.09 34.59 434.13 432.06 -404.94 -150.66 0.48 5969534.68 590537.83 N 70.32650508 W 149.26578319 2380.37 29.42 200.74 2196.20 2279.09 38.35 480.94 478.87 -448.82 -166.97 0.36 5969490.61 590522.05 N 70.32638520 W 149.26591543 SurveyEditor Ver SP 2.1 Bid( doc4Ox_1OO) Plan V-205 (S-P)\V-205\V-205\V-205 Generated 3/13/2007 11:40 AM Page 1 of 5 Comments Measured inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure n de de ft n n n n ft ft de 100 n ftUS nUS L4/b.t5b 3U.UbLUZ.4/ ZZ/y.1L 'L:525'L.UI 41.15 bL25.SU bZb.CL -4yL.254 -1254.41 1.11 by6y44b.J25 2571.35 30.53 203.90 2361.57 2444.46 42.67 576.46 574.33 -537.11 -203.38 0.91 5969401.89 2667.37 31.21 203.16 2443.99 2526.88 43.94 625.73 623.54 -582.28 -223.04 0.81 5969356.49 2762.64 29.85 202.93 2526.05 2608.94 45.59 674.12 671.91 -626.82 -241.99 1.43 5969311.73 2858.36 29.81 203.28 2609.09 2691.98 47.16 721.74 719.49 -670 .61 -260 .68 0.19 5969267.72 2953.52 29.81 203.78 2691.65 2774.54 48.37 769.04 766.76 -713 .98 -279 .56 0.26 5969224.13 2997.56 29.66 203.72 2729.90 2812.79 48.85 790.89 788.59 -733 .98 -288 .36 0.35 5969204.03 3069.45 29.63 203.84 2792.38 2875.27 49.61 826.45 824.12 -766 .52 -302. 70 0.09 5969171.32 3131.09 29.45 203.83 2846.00 2928.89 50.23 856.84 854.49 -794 .31 -314 .98 0.29 5969143.38 3226.33 29.77 200.81 2928.81 3011.70 52.43 903.89 901.53 -837 .84 -332 .84 1.60 5969099.65 3321.64 29.62 201.78 3011.60 3094.49 55.48 951.10 948.74 -881 .83 -349 .98 0.53 5969055.46 3417.70 29.40 201.19 3095.20 3178.09 58.38 998.42 996.06 -925 .85 -367 .31 0.38 5969011.23 3513.50 29.34 200.99 3178.69 3261.58 61.59 1045.40 1043.04 -969 .69 -384 .22 0.12 5968967.20 3608.80 29.92 198.33 3261.53 3344.42 65.98 1092.51 1090.12 -1014 .05 -400 .06 1.51 5968922.65 3704.57 30.42 193.43 3344.34 3427.23 73.62 1140.62 1137.99 -1060 .32 -413 .20 2.62 5968876.23 3799.95 31.74 190.62 3426.03 3508.92 84.69 1189.85 1186.59 -1108. 47 -423. 44 2.06 5968827.97 3895.55 32.21 184.91 3507.14 3590.03 99.69 1240.44 1235.89 -1158. 58 -430. 25 3.20 5968777.78 3988.01 31.97 178.04 3585.50 3668.39 119.26 1289.52 1282.40 -1207. 61 -431. 53 3.95 5968728.74 4087.58 31.97 167.55 3670.04 3752.93 147.26 1342.13 1329.48 -1259. 74 -424. 94 5.57 5968676.71 4184.25 4279.15 4374.72 4469.32 4564.46 4660.21 4755.79 4851.23 4947.22 5043.00 33.34 35.84 38.15 41.43 43.33 46.12 48.28 51.16 53.82 56.62 byUbUb.l4 IV /U.3ZbZb4yL W 14y.ZbbUbb25b 590486.72 N 70.32614398 W 149.26621063 590467.60 N 70.32602057 W 149.26637007 590449.19 N 70.32589891 W 149.26652368 590431.04 N 70.32577927 W 149.26667516 590412.68 N 70.32566078 W 149.26682828 590404.13 N 70.32560616 W 149.26689961 590390.19 N 70.32551726 W 149.26701585 590378.24 N 70.32544131 W 149.26711542 590360.91 N 70.32532242 W 149.26726022 590344.30 N 70.32520224 W 149.2673 590327.51 N 70.32508195 W 149.267 590311.13 N 70.32496219 W 149.2676 590295.83 N 70.32484099 W 149.26780518 590283.25 N 70.32471460 W 149.26791173 590273.60 N 70.32458306 W 149.26799468 590267.39 N 70.32444616 W 149.26804992 590266.71 N 70.32431221 W 149.26806022 590273.93 N 70.32416981 W 149.26800677 158.20 3751 .48 3834 .37 182 .21 1394.21 1371.98 -1309.43 -409.54 5.40 5968627.21 590289.92 N 70.32403406 W 149.26788194 154.17 3829 .61 3912 .50 222 .78 1448.07 1412.91 -1358.66 -387.75 3.57 5968578.25 590312.31 N 70. 32389956 W 149.26770520 150.16 3905 .95 3988 .84 268 .61 1505.56 1454.93 -1409.46 -360.86 3.49 5968527.78 590339.80 N 70. 32376077 W 149.26748721 145.43 3978 .64 4061 .53 319 .51 1566.07 1497.10 -1460.61 -328.55 4.72 5968477.03 590372.73 N 70. 32362106 W 149.26722521 141.67 4048 .93 4131. 82 375 .84 1630.18 1539.78 -1512.15 -290.43 3.33 5968425.96 590411.46 N 70. 32348026 W 149.26691618 139.15 4116 .96 4199 .85 436.70 1697.55 1583.49 -1564. 03 -247.48 3.45 5968374.60 134.88 4181 .91 4264 .80 501.70 1767.66 1627.57 -1615. 28 -199.65 3.98 5968323.95 131.67 4243 .62 4326 .51 570.83 1840.46 1671.58 -1665. 14 -146.63 3.96 5968274.73 128.51 4302 .07 4384 .96 644.33 1916.59 1716.41 -1714. 13 -88.37 3.81 5968226.45 125.07 4356 .71 4439 .60 721.32 1995.24 1761.38 -1761. 20 -25.37 4.15 5968180.16 590455.04 590503.47 590557.09 590615.93 590679.49 590747.28 590819.20 590894.34 590973.06 591054.75 591148.02 591249.22 591278.85 591309.27 591340.26 591371.13 591402.58 591434.35 591465.72 591497.11 N 70.32333851 W 149.26656790 N 70.32319852 W 149.26618016 N 70.32306230 W 149.26575029 N 70.32292846 W 149.26527797 N 70.32279989 W 149.26476720 N 70.32267878 W 149.264 N 70.32256101 W 149.26364294 N 70.32244260 W 149.26303797 N 70.32232444 W 149.26240396 N 70.32221088 W 149.26174569 N 70.32209156 W 149.26099373 N 70.32197912 W 149.26017721 N 70.32195045 W 149.25993805 N 70.32192387 W 149.25969233 N 70.32190122 W 149.25944190 N 70.32188189 W 149.25919232 N 70.32186433 W 149.25893791 N 70.32184809 W 149.25868094 N 70.32183158 W 149.25842720 N 70.32181408 W 149.25817329 5138.19 59.05 121.75 4407.39 4490.28 801.02 2075.81 1806.01 -1805.53 41.89 3.90 5968136.65 5233.93 62.20 120.50 4454.35 4537.24 883.96 2159.23 1852.11 -1848.64 113.31 3.48 5968094.41 5329.73 66.39 119.81 4495.89 4578.78 969.91 2245.53 1901.29 -1891.98 187.94 4.42 5968051.97 5425.73 70.86 118.10 4530.88 4613.77 1059.07 2334.90 1953.44 -1935.23 266.14 4.94 5968009.68 5521.04 75.58 116.14 4558.39 4641.28 1150.23 2426.13 2007.08 -1976.79 347.34 5.33 5967969.10 5625.65 81.81 114.30 4578.89 4661.78 1252.76 2528.66 2067.84 -2020.46 440.10 6.20 5967926.56 5735.22 84.99 110.16 4591.48 4674.37 1361.43 2637.48 2131.37 -2061.62 540.83 4.74 5967886.63 5766.64 85.58 108.99 4594.07 4676.96 1392.61 2668.80 2149.16 -2072.11 570.33 4.16 5967876.50 5798.55 86.68 106.60 4596.22 4679.11 1424.19 2700.63 2166.75 -2081.84 600.64 8.23 5967867.14 5830.58 87.56 103.44 4597.83 4680.72 1455.69 2732.62 2183.45 -2090.12 631.54 10.23 5967859.22 5862.19 88.43 102.44 4598.94 4681.83 1486.58 2764.21 2199.30 -2097.20 662.32 4.19 5967852.52 5894.24 87.93 100.69 4599.95 4682.84 1517.74 2796.25 2215.05 -2103.62 693.71 5.68 5967846.48 5926.52 87.29 100.54 4601.30 4684.19 1548.98 2828.50 2230.80 -2109.56 725.40 2.04 5967840.93 5958.44 86.92 101.31 4602.91 4685.80 1579.90 2860.38 2246.86 -2115.60 756.71 2.67 5967835.26 5990.46 86.68 101.80 4604.70 4687.59 1610.99 2892.35 2263.60 -2122.01 788.03 1.70 5967829.24 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V-205 (S-P)\V-205\V-205\V-205 Generated 3/1 3/2007 1 1:40 AM Page 2 of 5 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hale Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft tt it it tt ft tt de 00 ft ftUS ftUS 6021.77 88.65 101.51 4605.98 4688.87 1641.43 2923.63 2280.35 -2128.33 6053.76 91.54 99.03 4605.92 4688.81 1672.37 2955.62 2297.13 -2134.03 6085.80 91.89 96.49 4604.96 4687.85 1702.95 2987.64 2313.06 -2138.35 6117.64 91.07 93.19 4604.14 4687.03 1732.82 3019.47 2327.80 -2141.04 6149.74 88.38 89.71 4604.29 4687.18 1762.24 3051.57 2341.32 -2141.85 6181.16 86.78 87.21 4605.62 4688.51 1790.32 3082.96 2353.40 -2141.01 6213.18 88.47 83.31 4606.95 4689.84 1818.10 3114.95 2364.42 -2138.36 6245.15 88.60 80.26 4607.77 4690.66 1844.83 3146.91 2373.99 -2133.80 6276.80 89.26 76.58 4608.36 4691.25 1870.24 3178.56 2382.06 -2127.45 6308.52 87.91 72.68 4609.14 4692.03 1894.39 3210.27 2388.51 -2119.04 6340.17 88.79 68.30 4610.05 4692.94 1916.95 3241.90 2393.10 -2108.48 6372.20 89.71 64.66 4610.47 4693.36 1938.16 3273.93 2395.94 -2095.70 6404.55 89.77 62.06 4610.62 4693.51 1958.23 3306.28 2397.49 -2081.20 6436.53 90.31 57.83 4610.60 4693.49 1976.55 3338.26 2397.54 -2065.18 6468.39 88.71 55.24 4610.87 4693.76 1993.21 3370.12 2396.12 -2047.62 6500.66 86.62 53.60 4612.18 4695.07 2009.04 3402.36 2393.92 -2028.86 6531.78 87.15 49.71 4613.88 4696.77 2022.98 3433.43 2390.72 -2009.59 6563.61 87.32 45.33 4615.41 4698.30 2035.15 3465.22 2385.58 -1988.12 6596.15 88.19 40.82 4616.69 4699.58 2045.24 3497.74 2378.27 -1964.37 6627.63 88.66 37.75 4617.55 4700.44 2053.00 3529.21 2369.58 -1940.02 6659.65 86.97 35.14 4618.77 4701.66 2059.35 3561.20 2359.61 -1914.29 6691.13 87.98 36.71 4620.16 4703.05 2065.31 3592.65 2349.93 -1888.82 6723.43 89.66 38.32 4620.83 4703.72 2072.31 3624.94 2341.25 -1863.21 6755.48 91.24 39.44 4620.57 4703.46 2080.00 3656.99 2333.78 -1838.26 6787.54 91.48 39.73 4619.81 4702.70 2088.07 3689.04 2327.12 -1813.56 6818.83 92.04 39.93 4618.85 4701.74 2096.07 3720.32 2321.16 -1789.54 6850.54. 91.69 39.86 4617.82 4700.71 2104.22 3752.01 2315.57 -1765.22 6882.60 91.49 40.12 4616.93 4699.82 2112.51 3784.06 2310.40 -1740.67 6914.76 91.16 40.10 4616.19 4699.08 2120.89 3816.21 2305.71 -1716.08 6946.18 91.20 39.66 4615.54 4698.43 2128.96 3847.62 2301.43 -1691.97 6977.87 91.82 39.86 4614.70 4697.59 2137.03 3879.30 2297.47 -1667.62 7009.90 91.94 39.46 4613.65 4696.54 2145.13 3911.31 2293 .86 -1642.98 7041.99 92.37 36.70 4612.45 4695.34 2152.39 3943.38 2289 .80 -1617.74 7073.89 91.95 36.30 4611.24 4694.13 2158.74 3975.26 2285 .34 -1592.11 7104.52 91.57 35.97 4610.30 4693.19 2164.65 4005.87 2281 .26 -1567.39 7135.11 7165.85 7196.73 7227.95 7257.58 7288.94 7319.48 7350.22 90.03 89.88 89.47 89.01 88.62 88.81 89.42 89.91 SurveyEditor Ver SP 2.1 Bld( doc40x_100 ) 35.42 4609.88 4692.77 35.85 4609.90 4692.79 36.41 4610.08 4692.97 35.76 4610.49 4693.38 35.23 4611.10 4693.99 35.11 4611.81 4694.70 35.03 4612.28 4695.17 33.60 4612.46 4695.35 2170.33 2176.00 2181.96 2187.97 2193.36 2198.90 2204.24 2209.21 PI2 4036.46 4067.20 4098.08 4129.30 4158.92 4190.27 4220.81 4251.55 n V-205 (S-P 818.67 850.14 881.87 913.58 945.66 977.04 1008.91 1040.54 1071.53 1102.10 1131.92 1161.28 1190.19 1217.87 1244.44 1270.66 1295.03 1318.47 1340.67 1360.59 1379.60 1398.05 1417.71 1437.83 1458.25 1478.28 1498.61 1519.21 1539.92 1560.06 1580.32 1600.75 1620.53 1639.49 1657.55 2277.37 -1542.55 1675.39 2273.82 -1517.56 1693.30 2270.94 -1492.62 1711.51 2268.43 -1467.40 1729.90 2266.14 -1443.28 1747.10 2263.96 -1417.65 1765.15 2262.19 -1392.66 1782.70 2260.43 -1367.27 1800.03 ~\V-205\V-205\V-205 6.36 5967823.29 591527.82 N 70.32179680 W 149. 25792492 11.90 5967817.97 591559.36 N 70.32178122 W 149. 25766980 8.00 5967814.03 591591.13 N 70.32176939 W 149. 25741258 10.68 5967811.73 591622.87 N 70.32176205 W 149. 25715551 13.70 5967811.30 591654.96 N 70.32175982 W 149. 25689544 9.44 5967812.53 591686.32 N 70.32176211 W 149. 25664108 13.26 5967815.55 591718.16 N 70.32176932 W 149. 25638267 9.55 5967820.50 591749.73 N 70.32178178 W 149. 25612627 11.81 5967827.23 591780.64 N 70.32179912 W 149. 25587500 13.01 5967836.00 591811.10 N 70.32182207 W 149. 25562717 14.11 5967846.92 591840.78 N 70.32185091 W 149. 2553 11.72 5967860.05 591869.98 N 70.32188581 W 149. 2551 8.04 5967874.90 591898.72 N 70.32192542 W 149. 25491304 13.33 5967891.25 591926.19 N 70.32196916 W 149. 25468867 9.55 5967909.13 591952.55 N 70.32201713 W 149. 25447322 8.23 5967928.20 591978.54 N 70.32206837 W 149. 25426062 12.60 5967947.77 592002.67 N 70.32212101 W 149. 25406307 13.75 5967969.51 592025.85 N 70.32217964 W 149. 25387300 14.10 5967993.52 592047.76 N 70.32224450 W 149. 25369299 9.86 5968018.11 592067.38 N 70.32231102 W 149. 25353145 9.71 5968044,07 592086.07 N 70.32238132 W 149. 25337733 5.93 5968069,76 592104.21 N 70.32245088 W 149. 25322771 7.20 5968095.61 592123.57 N 70.32252085 W 149. 25306826 6.04 5968120.79 592143.38 N 70.32258899 W 149. 25290514 1.17 5968145.74 592163.50 N 70.32265646 W 149. 25273953 1.90 5968169.99 592183.24 N 70.32272206 W 149. 25257709 1.13 5968194.55 592203.27 N 70.32278848 W 149. 25241226 1.02 5968219.35 592223.56 N 70.32285555 W 149. 25224525 1.03 5968244.18 592243.98 N 70.32292271 W 149. 252 1.41 5968268.53 592263.82 N 70.32298856 W 149. 251 2.06 5968293.12 592283.79 N 70.32305508 W 149. 25174965 1.30 5968318.01 592303.92 N 70.32312239 W 149. 25158397 8.70 5968343.48 592323.38 N 70.32319133 W 149. 25142359 1.82 5968369.33 592342.03 N 70.32326132 W 149. 25126983 1.64 5968394.27 592359.78 N 70.32332886 W 149. 25112342 5.35 5968419.33 592377.33 N 70.32339671 W 149. 25097869 1.48 5968444.52 592394.93 N 70.32346496 W 149. 25083345 2.25 5968469.68 592412.83 N 70.32353308 W 149. 25068579 2.55 5968495.12 592430.91 N 70.32360199 W 149. 25053668 2.22 5968519.45 592447.82 N 70.32366787 W 149. 25039719 0.72 5968545.29 592465.56 N 70.32373787 W 149. 25025073 2.01 5968570.49 592482.80 N 70.32380614 W 149. 25010843 4.92 5968596.08 592499.82 N 70.32387548 W 149. 24996789 Generated 3/13/2007 11:40 AM Page 3 of 5 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de n n ft ft ft ft ft de 00 n ftUS ftUS 7380.49 89.90 32.98 4811.51 4(i9b.4U 1113.58 7411.16 89.46 32.21 4612.68 4695 .57 2217.63 7441.95 89.13 31.59 4613.06 4695 .95 2221.33 7472.69 88.68 31.10 4613.65 4696 .54 2224.73 7503.04 89.03 31.05 4614.25 4697 .14 2227.94 7533.38 88.41 31.07 4614.93 4697 .82 2231.14 7563.54 87.57 30.72 4615.99 4698 .88 2234.23 7594.94 88.87 31.85 4616.96 4699. 85 2237.67 7625.47 88.78 33.95 4617.59 4700. 48 2241.87 7655.80 88.66 35.30 4618.27 4701 .16 2246.93 7686.66 89.08 39.01 4618.88 4701 .77 2253.43 7717.09 89.99 43.07 4619.12 4702 .01 2261.84 7748.09 90.08 47.72 4619.10 4701 .99 2272.64 7778.73 90.40 50.20 4618.98 4701 .87 2285.08 7809.31 90.67 49.91 4618.69 4701 .58 2298.03 7841.39 91.14 48.67 4618.18 4701. 07 2311.22 7873.24 91.04 47.46 4617.58 4700. 47 2323.70 7905.41 91.47 44.16 4616.87 4699. 76 2335.12 7936.94 90.87 38.82 4616.23 4699. 12 2344.07 7968.84 89.12 36.50 4616.23 4699. 12 2351.06 8000.81 88.30 33.61 4616.95 4699 .84 2356.64 8031.75 88.39 30.15 4617.84 4700 .73 2360.34 8064.31 89.29 25.63 4618.50 4701. 39 2361.98 809626 89.64 21.84 4618.80 4701. 69 2361.28 8127.85 89.41 17.08 4619.06 4701. 95 2358.23 8159.68 88.85 13.45 4619.55 4702. 44 2352.85 8191.78 88.05 9.76 4620.42 4703 .31 2345.42 8223.57 88.52 5.70 4621.37 4704 .26 2335.98 8256.01 89.58 0.75 4621.91 4704 .80 2323.96 8287.33 89.64 359.16 4622.12 4705 .01 2310.70 8318.97 89.69 359.63 4622.30 4705 .19 2297.02 8350.96 89.21 358.24 4622.61 4705. 