The URL can be used to link to this page

Home My WebLink About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y Samantha Carlisle at 10:36 am, Aug 19, 2022 'LJLWDOO\VLJQHGE\7RULQ 5RVFKLQJHU '1FQ 7RULQ5RVFKLQJHU RX 8VHUV 'DWH 7RULQ5RVFKLQJHU '65 0,77WRSVL&0,77[,$WRSVLKRXUQRWLFHWR$2*&& '/% 0*5$8*'/% ; 9DULDQFHWR$$&EDSSURYHGDOORZLQJ,$FHPHQWLQJDVDPHDVXUHWRLVRODWH,&OHDN,VRODWLRQWRLQMHFWLRQ DVVHUWHGDV86,70$5VKRZVJRRGFHPHQWRQ[2+DQQXOXVIURP 0' 8OWUDVRQLF,PDJLQJ(YDOXDWLRQORJZLWKUDGLDOPDSSLQJWR$2*&&IRUDSSURYDOWRSODFHRQ*,1- ; GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.08.26 16:51:55 -08'00' RBDMS JSB 083122 ϭ /ĐĞŵĞŶƚƐƋƵĞĞǌĞͬWĞƌĨ ĚĚͬŽŶǀĞƌƚƚŽ'ĂƐ/ŶũĞĐƚŽƌ tĞůů͗EϭͲϮϭ Wd͗ϭϵϬͲϬϬϮ :HOO1DPH$3,1XPEHU &XUUHQW6WDWXV6,±3:,6HUYLFHOLQHV6OLFNOLQH(OLQH 3XPSLQJ6HUYLFH &RLO (VWLPDWHG6WDUW 'DWH (VWLPDWHG'XUDWLRQGD\V 5HJ$SSURYDO 5HT¶VWG" <HV 'DWH5HJ$SSURYDO 5HF¶YG 5HJXODWRU\&RQWDFW'DUFL+RUQHU3HUPLWWR'ULOO1XPEHU )LUVW&DOO(QJLQHHU-ROHHQ2VKLUR 2 0 6HFRQG&DOO (QJLQHHU -HULPLDK*DOORZD\ 2 0D[([SHFWHG%RWWRP+ROH3UHVVXUHSVL#¶79'VV %DVHGRQ6%+36RQ$ 0D[$QWLFLSDWHG6XUIDFH3UHVVXUHSVL%DVHGRQSVLIWJDVJUDGLHQW 5HIHUHQFH/RJ-HZHOU\/RJ±*5&&/$SU +LVWRU\ (QGLFRWWZHOOZDVGULOOHGDQGFRPSOHWHGLQDVDSURGXFHU,QD5:2ZDV SHUIRUPHGWRLQVWDOODQGFHPHQWWKH¶¶VFDEOLQHULQWKH¶¶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¶VJDVLQMHFWRUVDUHRQOLQHZLWKIXOO RSHQFKRNHV2QHRIWKHELJJHVWJDVLQMHFWRUVZHOOLQMHFWVPPVFIGKDVDQ$$ IRUVORZLQWHUPLWWHQW7[,$FRPPXQLFDWLRQPDQDJHDEOHE\EOHHGZKLOHRQJDVLQMHFWLRQ:H ZRXOGOLNHDEDFNXSJDVLQMHFWRUVRWKDWZHGRQRWQHHGWRWDNHDaERSGSURGXFWLRQ GHIHUUDOZKHQEHFRPHV1RW2SHUDEOH(QGLFRWWLVORFDWHGDWWKHFUHVWRIWKH VWUXFWXUHDQGLVSURSHUO\VXLWHGIRUJDVLQMHFWLRQ7KH(QGLFRWWSURGXFHGZDWHULQMHFWRU WRJDVLQMHFWRUFRQYHUVLRQDQGSHUIDGGZDVDSSURYHGLQVXQGU\ 2QD0,77ZDVH[HFXWHGDQGSDVVHGWRSVLRQZLWKVHDZDWHUDQG