50 2282.97 8382.74 89.29 358.09 4623.03 4705 .92 2268.62 8414.69 90.98 356.28 4622.95 4705 .84 2253.72 8447.08 91.48 355.15 4622.26 4705 .15 2237.88 8478.49 91.63 355.56 4621.41 4704 .30 2222.35 8510.38 91.10 354.20 4620.65 4703 .54 2206.35 8542.73 89.84 352.09 4620.38 4703 27 2189.28 8573.37 89.52 348.41 4620.55 4703 .44 2171.82 8605.05 90.56 345.52 4620.53 4703 .42 2152.30 8637.30 89.90 342.66 4620.40 4703 .29 2131.18 8669.32 89.48 341.81 4620.57 4703 .46 2109.44 4281.81 '1158.55 -1341.98 1818.84 4312.49 2256.70 -1316.13 1833.16 4343.28 2254.88 -1289.99 1849.43 4374.01 2253.18 -1263.74 1865.42 4404.35 2251.78 -1237.75 1881.08 4434.69 2250.77 -1211.77 1896.73 4464.83 2250.09 -1185.90 1912.21 4496.21 2250.02 -1159.08 1928.51 4526.74 2251.24 -1133.46 1945.09 4557.06 2253.77 •1108.50 1962.31 4587.91 2258.10 -1083.92 1980.95 4618.34 2264.81 •1060.97 2000.92 4649.34 2274.30 -1039.21 2022.99 4679.98 2285.84 -1019.09 2046.09 4710.56 2298.24 -999.46 2069.54 4742.63 2311.22 -978.54 2093.85 4774.48 2323.86 -957.26 2117.54 4806.64 2335.83 -934.84 2140.60 4838.16 2345.70 -911.24 2161.47 4870.06 2354.05 -885.99 2180.96 4902.02 2361.42 -859.83 2199.32 4932.95 2367.26 -833.57 2215.65 4965.50 2371.60 -804.80 2230.87 4997.45 2373.99 -775.56 2243.73 5029.04 2374.41 -745.79 2254.25 5060.87 2372.94 -715.09 2262.63 5092.96 2369.84 -683.66 2269.08 5124.73 2365.06 -652.18 2273.36 5157.17 2358.09 -619.81 2275.18 5188.49 2350.03 -588.49 2275.15 5220.13 2341.99 -556.85 2274.82 5252.11 2334.01 -524.87 2274.23 5283.89 2326.08 -493.11 2273.21 5315.84 2317.98 -461.20 2271.64 5348.22 2309.40 -428.91 2269.22 5379.62 2301.29 -397.61 2266.68 5411.50 2293.21 -365.86 2263.83 5443.85 2284.48 -333.75 2259.97 5474.49 2275.13 -303.55 2254.78 5506.17 2264.12 -272.70 2247.64 5538.42 2251.81 -241.68 2238.80 5570.44 2239.01 -211.19 2229.03 L.Ub b9888L1.58 b91518.13 N /U.3'L3`J44t)U W 14y.24`J83314 2.89 5968647.62 592532.34 N 70.32401518 W 149.24969914 2.28 5968673.95 592548.29 N 70.32408657 W 149.24956719 2.16 5968700.38 592563.95 N 70.32415827 W 149.24943751 1.16 5968726.56 592579.30 N 70.32422926 W 149.24931048 2.04 5968752.73 592594.63 N 70.32430023 W 149.24918354 3.02 5968778.77 592609.79 N 70.32437088 W 149.24905801 5.48 5968805.79 592625.77 N 70.32444414 W 149.24892582 6.88 5968831.61 592642.03 N 70.32451414 W 149.24879135 4.47 5968856.76 592658.96 N 70.32458229 W 149.24865162 12.10 5968881.57 592677.29 N 70.32464945 W 149.248 13.67 5968904.76 592696.98 5 N 70.32471212 W 149.248 15.00 5968926.78 592718.78 N 70.32477156 W 149.24815955 8.16 5968947.17 592741.64 N 70.32482649 W 149.24797215 1.30 5968967.09 592764.84 N 70.32488011 W 149.24778203 4.13 5968988.30 592788.90 N 70.32493725 W 149.24758485 3.81 5969009.86 592812.33 N 70.32499537 W 149.24739274 10.34 5969032.55 592835.11 N 70.32505659 W 149.24720573 17.04 5969056.40 592855.70 N 70.32512105 W 149.24703642 9.11 5969081.89 592874.88 N 70.32519002 W 149.24687835 9.39 5969108.26 592892.91 N 70.32526148 W 149.24672946 11.18 5969134.72 592908.93 N 70.32533320 W 149.24659698 14.15 5969163.66 592923.80 N 70.32541177 W 149.24647348 11.91 5969193.05 592936.30 N 70.32549164 W 149.24636916 15.08 5969222.95 592946.46 N 70.32557298 W 149.24628379 11.54 5969253.74 592954.47 N 70.32565684 W 149.24621578 11.76 5969285.24 592960.54 N 70.32574269 W 149.24616338 12.85 5969316.77 592964.43 N 70.32582868 W 149.24612865 15.60 5969349.16 592965.86 N 70.32591712 W 149.2461 5.08 5969380.47 592965.46 N 70.32600268 W 149.2461 1,49 5969412.10 592964.74 N 70.32608911 W 149.24611654 4.60 5969444.07 592963.76 N 70.32617649 W 149.24612128 0.53 5969475.81 592962.36 N 70.32626326 W 149.24612945 7.75 5969507.70 592960.41 N 70.32635043 W 149.24614210 3.81 5969539.96 592957.60 N 70.32643865 W 149.24616164 1.39 5969571.21 592954.68 N 70.32652415 W 149.24618218 4.58 5969602.93 592951.45 N 70.32661090 W 149.24620517 7.60 5969634.99 592947.20 N 70.32669864 W 149.24623640 12.06 5969665.12 592941.65 N 70.32678112 W 149.24627839 9.70 5969695.88 592934.13 N 70.32686543 W 149.24633624 9.10 5969726.78 592924.92 N 70.32695016 W 149.24640785 2.96 5969757.15 592914.78 N 70.32703347 W 149.24648699 8701.03 89.50 341.87 4620.86 4703.75 2087.75 5602.15 2226.52 -181.06 2219.15 0.20 5969787.16 592904.54 N 70.32711579 W 149.24656705 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V-205 (S-P)\V-205\V-205\V-205 Generated 3/1 3/2007 1 1:40 AM Page 4 of 5 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft tt ft ft de 00lt ftUS ftUS 8733.20 89.39 341.09 4621 .17 4704.06 2065.60 5634.32 2214.05 -150.58 2LU8.93 2.45 598981/.53 59"L893.95 N /U.32/1y913 W 149.24titi4984 8765.38 89.83 342.33 4621 .39 4704.28 2043.54 5666.49 2202.10 -120.01 2198.83 4.09 5969847.96 592883.49 N 70.32728260 W 149.24673165 8796.89 89.50 341.20 4621 .57 4704.46 2021.95 5698.00 2190.82 -90.08 2188.97 3.74 5969877.76 592873.27 N 70.32736437 W 149.24681153 8828.77 90.62 341.70 4621 .54 4704.43 1999.99 5729.88 2179.65 -59.86 2178.83 3.85 5969907.85 592862.76 N 70.32744694 W 149.24689369 8860.59 90.51 341.93 4621 .22 4704.11 1978.21 5761.70 2169.10 -29.63 2168.90 0.80 5969937.96 592852.47 N 70.32752953 W 149.24697415 8891.91 90.30 342.06 4621 .00 4703.89 1956.85 5793.02 2159.22 0.16 2159.22 0.79 5969967.62 592842.43 N 70.32761091 W 149.24705258 8924.47 89.87 342.52 4620 .95 4703.84 1934.77 5825.58 2149.54 31.17 2149.31 1.93 5969998.51 592832.15 N 70.32769565 W 149.24713282 8956.29 89.61 342.59 4621 .10 4703.99 1913.29 5857.40 2140.66 61.53 2139.78 0.85 5970028.75 592822.25 N 70.32777859 W 149.24721010 8988.19 90.39 340.17 4621 .10 4703.99 1891.29 5889.30 2131.57 91.76 2129.59 7.97 5970058.85 592811.70 N 70.32786118 W 149.24729262 9019.95 90.72 339.33 4620 .79 4703.68 1868.73 5921.06 2122.08 121.55 2118.60 2.84 5970088.51 592800.35 N 70.32794259 W 149.24738169 9051.92 90.52 338.55 4620 .44 4703.33 1845.71 5953.03 2112.54 151.39 2107.11 2.52 5970118.20 592788.50 N 70.32802410 W 149.24747 7 9083.93 89.70 338.30 4620 .38 4703.27 1822.47 5985.04 2103.16 181.15 2095.34 2.68 5970147.82 592776.37 N 70.32810543 W 149.247 9115.82 89.79 336.63 4620 .52 4703.41 1798.94 6016.93 2093.74 210.61 2083.12 5.24 5970177.12 592763.80 N 70.32818590 W 149.2476 9147.81 92.68 334.50 4619 .83 4702.72 1774.65 6048.90 2083.73 239.72 2069.89 11.22 5970206.06 592750.22 N 70.32826544 W 149.24777639 9179.33 92.75 333.77 4618 .34 4701.23 1750.23 6080.39 2073.56 268.05 2056.16 2.32 5970234.22 592736.15 N 70.32834285 W 149.24788771 9210.99 92.49 333.37 4616 .89 4699.78 1725.50 6112.02 2063.47 296.37 2042.08 1.51 5970262.37 592721.73 N 70.32842023 W 149.24800180 9243.42 92.40 332.63 4615 .51 4698.40 1699.97 6144.42 2053.29 325.24 2027.37 2.30 5970291.06 592706.67 N 70.32849911 W 149.24812102 9275.41 91.43 334.16 4614 .44 4697.33 1674.91 6176.39 2043.91 353.83 2013.05 5.66 5970319.47 592692.01 N 70.32857722 W 149.24823706 9306.90 88.32 334.46 4614 .51 4697.40 1650.55 6207.88 2035.61 382.20 1999.40 9.92 5970347.67 592678.02 N 70.32865474 W 149.24834769 9339.54 87.90 334.55 4615 .59 4698.48 1625.38 6240.50 2027.59 411.64 1985.36 1.32 5970376.94 592663.63 N 70.32873519 W 149.24846149 9370.94 88.02 334.62 4616 .70 4699.59 1601.20 6271.88 2020.39 439.99 1971.89 0.44 5970405.12 592649.82 N 70.32881263 W 149.24857065 9403.42 89.22 335.15 4617 .49 4700.38 1576.28 6304.35 2013.59 469.39 1958.11 4.04 5970434.34 592635.69 N 70.32889296 W 149.24868234 9435.14 89.81 336.12 4617 .76 4700.65 1552.21 6336.07 2007.84 498.28 1945.03 3.58 5970463.07 592622.25 N 70.32897190 W 149.24878839 9466.66 89.67 336.49 4617 .90 4700.79 1528.53 6367.59 2002.97 527.14 1932.36 1.26 5970491.78 592609.24 N 70.32905076 W 149.24889106 9498.61 90.65 337.18 4617.81 4700.70 1504.73 6399.54 1998.83 556.52 1919.79 3.75 5970521.00 9531.24 90.53 336.62 4617.47 4700.36 1480.44 6432.16 1995.15 586.53 1906.99 1.76 5970550.85 9562.73 90.48 336.88 4617.20 4700.09 1456.95 6463.65 1992.02 615.46 1894.56 0.84 5970579.63 Last MWD+IFR+MS 9575.65 89.82 336.99 4617.16 4700.05 1447.34 6476.57 1990.92 627.35 1889.50 5.18 5970591.45 TD (Projected) 9625.00 89.82 336.99 4617.32 4700.21 1410.66 6525.92 1987.54 672.77 1870.21 0.00 5970636.63 Survey Type: Definitive Survey NOTES: GYD CT DMS - (Gyrodata -cont. drillpipe m/s -- Gyrodata pump-down multishot surveys with continuous tool (RGS-CT) in drill-pipe.) MWD +IFR + MS - (In-field referenced MWD with mull-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Leaal Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 4692 FSL 1619 FEL S11 T11 N R11 E UM 5969941.37 590683.57 BHL : 85 FSL 5028 FEL S1 T11 N R11 E UM 5970636.63 592545.34 592596.32 N 70.32913102 W 149.24899292 592583.16 N 70.32921302 W 149.24909667 592570.38 N 70.32929207 W 149.24919741 592565.17 N 70.32932454 W 149.24923844 592545.34 N 70.32944865 W 149.24939478 ~~ ~J SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V-205 (S-P)\V-205\V-205\V-205 Generated 3/13/2007 11:40 AM Page 5 of 5 .~ = FMC 41/8" 5M WELLHEAD = FMC GEN 5 ACTUATOR = LEO KB. ELEV = 82.5' BF. ELEV = 54.5' KOP = 700 Datum MD = Datum ND = V-20`~ Completion V-205 LT V-205 L2 DRLG DRAFT 20" Conductor 109' 10 314" CSG., 45.5# L-80..0962 bof, ID= 9.95' 3047' 4.5"Pheonix Discharge Pressure Sub ,ID = 3.948" ~ 4861' 7" Phoenix CST Jet Pump Gauge, ID = 3.948" 4893' RA TAG 4973' I 7-518" x 5.5" BKR ZXP PACKER, ID = 4.82" 4976' L2 8KR HUGHES HOOK HGR, ID = 5.62" 5013' Minimum ID = 3.688" @ 5002', &.5150' - LEM's RA TAG 11 5104' 7-5i8" x 5.5" BKR 2:~P PACKER, ID = 4.95" 5094' BKR, Seal Bore Extension, ID= 4.750" 5113' L1 BKR HUGHES HOOK HGR, ID = 5.62" 5150' Seal Assembly from LEM #2 5121' NOTES: 2317' -14-1l2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 4 2632 2496 31 KBG-2 DMY SBK-2 0 02/18/07 3 3327 3099 30 KBG-2 DMY SBK-2 0 02/18/07 2 3975 3657 32 KBG-2 DMY SBK-2 0 02/18/07 1 4753 4263 48 KBG-2 DCK BEK 0 02/18/07 4871' 4.5" Baker CMD-BX Sliding Sleeee, 3.812" ID 4915' 7.625" x 4.5" Premier Packer 3.87" ID 4942' 4.5" HES Xnipple W! RHGM Plug, ID 3.813" 4963' 4.5" HES X nipple, ID 3.813" 4983't4989' 4.5" Mule shoe with fluted 5.25" No/Go 5.67' up 5036'- 5030' Hook Hanger below window - 3.99" ID 5108'- 509T 4.5" x 6.4" Swell Packer 3.9" ID - L2 5662'- 5651' 4.5" x 6.4" Swell Packer 3.9" ID - L2 6097'-5694' 4.5" L-80 12.6# IBT-M Slotted Liner 3.958" ID - L2 6123'- 6113' 4.5" x 6.4" Swell Packer 3.9" ID, L2 6752'- 6742' 4.5" x 6.4" Swell Packer 3.9" ID, L2 8664'- 6764' 4.5" L-80 12.6# IBT-M Slotted Liner 3.958" ID - L2 8690'- 8680' 4.5" x 6.4" Swell Packer 3.9" ID, L2 9269'- 9259' 4.5" x 6.4" Swell Packer 3.9" ID, L2 11307'- 9280' 4.5" L-80 12.6# IBT-M Slotted Liner 3.958" ID - L2 11,347' ~--~4.5" 12.6# L-80 IBT-M shoe - L2, OA (PBTD 11,345`) _._., a__ _~_~a~ RA TA3 1-f 5'•405' 7-5/8" x 5.5" BKR Z>Q' PACKER, ID = 4.95" 522T 7 5/8" x 5.5" BKR HMC Liner Hanger ID= 4.80 5249' BKR Seal Bore Extension, ID = 4.750" 5256'- 5275' Seal Assembly from LEM #1 5266' 7 5!8" CSG, 29.7# L-80 BTC, .0459 bpf, ID=6.875 H 5693' , it , 4.5" x 6.4" Swell Packer 3.9" ID 8056'- 806T 4.5" 12.6# L-80 IBT Slotted (3.958" ID} 569T- 8038' 4.5" x 6.4" Swell Packer 3.9" ID 8516'- 8527' 4.5" 12.6# L-80 IBT Slotted (3.958" ID) 8561'- 9621' , 4.5" 12.6# L-80 IBT Slotted/Solid Liner Shce - (PBTD 9621') Obd V-205 g623' ' , , , , r , 5173 - 516T' ~-{Hook Hanger below window - 3.99" JD 5274'- 5264' I-14.5" x 6.4" Swell Packer 3.9" ID-L1-Oba 5630'- 5620' I-~4.5" x 6.4" Swell Packer 3.9" ID-L1-Oba 7948'- 5649' I-14.5" L-80 12.6# IBT Slotted Liner 3.958" ID L1-Oba 7975'- 7965' 14.5" x 6.4" Swell Packer 3.9" ID-L1-Oba 8450'- 8440' 14.5" x 6.4" Swell Packer 3.9" ID-L1-Oba 9519'- 8462' I-14.5" L-80 12.6# IBT Slotted Liner 3.958" ID L1-Oba 9545'- 9535' 4.5" x 6.4" Swell Packer 3.9" ID-L1-Oba 9919'- 9908' 4.5" x 6.4" Swell Packer 3.9" ID-L1-Oba 11306'- 9931' 4.5" L-80 12.6# IBT Slotted Liner 3.958" ID L1-Oba 11345' 4.5" 12.6# L-80 IBT-M shoe - L1, OBa (PB1D 11,344') DATE REV BY COMMENTS DATE REV BY COMMENTS 02/18/07 BJB Actual Completion ORION UNff WELL: V-205, L1, L2 PERMIT No: 205- API No: 50-029- SEC 11, T11 N, R11 E, ' NSL & ' W EL BP Exploration (Alaska) __ , SCHLUMBERGER Survey report Client ...................: BP Exploration (Alaska) Inc. Field ....................: Orion Well ...................... V-205 API number ...............: 50-029-23338-00 Engineer .................: Bezerra RIG :...................... Nabors 9ES STATE :...................: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ---- Permanent datum..........: Depth reference..........: GL above permanent.......: KB above permanent.......: DF above permanent.......: ------------------ Mean Sea Level Driller's Pipe Tally 54.39 ft N/A (Top Drive) ft 82.89 ft ----- Vertical section origin---------------- Latitude (+N/S-).......... 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 0.00 degrees [(c)2007 IDEAL ID12 OC O1] 30-Jan-2007 11:39:05 Page 1 of 8 Spud date .............. 18-Jan-07 Last survey date.........: 30-Jan-07 Total accepted surveys...: 185 MD of first survey.......: 0.00 ft MD of last survey........: 9625.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2006 Magnetic date ............. 18-Jan-2007 Magnetic field strength..: 57632.23 LAMA Magnetic dec (+E/W-).....: 23.81 degrees Magnetic dip .............: 80.89 degrees ----- MWD survey Reference Reference G......... Reference H ............... Reference Dip ............. Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- ...... 1002.68 meal 57632.00 GAMA 80.89 degrees (+/-) 2.50 meal (+/-)300.00 LAMA (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 23.80 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 23.80 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... 2=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction SCHLUMBERGER Survey Report 30-Jan-2007 11:39:05 Page 2 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 1 0.00 0.00 197.35 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 100.00 0.05 244.35 100.00 100.00 -0.02 -0.02 -0.04 0.04 244.35 0.05 BP _GYD CT DMS 3 200.00 0.20 305.92 100.00 200.00 0.06 0.06 -0.22 0.23 286.37 0.18 BP _GYD CT DMS 4 300.00 0.07 0.94 100.00 300.00 0.23 0.23 -0.36 0.43 302.33 0.17 BP GYD CT DMS i 5 400.00 0.17 256.21 100.00 400.00 0.25 0.25 -0.50 0.56 296.75 0.20 BP _ _GYD CT DMS 6 500.00 0.13 294.00 100.00 500.00 0.26 0.26 -0.75 0.80 289.40 0.10 BP _GYD CT DMS 7 600.00 0.12 247.22 100.00 600.00 0.27 0.27 -0.95 0.99 285.85 0.10 BP _GYD CT DMS • 8 700.00 0.15 263.35 100.00 700.00 0.21 0.21 -1.18 1.20 280.32 0.05 BP _GYD CT DMS 9 800.00 0.77 201.39 100.00 799.99 -0.43 -0.43 -1.55 1.61 254.65 0.71 BP _GYD CT DMS 10 I 855.10 1.63 192.29 55.10 855.08 -1.54 -1.54 -1.85 2.41 230.36 1.59 BP MWD+IFR+MS - 11 946.78 3.11 196.21 91.68 946.68 -5.20 -5.20 -2.83 5.92 208.53 1.62 BP MWD+IFR+MS 12 1042.65 4.75 196.30 95.87 1042.32 -11.51 -11.51 -4.67 12.42 202.08 1.71 BP _ _MWD+IFR+MS 13 1137.52 6.45 205.62 94.87 1136.74 -20.08 -20.08 -8.07 21.64 201.90 2.03 BP _MWD+IFR+MS 14 1234.88 8.94 206.86 97.36 1233.21 -31.76 -31.76 -13.86 34.65 203.57 2.56 BP MWD+IFR+MS 15 1329.23 11.13 207.04 94.35 1326.11 -46.42 -46.42 -21.31 51.07 204.66 2.32 BP _ MWD+IFR+MS 16 1424.75 13.42 206.04 95.52 1419.45 -64.59 -64.59 -30.37 71.37 205.18 2.41 BP _MWD+IFR+MS 17 1519.99 17.08 206.24 95.24 1511.32 -87.07 -87.07 -41.41 96.42 205.43 3.84 BP _MWD+IFR+MS 18 1615.28 21.17 203.33 95.29 1601.33 -115.44 -115.44 -54.42 127.62 205.24 4.41 BP _MWD+IFR+MS 19 1710.48 21.38 200.38 95.20 1690.04 -147.49 -147.49 -67.27 162.10 204.52 1.15 $P MWD+IFR+MS 20 1806.38 24.19 198.13 95.90 1778.45 -182.56 -182.56 -79.47 199.10 203.52 3.07 BP _MWD+IFR+MS I 21 1902.25 28.71 196.28 95.87 1864.27 -223.35 -223.35 -92.04 241.57 202.40 4.79 BP _MWD+IFR+MS 22 1998.12 30.53 196.47 95.87 1947.61 -268.81 -268.81 -105.40 288.73 201.41 1.90 BP _MWD+IFR+MS 23 2093.81 30.26 196.39 95.69 2030.14 -315.24 -315.24 -119.10 336.99 200.70 0.29 $P MWD+IFR+MS 24 2189.82 29.80 200.59 96.01 2113.27 -360.79 -360.79 -134.32 384.98 200.42 2.24 BP _MWD+IFR+MS 25 2285.08 29.43 200.04 95.26 2196.09 -404.94 -404.94 -150.66 432.06 200.41 0.48 BP _MWD+IFR+MS 26 2380.37 29.42 200.74 95.29 2279.09 -448.82 -448.82 -166.97 478.87 200.41 0.36 BP _MWD+IFR+MS 27 2475.86 30.05 202.47 95.49 2362.01 -492.84 -492.84 -184.41 526.22 200.52 1.11 $P MWD+IFR+MS 28 2571.35 30.53 203.90 95.49 2444.46 -537.11 -537.11 -203.38 574.33 200.74 0.91 $P MWD+IFR+MS 29 2667.37 31.21 203.16 96.02 2526.88 -582.28 -582.28 -223.04 623.54 200.96 0.81 BP _MWD+IFR+MS 30 2762.64 29.85 202.93 95.27 2608.94 -626.82 -626.82 -241.99 671.91 201.11 1.43 BP _MWD+IFR+MS [(c)2007 IDEAL ID12 OC O1] SCHLUMBERGER Survey Report 30-Jan-2007 11:39:05 Page 3 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ ------- Displ ------- Total -------- At ----- DLS - ---- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (f t) (ft) (ft) (f t) (deg) 100f) type (deg) 31 2858.36 29.81 203.28 95.72 2691.98 -670.61 -670.61 -260.68 719.49 201.24 0.19 BP MWD+IFR+MS 32 2953.52 29.81 203.78 95.16 2774.54 -713.98 -713.98 -279.56 766.76 201.38 0.26 BP _ MWD+IFR+MS 33 2997.56 29.66 203.72 44.04 2812.78 -733.98 -733.98 -288.36 788.59 201.45 0.35 BP _ MWD+IFR+MS 34 3069.45 29.63 203.84 71.89 2875.26 -766.52 -766.52 -302.70 824.12 201.55 0.09 BP _ MWD+IFR+MS 35 3131.09 29.45 203.83 61.64 2928.89 -794.31 -794.31 -314.98 854.49 201.63 0.29 BP _ MWD+IFR+MS 36 3226.33 29.77 200.81 95.24 3011.70 -837.84 -837.84 -332.84 901.53 201.67 1.60 BP MWD+IFR+MS 37 3321.64 29.62 201.78 95.31 3094.49 -881.83 -881.83 -349.98 948.74 201.65 0.53 BP _ MWD+IFR+MS 38 3417.70 29.40 201.19 96.06 3178.09 -925.85 -925.85 -367.31 996.05 201.64 0.38 BP _ MWD+IFR+MS 39 3513.50 29.34 200.99 95.80 3261.58 -969.69 -969.69 -384.22 1043.04 201.62 0.12 BP _ MWD+IFR+MS 40 3608.80 29.92 198.33 95.30 3344.42 -1014.05 -1014.05 -400.06 1090.12 201.53 1.51 BP _ MWD+IFR+MS 41 3704.57 30.42 193.43 95.77 3427.23 -1060.32 -1060.32 -413.20 1137.99 201.29 2.62 BP MWD+IFR+MS 42 3799.95 31.74 190.62 95.38 3508.92 -1108.47 -1108.47 -423.44 1186.59 200.91 2.06 BP _ MWD+IFR+MS 43 3895.55 32.21 184.91 95.60 3590.03 -1158.58 -1158.58 -430.25 1235.89 200.37 3.20 BP _ MWD+IFR+MS 44 3988.01 31.97 178.04 92.46 3668.39 -1207.61 -1207.61 -431.53 1282.40 199.66 3.95 BP _ MWD+IFR+MS 45 4087.58 31.97 167.55 99.57 3752.93 -1259.74 -1259.74 -424.94 1329.48 198.64 5.57 BP _ MWD+IFR+MS 46 4184.25 33.34 158.20 96.67 3834.37 -1309.43 -1309.43 -409.54 1371.98 197.37 5.40 BP MWD+IFR+MS 47 4279.15 35.84 154.17 94.90 3912.50 -1358.66 -1358.66 -387.75 1412.91 195.93 3.57 BP _ MWD+IFR+MS 48 4374.72 38.15 150.16 95.57 3988.83 -1409.46 -1409.46 -360.86 1454.93 194.36 3.49 BP _ MWD+IFR+MS 49 4469.32 41.43 145.43 94.60 4061.53 -1460.61 -1460.61 -328.55 1497.10 192.68 4.72 BP _ MWD+IFR+MS 50 4564.46 43.33 141.67 95.14 4131.82 -1512.15 -1512.15 -290.43 1539.78 190.87 3.33 BP _ MWD+IFR+MS 51 4660.21 46.12 139.15 95.75 4199.85 -1564.03 -1564.03 -247.48 1583.49 188.99 3.45 BP MWD+IFR+MS 52 4755.79 48.28 134.88 95.58 4264.80 -1615.28 -1615.28 -199.65 1627.57 187.05 3.98 BP _ MWD+IFR+MS 53 4851.23 51.16 131.67 95.44 4326.51 -1665.14 -1665.14 -146.63 1671.58 185.03 3.96 BP _ MWD+IFR+MS 54 4947.22 53.82 128.51 95.99 4384.96 -1714.13 -1714.13 -88.37 1716.41 182.95 3.81 BP _ MWD+IFR+MS 55 5043.00 56.62 125.07 95.78 4439.60 -1761.20 -1761.20 -25.37 1761.38 180.83 4.15 BP _ MWD+IFR+MS 56 5138.19 59.05 121.75 95.19 4490.28 -1805.53 -1805.53 41.89 1806.01 178.67 3.90 BP MWD+IFR+MS 57 5233.93 62.20 120.50 95.74 4537.24 -1848.64 -1848.64 113.31 1852.11 176.49 3.48 BP _ MWD+IFR+MS 58 5329.73 66.39 119.81 95.80 4578.78 -1891.98 -1891.98 187.94 1901.29 174.33 4.42 BP _ MWD+IFR+MS 59 5425.73 70.86 118.10 96.00 4613.77 -1935.23 -1935.23 266.14 1953.44 172.17 4.94 BP _ MWD+IFR+MS 60 5521.04. 75.58 116.14 95.31 4641.28 -1976.79 -1976.79 347.35 2007.08 170.03 5.33 BP _ MWD+IFR+MS • C, J [(c)2007 IDEAL ID12 OC O1] SCHLUMBERGER Survey Report 30-Jan-2007 11:39:05 Page 4 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (f t) (deg) (deg) (ft) (ft) (ft) (f t) (ft) (ft) (deg) 100f) type (deg) 61 5625.65 81.81 114.30 104.61 4661.78 -2020.46 -2020.46 440.10 2067.84 167.71 6.20 BP _MWD+IFR+MS 62 5735.22 84.99 110.16 109.57 4674.37 -2061.62 -2061.62 540.83 2131.37 165.30 4.74 BP _MWD+IFR+MS 63 5766.64 85.58 108.99 31.42 4676.96 -2072.11 -2072.11 570.33 2149.16 164.61 4.16 BP _MWD+IFR+MS 64 5798.55 86.68 106.60 31.91 4679.11 -2081.84 -2081.84 600.64 2166.75 163.91 8.23 BP _MWD+IFR+MS 65 5830.58 87.56 103.44 32.03 4680.72 -2090.12 -2090.12 631.54 2183.45 163.19 10.23 BP MWD+IFR+MS 66 5862.19 88.43 102.44 31.61 4681.83 -2097.20 -2097.20 662.32 2199.30 162.47 4.19 BP _MWD+IFR+MS 67 5894.24 87.93 100.69 32.05 4682.84 -2103.62 -2103.62 693.71 2215.05 161.75 5.68 BP _MWD+IFR+MS 68 5926.52 87.29 100.54 32.28 4684.19 -2109.56 -2109.56 725.40 2230.80 161.02 2.04 BP _MWD+IFR+MS 69 5958.44 86.92 101.31 31.92 4685.80 -2115.60 -2115.60 756.71 2246.86 160.32 2.67 BP _MWD+IFR+MS 70 5990.46 86.68 101.80 32.02 4687.59 -2122.01 -2122.01 788.03 2263.60 159.63 1.70 BP MWD+IFR+MS 71 6021.77 88.65 101.51 31.31 4688.87 -2128.33 -2128.33 818.67 2280.35 158.96 6.36 BP _MWD+IFR+MS 72 6053.76 91.54 99.03 31.99 4688.81 -2134.03 -2134.03 850.14 2297.13 158.28 11.90 BP _MWD+IFR+MS 73 6085.80 91.89 96.49 32.04 4687.85 -2138.35 -2138.35 881.87 2313.06 157.59 8.00 BP _MWD+IFR+MS 74 6117.64 91.07 93.19 31.84 4687.03 -2141.04 -2141.04 913.58 2327.80 156.89 10.68 BP _MWD+IFR+MS 75 6149.74 88.38 89.71 32.10 4687.19 -2141.85 -2141.85 945.66 2341.32 156.18 13.70 BP MWD+IFR+MS 76 6181.16 86.78 87.21 31.42 4688.51 -2141.01 -2141.01 977.04 2353.40 155.47 9.44 BP _MWD+IFR+MS 77 6213.18 88.47 83.31 32.02 4689.84 -2138.36 -2138.36 1008.91 2364.42 154.74 13.26 BP _MWD+IFR+MS 78 6245.15 88.60 80.26 31.97 4690.66 -2133.80 -2133.80 1040.54 2373.99 154.00 9.55 BP _MWD+IFR+MS 79 6276.80 89.26 76.58 31.65 4691.25 -2127.45 -2127.45 1071.53 2382.06 153.27 11.81 BP _MWD+IFR+MS 80 6308.52 87.91 72.68 31.72 4692.03 -2119.04 -2119.04 1102.10 2388.51 152.52 13.01 BP MWD+IFR+MS 81 6340.17 88.79 68.30 31.65 4692.94 -2108.48 -2108.48 1131.92 2393.10 151.77 14.11 BP _MWD+IFR+MS 82 6372.20 89.71 64.66 32.03 4693.36 -2095.70 -2095.70 1161.28 2395.94 151.01 11.72 BP _MWD+IFR+MS 83 6404.55 89.77 62.06 32.35 4693.51 -2081.20 -2081.20 1190.19 2397.49 150.24 8.04 BP _MWD+IFR+MS 84 6436.53 90.31 57.83 31.98 4693.49 -2065.18 -2065.18 1217.87 2397.54 149.47 13.33 BP _MWD+IFR+MS 85 6468.39 88.71 55.24 31.86 4693.76 -2047.62 -2047.62 1244.44 2396.12 148.71 9.55 BP MWD+IFR+MS 86 6500.66 86.62 53.60 32.27 4695.07 -2028.86 -2028.86 1270.66 2393.92 147.94 8.23 BP _MWD+IFR+MS 87 6531.78 87.15 49.71 31.12 4696.77 -2009.58 -2009.58 1295.03 2390.72 147.20 12.60 BP _MWD+IFR+MS 88 6563.61 87.32 45.33 31.83 4698.30 -1988.12 -1988.12 1318.47 2385.58 146.45 13.75 BP _MWD+IFR+MS 89 6596.15 88.19 40.82 32.54 4699.58 -1964.37 -1964.37 1340.67 2378.27 145.69 14.10 BP _MWD+IFR+MS 90 6627.63 88.66 37.75 31.48 4700.44 -1940.02 -1940.02 1360.59 2369.58 144.96 9.86 BP MWD+IFR+MS • [(c)2007 IDEAL ID12 OC O1] SCHLUMBERGER Survey Report 30-Jan-2007 11:39:05 Page 5 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (f t) (ft) (deg) 100f) type (deg) 91 6659.65 86.97 35.14 32.02 4701.66 -1914.29 -1914.29 1379.60 2359.61 144.22 9.71 BP _MWD+IFR+MS 92 6691.13 87.98 36.71 31.48 4703.05 -1888.82 -1888.82 1398.05 2349.93 143.49 5.93 BP _MWD+IFR+MS 93 6723.43 89.66 38.32 32.30 4703.72 -1863.21 -1863.21 1417.71 2341.25 142.73 7.20 BP _MWD+IFR+MS 94 6755.48 91.24 39.44 32.05 4703.46 -1838.26 -1838.26 1437.83 2333.78 141.97 6.04 BP _MWD+IFR+MS 95 6787.54 91.48 39.73 32.06 4702.70 -1813.56 -1813.56 1458.25 2327.12 141.20 1.17 BP MWD+IFR+MS 96 6818.83 92.04 39.93 31.29 4701.74 -1789.54 -1789.54 1478.28 2321.16 140.44 1.90 BP _MWD+IFR+MS 97 6850.54 91.69 39.86 31.71 4700.71 -1765.22 -1765.22 1498.61 2315.57 139.67 1.13 BP _MWD+IFR+MS 98 6882.60 91.49 40.12 32.06 4699.82 -1740.67 -1740.67 1519.21 2310.39 138.89 1.02 BP _MWD+IFR+MS 99 6914.76 91.16 40.10 32.16 4699.08 -1716.08 -1716.08 1539.92 2305.71 138.10 1.03 BP _MWD+IFR+MS 100 6946.18 91.20 39.66 31.42 4698.43 -1691.97 -1691.97 1560.06 2301.43 137.32 1.41 BP MWD+IFR+MS 101 6977.87 91.82 39.86 31.69 4697.59 -1667.62 -1667.62 1580.32 2297.47 136.54 2.06 BP _MWD+IFR+MS 102 7009.90 91.94 39.46 32.03 4696.54 -1642.98 -1642.98 1600.76 2293.86 135.75 1.30 BP _MWD+IFR+MS 103 7041.99 92.37 36.70 32.09 4695.34 -1617.74 -1617.74 1620.53 2289.80 134.95 8.70 BP _MWD+IFR+MS 104 7073.89 91.95 36.30 31.90 4694.13 -1592.11 -1592.11 1639.49 2285.34 134.16 1.82 BP _MWD+IFR+MS 105 7104.52 91.57 35.97 30.63 4693.19 -1567.39 -1567.39 1657.55 2281.26 133.40 1.64 BP MWD+IFR+MS 106 7135.11 90.03 35.42 30.59 4692.77 -1542.55 -1542.55 1675.39 2277.36 132.64 5.35 BP _MWD+IFR+MS 107 7165.85 89.88 35.85 30.74 4692.79 -1517.56 -1517.56 1693.30 2273.82 131.87 1.48 BP _MWD+IFR+MS 108 7196.73 89.47 36.41 30.88 4692.97 -1492.62 -1492.62 1711.51 2270.94 131.09 2.25 BP _MWD+IFR+MS 109 7227.95 89.01 35.76 31.22 4693.38 -1467.40 -1467.40 1729.90 2268.43 130.31 2.55 BP _MWD+IFR+MS 110 7257.58 88.62 35.23 29.63 4693.99 -1443.28 -1443.28 1747.10 2266.14 129.56 2.22 BP MWD+IFR+MS 111 7288.94 88.81 35.11 31.36 4694.70 -1417.65 -1417.65 1765.15 2263.96 128.77 0.72 BP _MWD+IFR+MS 112 7319.48 89.42 35.03 30.54 4695.17 -1392.66 -1392.66 1782.70 2262.19 128.00 2.01 BP _MWD+IFR+MS 113 7350.22 89.91 33.60 30.74 4695.35 -1367.27 -1367.27 1800.03 2260.43 127.22 4.92 BP _MWD+IFR+MS 114 7380.49 89.90 32.98 30.27 4695.40 -1341.96 -1341.96 1816.64 2258.55 126.45 2.05 BP _MWD+IFR+MS 115 7411.16 89.46 32.21 30.67 4695.57 -1316.13 -1316.13 1833.16 2256.70 125.68 2.89 BP MWD+IFR+MS 116 7441.95 89.13 31.59 30.79 4695.95 -1289.99 -1289.99 1849.43 2254.88 124.90 2.28 BP _MWD+IFR+MS 117 7472.69 88.68 31.10 30.74 4696.54 -1263.74 -1263.74 1865.42 2253.18 124.12 2.16 BP _MWD+IFR+MS 118 7503.04 89.03 31.05 30.35 4697.14 -1237.75 -1237.75 1881.08 2251.78 123.34 1.16 BP _MWD+IFR+MS 119 7533.38 88.41 31.07 30.34 4697.82 -1211.77 -1211.77 1896.73 2250.77 122.57 2.04 BP _MWD+IFR+MS 120 7563.54 87.57 30.72 30.16 4698.88 -1185.90 -1185.90 1912.21 2250.09 121.81 3.02 BP MWD+IFR+MS [(c)2007 IDEAL ID12 OC O1] SCHLUMBERGER Survey Report 30-Jan-2007 11:39:05 Page 6 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) {deg) (f t) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 121 7594.94 88.87 31.85 31.40 4699.85 -1159.08 -1159.08 1928.51 2250.02 121.01 5.48 BP MWD+IFR+MS 122 7625.47 88.78 33.95 30.53 4700.48 -1133.46 -1133.46 1945.09 2251.24 120.23 6.88 BP _ MWD+IFR+MS 123 7655.80 88.66 35.30 30.33 4701.16 -1108.50 -1108.50 1962.31 2253.77 119.46 4.47 BP _ MWD+IFR+MS 124 7686.66 89.08 39.01 30.86 4701.77 -1083.92 -1083.92 1980.95 2258.10 118.69 12.10 BP _ MWD+IFR+MS 125 7717.09 89.99 43.07 30.43 4702.01 -1060.97 -1060.97 2000.92 2264.81 117.93 13.67 BP _ MWD+IFR+MS 126 7748.09 90.08 47.72 31.00 4701.99 -1039.21 -1039.21 2022.99 2274.30 117.19 15.00 BP MWD+IFR+MS 127 7778.73 90.40 50.20 30.64 4701.86 -1019.09 -1019.09 2046.09 2285.84 116.48 8.16 BP _ MWD+IFR+MS 128 7809.31 90.67 49.91 30.58 4701.58 -999.46 -999.46 2069.54 2298.24 115.78 1.30 BP _ MWD+IFR+MS 129 7841.39 91.14 48.67 32.08 4701.07 -978.54 -978.54 2093.85 2311.22 115.05 4.13 BP _ MWD+IFR+MS 130 7873.24 91.04 47.46 31.85 4700.47 -957.26 -957.26 2117.54 2323.86 114.33 3.81 BP _ MWD+IFR+MS 131 7905.41 91.47 44.16 32.17 4699.76 -934.84 -934.84 2140.60 2335.83 113.59 10.34 BP MWD+IFR+MS 132 7936.94 90.87 38.82 31.53 4699.12 -911.24 -911.24 2161.47 2345.70 112.86 17.04 BP _ MWD+IFR+MS 133 7968.84 89.12 36.50 31.90 4699.12 -885.99 -885.99 2180.96 2354.05 112.11 9.11 BP _ MWD+IFR+MS 134 8000.81 88.30 33.61 31.97 4699.84 -859.83 -859.83 2199.32 2361.42 111.35 9.39 BP _ MWD+IFR+MS 135 8031.75 88.39 30.15 30.94 4700.73 -833.57 -833.57 2215.65 2367.26 110.62 11.18 BP _ MWD+IFR+MS 136 8064.31 89.29 25.63 32.56 4701.39 -804.80 -804.80 2230.87 2371.60 109.84 14.15 BP MWD+IFR+MS 137 8096.26 89.64 21.84 31.95 4701.69 -775.56 -775.56 2243.73 2373.99 109.07 11.91 BP _ MWD+IFR+MS 138 8127.85 89.41 17.08 31.59 4701.95 -745.79 -745.79 2254.25 2374.41 108.31 15.08 BP _ MWD+IFR+MS 139 8159.68 88.85 13.45 31.83 4702.44 -715.09 -715.09 2262.63 2372.94 107.54 11.54 BP _ MWD+IFR+MS 140 8191.78 88.05 9.76 32.10 4703.31 -683.66 -683.66 2269.08 2369.84 106.77 11.76 BP _ MWD+IFR+MS 141 8223.57 88.52 5.70 31.79 4704.26 -652.18 -652.18 2273.36 2365.06 106.01 12.85 BP MWD+IFR+MS 142 8256.01 89.58 0.75 32.44 4704.80 -619.81 -619.81 2275.18 2358.09 105.24 15.60 BP _ MWD+IFR+MS 143 8287.33 89.64 359.16 31.32 4705.01 -588.49 -588.49 2275.15 2350.03 104.50 5.08 BP _ MWD+IFR+MS 144 8318.97 89.69 359.63 31.64 4705.19 -556.85 -556.85 2274.82 2341.99 103.75 1.49 BP _ MWD+IFR+MS 145 8350.96 89.21 358.24 31.99 4705.50 -524.87 -524.87 2274.23 2334.01 103.00 4.60 BP _ MWD+IFR+MS 146 8382.74 89.29 358.09 31.78 4705.92 -493.11 -493.11 2273.21 2326.08 102.24 0.53 BP MWD+IFR+MS 147 8414.69 90.98 356.28 31.95 4705.84 -461.20 -461.20 2271.64 2317.98 101.48 7.75 BP _ MWD+IFR+MS 148 8447.08 91.48 355.15 32.39 4705.15 -428.91 -428.91 2269.22 2309.40 100.70 3.81 BP _ MWD+IFR+MS 149 8478.49 91.63 355.56 31.41 4704.29 -397.61 -397.61 2266.68 2301.29 99.95 1.39 BP _ MWD+IFR+MS 150 8510.38 91.10 354.20 31.89 4703.54 -365.86 -365.86 2263.83 2293.21 99.18 4.58 BP _ MWD+IFR+MS • [(c)2007 IDEAL ID12 OC O1] SCHLUMBERGER Survey Report 30-Jan-2007 11:39:05 Page 7 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 151 8542.73 89.84 352.09 32.35 4703.27 -333.75 -333.75 2259.97 2284.48 98.40 7.60 BP MWD+IFR+MS 152 8573.37 89.52 348.41 30.64 4703.44 -303.55 -303.55 2254.78 2275.13 97.67 12.06 BP _ MWD+IFR+MS 153 8605.05 90.56 345.52 31.68 4703.42 -272.70 -272.70 2247.64 2264.12 96.92 9.70 BP _ MWD+IFR+MS 154 8637.30 89.90 342.66 32.25 4703.29 -241.68 -241.68 2238.80 2251.81 96.16 9.10 BP _ MWD+IFR+MS 155 8669.32 89.48 341.81 32.02 4703.46 -211.19 -211.19 2229.03 2239.01 95.41 2.96 BP _ MWD+IFR+MS 156 8701.03 89.50 341.87 31.71 4703.75 -181.06 -181.06 2219.15 2226.52 94.66 0.20 BP _MWD+IFR+MS 157 8733.20 89.39 341.09 32.17 4704.06 -150.56 -150.56 2208.93 2214.05 93.90 2.45 BP MWD+IFR+MS 158 8765.38 89.83 342.33 32.18 4704.28 -120.01 -120.01 2198.83 2202.10 93.12 4.09 BP _ MWD+IFR+MS 159 8796.89 89.50 341.20 31.51 4704.46 -90.08 -90.08 2188.97 2190.82 92.36 3.74 BP _ _MWD+IFR+MS 160 8828.77 90.62 341.70 31.88 4704.43 -59.86 -59.86 2178.83 2179.65 91.57 3.85 BP MWD+IFR+MS 161 8860.59 90.51 341.93 31.82 4704.11 -29.63 -29.63 2168.90 2169.10 90.78 0.80 BP MWD+IFR+MS 162 8891.91 90.30 342.06 31.32 4703.89 0.16 0.16 2159.22 2159.22 90.00 0.79 BP _ MWD+IFR+MS 163 8924.47 89.87 342,52 32.56 4703.84 31.17 31.17 2149.31 2149.54 89.17 1.93 BP _ _MWD+IFR+MS 164 8956.29 89.61 342.59 31.82 4703.99 61.53 61.53 2139.78 2140.66 88.35 0.85 BP MWD+IFR+MS 165 8988.19 90.39 340.17 31.90 4703.99 91.76 91.76 2129.59 2131.57 87.53 7.97 BP _ MWD+IFR+MS 166 9019.95 90.72 339.33 31.76 4703.68 121.55 121.55 2118.60 2122.08 86.72 2.84 BP _MWD+IFR+MS 167 9051.92 90.52 338.55 31.97 4703.33 151.39 