GLHVHOFDSORVVHVRISVLIROORZHGE\SVLHQGLQJ7,2 +RZHYHU RQDQ0,7,$IDLOHGDWSVLRQWKH,$SVLRQWKHWXELQJ,$OLTXLGOHDN UDWHZDVESPDWSVL $QDFRXVWLFOHDNGHWHFWORJ/'/ZDVUXQRQDQGGLHVHOZDVSXPSHGGRZQWKH ,$DWSVL7KHORJLGHQWLILHGDSURGXFWLRQFDVLQJOHDNDW¶0'¶79' '/% Ϯ /ĐĞŵĞŶƚƐƋƵĞĞǌĞͬWĞƌĨ ĚĚͬŽŶǀĞƌƚƚŽ'ĂƐ/ŶũĞĐƚŽƌ tĞůů͗EϭͲϮϭ Wd͗ϭϵϬͲϬϬϮ &XUUHQWVWDWXV x :HOOLVFODVVLILHGDV1RW2SHUDEOHDQGLVVHFXUHGZLWKDSOXJDW¶0'SOXJVHW x /DVW0,770,77SDVVHGWRSVLZLWKVHDZDWHUDQGGLHVHOFDSORVVHV RISVLIROORZHGE\SVLHQGLQJ7,2 o 0RVWUHFHQWFDOLSHUZDVUXQRQZKHUHQRVLJQLILFDQWZDOOSHQHWUDWLRQV ! QRU VLJQLILFDQW FURVVVHFWLRQDO ZDOO ORVV ! ZHUH UHFRUGHG 1R VLJQLILFDQW,'UHVWULFWLRQVZHUHUHFRUGHGHLWKHU x /DVW0,7,$0,7,$IDLOHGDWSVLRQWKH,$SVLRQWKHWXELQJ 1RFRPPXQLFDWLRQZLWKWXELQJ,$//5 ESP#SVL x $FRXVWLFOHDNGHWHFWORJLGHQWLILHGSURGXFWLRQFDVLQJ OHDNDW¶0' x 0RVWUHFHQWGULIWVOLFNOLQHGULIWHGZLWK´FHQWUDOL]HUZLWK´VDPSOHEDLOHUWR ¶0' 9DULDQFH5HTXHVW5HTXHVWLQJDYDULDQFHWR$$&E([LVWLQJSURGXFWLRQSDFNHU VHWGHSWKLVJUHDWHUWKDQIWPHDVXUHGGHSWKIURPRSHQSHUIRUDWLRQVSURGXFWLRQSDFNHULV DW¶0'ZKLFKLV¶0'DERYHWKHWRSVKRWRIWKHXSSHUPRVWSURSRVHGSHUIRUDWLRQDW ¶0'6XSSRUWLQJLQIRUPDWLRQWRDVVXUHWKDW(QGLFRWWZHOOKDVDQHTXDOO\HIIHFWLYH PHDQVRIFRPSO\LQJWRWKHUHTXLUHPHQWLVDVIROORZV x 6FKOXPEHUJHU86,7ORJUDQRQDFURVVWKH¶¶FDVLQJOEIWSSJ FHPHQWLQGLFDWHVWKHIROORZLQJ o *RRGFHPHQWIURP¶±¶0' o 6HFWLRQVRISDWFK\FHPHQWDW ¶±¶0' ¶±¶0' ¶±¶0' o 7RSRIFHPHQWDW¶0' o 6HH86,7ORJVHQWDVDSGIDWWDFKPHQWWRWKLVVXQGU\IRUUHIHUHQFH ϯ /ĐĞŵĞŶƚƐƋƵĞĞǌĞͬWĞƌĨ ĚĚͬŽŶǀĞƌƚƚŽ'ĂƐ/ŶũĞĐƚŽƌ tĞůů͗EϭͲϮϭ Wd͗ϭϵϬͲϬϬϮ 3URJUDP2EMHFWLYHV 5HVWRUHLQWHJULW\RIWKHZHOOUHSDLUSURGXFWLRQFDVLQJOHDNDW¶0' $GGXSSHU.$SHUIRUDWLRQV ,QVWDOOVXUIDFHHTXLSPHQWWRPDNHZHOODJDVLQMHFWRU7DUJHWJDVLQMHFWLRQUDWH PPVFIG 3RVW-RE(YDOXDWLRQ x &0,77[,$DQG0,77 x 8OWUDVRQLFLPDJLQJHYDOXDWLRQORJZLWKUDGLDOPDSSLQJ /RQJ7HUP,QWHJULW\0RQLWRULQJ x 5HFRUG:+3VGDLO\ x %LHQQLDO&0,77[,$DQG0,77 $WWDFKPHQWV &XUUHQW:HOOERUH6FKHPDWLF 3URSRVHG:HOOERUH6FKHPDWLF 7XELQJ7DOO\ /HDN'HWHFW/RJVLJQDWXUH 7LH,QORJ6/%*5&&/ ϰ /ĐĞŵĞŶƚƐƋƵĞĞǌĞͬWĞƌĨ ĚĚͬŽŶǀĞƌƚƚŽ'ĂƐ/ŶũĞĐƚŽƌ tĞůů͗EϭͲϮϭ Wd͗ϭϵϬͲϬϬϮ :(//:25.352&('85( Slickline RU #1 586/XQLWDQGSUHVVXUHWHVWWRSVLORZSVLKLJK 3XOO3;1SOXJDW¶0' 'ULIWWR3%7' 3XOO*/0DW¶0' E-Line RU #1 + Pumping Assist 58(/XQLWDQGSUHVVXUHWHVWWRSVLORZSVLKLJK 6HW¶¶&%3LQWKHPLGGOHRIWKHILUVWIXOOMRLQWEHORZ*/0ULJKWDERYHSURGXFWLRQ SDFNHU(VWLPDWHGVHWGHSWKa¶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¶¶WXELQJYROXPHWR¶0' EEOEEO.&OEEOGLHVHOFDS ¶¶[¶¶,$YROXPHIURP¶0'WRVXUIDFH EEO[WEJYROXPH EEO 6HWFHPHQWUHWDLQHULQWKHPLGGOHRIWKHMRLQWDERYH*/0(VWLPDWHGVHWGHSWK a¶0' $OOGHSWKVUHIHUHQFHDWWDFKHGWXELQJWDOO\RI 3&( ϱ /ĐĞŵĞŶƚƐƋƵĞĞǌĞͬWĞƌĨ ĚĚͬŽŶǀĞƌƚƚŽ'ĂƐ/ŶũĞĐƚŽƌ tĞůů͗EϭͲϮϭ Wd͗ϭϵϬͲϬϬϮ Coiled Tubing 0,58&RLOHG7XELQJ8QLWDQGVSRWDQFLOODU\HTXLSPHQW 3HUIRUP%23WHVWLIRQHKDVQRWEHHQFRPSOHWHGLQODVWGD\V 08VWLQJHUIRU¶¶FHPHQWUHWDLQHU 'LVSODFH&7WRGLHVHOEHIRUH5,+ 6WLQJLQWRUHWDLQHUIODJSLSH3UHVVXUHWHVW&7[7%*EDFNVLGHWRSVLWRHQVXUHUHWDLQHU LVVHWDQGVWLQJHUVHDOVDUHKROGLQJ 3XPSWKHIROORZLQJGRZQ&7LQWRWKH,$1RWHWKDWWKH,$KDVDOUHDG\EHHQIXOO\GLVSODFHG WR GLHVHO GXULQJ WKH SUHYLRXV VWHS ,I IHDVLEOH SOHDVH WDNH GLHVHO UHWXUQV WR (QGLFRWW SURGXFWLRQ ¾ EEOZDWHUVSDFHU ¾ aEEOVFHPHQWSHUGHVLJQXQVWLQJIURPUHWDLQHUDQGOD\ODVWEEORIFHPHQWRQ WRSRIUHWDLQHU ¾ &7YROXPHZDWHU 1RWH(VWLPDWHG72&LV¶0'ZKLFKLV¶0'DERYHWKHSURGXFWLRQFDVLQJOHDNDW ¶0' 8QVWLQJIURPUHWDLQHUDQGUHYHUVHRXWFHPHQW 3XPSSLSHGLVSODFHPHQWZKLOH322+ $WVXUIDFHZDVK%23VLIQHFHVVDU\ 3XPSEDOODURXQGEHIRUH08PLOOLQJ%+$ 08´PLOODQG5,+ :DLWRQFHPHQWDVQHFHVVDU\0LOOFHPHQWDQGUHWDLQHUQRWLI\2(EHIRUHPLOOLQJ:KHQDW IODJWLHLQXVLQJPRWRUDQGPLOO%+$ 2QFHEHORZ*/0DW¶0'EXWDERYH&%3DWa¶0'UHIHUHQFHDFWXDOHOLQH &%3VHWGHSWKSXPSJHOVZHHSDQGFLUFXODWHERWWRPVXSWROLPLWFHPHQWDQGPLOOLQJGHEULV IURPHQWHULQJWKHSHUIRUDWLRQV 0LOO&%3DQGSXVKWR7'UHIHUHQFHVOLFNOLQH7'WDJREWDLQHGHDUOLHULQWKHSURJUDP 322+DQG)3ZHOODVQHFHVVDU\ ϲ /ĐĞŵĞŶƚƐƋƵĞĞǌĞͬWĞƌĨ ĚĚͬŽŶǀĞƌƚƚŽ'ĂƐ/ŶũĞĐƚŽƌ tĞůů͗EϭͲϮϭ Wd͗ϭϵϬͲϬϬϮ Slickline RU #2 + Pumping Assist Note: It is advised to wait at least 3 days from the time cement is placed before performing MITs. 586/XQLWDQGSUHVVXUHWHVWWRSVLORZSVLKLJK 'ULIWZLWK%+$WKDWHPXODWHV¶[´JXQVWRWDUJHWGHSWKRI¶0'GHHSHULI VDIHO\SRVVLEOH,IWDJJLQJVLJQLILFDQWO\VKDOORZHUWKDQSUHYLRXVGULIWUXQVVKRUWHQGULIW OHQJWKDQGLQIRUP2(,IFRQWLQXLQJWRKDYHGXPP\JXQGULIWLVVXHVFRQWDFW2(DQG GLVFXVVZD\IRUZDUG 6HWSOXJLQ;1QLSSOHDW¶0'RU;QLSSOHDW¶0' $2*&&ZLWQHVVHG0,77WRSVLWDUJHWSUHVVXUHSVLPD[DSSOLHG SUHVVXUH,IIDLOVHVWDEOLVKOLTXLGOHDNUDWHDQGFRQWDFW2( $2*&&ZLWQHVVHG &0,77[,$WRSVLWDUJHWSUHVVXUHSVLPD[DSSOLHG SUHVVXUH,IIDLOVHVWDEOLVKOLTXLGOHDNUDWHDQGFRQWDFW2( ,I0,7VSDVVSXOOSOXJ 1RWHV&0,77[,$DQG0,77WDUJHWWHVWSUHVVXUHVZHUHFDOFXODWHGWREHWLPHV WKHPD[LPXPDQWLFLSDWHGWXELQJSUHVVXUHVHHQGXULQJJDVLQMHFWLRQRSHUDWLRQDWWKH HVWLPDWHG,$72&GHSWKRI¶0'¶79' x 7XELQJSUHVVXUHGXULQJJDVLQMHFWLRQRSHUDWLRQ#¶0'¶79' SVL o SVLPD[DQWLFLSDWHGZHOOLQMHFWLRQSUHVVXUH o SVLK\GURVWDWLFFROXPQRIJDV#SVLIWJUDGLHQW x [SVL SVL x 3RVW,$FHPHQWVTXHH]H0,77SUHVVXUHGHULYDWLRQ o SVL SVLIW ¶79'WDUJHW0,77VXUIDFHSUHVVXUH o 7DUJHW0,77VXUIDFHSUHVVXUH SVL x 3RVW,$FHPHQWVTXHH]H&0,77[,$SUHVVXUHGHULYDWLRQ o SVL SVLIW ¶ 79' WDUJHW &0,7 7[,$ VXUIDFH SUHVVXUH o 7DUJHW&0,77[,$VXUIDFHSUHVVXUH SVL ÆSVLURXQGXS $2*&&ZLWQHVVHG0,77WRSVLWDUJHW $2*&&ZLWQHVVHG &0,77[,$WR ϳ /ĐĞŵĞŶƚƐƋƵĞĞǌĞͬWĞƌĨ ĚĚͬŽŶǀĞƌƚƚŽ'ĂƐ/ŶũĞĐƚŽƌ tĞůů͗EϭͲϮϭ Wd͗ϭϵϬͲϬϬϮ E-Line RU #2 58(/XQLWDQGSUHVVXUHWHVWWRSVLORZSVLKLJK 2EWDLQDQXOWUDVRQLFLPDJLQJHYDOXDWLRQORJZLWKUDGLDOPDSSLQJIURPa¶0'WR