151.39 2107.11 2112.54 85.89 2.52 BP _MWD+IFR+MS 168 9083.93 89.70 338.30 32.01 4703.27 181.15 181.15 2095.34 2103.16 85.06 2.68 BP MWD+IFR+MS 169 9115.82 89.79 336.63 31.89 4703.42 210.61 210.61 2083.12 2093.74 84.23 5.24 BP _ MWD+IFR+MS 170 9147.81 92.68 334.50 31.99 4702.73 239.72 239.72 2069.89 2083.73 83.39 11.22 BP _ MWD+IFR+MS 171 9179.33 92.75 333.77 31.52 4701.23 268.05 268.05 2056.16 2073.56 82.57 2.32 BP MWD+IFR+MS 172 9210.99 92.49 333.37 31.66 4699.79 296.37 296.37 2042.08 2063.47 81.74 1.51 BP _ MWD+IFR+MS 173 9243.42 92.40 332.63 32.43 4698.40 325.24 325.24 2027.37 2053.29 80.89 2.30 BP _ MWD+IFR+MS 174 9275.41 91.43 334.16 31.99 4697.33 353.83 353.83 2013.05 2043.91 80.03 5.66 BP _ MWD+IFR+MS 175 9306.90 88.32 334.46 31.49 4697.40 382.20 382.20 1999.40 2035.61 79.18 9.92 BP _ MWD+IFR+MS 176 9339.54 87.90 334.55 32.64 4698.48 411.65 411.65 1985.36 2027.59 78.29 1.32 BP _MWD+IFR+MS 177 9370.94 88.02 334.62 31.40 4699.60 439.99 439.99 1971.89 2020.39 77.42 0.44 BP _MWD+IFR+MS 178 9403.42 89.22 335.15 32.48 4700.38 469.39 469.39 1958.11 2013.59 76.52 4.04 BP MWD+IFR+MS 179 9435.14 89.81 336.12 31.72 4700.65 498.28 498.28 1945.03 2007.84 75.63 3.58 BP _ MWD+IFR+MS 180 9466.66 89.67 336.49 31.52 4700.79 527.14 527.14 1932.36 2002.97 74.74 1.25 BP _ MWD+IFR+MS • • [(c)2007 IDEAL ID12 OC O1] SCHLU MBERGER Survey Rep ort 30-Jan-2007 11:39:05 Page 8 of 8 Seq Measured Incl Azimuth Course TVD Vertical -------- Displ -------- Displ --------- Total ------ At ----- DLS ----- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 181 9498.61 90.65 337.18 31.95 4700.70 556.52 556.52 ------ 1919.79 --------- 1998.83 ------ 73.83 ----- 3.75 ----- ------ BP MWD+IFR+MS 182 9531.24 90.53 336.62 32.63 4700.36 586.53 586.53 1906.99 1995.15 72.90 1.76 _ BP MWD+IFR+MS 183 9562.73 90.48 336.88 31.49 4700.09 615.46 615.46 1894.56 1992.02 72.00 0.84 _ BP MWD+IFR+MS 184 9575.65 89.82 336.99 12.92 4700.05 627.35 627.35 1889.50 1990.92 71.63 5.18 _ BP MWD+IFR+MS 185 9625.00 89.82 336.99 49.35 4700.21 672.77 672.77 1870.21 1987.54 70.21 0.00 _ Project to TD J [(c)2007 IDEAL ID12 OC O1] • • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Christine Mahnken Well No V-205 Date Dispatched: 7-Mar-07 Installation/Rig Nabors 9ES Dispatched By: Nate Rose LWD Log DeliveryV1.1,10-02-03 Data No Of Prints No of Floppies Surveys 2 1 Received By: Please sign and return to: Drilling & Measurements LWD Division ~~ 2525 Gambell Street, Suite 400 Anchorage, Alaska 99501 nroselQslb.com Fax:907-561-8317 a~~-~~~ i ~~yT~~++ --~~tt~~~~ ~Ai,~ ®id-7~R~~ii®ls ~lii•~~e7~®id Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 SARaW PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Orion Oil Pool, PBU V-205 BP Exploration (Alaska) Inc. Permit No: 206-180 Surface Location: 4692' FSL, 1619' FEL, SEC. 11, T11N, Rl lE, UM Bottomhole Location: 98' FSL, 356' FWL, SEC. O1, T11N, R11E, UM Dear Mr. Tirpack: 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 comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED thisday of December, 2006 cc: Department of Fish & Game, Habitat Section w/ o .encl. Department of Environmental Conservation w/o encl. ~~~~ ~~' > , STATE OF ALASKA ~-06 RECEIV'~C~~ ALAS~IL AND GAS CONSERVATION COMMI PERMIT TO DRILL SEC 2 1 2006 20 AAC 25.005 ~'~~ ~18:SiC~ (71i e~'i ~;se ('nne 1 a. Type of work ® Drill ^ Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proF~ ^ Coalbed Methane LJ'~~~r ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 / 11. Well Name and Number: PBU V-205 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 9605 TVD 4708 12. Field /Pool(s): Prudhoe Bay Field / Orion 4a. Location of Well (Governmental Section): Surface: 4692' FSL 1619' FEL 11 SEC T11N R11E UMW 7. Property Designation: ADL 028240 Schrader Bluff , , , . , , . Top of Productive Horizonr ~ 2633' FSL, 1050' FEL;`SEC. `11,'T11N, R11E, UM (OBd) 8. Land Use Permit: 13. Approximate Spud Date: January 5, 2007 Total Depth: ~ ~ ~ `. " ~ '~ia 98' FSL, 356' FWL, SEC. 01, T11N, R1'IE, UM 9. Acres in Property: 2560 ~ 14. Distance to Nearest Property: 7850' 4b. Location of Well (State Base Plane Coordinates): Surface: x-590684 y-5969941 Zone-ASP4 10. KB Elevation Plan (Height above GL): 82.5 feet 15. Distance to Nearest Well Within Pool: ~T t ~ c 16. Deviated Wells: Kickoff Depth: 700 feet Maximum Hole An le: 94 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2084 Surface: 1625 18. a in Pro ram: S fi i ns T in D h -Bottom uanti of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 48" 20" x 34" 215.5# A53 Weld 110' Surface Surface 110' 110' 260 sx Arctic Se A rox. 13-1/2" 10-3/4" 45.5# L-80 BTC 3036' Surface Surface 3036' 2848' 580 sx AS Lite 320 sx Class'G' -7/8" 7-5/8" 2 .7# L-8 BTC-M / TCII 575 ' rf c Surfa 5753' 4688' 446 Cla 'G' 6-3/4" 4-112" 12.6# L-80 IBT 4305' 5300' 9605' 4708' Uncemented Slotted Liner 3 19. PRESE NT'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 TVD (ft): Junk (measured): asirrg Length:.. ize ement Vottame MD TVD Conduct6Ea Structural Surface ' Intermediate Pr i n Liner - Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Scott Kolstad, 564-5347 Printed Name Robert Tirpack Title Senior Drilling Engineer ~~!!~ Prepared By Name/Number: Si nature IKA~ Phone 564-4166 Date la ~~La~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: ®~~ -/per API Number: 50-j,~~9'v7.333~'fi1O Permit Ap royal Da e: I See cover letter for oth r re irements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: Samples Req'd: ^ Yes ,~No Mud Log Req'd: ^ Yes ,~Vo ~,'~ ~P ~ ~ p C~~ ~ Ru~caS,o~SC~> Ci~S Measures: ~es ^ No D rectional Survey Req'd: ~es ^ No Other: ~~ ~ '+"~1~iv-emu ~*1\~2~~ -~~.~"~- Date ~a- r' Q,~ APPROVED BY THE COMMISSION COMMISSIONER _ ~, ates Form 10-401 Revised 12/2005 °~ -~ ~ r ~~ ~ Submit In Duplicate - I ~ ~. F ~ Well Name: ~ ~ V-205, V~205 L1, V-205 L2 ~ Drill a lete Plan Summary Type of Well (producer or injector): Schrader Bluff OA, OBa, and OBd Multi-Lat producer Surface Location: X = 590,683.57 Y = 5,969,941.37 A Sec 11 T 11 N R 11 E 58 ' L V-205 OBd Target Start: X = 591279 Y = 5967889 Z = -4605 TVDSS r Sec 11, T 11 N, R11 E, FEL: 1050' FSL: 2633' ~~~5 r~ V-205 OBd Target End: X = 592650 Y = 5970650 Z = -4625 TVDSS Sec 1 T 11 N, R11 E, FWL: 356' FSL: 98' V-205L1 OBa Target Start: X = 590772 Y = 5,968125 Z = - VDSS Sec 11, T 11 N, R11 E, FEL: 1554' FNL: 2405' V-205L1 OBa Target End: X = 594465 Y = 5972320 Z = -4520 TVDSS Sec 1, T 11 N, R11 E, FWL: 2193' FSL: 1744' V-205L2 OA Target Start: X = 590652 Y = 5,968,205 Z = -4340 TVDSS Sec 11, T 11 N, R11 E, FEL: 1673' FNL: 2323 V-205L2 OA Target End: X = 594445 Y = 5,972,287 Z = -4465 TVDSS Sec 1, T 11 N, R11 E, FWL: 2173' FSL: 1712' AFE Number: TBD Ri Nabors 9ES GL: 54.5 RT: 28.5 RTE: 82.5 Estimated Start Date: January 5, 2007 O eratin da s to com lete: 36 Well Information Distance to Nearest Property: Distance to Nearest Well in Pool: Well Type: Current Status: Conductor: BHT: BHP: 7850' to PBU boundary 102' from V-115 well bore in the OBd interval Schrader O-sand Tri-lateral Producer New well 20" X 34", 215.5 ppf, A53, ERW set at 110' KB 90 °F C~3 4590' TVDss 8.3 - 8.7 EMW ppg in Schrader OBd sands Permit to Drill 6/21/06 • • (7) Formation Tops(TVDss) and Estimated Pore Pressures Commerci al Est. Est. Hydrocarb Pore Formation on Pres To s Uncertaint Bearin s. Est. Pore Press. Formation TVDss feet Yes/No Psi EMW NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation tops are required from surface to TD for all new wells G1 -245 +/-50' No 111 8.7 SV6 -890 +/-50' No 404 8.7 SV5 -1545 +/-50' No 701 8.7 SV4 -1675 +/-50' No 760 8.7 Base Permafrost -1705 +/-50' No 774 8.7 Gas SV3 -2055 +/-50' H drates 933 8.7 Gas SV2 -2230 +/-50' H drates 1012 8.7 Gas SV1 -2550 +/-50' H drates 1158 8.7 UG4 -2845 +/-50' Thin coal 1292 8.7 Heavy Oil between - 2875 and - UG4A -2875 +/-50' 3070 SS 1305 8.7 Thin coals; Poss. Heavy oil in several thin sds between 3400'-3550' UG3 -3220 +/-50' ss 1462 8.7 Heavy oil in several thin sds between 3820'-3950' UG1 -3715 +/-50' SS 1687 8.7 UG_Ma -3995 +/-50' No, wet 1814 8.7 UG_Mbl -4040 +/-50' No, wet 1834 8.7 UG_Mb2 -4110 +/-50' No, wet 1866 8.7 UG_Mc -4160 +/-50' No, wet 1889 8.7 +/- 150' Fault #1 -4180 MD 1898 Yes, thin, SB_Nb -4205 +/-25' ti ht sd 1909 8.7 SB_Nc -4235 +/-25' No 1923 8.7 SB_Ne -4243 +/-25' No 1926 8.7 1890- SB_OA -4355 +/-25' Yes 1977 8.3-8.7 1920- SB_OBa -4430 +/-25' Yes 2011 8.3-8.7 1940- SB_OBb -4470 +/-25' Yes 2029 8.3-8.7 SB_OBc -4530 +/-25' Yes 2057 8.7 1980- SB_OBd -4590 +/-25' Yes 2084 8.3-8.7 Not SB OBe Reached 2290 8.7 Permit to Drill 12/12/06 • • ~~' TD for all laterals will be at end of polygon. No extensions beyond the end of Well TD Criteria the polygons are planned. Note that OBd polygon is shorter than that for OA (i.e. ??ft TVD, and OBa. End of OBd polygon defined by standoff from V-2121 injector. End ??ft Rathole, etc.) of OA, OBa polygons defined by standoff from large fault. Formation pressures from surface to N Sands sands are calculated based on a .454 water gradient based on V-100 MDT data. A formation pressure range is estimated for the SB_OA, SB_OBa, SB_OBb, and SB_OBd sands with the higher pressure limit for each sand assumed at original pressure conditions and the lower pressure limit assumed based on moderate pressure depletion resulting from production from the V-9()4 mi~ltilataral wall which has laterals ~mm~leteri in each of ihasa 4 Sancls_ Mud Program: 13-1/2" Surface Hole Mud Pro erties: Spud -Freshwater Mud Interval Densit Funnel vis YP PH FL Initial 8.5 - 9.1 250-300 50-70 8.5-9.0 NC-8.0 Base Perm 9.0 - 9.5 200-250 30-45 8.5-9.0 8.0 Interval TD 9.6 max 200-250 30-40 8.5-9.0 5.0-7.0 9-7/8" Intermediate Hole Mud Pro erties: Freshwater Mud (LSND) Interval Densit YP PV API Filtrate MBT H Chlorides Surface shoe to interval TD 8.8 - 9.3 22-30 12-18 4-6 < 20 9.0-9.5 <600 6-3/4" Production Hole Mud Pro erties: LVT-200 MOBM (Versa-Pro) Interval Densit Stabili Oil: Water Ratio YP PV API Filtrate MBT All five Laterals 9.2 650-900 80:20, initial 15-19 <20 4-5.5 < 6 Survey and Logging Program: 13-1/2" Hole Section: Surface Gyro may be needed O en Hole: MWD / GR Cased hole: None 9-7/8" Intermediate Hole: Surveys will be IIFR corrected real time and multi-station O en hole: MWD / GR / Res / Azimuthal Den / Neu /PWD Cased Hole: None 6-3/4" Produciton Holes: Surve s will be IIFR corrected real time and multi-station O en hole: MWD / GR / Res / Azimuthal Den / Neu /AIM /PWD Cased Hole: N/A Casin lTubin Pro ram Hole Size Csg / Tb O.D. WUFt Grade Conn Burst si Collapse si Length Top MD /TVD Bottom MD /TVD 48" 20" X 34" 215.5# A53 Weld GL 110'/110' 13-~h" 10-3/a" 45.5# L-80 BTC 5210 2480 GL 3036' / 2848' 9-%8" 7 5/" 29.7# L-80 BTC-M / TC-II 6,890 4,790 5753' GL 5753' / 4688' 6-3/a" OBd 4-~h" slotted 12.6# L-80 IBT N/A N/A 4305' 5300' / 4478' 9605' / 4708' 6-3/a" OBa 4-'h" slotted 12.6# L-80 IBT N/A N/A 6411' 5100' / 4567' 11511' / 4603' 6-3/a" OA 4-~h" slotted 12.6# L-80 IBT N/A N/A 6518' 4931' / 4385' 11449' / 4548' Tubing 4-'/z" 12.6# 13Cr- 80 Vam To 8,430 7,500 4941' GL 4941' / 4391' 3 Permit to Drill 12/12/06 ~^-- Surface and Anti-Collision Issues • Surface Shut-in Wells: No wells will require surface shut-in. V-01 will require well house removal in order to move over well V-205. No other wells should require well house removal or surface shut-in. Close Approach Shut-in Wells: No wells will require subsurface isolation for this directional profile. Close Approach Well List: Ensure the anti-collision scan is run again after V-217i is drilled. Lateral Well Ctr-Ctr Reference Allowable Precautionary Name Distance MD Deviation Comment Main V-01 31.17 455 22.93 Use Traveling bore C tinder Main V-217 16.3 475 7.15 Use Traveling bore lanl C tinder Main V-100 89.5 793 77.15 Use Traveling bore C tinder Main V-117 59.72 394 52.77 Use Traveling bore C tinder Main V-119 77.81 1703 49.76 Use Traveling bore C tinder L1 V-214 89 8588 4177 L2 V-214 94 8714 4312 Cement Calculations Casing Size: 10-3/a -in 45.5-Ib/ft L-80 BTC surface casing Basis: Lead: 250% excess over gauge hole in permafrost, 30% excess over gauge hole below permafrost Lead TOC: Surface Tail: 700' of open hole with 30% excess, plus 80' shoe track Tail TOC: 2,336' MD 700' MD above shoe to kee tail TOC below base of ermafrost Total Cement Volume: Spacer 75 bbls of Viscosified Spacer weighted to 10.10 ppg (Mud Push) Lead 459 bbls, 2575 cuft, 580 sks 10.7 Ib/ al ASL G + adds - 4.44 cufUsk Tail 67 bbls, 374 cuft, 320 sks 15.8 Ib/ al Class G + adds - 1.17 cuft/sk Temp BHST ~55° F. BHCT ~60° F estimated by Schlumberoer In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Casing Size: 7-5/8", 29.7-Ib/ft L-80 BTC-M / TC-II intermediate casin Basis: Lead: None Lead TOC: N/A Tail: 1780' of open hole with 30% excess, plus 80' shoe track Tail TOC: 3973' MD (500' MD above the Ma, 936' MD below Surface Shoe) 3 acer 50 bbls of Viscosified S acer Mud ush Wei hted to 10.3 Tail 92 bbls, 518 cuft, 446 sks 15.8 Ib/ al G + Gasblok -1.16 c Temp BHST ~ 90° F at 4590 TVDss Centralizer Recommendations 10-3/a" Casing Centralizer Placement a) Run (25) 10-3/4" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 1,000' MD above the shoe. 7 5/8" Casing Centralizer Placement • Run two centralizers per joint separated w/ a stop ring in the middle of the joint from TD to planned TOC. 4 Permit to Drill 12/12/06 • • 7 5/e" Casing Space Out a) Spaceout the 7 5/e" casing to place a full joint in the window area of the OBa and OA sands. b) Place 1 RA tag above each window exit. RA tags to be spaced out ~40 - 80' above window depth except on the OBd lateral. The RA tag for the OBd lateral will need to be placed 1125' above the casing shoe. c) Marker joints: Marker joints will be placed above each window. Permit to Drill 12/12/06 • Well Control • Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. BOP regular test frequency will be 14 days, with a function test every 7 days. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Surface Hole A diverter will be nippled up and function testetl prior to drilling surface hole Intermediate Section • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 10-3/4" Casing Test: • Integrity Test - 9-7/8" hole: • Kick Tolerance: Production Section • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 7-5/8" Casing Test: • Integrity Test - 6-3/4" hole: • Kick Tolerance: • Planned completion fluid: 2,084 psi -Schrader OBe (8.7 ppg @ 4,590' TVDss) 1,625 psi -Based on a full co'-lumn of gas C~ 0.10 psi/ft 3,500 psi/250 psi Rams 2,500 psi/250 psi Annular 3,500 psi LOT 109 bbls with a 12.5 ppg EMW LOT , 8.7 ppg OBd 2,084 psi - Schrader OBd (8.7 ppg @ 4,590' TVDss) 1,625 psi -Based on a full column of gas C«~ 0.10 psi/ft 3,500 psi/250 psi Rams 2,500 psi/250 psi Annular 3,500 psi FIT to 11.5ppg EMW for OBd lateral only Infinite at OBd, OBa, and OA with an 11.5 ppg EMW FIT 9.2 ppg SF OBM in Laterals, 9.2 ppg Brine, 6.8 ppg diesel in mother bore Disposal • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. 6 Permit to Drill 12/12/06 • • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control A. The Schrader in the target fault block is expected to be normal pressured at 8.3-8.7 ppg EMW. This pressure is estimated based on offset well pressures and material balance. II. Hydrates and Shallow gas A. Gas Hydrates are expected at V-pad from the SV5 thru the SV1 sands below the base of the permafrost. Setting casing through the SV1 should keep hydrate exposure from extending past the surface hole. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. Occasionally hydrates are encountered below the SV1. III. Lost Circulation/Breathing A. Lost circulation is not expected at fault #1. This fault has been penetrated by most wells drilled from V Pad. B. Breathing is not expected on this well. IV. Kick Tolerance/Integrity Testing Kick Tolerance / Inte rit Testin Summa Table Casing set / Maximum Influx Valume Mud Weight Exp Pore Press Min LOT /FIT Interval Surface / 9 7/8" 109 bbls 9.3 8.7 (OBd) (LOT, 12.5 ppg assumed) Intermediate / 6-3/4" Infinite 9.3 8.7 (OBd) 11.5 (FIT for OBd lateral onl NOTE: All LOT /FIT will be taken with a minimum of 20-ft and a maximum of 50-ft of new hole drilled outside of the previous casing string An FIT will only be performed for the OBd lateral, not the OBa or OA. V-Pad development wells may have "kick tolerances" in the 25 bbl range. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/ roduction intervals. V. Hydrogen Sulfide V Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 - 110 ppm is expected as a result of the use of Ivishak gas lift gas. All V Pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: Adjacent producers at Surface: ~vcs~~ V-01 15 ppm ~+-ilQvr.~~- V-117 20 ppm Adjacent producers at TD: 11~~,~J~ V-109 10 ppm V-117 20 ppm QQ (/'~'~`r`' 1[. V-204 100 ppm S L~~r-cac.l~~a VI. Faults A. One fault is expected to be crossed in V-205 and two additional faults may be encountered.. No losses are expected to be associated with these faults. No faults are expected in the reservoir section, although sub seismic faults with throws <25' may be encountered. Fault Location MD TVDss Throw Direction Uncertainty Fault #1 - V Pad Fault 4723' -4180 -100' Southwest +/- 150' MD 7 Permit to Drill 12/12/06 • • Possible fault - V-205 (&Li/L2 - V-205 HA MD listed 6,835 -4615 -5' Southwest +/-150' M.D. Possible fault - V- 205L1 & L2 (MD is from L1 10,400 -4513 -5' Southwest +/- 150' M.D. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION V-205, V-205 L1, V-205 L2 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rice Work: 1. A 34" x 20" insulated conductor has already been set and surveyed. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. Prepare neighboring wells for the rig move and production simops. Drilling Riq Operations: 1. MIRU Nabors 9ES. Nipple up diverter spool and riser. Function test diverter. PU 4" DP and stand back in derrick. 2. MU 13-'/z" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3036' MD. The actual surface hole TD will be +/-200' TVD below the top of the SV1 sand. 3. Run and cement the 10-3/a", 45.5#, L-80 BTC surface casing back to surface. ND drilling spool and riser and NU casing /tubing head. NU BOPE and test to 3,500 psi. 4. MU 9-'/e" directional drilling assembly with MWD/GR/Res/Den/Neu/PWD and a Ghost reamer±1,300' from the bit. RIH to float collar. Test the 10-3/a" casing to 5,500 psi for 30 minutes. 5. Drill out shoe track and displace the well to new 8.8 LSND drilling fluid. Drill 20' of new formation and perform a LOT. Directionally drill ahead to TD at ± 5753'. (±86' MD below Top OBd). 6. MU and run 7-5/e", 29.7#, L-80, BTC-M, TC-II casing to TD. Cement in one stage to 500' MD above the Ma. Bump plug with seawater. 7. Clean pits for displacement. Freeze protect 7 5/8" x 10-3/a" annulus to 2,200' TVD. • V-205 OBd Lateral 8. PU 6-3/a" conventional assembly with MWD/GR/Res/Den /Neu/AIM/PWD and RIH to the float collar. Test the 7-5/s" casing to 3,500 psi for 30 minutes. h x 9. Displace well over to 9.2 ppg Versapro MOBM. Drill out shoe track, circulate and condition mud. Drill 20' of \ a'' new formation and perform FIT to 11.5 ppg EMW. ~~ 10. Directionally drill ahead to TD geo-steering through the OBd to TD at 9605' MD. Back ream out of the hole to Q the shoe, circulate and condition mud. RIH to TD and displace well bore to SF MOBM. - 11. POOH to near OBa window depth, log the top OBa and OA (RA markers) with GR. ~~~' ~~` 12. MU and run 4-~/z" 12.6# L-80 BTC-M slotted liner with liner hanger and liner top packer. Position TOL for OBb whi stock. POOH. • V-205L1, OBa Lateral 13. PU the 7 5/a' whipstock assembly. Set the whipstock on the OBd liner top packer such that the top of the window is near the top of the OBa sand. Orient and set whipstock. Shear off Whipstock. Displace well over to 9.2 ppg Versapro MOBM. Mill window. POOH. ~(4,'~~ 14. RIH with 6-3/a" conventional drilling assembly with MWD/GR/Res/Den/Neu/AIM/PWD to whipstock. Directionally drill to the planned TD of the OBa lateral. Back ream out of hole to KOP, circulate and condition mud. RIH to TD and displace well bore to SF MOBM. POOH. 15. Pull whipstock #1. Run and set 4-~/z" slotted liner and hook hanger, POOH and LD liner running string. Run Baker Lateral Entry Module #1 with ZXP liner top packer, POOH. • V-205L2. OA Lateral ~~ 16. PU the 7 5/$" whipstock assembly. Set the whipstock on the OBa liner top packer such that the top of the ~iJ window is near the top of the OA sand. Orient and set whipstock. Shear off of Whipstock. Displace well over to 9.2 ppg Versapro MOBM. Mill window. POOH. 8 Permit to Drill 12/12/06 • ~ 17. RIH with 6-3/a" conventional drilling assembly with MWD/GR/Res/Den/Neu/AIM/PWD to whipstock. Directionally drill to the planned TD of the OA lateral. Back ream out of hole to KOP, circulate and condition mud. RIH to TD and displace well bore to SF MOBM. POOH. 18. Pull whipstock #2. Run 4-'/2" slotted liner and hook hanger, POOH and LD liner running string. Run Baker Lateral Entry Module #2 with ZXP liner top packer. Clean pits for displacement. Displace mother bore over to 9.2 ppg KCL brine. POOH. 19. MU 4-~/z" 12.6# IBT-M, L-80 completion assembly and RIH. See completion schematic for details. Land tubing hanger and run in lockdown screws. 20. Drop RHC ball and rod and set packer as per Baker recommendation and test tubing to 3,500 psi and annulus to 3,500 psi. Shear DCK valve. 21. Install two-way check and test to 1,000 psi from below. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 22. Pull two-way check. Reverse in brine with corrosion inhibitor to protect the annulus and freeze protect the well to 2,200' TVD. Install VR plug in 7-6/8" casing annulus valves. 23. Install BPV. Secure the well and rig down /move off Nabors 9ES. Post-Rig Work: 1. MIRU slickline. Pull the ball and rod /RHC plug. 2. Pull out DCK shear valve, install GLV in all of the other mandrels as per the PE. 9 Permit to Drill 12/12/06 TREE= FMC4-1/8" 5M WELLHEAD = FMC GEN 5 ACTUATO = KB. ELEV = 82.5' BF. ELEV = 54.5". KOP = 700', Max Angle=L1 Xdeg @ X~ Datum MD = xxxx' Datum TVD = xxxx' SS (103/4' C~ 4~i5L-$~ I~~~' 4.5"PHOENIX DSCHRGE PRESS SUB,ID = 3.948" 4.5" PHNUC MULTI-PRESS SENSOR, ID = 3.994" V-205 Proposed Completi DRLG DRAFT V-205 V-205 L2 -2400' 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS I 4870' 1 ~RA TAG I~tbd 1~ 7-5/8" x 5.5" BKR ZXP PACKER, ID = 4.82" 4931' Seal Assembly from LEM#2 L2 BKR HUGHES HOOK HGR, ID = 5.62" 4.97$' Minimum ID = 3.688" @', &' - LEM's 7-5/8" x 5.5" BKR ZXP PACKER, ID = 4.82" 5100' Seal Assembly from LEM#1 - L1 BKR HUGHES HOOK HGR, ID = 5.62" 5145' ~~I-I ibd 7-5/8" x 5.5" BKR ZXP PACKER, ID = 4.82" 5300' Seal Assembly from LEM#1 5315' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 KBG-2 DMY BK 3 KBG-2 SHEAR BK 2 KBG-2 DMY BK 1 KBG-2 DMY BK 4850' 4.5" Baker CMD-BX Sliding Sleeve, 3.812" ID 4891' 7.625" x 4.5" Prernier Packer 3.87" ID 4911' 4.5" HES X nipple W/ RHGM Plug, ID 3.813" 4931' 4.5" HES X nipple, ID 3.813" 4941' 4.5" WLEG 4995'- 5001'( I Hookw all Hanoer below window - 3.99" ID - L2 OA tbd 4.5" L-80 12.6# BTC Slotted Liner 3.958" ID - L2 tbd 4" x 6.4" Swell Packer 3.9" ID - L2 X'-11,449' 4.5" L-80 12.6# BTC Slotted Liner 3.958" ID - L2 11449' 4.5" 12.6# L-80 IBT-M shoe - L2 5162'-5168' Hookwall Hanger below window - 3.99" ID- L1 5168'-5188' 4" x 6.4" Swell Packer 3.9" ID - L1 tbd 4.5" L-80 12.6# BTC Sbtted Liner 3.958" ID - L1 tbd 4" x 6.4" Swell Packer 3.9" ID - L1 x-11511' 4.5" L-80 12.6# BTC Slotted Liner 3.958" ID - L1 11511' 4.5" 12.6# L-80 IBT-M shoe (11,740' PBTD) - L1 ~T~I~ tbd 7-5/8" 29.7# L-80 BTGMISTL(6.875"ID)-MB 5753' ~ ~ 4.5" 12.6# L-80 BTC Slotted (3.958" ID) ' ; 4" x 6.4" Swell Packer 3.9" ID tbd r ~ ~ 4.5" 12.6# L-80 BTC Slotted (3.958" ID) , , 4.5" 12.6# L-80 BTGIBT Slotted/Solid Liner ' ' Shoe - Obd 9606' ' ~ ~ ~ u DATE REV BY COMMENTS DATE REV BY COMMENTS OR~N UNff 10/19/06 SRK Proposed COMPLETION WELL: V-205, L1, L2 PERMIT No: 205- API No: 50-029- SEC 11, T11 N, R11 E, ' NSL & ' WEL BP Exploration (Alaska) 109' ---- -- ~-- --------- ~-P s°~. -u.~„ YVno .o I I ~ a°~ ~ d : a~` ° ° I~ ~ y~ Na I 15'00'00" GRID I I u`d ,; e o~° q° o~' T I PLANT I I a KwESTUK I . .i '+. ~ °, ~ N e 'o° ~p ~. _ c I i ~ ors'- ~ = 2 ° ~ ` ~ 1 " A I I 3 ~ c/ PROJEC~~I= I ^ v-12o ^ v-115 I ~~° AREA I ^ V-03 ^ V-213i I a `~ I ^ V-110 V-100 i ,F, 9~Y:.` • VP ~b~ a •. ^ v-111 ~- V-122 I ^ V-103 V-117 I ~ :~ o `. .6 ~°~ •°Fu. ^ V-212 SLOT S-R I ~ ° 10 ' ; , 1~ ~ ~ ^ V-106 V-2171 I ~N~ b~ 12 °"~ I ^ v-o4 ~ V-205 I ~., a. ~ a o Q I ^ V-1051 ^ V-Ot I v-22,i ' VICINITY MAP I I I I N.T.S. I ~ ^ V-102 ^ V-SPARE (aur s-L) ( to ^ V-201 I ^ V-107 ^ SLOT S-J I I Z ^ V-~04i ^ V-204 m l '(~ ° ~ F, A ~q I ^ V-2101 ^ V-114 0~l .`Q`°°` '°°sf I ^ V-202 ^ V-119 Z I G~ ,^ ~ ^, -9 I : v=2'o;` ^ v-log , ,ago°49~• ~°~ I ^ V-211i ^ V-113 I °°°e°°°°°°°°°°°°°°°°°°°°°°°e°°° I ^ V-203 ^ V-112 I I I °°°°°°°°°°°°°°°°°°° °'c ~° Leonard J. O'Hanley ° I I ~ ° 11386 °°_ I I~ ~'s°s I o~ua- `~ I I I V-PAD ~- I SURVEYOR'S CERTIFICATE TO SPINE ROAD ~~ - - IHEREBY CERTIFY THAT I AM _ _ - PROPERLY REGISTERED AND LICENSED / - I THEPSTATE OF ANASKA ANDNTHAT ~// ,tD °1WA ~ PAD ~' ~ ~' I' MADEABY MUELOR UNDER MY DIRECTLY ~i ~,~' SUPERVISION AND THAT ALL -' ~ DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF DECEMBER 2, 2006. NOTES LEGEND 1. DATE OF SURVEY: DECEMBER 1 & 2, 2006. -~ AS-BUILT CONDUCTOR 2. REFERENCE FIELD BOOK: W006-14 PG's 54-57. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, ^ EXISTING CONDUCTOR NAD 27. GEODETIC POSITIONS ARE NAD-27. 4. BASIS OF HORIZONTAL CONTROL IS V-PAD OPERATOR MONUMENTATION. 5. BASIS OF ELEVATION IS KUPARUK PIPELINE CONTROL. ELEVATIONS ARE BP MEAN SEA LEVEL DATUM. 6. THE MEAN SCALE FACTOR FOR V-PAD IS 0.999909334. LOCATED WITHIN PROTRACTED SEC. 11. T. 11 N., R. 11 E.. UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD BOX ELEV. OFFSETS V-122 Y 5,969,960.76 N 10,000.14 70'19'39.583" " 70.3276619' 54 35' 4 711' FSL ' X 590,756.02 E 4,970.04 149'15'50.300 149.2639722' . 1,546 FEL V-205 Y 5,969,941.37 N 10,000.16 70'19'39.401" 70.3276114' 39" 54 4,692' FSL ' X 590,683.57 E 4,895.04 149'15'52.422" 149.2645617' . 1,619 FEL V-217i Y 5,969,945.18 N 10,000.12 70'19'39.437" 70.3276214' 54 45' 4,696' FSL ' X 590,697.94 E 4,909.90 149'15'52.001" 149.2644447' . 1,605 FEL C. KOD2I'L ~'~~ CeeIARKE (~ t cHEDMINISH by D ~ I' I DATE: I~~l 11Jn71 12/02/2006 ~~` DRAWING: FReoe wov os-oo GREATER PRUDHOE BAY V-PAD SHEET: ~ 19J~~OO ~o '10B NG. AS-BUILT CONDUCTORS 0 12 ISSUED FOR INFORMATON CMO ADM waxm~s xq w.o sux~.an SCALE 1 OF 1 t•=tso' WELLS V-122, V-205, V-217i N0. DA1E REVISION BY CNK ,wa°x.a, .+.~+~~ wsw Variance Request Issue Compliance with AOGCC testing requirements for BOP rams after they have been used in the normal coarse of operations. Re uest The AOGCC is in the process of developing a guideline document clarifing the intent of the regulations pertaining to function pressure testing ram type BOP's. BPXA requests a variance to the provisions of 20 AAC 25.035 {e)(~0)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment. Background AOGCC regulations require rams that have been used in the course of primary drilling & completion, workover and through tubing drilling operations be function pressure tested before the next wellbore entry. This is not a new regulation. The intent of this regulation is to ensure that ram type equipment has integrity after it has been utilized in a wellbore...for example; to ensure integrity if a ram was closed on a tool joint. The exact regulation language is: "if BOP sealing ram type equipment has been used, i# must be function pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure;" The pertinent sections are: 20 AAC 25.035 (e}(10)C PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036 {d){4) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285 (f)(2) TUBING WORKOVERS: 20 AAC 25.286(e}(1} WORKSTRING SERVICE OPERATIONS This issue has been discussed with Winton Aubert at the AOGCC. The test requirement in the regulation is intended to apply to ram type equipment only. The AOGCC understands that rarn type BOP's are utilized for purposes other than well control in the normal coarse of operations. The regulations allowing a variance are at 20 AAC 25.035{h) PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036{f) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285(h} TUBING WORKOVERS; 20 AAC 25.286(g} WORKSTRING SERVICE OPERATIONS...which says generally: 20 AAC 25.035(h)... Upon request of the operator, the commission will, in its discretion, approve a variance (1) from the BOPS requirements in (e) of this section if the variance provides at least an equally effective means of welt control; by V-205 (P6) Proposal S~hlumberger Report Date: October 24, 2006 CIieM: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA StructurelSlot: V-Pad/PIanV-205(S-P) ~~~~f~~ Well: Plan V-205 (S-P) Borehole: Plan V-205 OBd UWIIAPf#: 50029 Survey Name 1 Date: V-205 (P6) OBd /October 24, 2006 Tort 1 AHD 1 DDI 1 ERD ratio: 269.310° / 6514.41 ft / 6.554 / 1.384 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LatlLong: N 70.32761089, W 149.2645614 Location Grid NIE YIX: N 5969941.210 ftUS, E 590683.580 ftUS Grid Convergence Angle: +0.69251740° Vertical Section Azimuth: 0.000° Vertical Section Origin: N 0.000 ft, E 0.000 ft I~ TVD Reference Datum: RTE TVD Reference Elevation: 82.50 ft relative to MSL Sea Bed /Ground Level Elevation: 54.50 ft relative to MSL Magnetic Decination: 23.812° Total Field Strength: 57631.734 nT Magnetic Dip: 80.886° Declination Date: 15-Jan-07 Magnetic Declination Model: BGGM 2006 North Reference: True North Total Corr Mpg North •> True North: +23.812° Measured Vertlcal Gravity Comments Inclination Azimuth Sub•Sea TVD TVD NS EW DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Tool Face R d d R ft R R ft de d 100 R d 100 R de 100 R RUS RUS Klt U.VU V.VV lyL 3b -tSY. SU U .UU U .UU U. UU U.UU --- U.UU U.UU U.UU 59ti9941 .11 59U6ti3.5t5 N /U .3"L/61Uti9 W 14916456149 G1 327.50 0.00 197. 