a¶0' 7LHLQORJ 6/%-HZHOU\ORJ*5&&/6HQGORJWR -ROHHQRVKLUR#KLOFRUSFRP ORJZLOOQHHGWRJHW$2*&&DSSURYDOSULRUWRJDVLQMHFWLRQVWDUW 5,+ZLWKJXQVDQGREWDLQD*5&&/FRUUHODWLRQSDVV 7LHLQORJ 6/%-HZHOU\ORJ*5&&/ 3OHDVHVHQGSGIDQGODVILOHVWRIROORZLQJSHRSOHDQGFRQWDFW -ROHHQ2VKLUR DWWRJHWILQDOSHUIGHSWKVDQGWLHLQORJVKLIW D%UXVW#KLOFRUSFRP E-ROHHQRVKLUR#KLOFRUSFRP 3HUIRUDWHSHUILQDODSSURYHGSHUIGHSWKV *XQ5XQ 3HUI7RS 3HUI%RWWRP 3HUI/HQJWK ¶0' ¶0' ¶0' ¶0' ¶0' ¶0' ¶0' ¶0' ¶0' ¶0' ¶0' ¶0' 7RWDO ¶0' 7DEOH(1'3URSRVHG3HUI*XQ5XQV Slickline RU #3 586/XQLWDQGSUHVVXUHWHVWWRSVLORZSVLKLJK 6HW$LQMHFWLRQYDOYHDW¶0' Wellhead 6HW%39RU7:&LQZHOO ,QVWDOOSVLWUHH 3XOO%39RU7:&DIWHUWUHHVZDS Surface ,QVWDOOYDOYHVDQGDVVRFLDWHGSLSLQJWRWLHZHOOLQWRJDVLQMHFWLRQKHDGHU Integrity Engineer $GG%LHQQLDO&0,77[,$DQG0,77WR$.,06 2EWDLQDQXOWUDVRQLFLPDJLQJHYDOXDWLRQORJZLWKUDGLDOPDSSLQJIURPa¶0'WR a¶0' ϴ /ĐĞŵĞŶƚƐƋƵĞĞǌĞͬWĞƌĨ ĚĚͬŽŶǀĞƌƚƚŽ'ĂƐ/ŶũĞĐƚŽƌ tĞůů͗EϭͲϮϭ Wd͗ϭϵϬͲϬϬϮ Figure 1: Current Wellbore Schematic ϵ /ĐĞŵĞŶƚƐƋƵĞĞǌĞͬWĞƌĨ ĚĚͬŽŶǀĞƌƚƚŽ'ĂƐ/ŶũĞĐƚŽƌ tĞůů͗EϭͲϮϭ Wd͗ϭϵϬͲϬϬϮ Figure 2: Proposed Wellbore Schematic ϭϬ /ĐĞŵĞŶƚƐƋƵĞĞǌĞͬWĞƌĨ ĚĚͬŽŶǀĞƌƚƚŽ'ĂƐ/ŶũĞĐƚŽƌ tĞůů͗EϭͲϮϭ Wd͗ϭϵϬͲϬϬϮ Figure 3: Tubing Tally ϭϭ /ĐĞŵĞŶƚƐƋƵĞĞǌĞͬWĞƌĨ ĚĚͬŽŶǀĞƌƚƚŽ'ĂƐ/ŶũĞĐƚŽƌ tĞůů͗EϭͲϮϭ Wd͗ϭϵϬͲϬϬϮ Figure 4: 11/29/21 Leak Detect Log signature ϭϮ /ĐĞŵĞŶƚƐƋƵĞĞǌĞͬWĞƌĨ ĚĚͬŽŶǀĞƌƚƚŽ'ĂƐ/ŶũĞĐƚŽƌ tĞůů͗EϭͲϮϭ Wd͗ϭϵϬͲϬϬϮ )LJXUH7LH,QORJ6/%*5&&/ ϭϯ /ĐĞŵĞŶƚƐƋƵĞĞǌĞͬWĞƌĨ ĚĚͬŽŶǀĞƌƚƚŽ'ĂƐ/ŶũĞĐƚŽƌ tĞůů͗EϭͲϮϭ Wd͗ϭϵϬͲϬϬϮ Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 12/07/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPI 1-21 (PTD 190-002) Leak Point Survey 11/29/2021 Please include current contact information if different from above. 