35 245. 00 327. 50 0. 00 0. 00 0.00 --- 0.00 0.00 0.00 5969941. 21 590683.58 N 70. 32761089 W 149.26456149 KOP Bld 1.5/100 700.00 0.00 197 .35 617. 50 700 .00 0 .00 0. 00 0.00 HS 0.00 0.00 0.00 5969941 .21 590683.58 N 70 .32761089 W 149.26456149 Bld 2.5/100 800.00 1.50 197 .35 717. 49 799 .99 -1 .25 -1. 25 -0.39 4.59R 1.50 1.50 0.00 5969939 .96 590683.20 N 70 .32760748 W 149.26456465 900.00 4.00 200 .22 817. 37 899 .87 -5 .77 -5. 77 -1.99 1.72R 2.50 2.50 2.87 5969935 .42 590681.66 N 70 .32759513 W 149.26457759 SV6 972.90 5.82 200. 76 890. 00 972. 50 -11. 61 -11. 61 -4.17 1.19R 2.50 2.50 0.74 5969929. 55 590679.55 N 70. 32757918 W 149.26459534 1000.00 6.50 200 .89 916. 94 999 .44 -14 .33 -14. 33 -5.21 1.O6R 2.50 2.50 0.46 5969926 .82 590678.55 N 70 .32757176 W 149.26460372 1100.00 9.00 201 .18 1016. 02 1098 .52 -26 .90 -26. 90 -10.05 0.77R 2.50 2.50 0.30 5969914 .19 590673.86 N 70 .32753740 W 149.26464299 1200.00 11.50 201 .35 1114. 42 1196 .92 -43 .48 -43. 48 -16.51 O.60R 2.50 2.50 0.17 5969897 .54 590667.60 N 70 .32749212 W 149.26469533 1300.00 14.00 201 .46 1211. 94 1294 .44 -64 .02 -64. 02 -24.56 0.50R 2.50 2.50 0.11 5969876 .91 590659.80 N 70 .32743601 W 149.26476064 1400.00 16.50 201 .54 1308. 42 1390 .92 -88 .48 -88. 48 -34.20 0.42R 2.50 2.50 0.08 5969852 .33 590650.46 N 70 .32736918 W 149. 9 1500.00 19.00 201 .59 1403. 65 1486 .15 -116 .82 -116. 82 -45.40 0.37R 2.50 2.50 0.06 5969823 .86 590639.60 N 70 2 .32729175 W 149.2 3 1600.00 21.50 201 .64 1497. 47 1579 .97 -148 .99 -148. 99 -58.15 HS 2.50 2.50 0.04 5969791 .54 590627.24 N 70 .32720387 W 149.265 00 SV5 1651.32 22.78 201. 66 1545. 00 1627. 50 -166. 96 -166. 96 -65.28 HS 2.50 2.50 0.04 5969773. 49 590620.33 N 70. 32715477 W 149.26509084 1700.00 24.00 201 .67 1589. 68 1672 .18 -184 .92 -184. 92 -72.42 HS 2.50 2.50 0.03 5969755 .44 590613.41 N 70 .32710570 W 149.26514868 SV4 1794.28 26.35 201. 70 1675. 00 1757. 50 -222. 18 -222. 18 -87.23 HS 2.50 2.50 0.03 5969718. 01 590599.05 N 70. 32700391 W 149.26526884 1800.00 26.50 201 .70 1680. 12 .1762 .62 -224 .55 -224. 55 -88.18 HS 2.50 2.50 0.03 5969715 .63 590598.13 N 70 .32699745 W 149.26527648 Base Perm 1827.88 27.19 201. 71 1705. 00 1787. 50 -236. 25 -236. 25 -92.83 HS 2.50 2.50 0.03 5969703. 88 590593.62 N 70. 32696549 W 149.26531423 End Bld 1889.04 28.72 201 .72 1759. 02 1841 .52 -262 .88 -262. 88 -103.44 --- 2.50 2.50 0.02 5969677 .12 590583.33 N 70 .32689273 W 149.26540025 SV3 2226.54 28.72 201. 72 2055. 00 2137. 50 -413. 55 -413. 55 -163.47 -- 0.00 0.00 0.00 5969525. 75 590525.13 N 70. 32648111 W 149.26588700 SV2 2426.10 28.72 201. 72 2230. 00 2312. 50 -502. 63 -502. 63 -198.97 --- 0.00 0.00 0.00 5969436. 25 590490.72 N 70. 32623773 W 149.26617478 SV1 2790.99 28.72 201. 72 2550. 00 2632. 50 -665. 53 -665. 53 -263.87 --- 0.00 0.00 0.00 5969272. 60 590427.80 N 70. 32579271 W 149.26670099 10-3/4" Csg Pt ~--t 3036.15 28.72 201. 72 2765. 00 2847. 50 -774. 98 -774. 98 -307.48 --- 0.00 0.00 0.00 5969162. 65 590385.52 N 70. 32549371 W 149.26705453 WeIlDesign Ver SP 2.1 Bld( doc40x_100) Plan V-205 (S-P)\Plan V-205 (S-P)\Plan V-205 OBdiV-205 (P6) Oed Generated 10/24/2006 10:07 AM Page 1 of 3 Measured Vertical Gra~ty Comments Inclination Azimuth SutrSea TVD 7VD NS EW DLS Build Rate Walk Rate Northing Easting Latitude LongiWde Depth Section Tool face ft d de ft ft ft ft ft de de 1100 ft de 100 ft de 100 ft ftUS ftUS vvr alu.JO to./L LVL/L LO'FO.UV LyU. OV -010./V -010./V -JLJ. /V --- V.UV U.UU U.UV 0JOJ ICE/J 0`JUJOJ. /J IV /U. JL030L40 W 74`J.ZO/700V0 UG4A 3161.58 28.72 201. 72 2875.00 2957. 50 -830.97 -830. 97 -329. 79 --- 0.00 0.00 0.00 5969106. 39 590363. 89 N 70. 32534073 W 149.26723540 UG3 3554.99 28.72 201. 72 3220.00 3302. 50 -1006.59 -1006. 59 -399. 76 --- 0.00 0.00 0.00 5968929. 95 590296. 05 N 70. 32486094 W 149.26780268 Crv 4/100 3638.57 28.72 201 .72 3293.30 3375 .80 -1043.91 -1043 .91 -414 .63 95 .47E 0.00 0.00 0.00 5968892 .46 590281. 64 N 70 .32475900 W 149.26792320 3700.00 28.58 196 .61 3347.22 3429 .72 -1071.70 -1071 .70 -424 .29 90 .98E 4.00 -0.23 -8.33 5968864 .55 590272. 31 N 70 .32468305 W 149.26800155 3800.00 28.77 188 .27 3434.99 3517 .49 -1118.46 -1118. 46 -434 .59 83 .67E 4.00 0.19 -8.33 5968817 .68 590262. 57 N 70 .32455532 W 149.26808506 3900.00 29.46 180 .17 3522.39 3604 .89 -1166.88 -1166. 88 -438 .13 76 .58E 4.00 0.69 -8.10 5968769 .22 590259. 62 N 70 .32442303 W 149.26811372 4000.00 30.61 172 .51 3608.99 3691 .49 -1216.74 -1216. 74 -434 .88 69 .95E 4.00 1.15 -7.66 5968719 .42 590263. 47 N 70 .32428684 W 149.26808737 4100.00 32.18 165 .44 3694.38 3776 .88 -1267.78 -1267. 78 -424 .87 63 .92E 4.00 1.57 -7.07 5968668 .51 590274. 10 N 70 .32414740 W 149.26800615 UG1 4124.43 32.62 163. 82 3715.00 3797. 50 -1280.40 -1280. 40 -421. 40 62. 54E 4.00 1.80 -6.66 5968655. 93 590277. 72 N 70. 32411293 W 149.26797801 4200.00 34.11 159 .03 3778.13 3860 .63 -1319.75 -1319. 75 -408 .14 58 .54E 4.00 1.97 -6.33 5968616 .74 590291. 46 N 70 .32400541 W 149. 6 4300.00 36.34 153 .27 3859.84 3942 .34 -1372.42 -1372. 42 -384 .76 53 .83E 4.00 2.23 -5.76 5968564 .37 590315. 47 N 70 2 .32386154 W 149.2 5 4400.00 38.81 148 .11 3939.10 4021 .60 -1425.51 -1425. 51 -354 .87 49 .75E 4.00 2.48 -5.15 5968511 .65 590346. 00 N 70 .32371651 W 149.26743855 Ma 4472.73 40.74 144. 71 3995.00 4077. 50 -1464.24 -1464. 24 -329. 11 47. 13E 4.00 2.65 -4.68 5968473. 23 590372. 22 N 70. 32361069 W 149.26722971 4500.00 41.49 143 .50 4015.55 4098 .05 -1478.77 -1478. 77 -318 .59 46 .22E 4.00 2.74 -4.42 5968458 .84 590382. 91 N 70 .32357101 W 149.26714445 Mb 4532.88 42.41 142. 09 4040.00 4122. 50 -1496.27 -1496. 27 -305. 30 45. 17E 4.00 2.79 -4.28 5968441. 49 590396. 41 N 70. 32352318 W 149.26703668 4600.00 44.34 139 .37 4088.79 4171 .29 -1531.94 -1531. 94 -276 .12 43 .19E 4.00 2.87 -4.06 5968406 .19 590426. 02 N 70 .32342575 W 149.26680007 Mc 4629.88 45.21 138. 22 4110.00 4192. 50 -1547.77 -1547. 77 -262. 25 42. 38E 4.00 2.94 -3.86 5968390. 53 590440. 07 N 70. 32338250 W 149.26668766 4700.00 47.32 135 .65 4158.48 4240 .98 -1584.76 -1584. 76 -227 .65 40 .60E 4.00 3.00 -3.67 5968353 .96 590475. 12 N 70 .32328145 W 149.26640709 Nb 4770.06 49.47 133. 25 4205.00 4287. 50 -1621.42 -1621. 42 -190. 25 39. 00E 4.00 3.07 -3.42 5968317. 76 590512. 96 N 70. 32318130 W 149.26610385 4800.00 50.40 132 .27 4224.27 4306 .77 -1636.98 -1636. 98 -173 .42 38 .37E 4.00 3.12 -3.27 5968302 .41 590529. 97 N 70 .32313880 W 149.26596744 Nc 4816.93 50.94 131. 73 4235.00 4317. 50 -1645.74 -1645. 74 -163. 69 38. 03E 4.00 3.14 -3.20 5968293. 76 590539. 81 N 70. 32311487 W 149.26588854 Ne 4829.68 51.34 131. 32 4243.00 4325. 50 -1652.32 -1652. 32 -156. 26 37. 78E 4.00 3.16 -3.16 5968287. 27 590547. 32 N 70. 32309689 W 149.26582828 4900.00 53.58 129 .18 4285.85 4368. 35 -1688.33 -1688. 33 -113 .70 36 .47E 4.00 3.19 -3.04 5968251 .78 590590. 30 N 70. 32299851 W 149.26548325 OA 4994.70 56.66 126. 49 4340.00 4422. 50 -1735.95 -1735. 95 -52. 34 34. 93E 4.00 3.25 -2.85 5968204. 92 590652. 23 N 70. 32286844 W 149.26498583 5000.00 56.83 126 .34 4342.91 4425. 41 -1738.58 -1738. 58 -48 .77 34 .85E 4.00 3.28 -2.74 5968202 .33 590655. 83 N 70. 32286124 W 149.26495689 '~ 5100.00 60.14 123 .71 4395.18 4477. 8 -1787.47 -1787. 47 21 .04 33 .47E 4.00 3.31 -2.63 5968154 .29 590726. 22 N 70. 32272768 W 149.26439091 OBa 5161.87 62.22 122. 17 4425.00 4507. 50 -1816.93 -1816. 93 66. 53 32. 73E 4.00 3.35 -2.49 5968125. 38 590772. 06 N 70. 32264719 W 149.26402212 5200.00 63.50 121 .25 4442.40 4524 .90 -1834.77 -1834. 77 95 .40 32 .31 L 4.00 3.37 -2.42 5968107 .90 590801. 14 N 70. 32259847 W 149.2 8 OBb 5264.34 65.69 119. 74 4470.00 4552. 50 -1864.25 -1864. 25 145. 48 31. 66E 4.00 3.39 -2.35 5968079. 03 590851. 57 N 70. 32251793 W 149.26 8 ....~. 5300.00 66.90 118 .92 4484.34 4i -1880.24 -1880. 24 173 .94 31 .34E 4.00 3.41 -2.28 5968063 .39 590880. 22 N 70. 32247424 W 149.26315134 5400.00 70.33 116 .71 4520.79 4603 .29 -1923.66 -1923. 66 256 .29 30 .53E 4.00 3.43 -2.21 5968020 .96 590963. 08 N 70. 32235560 W 149.26248378 Oec 5428.02 71.30 116. 11 4530.00 4612. 50 -1935.43 -1935. 43 279. 99 30. 33E 4.00 3.45 -2.15 5968009. 48 590986. 91 N 70. 32232344 W 149.26229167 5500.00 73.79 114 .60 4551.59 4634 .09 -1964.83 -1964. 83 342 .04 29 .88E 4.00 3.46 -2.10 5967980 .84 591049. 31 N 70. 32224312 W 149.26178865 5600.00 77.27 112 .56 4576.58 4659 .08 -2003.54 -2003. 54 430 .77 29 .37E 4.00 3.48 -2.04 5967943 .20 591138. 49 N 70 .32213735 W 149.26106935 OBd 5666.95 79.61 111. 22 4590.00 4672. 50 -2028.00 -2028. 00 491. 63 29. 10E 4.00 3.49 -1.99 5967919. 49 591199. 64 N 70. 32207054 W 149.26057598 End Crv /Target 5678.25 80.00 111 .00 4592.00 4674 .50 -2032.00 -2032. 00 502 .00 --- 4.00 3.50 -1.98 5967915 .61 591210. 05 N 70 .32205960 W 149.26049190 5753.11 80.00 111. 00 4605.00 4687. 50 -2058.42 -2058. 42 570. 83 --- 0.00 0.00 0.00 5967890. 03 591279. 19 N 70. 32198740 W 149.25993393 7-5/8" Csg Pt -~ 5753.25 80.00 111 .00 4605.02 4687 .52 -2058.47 -2058. 47 570 .95 --- 0.00 0.00 0.00 5967889 .98 591279. 32 N 70. 32198727 W 149.25993292 Crv 10/100 5773.25 80.00 111 .00 4608.50 4691 .00 -2065.53 -2065. 53 589 .34 48 .07E 0.00 0.00 0.00 5967883 .15 591297. 79 N 70 .32196798 W 149.25978386 5800.00 81.79 108 .99 4612.73 4695 .23 -2074.56 -2074. 56 614 .16 47 .75E 10.00 6.70 -7.52 5967874 .42 591322. 71 N 70 .32194331 W 149.25958267 WeIlDesign Ver SP 2.1 Bld( doc40x_100) Plan V-205 (S-P)\Plan V-205 (S-P)\Plan V-205 OBd\V-205 (P6) OBd Generated 10/24/2006 10:07 AM Page 2 of 3 Measured Vertical Gravity Comments Inclination Azimuth Sub-SeaTVD TVD NS EW DLS Build Rate Walk Rate Northing Easting Latitude LongiWde Depth Section Tool Face ft d d ft ft ft ft ft de de 100 ft de 100 ft de 100 ft ftUS ftUS byUU. UU t52f .b/ 1Vl. l)U 4t)Zl .'14 4/U3. 64 -'L"IUU ./ti -'L'IUU ./tf /1U.1ti 4/."13L IU.UU li.// End Crv 5916. 41 89 .68 100. 40 4621 .39 4703. 89 -2103. 91 -2103 .91 726.27 --- 10.00 6.80 Crv 10/100 5954. 87 89 .68 100. 40 4621 .60 4704. 10 -2110. 85 -2110 .85 764.09 88.42E 0.00 0.00 6000. 00 89 .78 96. 79 4621 .81 4704. 31 -2117. 59 -2117 .59 808.71 88.41 L 8.00 0.22 V-205 OBd Tgt 2 6097. 41 90 .00 89. 00 4622 .00 4704. 50 -2122. 51 -2122 .51 905.92 89.56E 8.00 0.22 6100. 00 90 .00 88. 79 4622 .00 4704. 50 -2122. 46 -2122 .46 908.51 89.56E 8.00 0.06 6200. 00 90 .06 80. 79 4621 .94 4704. 44 -2113. 39 -2113 .39 1008.02 89.56E 8.00 0.06 6300. 00 90 .12 72. 79 4621 .78 4704. 28 -2090. 56 -2090 .56 1105.29 89.58E 8.00 0.06 6400. 00 90 .18 64. 79 4621 .52 4704. 02 -2054. 42 -2054 .42 1198.45 89.60E 8.00 0.06 6500. 00 90 .24 56. 79 4621 .15 4703. 65 -2005. 66 -2005 .66 1285.66 89.63E 8.00 0.05 6600. 00 90 .28 48. 79 4620 .70 4703. 20 -1945. 24 -1945 .24 1365.24 89.66E 8.00 0.05 6700. 00 90 .33 40. 79 4620. 16 4702. 66 -1874. 34 -1874 .34 1435.64 89.71 L 8.00 0.04 End Crv 6783. 78 90 .36 34. 09 4619 .66 4702. 16 -1807. 86 -1807 .86 1486.54 --- 8.00 0.04 Crv 8/100 7427. 37 90 .36 34. 09 4615 .60 4698. 10 -1274. 88 -1274 .88 1847.27 11.61 R 0.00 0.00 V-205 OBd Tgt 3 7452. 75 92 .35 34. 50 4615 .00 4697. 50 -1253. 92 -1253 .92 1861.57 12.21 R 8.00 7.84 End Crv 7478. 75 94 .38 34. 94 4613 .47 4695. 97 -1232. 59 -1232 .59 1876.35 --- 8.00 7.82 Crv 8/100 7626. 53 94 .38 34. 94 4602 .18 4684. 68 -1111. 80 -1111 .80 1960.75 163.96R 0.00 0.00 V-205 OBd Tgt 4 7683. 53 90 .00 36. 20 4600 .00 4682. 50 -1065. 48 -1065 .48 1993.87 165.23R 8.00 -7.69 7700. 00 88 .73 36. 54 4600 .18 4682. 68 -1052. 22 -1052 .22 2003.63 165.22R 8.00 -7.74 End Crv 7741. 10 85 .55 37. 38 4602 .24 4684. 74 -1019. 42 -1019 .42 2028.31 --- 8.00 -7.73 Crv 8/100 7872. 72 85 .55 37. 38 4612 .45 4694. 95 -915. 15 -915 .15 2107.97 32.32R 0.00 0.00 7900. 00 87 .39 38. 54 4614 .13 4696. 63 -893. 68 -893 .68 2124.72 32.25R 8.00 6.76 V-205 OBd Tgt 5 7934. 10 89 .70 40. 00 4615 .00 4697. 50 -867. 29 -867 .29 2146.29 --- 8.00 6.77 Crv 10/100 8034. 10 89 .70 40. 00 4615 .52 4698. 02 -790. 69 -790 .69 2210.57 90.22E 0.00 0.00 8100. 00 89 .68 33. 41 4615 .88 4698. 38 -737. 89 -737 .89 2249.94 90.18E 10.00 -0.04 8200. 00 89 .65 23. 41 4616 .47 4698. 97 -650. 04 -650 .04 2297.45 90.13E 10.00 -0.03 8300. 00 89 .63 13. 41 4617 .10 4699. 60 -555. 28 -555 .28 2328.99 90.06E 10.00 -0.02 8400. 00 89 .63 3. 41 4617 .75 4700. 25 -456. 49 -456 .49 2343.60 90.00E 10.00 -0.01 8500. 00 89 .63 353. 41 4618 .39 4700. 89 -356. 65 -356 .65 2340.83 89.93E 10.00 0.01 8600. 00 89 .65 343. 41 4619 .02 4701. 52 -258. 82 -258 .82 2320.76 89.87E 10.00 0.02 End Crv 8635. 91 89 .66 339. 82 4619 .24 4701. 74 -224. 75 -224 .75 2309.44 --- 10.00 0.02 TD / 4-1/2" Lnr 9605.22 89.66 339.82 4625.00 4707.50 685.03 685.03 1975.03 --- 0.00 0.00 -/.:Sy 5yti/2f4y.Sti 5y"141y.U1 N /U.:SL1t5/ltib W '14y.'LStfifU44J -7.33 5967846.43 591435.15 N 70.32186310 W 149.25867387 0.00 5967839.94 591473.06 N 70.32184412 W 149.25836725 -8.00 5967833.74 591517.75 N 70.32182569 W 149.25800554 -8.00 5967830.00 591615.00 N 70.32181223 W 149.25721751 -8.00 5967830.08 591617.59 N 70.32181236 W 149.25719650 -8.00 5967840.35 591716.97 N 70.32183710 W 149.25638983 -8.00 5967864.35 591813.96 N 70.32189943 W 149.25560122 -8.00 5967901.62 591906.66 N 70.32199814 W 149.25484602 -8.00 5967951.42 591993.27 N 70.32213129 W 149.25413892 -8.00 5968012.79 592072.10 N 70.32229632 W 149.29 -8.00 5968084.53 592141.63 N 70.32248999 W 149.25292288 -8.00 5968151.62 592191.73 N 70.32267158 W 149.25251009 0.00 5968688.86 592545.95 N 70.32412740 W 149.24958461 1.61 5968710.00 592560.00 N 70.32418466 W 149.24946865 1.70 5968731.50 592574.52 N 70.32424293 W 149.24934875 0.00 5968853.29 592657.44 N 70.32457286 W 149.24866427 2.21 5968900.00 592690.00 N 70.32469937 W 149.24839561 2.04 5968913.38 592699.60 N 70.32473558 W 149.24831642 2.05 5968946.47 592723.87 N 70.32482517 W 149.24811628 0.00 5969051.69 592802.26 N 70.32510998 W 149.24747018 4.28 5969073.36 592818.74 N 70.32516861 W 149.24733434 4.27 5969100.00 592840.00 N 70.32524069 W 149.24715933 0.00 5969177.37 592903.34 N 70.32544991 W 149.24663798 -10.00 5969230.64 592942.06 N 70.32559413 W 149.24631868 -10.00 5969319.04 592988.51 N 70.32583407 W 149.24593319 -10.00 5969414.17 593018.90 N 70.32609292 W 149.24567721 -10.00 5969513.12 593032.31 N 70.32636281 W 149.24555853 -10.00 5969612.91 593028.33 N 70.32663555 W 149. 6 -10.00 5969710.48 593007.09 2 N 70.32690284 W 149.2 2 -10.00 5969744.41 592995.35 N 70.32699594 W 149.24583497 0.00 5970650.00 592650.00 N 70.32948164 W 149.24854466 WeIlDesign Ver SP 2.1 Bld( doc40x_100) Plan V-205 (S-P)\Plan V-205 (S-P)\Plan V-205 OBd\V-205 (P6) OBd Generated 10/24/2006 10:07 AM Page 3 of 3 by Schiumberger WELL V-205 (P6) FIELD Prudhoe Bay Unit - WOA 6TRUCNRE V-Pad Me9~eec Paremelers Surface LaciOen w.D3] Nlaska State Planes. Zone O0, U5 Feet Mrscetlaneous Motley. BGGM 2006 Dip 80.888' Data Janlnry 15. 