192-002 T36422 Meredith Guhl Digitally signed by Meredith Guhl Date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y Samantha Carlisle at 9:14 am, Dec 29, 2021 'LJLWDOO\VLJQHGE\7RULQ 5RVFKLQJHU '1FQ 7RULQ5RVFKLQJHU RX 8VHUV 'DWH 7RULQ5RVFKLQJHU 3HUIRUDWH DSR-1/3/22 Jan 25, 2022 SFD 12/29/2021 &RQYHUWWR*DV,QMHFWRU SFD 12/29/2021 SFD 12/29/2021 6XXEVHTXHQW )R)RUP5HTXLUHG $33529(''%< &2200,66,21(5 7+($2*&&&& 6 &200,66,21(5 7+( $2*&& 6 &2000,66,221(5 7+($22*&& RBDMS SJC 020822 /ĐĞŵĞŶƚƐƋƵĞĞǌĞͬWĞƌĨ ĚĚͬŽŶǀĞƌƚƚŽ'ĂƐ/ŶũĞĐƚŽƌ tĞůů͗EϭͲϮϭ Wd͗ϭϵϬͲϬϬϮ :HOO1DPH$3,1XPEHU &XUUHQW6WDWXV6,±3:,6HUYLFHOLQHV6OLFNOLQH(OLQH 3XPSLQJ6HUYLFH &RLO (VWLPDWHG6WDUW 'DWH (VWLPDWHG'XUDWLRQGD\V 5HJ$SSURYDO 5HT¶VWG" <HV 'DWH5HJ$SSURYDO 5HF¶YG 5HJXODWRU\&RQWDFW'DUFL+RUQHU3HUPLWWR'ULOO1XPEHU )LUVW&DOO(QJLQHHU-ROHHQ2VKLUR 2 0 6HFRQG&DOO (QJLQHHU 2OLYHU6WHUQLFNL 2 0D[([SHFWHG%RWWRP+ROH3UHVVXUHSVL#¶79'VV %DVHGRQ6%+36RQ$ 0D[$QWLFLSDWHG6XUIDFH3UHVVXUHSVL%DVHGRQSVLIWJDVJUDGLHQW 5HIHUHQFH/RJ-HZHOU\/RJ±*5&&/$SU +LVWRU\ (QGLFRWWZHOOZDVGULOOHGDQGFRPSOHWHGLQDVDSURGXFHU,QD5:2ZDV SHUIRUPHGWRLQVWDOODQGFHPHQWWKH¶¶VFDEOLQHULQWKH¶¶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¶VJDVLQMHFWRUVDUHRQOLQHZLWKIXOO RSHQFKRNHV2QHRIWKHELJJHVWJDVLQMHFWRUVZHOOLQMHFWVPPVFIGKDVDQ$$ IRUVORZLQWHUPLWWHQW7[,$FRPPXQLFDWLRQPDQDJHDEOHE\EOHHGZKLOHRQJDVLQMHFWLRQ:H ZRXOGOLNHDEDFNXSJDVLQMHFWRUVRWKDWZHGRQRWQHHGWRWDNHDaERSGSURGXFWLRQ GHIHUUDOZKHQEHFRPHV1RW2SHUDEOH(QGLFRWWLVORFDWHGDWWKHFUHVWRIWKH VWUXFWXUHDQGLVSURSHUO\VXLWHGIRUJDVLQMHFWLRQ7KH(QGLFRWWSURGXFHGZDWHULQMHFWRU WRJDVLQMHFWRUFRQYHUVLRQDQGSHUIDGGZDVDSSURYHGLQVXQGU\ 2QDQGDVSHUVXQGU\D0,77ZDVH[HFXWHGDQGSDVVHGWRSVLRQ ZLWKVHDZDWHUDQGGLHVHOFDSORVVHVRISVLIROORZHGE\SVLHQGLQJ7,2 +RZHYHURQDQ0,7,$IDLOHGDWSVLRQWKH,$SVLRQ WKHWXELQJ,$OLTXLGOHDNUDWHZDVESPDWSVL $QDFRXVWLFOHDNGHWHFWORJ/'/ZDVUXQRQDQGGLHVHOZDVSXPSHGGRZQWKH ,$DWSVL7KHORJLGHQWLILHGDSURGXFWLRQFDVLQJOHDNDW¶0' -00 