300] Lar. N]01939.399 WtlNlq 5%990111 MU5 Gntl Donv X069351 ]00' Sbr. Plan V-305(5-P1 NO ReI. Robry Tebb (935011 above MSLI Map Dec'. r3J 813' F5. 5]631 ]nt Lon W109 15 53 03t EasBrg. 590683.56 M15 Sca4 Feq.0999909301] Pbn. V-305 (P610Btl Srvy Date. Oclaber 21, 3006 -2400 -1800 -1200 -600 0 600 0 600 1200 3000 1800 ~.' O O (D c 2400 d `~ O 3600 RTE .-..-..-..~..-..-..-..- -..-..-..-..-..-..-..-..-j.-..-..~..-..-..-..~..-. -..-..-..-..-..-.. -..- ~ .-..-..-..-..-..-..-..f..-..-..-..-..-..- :..................................:...................................:..................................:....................................................................:............................ KOP Bid 1.SH 00 Bld 2.5/700 .-..-..-..~..-..-..-..- -..-..-..-..-..-..-..-..- -..-..~..~..-..-..~..-. -.._.._.. _..~..-..-..- v~..-..-..-..-..-..-..- - .-..-..-..-..-..- j ..................................j.................................. ~..................................i............................... .j...................................;............................ ~. 4200 v-zos oBt 4800 I Cib T0~ / I 1 End Crv V-205 OBd Tgt 3 I Crv ~r End Crv End Crv tt9os.nwn r.,r 9 .............i..................................:.................................. o........................... ..._.._...{.._.._.._.._.._.._.._.._ .;. _.._.._.._.._.._.._.._ .t.._.._.._.._.._.._. OBd Tgt 8 Entl Crv (PO> oed c-rvv - 1 uvv - -vuv v vvv Vertical Section (ft) Azim = 0°, Scale = 1(in):600(ft) Origin = 0 N/-S, 0 E/-V 0 600 1200 1800 2400 3000 3600 4200 4800 by Schiumberger WELL V-205 (P6) FIELD Prudhoe Bay Unit - WOA STRUCTURE V-Pad Mafleel'r Parameters Motlel BGGM 2006 Dlp. BO 666' Date Janwry 15, 300] Surface Location NAD2]Nlaske Slala Planes, ZOrre Od,US Feel Lat'. N'l019 ]9 ]99 Notlbmfl 59899d121 f618 GnE COnv s0.69351 ]d0' Mlscella Glen. reaus Plan V-20515~P1 NDReI. Rotary Tade 162506 above MSLI i Mag Oec X2]012' FG'. 5>631 ]nT Lon: W1d91552.d21 Easlirg. 590603.56 M1G Scale Facf. 09999093x1] Plan: V-2051Pe10Btl Grvy Dale. October 20. 2006 -500 0 500 1000 1500 2000 2500 1000 500 0 n n n Z ~ -500 0 0 c N m U ~ -1000 v v v -1500 -2000 -2500 1000 500 0 -500 -1000 -1500 -2000 .......:...................................>..................................i..................................:..................................s..................................5................................ -2500 -500 0 500 1000 1500 «< W Scale = 1(in):500(ft) E »> 2000 2500 Plan V-205 (S-P)/Plan V-205 /< ~/ /~O i" I ~ O - Plan V-205 BP Alaska Anticollision Report -- ._ Company: SP Amoco Field: Prudhoe Bay Reference Site: PB V Pad Keference Well: Plan V-205 (S-P) Reference Wellpath: Plan V-205 _ - __ NO GLOBAL SCAN: Using user defined selection & scan criteria li Interpolation Method: MD Interval: 5.00 ft Depth Range: 28.70 to 9605.22 ft Maximum Radius:10000.00 ft Date: 10!24/2006 "Time: 10:23:37 Page: 1 Co-ordinate(NE) Reference: Well: Plan V-205 (S-P), True North Vertical (TVD) Reference: V-205 Pfan S-P 82.5 Db: Oracle _ .-- Reference: Principal Plan 8~ PLANNED PROGRAM Error Model: ISCWSA Ellipse Scan Method: Trav Cylinder North ' Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath -- -- _ --- Date: 8/21/2002 Validated: No Version: 10 Planned From To Survey Toolcode Tool Name ft ft 28.70 800.00 Planned: Plan #6 V2 GYD-GC-SS Gyrodata gyro single shots 800.00 2200.00 Planned: Plan #6 V2 MWD MWD -Standard 800.00 3000.00 Planned: Plan #6 V2 MWD+IFR+MS MWD +IFR + Multi Station ~! 3000.00 5700.00 Planned: Plan #6 V2 MWD+IFR+MS MWD +IFR + Multi Station 5700.00 9605.22 Planned: Plan #6 V2 MWD+IFR+MS MWD +IFR + Multi Station Casing Points _ _ MD 'TVD Diameter -" . T Hole Size Name _ _T ft ft in io 3036.15 2847.50 10.750 13.500 10 3/4" 5753.11 4687.50 7.625 9.875 7 5/8" 9605.22 4707.50 4.500 6.750 41/2" Summary - _- <------------ Offset Wellpath - -- - ---> -- Reference - Offset Ctr-Ctr No-Go Allowable ' Site Nell Wellpath MD D9D Distance Area lleviation Warning ft ft ft ft ft PB V Pad Plan V-04 (N-O) Plan V-04 V2 Plan: Pla 579.99 580.00 181.32 11.07 170.26 Pass: Major Risk PB V Pad Plan V-121 (S-R) Plan V-121 V2 Plan: PI 608.78 610.00 30.61 11.54 19.06 Pass: Major Risk PB V Pad Plan V-122 (S-U) Plan V-122 V4 Plan: PI 608.46 610.00 76.81 11.51 65.30 Pass: Major Risk PB V Pad Plan V-122 (S-U) Plan V-122PB1 V5 Plan: 608.46 610.00 76.81 11.51 65.30 Pass: Major Risk PB V Pad Plan V-217 (S-O) Plan V-217 V1 Plan: PI 473.93 475.00 16.13 8.98 7.15 Pass: Major Risk PB V Pad V-01 V-01 V15 454.82 455.00 31.17 8.24 22.93 Pass: Major Risk PB V Pad V-02 V-02 V12 1231.19 1240.00 205.88 19.81 186.07 Pass: Major Risk ' PB V Pad V-03 V-03 V7 730.74 650.00 211.87 12.02 199.86 Pass: Major Risk ', PB V Pad V-100 V-100 V7 792.86 795.00 89.53 12.38 77.15 Pass: Major Risk ', PB V Pad V-101 V-101 V7 390.17 390.00 283.10 6.76 276.34 Pass: Major Risk ', ', PB V Pad V-102 V-102 V5 430.37 430.00 202.60 8.58 194.02 Pass: Major Risk ~ PB V Pad V-103 V-103 V6 274.99 275.00 187.43 4.89 182.55 Pass: Major Risk PB V Pad V-104 V-104 V13 550.17 550.00 244.95 9.24 235.71 Pass: Major Risk PB V Pad V-105 V-105 V13 930.19 940.00 157.08 15.32 141.76 Pass: Major Risk PB V Pad V-106 V-106 V10 409.67 410.00 179.96 6.64 173.32 Pass: Major Risk PB V Pad V-106 V-106A V9 119.70 120.00 180.89 2.35 178.54 Pass: Major Risk PB V Pad V-106 V-106APB1 V6 119.70 120.00 180.89 2.35 178.54 Pass: Major Risk PB V Pad V-106 V-106AP62 V2 119.70 120.00 180.89 2.35 178.54 Pass: Major Risk ', PB V Pad V-106 V-106APB3 V2 119.70 120.00 180.89 2.35 178.54 Pass: Major Risk ', , PB V Pad V-107 V-107 V5 964.08 970.00 197.16 15.25 181.91 Pass: Major Risk ', '~ PB V Pad V-108 V-108 V7 175.19 175.00 309.36 3.16 306.21 Pass: Major Risk '; PB V Pad V-109 V-109 V2 1457.80 1450.00 178.51 22.62 155.90 Pass: Major Risk ', PB V Pad V-109 V-109PB1 V5 1457.80 1450.00 178.51 22.62 155.90 Pass: Major Risk PB V Pad V-109 V-109P62 V2 1457.80 1450.00 178.51 22.62 155.90 Pass: Major Risk PB V Pad V-111 V-111 V25 762.36 765.00 195.76 14.14 181.62 Pass: Major Risk PB V Pad V-111 V-111 PB1 V8 762.36 765.00 195.76 14.14 181.62 Pass: Major Risk PB V Pad V-111 V-111 P62 V2 762.36 765.00 195.76 14.14 181.62 Pass: Major Risk , PB V Pad i V-111 V-111 P63 V6 762.36 765.00 195.76 14.14 181.62 Pass: Major Risk t PB V Pad V-112 V-112 V7 330.99 330.00 266.40 6.19 260.21 Pass: Major Risk i PB V Pad V-113 V-113 V6 500.49 500.00 237.39 8.00 229.39 Pass: Major Risk PB V Pad V-114 V-114 V5 340.68 340.00 176.09 5.94 170.15 Pass: Major Risk PB V Pad V-114 V-114A V4 340.68 340.00 176.09 5.94 170.15 Pass: Major Risk ~' PB V Pad V-114 V-114AP61 V4 340.68 340.00 176.09 5.94 170.15 Pass: Major Risk ~, PB V Pad V-114 V-114AP62 V2 340.68 340.00 176.09 5.94 170.15 Pass: Major Risk ', PB V Pad V-115 V-115 V5 8175.89 5325.00 101.86 71.67 30.19 Pass: Major Risk ', PB V Pad V-115 V-115P61 V4 8175.89 5325.00 101.87 71.67 30.20 Pass: Major Risk ', PB V Pad V-117 V-117 V9 393.68 395.00 59.72 6.95 52.77 Pass: Major Risk ', ', PB V Pad V-117 V-117P61 V6 393.68 395.00 59.72 6.95 52.77 Pass: Major Risk PB V Pad V-117 V-117P62 V6 393.68 395.00 59.72 6.95 52.77 Pass: Major Risk ~~ BP Alaska • Anticollision Report Company: BP Amoco Field: Prudhoe Bay Reference Site: PB V Pad Reference Well: Plan V-205 (S-P) Reference Wellpath: Plan V-205 Summar~~ <----------- O ffset Wellpath --------~ Site Well Wellpath Date: 10/24/2006 Time: 10:23:37 Page: 2 Coa~rdinate(IVE) Reference: Well: Plan V-205 (S-P), True North Vertical (TVD) Reference: V-205 Plan S-P 82.5 Db: Oracle __ Reference -MD ft PB V Pad V-119 V-119 V13 1702.86 PB V Pad V-120 V-120 V5 250.39 PB V Pad V-201 V-201 V8 319.00 PB V Pad V-202 V-202 V9 897.91 PB V Pad V-202 V-202L1 V5 897.91 ', PB V Pad V-202 V-202L2 V5 897.91 PB V Pad V-203 V-203 V18 600.75 !: PB V Pad V-203 V-203L1 V6 3029.86 PB V Pad V-203 V-203L2 V4 3287.29 ', PB V Pad V-203 V-203L3 V3 3287.11 PB V Pad V-203 V-203L4 V3 600.75 ', PB V Pad V-204 V-204 V2 593.53 PB V Pad V-204 V-204L1 V2 593.53 PB V Pad V-204 V-204L1 P61 V6 593.53 PB V Pad V-204 V-204L2 V2 593.53 '~ PB V Pad V-204 V-204L2P61 V5 593.53 ', PB V Pad V-204 V-204L3 V3 593.53 ', PB V Pad V-204 V-204P61 V9 593.53 i, PB V Pad V-204 V-204P62 V2 593.53 PB V Pad V-210 V-210 V9 236.39 ', PB V Pad V-211 V-211 V5 246.59 'i PB V Pad V-212 V-212 V7 447.49 PB V Pad V-213 V-213 V5 274.60 ~i PB V Pad V-213 V-213P61 VS 274.60 i PB V Pad V-214 Plan V-214 V1 Plan: PI 290.49 PB V Pad V-214 V-214PB1 V2 578.41 PB V Pad V-214 V-214P62 V3 313.67 '~ PB V Pad V-214 V-214P63 V5 313.67 '~ PB V Pad V-214 V-214P64 V2 313.67 PB V Pad V-216 V-216 V8 210.88 ', PB V Pad V-221 V-221 V6 330.85 Offset Ctr-Ctr ho-Go Allowable MD Distance Area Deviation Warning ft ft ft ft __. 1685.00 -- 77.81 28.05 -- 49.76 Pass: Major Risk ~ 250.00 217.32 4.66 212.66 Pass: Major Risk ', 320.00 214.38 5.54 208.84 Pass: Major Risk 900.00 252.86 14.97 237.90 Pass: Major Risk 900.00 252.86 14.92 237.94 Pass: Major Risk 900.00 252.86 14.92 237.94 Pass: Major Risk 600.00 306.26 11.68 294.57 Pass: Major Risk 7715.00 5773.33 No Offset Errors 6965.00 5302.86 No Offset Errors 6915.00 5262.81 No Offset Errors 600.00 306.26 11.68 294.57 Pass: Major Risk 595.00 160.03 10.77 149.26 Pass: Major Risk 595.00 160.03 10.77 149.26 Pass: Major Risk 595.00 160.03 10.77 149.26 Pass: Major Risk 595.00 160.03 10.77 149.26 Pass: Major Risk 595.00 160.03 10.77 149.26 Pass: Major Risk I, 595.00 160.03 10.77 149.26 Pass: Major Risk ', 595.00 160.03 10.77 149.26 Pass: Major Risk 595.00 160.03 10.77 149.26 Pass: Major Risk ', 235.00 251.69 4.25 247.44 Pass: Major Risk ', 245.00 296.98 4.36 292.61 Pass: Major Risk 445.00 184.17 7.83 176.35 Pass: Major Risk 275.00 106.66 5.17 101.49 Pass: Major Risk ', 275.00 106.66 5.17 101.49 Pass: Major Risk 290.00 273.77 5.95 267.82 Pass: Major Risk 575.00 276.72 12.52 264.20 Pass: Major Risk 310.00 274.57 6.25 268.32 Pass: Major Risk 310.00 274.57 6.25 268.32 Pass: Major Risk ', 310.00 274.57 6.25 268.32 Pass: Major Risk 210.00 191.69 4.00 187.69 Pass: Major Risk 330.00 186.23 6.82 179.41 Pass: Major Risk ~ • FieldPrudhoe Bay Site PB V Pad We11:Plan V-205 (S-P) WellpathPlan V-205 -3 1 3 300 200 100 0 2 100 200 300 313 0 Travelling Cylinder Azimuth (TFO+AZI) [degJ vs Centre t Alaska Department of Natural Resources Land Administration System .,Alaska Mapper Land RecordsJStatus Plats Recorder's Search State Cabins Page 1 of 10 aturnll~~A~~aarce~ A~c"~S (~aSE' S c'~C File Type: AD~ i File Number: 28240 ~ Printable Case File Abstract See Township, Range, Section and Acreage? { ~` Yes No _ New Search 1 LAS......e....n...u. I Case Summary I Case Detail I Land Abstract ~. File: ADL 28240 ~ `'~'~~ As of 12/26/2006 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISS/APPRV/ACTV AUTH Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridian: U Township: O11N Range: O1 IE Section: O1 Section Acres: 640 Search Plats Meridian: U Township: O11N Range: Ol lE Section: 02 Section Acres: 640 Meridian: U Township: O11N Range: 011E Section: 11 Section Acres: 640 Meridian: U Township: O11N Range: 011E Section: 12 Section Acres: 640 Case Actions OS-28-1965 TRACT DEFINED SALE DATE 07-28-1965 STATUS (11) 11 TRACT DEFINED BID TYPE 1 FIXED ROYALTY RATE SALE NUMBER 14 TRACT NUMBER 19 FORM NUMBER 5 DL-lOCTOBER 1963 CONDITIONAL Y/N N PRIMARY TERM 10 http://www.dnr.state.ak.us/las/Case_Abstract.cfm?FileType=ADL&FileNumber-028240... 12/26/2006 Alaska Department of Natural Resources Land Administration System • 07-14-1965 BID RECEIVED STATUS (12) 12 BID RECEIVED BID TYPE 1 FIXED ROYALTY RATE TOTAL BONUS BID 9113.600000 DEPOSIT AMOUNT 1823 ROYALTY SHARE % 12.500000 RICHFIELD OIL CORPORATION, 50%; HUMBLE OIL & REFINING CO., SO% 07-14-1965 NOTIFICATION LESSEE DESIGNATED NEW REL (20) 20 NOTIFICATION LESSEE OLD REL CODE 21 DISPOSAL NAME NOTIFICATION CID NUMBER 169397 RICHFIELD OIL CORPOR OLD CID # (SALE NO) 4568 SALE 14 07-14-1965 INITIAL OWNER SEGMENT CODE 1 CID NUMBER 000169397 WORKING INTEREST ROYALTY INTEREST 07-14-1965 INITIAL OWNER SEGMENT CODE 1 CID NUMBER 000106600 RICHFIELD OIL CORPOR 50 43.750000 HUMBLE OIL & REFININ WORKING INTEREST % 50 ROYALTY INTEREST % 43.750000 07-14-1965 INITIAL OWNER SEGMENT CODE 1 CID NUMBER 000004568 SALE 14 ROYALTY INTEREST % 12.500000 07-16-1965 LEASE AWARDED STATUS (13) 13 LEASE AWARDED 09-14-1965 LEASE ISSUED EFFECTIVE DATE 10-01-1965 EXPIRATN DATE 09-30-1975 STATUS (20) 20 ACTIVE 02-03-1966 CUSTOMER CHANGED NAME NEW NAME.• ATLANTIC REFINING COMPANY OLD NAME: RICHFIELD OIL CORPORATION OS-20-1966 CUSTOMER CHANGED NAME NEW NAME: ATLANTIC RICHFIELD COMPANY Page 2 of 10 http://www.dnr.state. ak.us/las/Case_Abstract.cfm?FileType=ADL&FileNumber=028240... 12/26/2006 ' ~ Alaska Department of Natural Resources Land Administration System Page 3 of 10 OLD NAME: ATLANTIC REFINING COMPANY 01-17-1973 CUSTOMER CHANGED NAME NEW NAME: EXXON CORPORATION OLD NAME: HUMBLE OIL & REFINING COMPANY 04-08-1974 PATENT RECEIVED EFFECTIVE DATE 03-27-1974 EXPIRATN DATE 03-27-1984 04-01-1977 UNITIZED EFFECTIVE DATE 04-01-1977 UNIT CODE PB PRUDHOE BAY TOTAL ACRES 2560 UNIT ACRES 2560 DECISION LETTER NOT IN CASEFILE. 04-01-1977 PARTICIPATING AREA ESTABLISHED EFFECTIVE DATE 04-01-1977 UNIT CODE 1 PB PRUDHOE BAY UNIT TRACT 50 TOTAL LEASE ACRES 2560 UNITIZED ACRES 1 2560 PARTICIPATING ACRES 1 2560 LEASE INCORPORATED INTO OIL RIM/GAS CAP PA 01-23-1981 NOTIFICATION LESSEE CHANGED NEW NL (20) 20 NOTIFICATION LESSEE OLD NL (20) 20 NOTIFICATION LESSEE NEW NOTIF LESSEE CID# 106346 ARCO ALASKA INC OLD NOTIF LESSEE CID# 169397 ATLANTIC RICHFIELD C 01-23-1981 ASSIGNMENT APPROVED EFFECTIVE DATE 01-23-1981 SEGMENT CODE 1 ASSIGNOR'S CID 000169397 ATLANTIC RICHFIELD C ASSIGNEE'S CID 000106346 ARCO ALASKA INC WORKING INTER % ASSIGNED 50 ROYALTY INTER % ASSIGNED 43.750000 09-12-1990 COMMENTS ARCO ROYALTY SETTLEMENT FILE IN AABA FORMULA FOR ROYALTY VAL UATION REVISED 03-17-1998 COMMENTS http://www. dnr. state.ak.us/las/Case_Abstract. cfm?FileType=ADL&FileNumber=028240... 12/26/2006 ' ~ Alaska Department of Natural Resources Land Administration System Page 4 of 10 ON 1/22/98 TESTING, EVALUATION, AND PILOT PRODUCTIONFROMNWE 1-03 WELL WAS APPROVED THR U THE END OF TUNDRA TRAVEL. 03-31-2000 CUSTOMER CHANGED NAME NEW NAME.• EXXONMOBIL CORPORATION OLD NAME: EXXON CORPORATION OS-10-2000 CUSTOMER CHANGED NAME NEW NAME: PHILLIPS ALASKA, INC. OLD NAME: ARCO ALASKA, INC. 08-03-2000 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2000 SEGMENT CODE 1 ASSIGNORS CID 000106600 EXXON MOBIL CORPORAT ASSIGNEES CID 000107377 BP EXPLORATION (ALAS WORKING INTER % ASSIGNED 13.157370 ROYALTY INTER % ASSIGNED 11.SI2700 08-03-2000 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2000 SEGMENT CODE 1 ASSIGNORS CID 000106600 EXXON MOBIL CORPORAT ASSIGNEES CID 000033073 MOBIL ALASKA E&P INC WORKING INTER % ASSIGNED .999800 ROYALTY INTER % ASSIGNED .874830 08-03-2000 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2000 SEGMENT CODE 1 ASSIGNORS CID 000106600 EXXON MOBIL CORPORAT ASSIGNEES CID 000034758 FORCENERGY INC WORKING INTER % ASSIGNED .020000 ROYALTY INTER % ASSIGNED .017500 08-03-2000 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2000 SEGMENT CODE 1 ASSIGNORS CID 000106346 PHILLIPS ALASKA, INC ASSIGNEES CID 000107377 BP EXPLORATION (ALAS WORKING INTER % ASSIGNED 13.507300 ROYALTY INTER % ASSIGNED 11.818890 08-03-2000 NOTIFICATION LESSEE CHANGED http ://www. dnr. state. ak.us/las/Case_Abstract. cfin?FileType=ADL&FileNumber=02 8240... 12/26/2006 ' -Alaska Department of Natural Resources Land Administration System Page 5 of I O NEW NL (20) 20 NOTIFICATION LESSEE OLD NL (20) 20 NOTIFICATION LESSEE NEW NOTIF LESSEE CID# 000107377 BP EXPLORATION (ALAS OLD NOTIF LESSEE CID# 000106346 PHILLIPS ALASKA, INC 01-02-2001 COMMENTS OVERRIDING ROYALTYINTERESTS ARE NOT TRACKED AFTER INITIAL SEPARATION FROM THE WORKING INTEREST. CHECK THE APPROPRIATE RECORDER'S OFFICE. 03-30-2001 ASSIGNMENT APPROVED EFFECTIVE DATE 02-01-2001 SEGMENT CODE 1 ASSIGNORS CID 000034758 FORCENERGY INC ASSIGNEES CID 000004134 FOREST OIL CORPORATI WORKING INTER % ASSIGNED .020000 ROYALTY INTER % ASSIGNED .017500 07-31-2001 CUSTOMER CHANGED NAME NEW NAME: EXXONMOBIL ALASKA PRODUCTION, INC. OLD NAME: MOBIL ALASKA E&P INC. 09-21-2001 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2001 SEGMENT CODE 1 ASSIGNORS CID 000106600 EXXON MOBIL CORPORAT ASSIGNEES CID 000033073 EXXONMOBIL ALASKA PR WORKING INTER % ASSIGNED 35.822830 ROYALTY INTER % ASSIGNED 31.344930 08-30-2002 PARTICIPATING AREA ESTABLISHED EFFECTIVE DATE 11-01-2001 UNIT CODE 1 PB PRUDHOE BAY UNIT TRACT 50 TOTAL LEASE ACRES 2560 UNITIZED ACRES 1 2560 PARTICIPATING ACRES 1 1840 LEASE INCORPORATED IN PART INTO BOREALIS PA 09-26-2002 CUSTOMER CHANGED NAME NEW NAME: CONOCOPHILLIPS ALASKA, INC. OLD NAME: PHILLIPS ALASKA, INC. 12-04-2002 ASSIGNMENT APPROVED http://www. dnr.state. ak.us/las/Case_Abstract.cfm?FileType=ADL&FileNumber=028240... 12/26/2006 Alaska Department of Natural Resources Land Administration System Page 6 of 10 EFFECTIVE DATE 11-01-2002 SEGMENT CODE 1 ASSIGNORS CID 000107377 BP EXPLORATION (ALAS ASSIGNEES CID 000106539 CHEVRON U.S.A. INC WORKING INTER % ASSIGNED .309314 ROYALTY INTER % ASSIGNED .270650 12-04-2002 ASSIGNMENT APPROVED EFFECTIVE DATE 11-01-2002 SEGMENT CODE 1 ASSIGNORS CID 000106346 CONOCOPHILLIPS ALASK ASSIGNEES CID 000106539 CHEVRON U.S.A. INC WORKING INTER % ASSIGNED .423315 ROYALTY INTER % ASSIGNED .370401 12-04-2002 ASSIGNMENT APPROVED EFFECTIVE DATE 11-01-2002 SEGMENT CODE 1 ASSIGNORS CID 000033073 EXXONMOBIL ALASKA PR ASSIGNEES CID 000106539 CHEVRON U.S.A. INC WORKING INTER % ASSIGNED .427139 ROYALTY INTER % ASSIGNED .373747 12-04-2002 ASSIGNMENT APPROVED EFFECTIVE DATE 11-O1-2002 SEGMENT CODE 1 ASSIGNORS CID 000004134 FOREST OIL CORPORATI ASSIGNEES CID 000106539 CHEVRON U.S.A. INC WORKING INTER % ASSIGNED .000232 ROYALTY INTER % ASSIGNED .000203 12-31-2002 STATUS CODE STANDARDIZED STATUS CODE 35 ISS/APPRV/ACTV AUTH * * * * * STAT US CODE STANDARDIZATION * STATUS CODE CHANGED BYBATCH UPDATE 03-14-2003 COMMENTS ORION V-201 TRACT OPERATIONAPPROVAL EXTENDED TO 6/30/2003 03-31-2004 PARTICIPATING AREA ESTABLISHED EFFECTIVE DATE 02-01-2004 UNIT CODE 1 PB PRUDHOE BAY UNIT TRACT 50 http://www.dnr. state.ak.us/las/Case_Abstract.cfin?FileType=ADL&FileNumber=028240... 12/26/2006 ` ~ Alaska Department of Natural Resources Land Administration System TOTAL LEASE ACRES 2560 UNITIZED ACRES 1 2560 PARTICIPATING ACRES 1 2320 LEASE INCORPORATED IN PART INTO THE ORLON PA. OS-10-2005 PARTICIPATING AREA EXPANDED EFFECTIVE DATE 12-01-2004 UNIT CODE 1 PB PRUDHOE BAY UNIT TRACT 50 TOTAL LEASE ACRES 2560 UNITIZED ACRES 1 2560 PARTICIPATING ACRES 1 640 LEASE INCORPORATED IN PART INTO BOREALIS PA 12-04-2006 ASSIGNMENT APPROVED EFFECTIVE DATE 09-01-2006 SEGMENT CODE 1 ASSIGNOR'S CID 000004134 FOREST OIL CORPORATI ASSIGNEE'S CID 000106346 CONOCOPHILLIPS ALASK WORKING INTER % ASSIGNED .007361 ROYALTY INTER % ASSIGNED .006441 12-04-2006 ASSIGNMENT APPROVED EFFECTIVE DATE 09-01-2006 SEGMENT CODE 1 ASSIGNOR'S CID 000004134 ASSIGNEE'S CID 000107377 WORKING INTER %ASSIGNE ROYALTY INTER % ASSIGNEE 12-04-2006 ASSIGNMENT APPROVED EFFECTIVE DATE 09-01-2006 SEGMENT CODE 1 ASSIGNOR'S CID 000004134 ASSIGNEE'S CID 000033073 WORKING INTER %ASSIGNE ROYALTY INTER %ASSIGNE FOREST OIL CORPORATI BP EXPLORATION (ALAS D .005211 004560 FOREST OIL CORPORATI EXXONMOBIL ALASKA PR D .007196 D .006296 Legal Description OS-28-1965 * * *SALE NOTICE LEGAL DESCRIPTION* Page 7 of 10 http://www.dnr. state.ak.us/las/Case_Abstract.cfm?FileType=ADL&FileNumber=028240... 12/26/2006 ' ~ Alaska Department of Natural Resources Land Administration System Page 8 of 10 ~ i C14-19 011N-011E-UM 1,2,11,12 2560.00 04-01-1977 * * UNITIZED,LEASE AND PARTICIPATING AREA LEGAL DESCRIPTION* LEASE COMMITTED IN ENTIRETY TO PR UDHOE BAY UNIT AND OIL RIM GAS CAP PA PRUDHOE BAY UNIT TRACT SD OIL RIMAND GAS CAP PARTICIPATING AREAS T. 11 N., R. 11 E., UMIAT MERIDIAN, ALASKA SECTION 1: ALL, 640.00 ACRES; SECTION 2: ALL, 640.00 ACRES; SECTION 11: ALL, 640.00 ACRES; SECTION 12: ALL, 640.00 ACRES; CONTAINING APPROXIMATELY2,560.00RCRES, MORE OR LESS. ********************************************************************** 11-01-2001 * *FORMATION OF BOREALIS PARTICIPATING AREA LEGAL DESCRIPTION LEASE INCORPORATED IN PART INTO THE BPA PR UDHOE BAY UNIT BOREALIS PARTICIPATING AREA TRACT SO (PARTIAL) T.IIN., R.IIE., UMIAT MERIDIAN, ALASKA SECTION 1: W2, W2E2, 480.00 ACRES; SECTION 2: ALL, 640.00 ACRES; SECTION 11: N2, N2S2, 480.00 ACRES; SECTION 12: NW4, W2NE4, 240. DO ACRES; THIS TRACT CONTAINS 1,840.00 ACRES, MORE OR LESS. ********************************************************************** 02-01-2004 * *FORMATION OF ORION PARTICIPATING AREA LEGAL DESCRIPTION* http://www.dnr.state.ak.us/las/Case Abstract.cfm?FileType=ADL&FileNumber=028240... 12/26/2006 ' ~ Alaska Department of Natural Resources Land Administration System Page 9 of 10 LEASE COMMITTED IN PART TO ORION PARTICIPATING AREA PR UDHOE BA Y UNIT TRACT 50 ORION PARTICIPATING AREA T. 11 N., R. 11 E., UMIAT MERIDIAN, ALASKA SECTION 1: ALL, 640.00 ACRES; SECTION 2: ALL, 640.00 ACRES; SECTION 11: El /2, El /2NW1 /4, 400.00 ACRES; SECTION 12: ALL, 640.00 ACRES; CONTAINING APPROXIMATELY 2, 320. DO ACRES, MORE OR LESS. ********************************************************************** 1 Z-01-2004 * * * *BOREALIS PA EXPANDED, LEASE INCORPORATED IN PART LEGAL DESCRIPTION IS AS FOLLOWS: PR UDHOE BAY UNIT BOREALIS PARTICIPATING AREA TRACT SO (PARTIAL) T.11 N., R.11 E., UMIAT MERIDIAN, ALASKA SECTION 1: E2E2, 160.00 ACRES,• SECTION 11: S2SE4, 80.00 ACRES; SECTION 12: S2, E2NE4, 400.00 ACRES; THIS TRACT CONTAINS 640.00 ACRES, MORE OR LESS. * *THE ACREAGE NOW INCORPORATED INTO THE BPA IS DESCRIBED AS FOLLOWS: PR UDHOE BAY UNIT BOREALIS PARTICIPATING AREA TRACT SO (PARTIAL) http ://www. dnr. state. ak.us/las/Case_Abstract.cfm?FileType=ADL&FileNumber =028240... 12/26/2006 ' t Alaska Department of Natural Resources Land Administration System Page 10 of 10 T.IIN., T.IlE., UMIAT MERIDIAN, ALASKA SECTION 1: ALL, 640.00 ACRES; SECTION 2: ALL, 640.00 ACRES; SECTION 11: N2, SE4, N2SW4, 560 ACRES; SECTION I2: ALL, 640.00 ACRES; THIS TRACT CONTAINS 2480.00 ACRES, MORE OR LESS. 1'1 '~ ~~~~ S$M"~Ct Last updated on 12/26/2006. Not sure who to contact? Have a question about DNR? Visit the Public Tnfcarmat€on Center. Report technical problems with this page to the ~ ':~ .raster. Site optimized for Netscape 7, IE 6 or above. This site also requires that all COKIES must be accepted. State of Alaska Natural Resources LAS Home Copyright Privacy System Status _. http://www. dnr. state. ak.us/las/Case-Abstract.cfm?FileType=ADL&FileNumber=028240... 12/26/2006 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 6000000 5950000 5900000 5850000 400000 500000 600000 700000 800000 • RE: V-205 Subject: RE: V-205 ~~ (O ~ ~~~ From: "Kolstad, Scott R" <Scott.Kolstad@bp.com> Date: Wed, 27 Dec 2006 12:04:46 -0900 'To: ~ll~on~as Maunder ~ -tom maunder(u-acln~i~~.statc.ak.us~- Hi Tom, I'll respond to your questions in sequence: r1 1. The top depth for the Obd slotted liner should read, 5,300' MD / 4,567' TVD. 2. The "aIl five laterals" is an error. This well will be a tri-lateral. The Versa-Pro MOBM will be used for the production section of all three laterals. 3. V-212 will be the closest 200 series well to V-205 within the SB Pool. V-212 (1005' Top OBd to V-205) Happy Holidays, Scott Kolstad -----Original Message----- From: Thomas Maunder [mailto:tom mains=der:~?admisz.stat:e.ak.tzs] Sent: Tuesday, December 26, 2006 2:49 PM To: Kolstad, Scott R Subject: V-205 Scott, I am reviewing your application for V-205. I have a couple of questions. 1. On the 401 sheet, the slotted liner top depths are shown as 5300' and and 4478' tvd. In the directional plan, the tvd for 5300' and is given as 4567'. This is the tvd listed for the top of the L1 liner. Could you reconcile? 2. In the mud program for the 6-3/4" hole, it says "All five laterals". Are there 2 or 5 laterals planned? 3. The distance to the nearest well in pool (V-115) is given as 102'. While this physically may be the closest well, I believe the "in pool" would be another V-2 _ well. What is the nearest V-2 _ _ well? Thanks in advance for your reply. Call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 12/27/2006 1:02 PM • Sondra D. Stewman BP Exploration AK INC. PO Box 196612 MB 7-5 Anchorage, AK 99519-6612 PAY TO THE ORDER OF "Mastercard Check" L' 89-6/1252 152 DATE ~ 1 $ )fit ' C""'`' ~ ~ DOLLARS First Nations ank Alaska An rage, AK 99501 MEMO ~ ~ F/ ~ ~ ~:L25200060~:99i46227i56411• Oi52 ~ • ~'RAYSl0~IITTAL LETTEia CFIECKLIST WELT. NAIVtE ,~,~Ll /- aus PTD# ~~~ - ~~~~ / Development Service Exploratory Stratigraphic Vest Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ~ ADD-ONS WHAT ~ (OPTIONS) APPLIES TEXT FOR APPROVAL LETTER MliLTI LATERAL ~ The permit is for a new wellbore segment of existing ~ well ~~ (If last two digits in I Permit No. , API No. 50- - - API number are ; ~ Production should continue to be reported as a function of the between 60-69) original API number stated above. .PILOT E-IOLE [n accordance with 20 A.AC 25.005(f), all records, data and logs !acquired for the pilot hole must be clearly differentiated in both 1 i j well name ( PH) and API number I +(~0_ _ -_, from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC 'EXCEPTION ~ 25.05. Approval to perforate and Qroduce /inject is contingent upon issuance of a conservation order approving a spacing ~ i .exception. assumes the ~ liability of any protest to the spacing exception that may occur. I DRY D[TCH ;All dry ditch sample sets submitted to the Commission must be in i i SA!~IPLE I no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals j ;through target zones. ;Please note the following special condition of this permit: Non-Conventional' ~ production or production testing of coal bed methane is not allowed I Well ;for (name of well) until after jCom~anv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. fCom~any Name) must contact the j 'Commission to obtain advance approval of such water well testing I ~ program. _ ~ Rev: ('>ji06 C ^ jody~transmittal_checklist WELL PERM[T CHECKLIST Field & Pool PRUDHOE BAY, ORION SCHR BL OIL - 640135 __Well Name: PRUDHOE_BAY UN V-205 Program DEV ____ Well bore seg PTD#:2061800 Company BP EXPLORATION (ALASKAN INC _ __ _ Initial Class/Type _ DEV / PEND GeoArea __._ _ Unit 11650 __-_ On/Off Shore On ___ Annular Disposal Administration 1 Permitfee attached_ Yes 2 Lease number appropriate_ Yes 3 ~, Unique well-name and number _ _ _ _ - _ _ - Yes 4 Well located in a_defined_pool . . Yes ~5 Well located proper distance_ from_ drilling unit-boundary_ _ _ _ _ . - - Yes _ _ _ _ _ - 6 Well located proper distance_ from other wells- _ - _ _ _ _ _ Yes _ 7 Sufficient acreage available in drilling unit- . Yes 8 If deviated, is we_Ilbore plat_included - - . - Yes 9 Operator on.lg affected party Yes --------------- ; 10 Operator has_appropriate_bond in fore - .. _ _ _ Yes ' 11 Permit can be issued without conservation order_ . - Yes Date pRr 12 Permit-can be issued without administraliv_e_approyal Yes ----- ------ 13 Can permit be approved before 15-day_wa_it_ Yes - ACS 12127!2006 14 Well located within area and strata authorized by_ Injection Order # (put_1O# in_comments)(For NA_ 15 All wells_within 1/4_mile area of review identified (For service well only) NA - 16 Pre-produced injector; duration of pre production less than_ 3 months_ (For_service well_ only) NA- . , 17 Nonconyen, gas conforms to AS31.05,D30Q.1_.A),O.2.A-D) NA. - 18 Conductor stung provided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ ---- Engineering 19 Surface casingprotects all-knpwn_USDWs - - - - - - . . - . NA_ All_aquifers exempted, 40 CFR 147.102 (b)-(3)._ _ ;20 CMT_vol_adequateto circulate on conductor_& surf-csg _ Yes . X21 CMT vot adequate. to tie-in long string to surf csg_ - - - - - - - No_ X22 CMT_will coyer_all known_productiye horizons_ No_ Slotted liner completion planned, Hydrocarbons ~^nll be covered b intermediate cement._ 123 Casing designs adequate for C, T B &_permafr_ost_ Yes 24 Adequate tankage-or reserve pit Yes - - - - - - Rig is_egUipped with steel_pits. -No resen!e_pitplanned, All waste to approved disposal_wells.- - - - - I25 If_a_ re-drill, has a 10-403 for abandonment been approved - - - .. - - - - - NA_ . I26 Adequate wellbore separationproposed Yes Proximity analysis performed, Traveling cylinder path calculated, Shallow gyros possible. 127 If_diverter required, does it meet regulations_ Yes _ _ 28 _Drrilling fluid_ program schematic & equip list_adequate_ Yes Maximum expected formation pressure 8,7_EMW.. Planned MW 9,3ppg in 9-7/t3" hole and 9.2 ppg in reservoir. Appr Date ,29 BOPES,.do they meet regulation Yes - . . - - 12/26/2006 30 ROPE-press rating appropriate; test t_o-(put prig in comments)_ _ _ - Yes _ _ _ _ _ _ MASP calculated at 1625 psi. 3500-psi BOP testplanned, - 31 Choke manjfold complies w/API RP-53 GMay 84)_ Yes _ - - 32 Work will occur without operation shutdow_n_ - - Yes - . - - 33 Is presence-of H2$ gas_ probable _ _ Yes _ _ H2S has_ been reported on V_pad.- Mud should preclude H2$ on_rig, Rig_is equipped_ with sens_ors_and alarms. _ _ j34 Mechanical condition of wells within AOR verified (For-service well only) _ _ _ - . NA_ . - ------ - -- ------------- --~ 35 .Permit-can be issued w/o hydrogen_sul_fide measures No ----- -- - -- Geology 36 Datapresented on potential oye_rpressure zones - . - . - No_ - ------------ - - 37 Seismic analysis of sha_Ilow gas_zones_ NA- - , _ _ Appr Date 38 .Seabed cgndifion survey (if off-shore) NA- - A 12/27/2006 I39 .Contact name/pho_ne for weekly_progress reports_ [explora_tory only] - NA_ Geologic Engineering i Commissioner: Date: Commissioner: Date o is er Date