DLB /ĐĞŵĞŶƚƐƋƵĞĞǌĞͬWĞƌĨ ĚĚͬŽŶǀĞƌƚƚŽ'ĂƐ/ŶũĞĐƚŽƌ tĞůů͗EϭͲϮϭ Wd͗ϭϵϬͲϬϬϮ 'XHWRWKHLQFUHDVHGVFRSHRIWKHSURMHFWEURXJKWDERXWE\GLVFRYHULQJDSURGXFWLRQFDVLQJ OHDNLQZHOO+LOFRUS$ODVNDUHTXHVWVWKDQVXQGU\EHFDQFHOOHGDQGDVNVWKH $2*&&WRFRQVLGHUWKLVVXQGU\LQLW¶VSODFH &XUUHQWVWDWXV x :HOOLVFODVVLILHGDV1RW2SHUDEOHDQGLVVHFXUHGZLWKDSOXJDW¶0'SOXJVHW x /DVW0,770,77SDVVHGWRSVLZLWKVHDZDWHUDQGGLHVHOFDSORVVHV RISVLIROORZHGE\SVLHQGLQJ7,2 x /DVW0,7,$0,7,$IDLOHGDWSVLRQWKH,$SVLRQWKHWXELQJ 1RFRPPXQLFDWLRQZLWKWXELQJ,$//5 ESP#SVL x $FRXVWLFOHDNGHWHFWORJLGHQWLILHGSURGXFWLRQFDVLQJOHDNDW¶0' 9DULDQFH5HTXHVW5HTXHVWLQJDYDULDQFHWR$$&E([LVWLQJSURGXFWLRQSDFNHU VHWGHSWKLVJUHDWHUWKDQIWPHDVXUHGGHSWKIURPRSHQSHUIRUDWLRQVSURGXFWLRQSDFNHULV DW¶0'ZKLFKLV¶0'DERYHWKHWRSVKRWRIWKHXSSHUPRVWSURSRVHGSHUIRUDWLRQDW ¶0' 3URJUDP2EMHFWLYHV 5HVWRUHLQWHJULW\RIWKHZHOOUHSDLUSURGXFWLRQFDVLQJOHDNDW¶0'3DVVLQJ 0,77DQG&0,77[,$WRWDUJHWSUHVVXUHSVL $GGXSSHU.$SHUIRUDWLRQV ,QVWDOOVXUIDFHHTXLSPHQWWRPDNHZHOODJDVLQMHFWRU7DUJHWJDVLQMHFWLRQUDWH PPVFIG 3RVW-RE(YDOXDWLRQ x &0,77[,$DQG0,77 x 6&07WRORFDWH72& /RQJ7HUP,QWHJULW\0RQLWRULQJ x 5HFRUG:+3VGDLO\ x %LHQQLDO&0,77[,$DQG0,77 SSMJ \JS J +LOFRUS$ODVNDUHTXHVWVWKDQVXQGU\EHFDQFHOOHGDQGDVNVWKHS T $2*&&WRFRQVLGHUWKLVVXQGU\LQLW¶VSODFH /ĐĞŵĞŶƚƐƋƵĞĞǌĞͬWĞƌĨ ĚĚͬŽŶǀĞƌƚƚŽ'ĂƐ/ŶũĞĐƚŽƌ tĞůů͗EϭͲϮϭ Wd͗ϭϵϬͲϬϬϮ :(//:25.352&('85( Slickline RU #1 586/XQLWDQGSUHVVXUHWHVWWRSVLORZSVLKLJK 3XOO3;1SOXJDW¶0' 'ULIWWR3%7' 3XOO*/0DW¶0' E-Line RU #1 + Pumping Assist 58(/XQLWDQGSUHVVXUHWHVWWRSVLORZSVLKLJK 6HW¶¶&%3LQWKHPLGGOHRIWKHILUVWIXOOMRLQWEHORZ*/0ULJKWDERYHSURGXFWLRQ SDFNHU(VWLPDWHGVHWGHSWKa¶0' &0,77[,$OHDNWHVWWRYHULI\&%3VHW:HKDYHDNQRZQOLTXLGOHDNUDWHRIESP #SVLSUHVVXUHWHVWVRLIWKH&0,77[,$LVJUHDWO\DERYHRXUNQRZQ OLTXLGOHDNUDWHWKLVLQGLFDWHVWKDWWKH&%3FRXOGEHPLVVHW&RQWDFW2(LI&0,77[,$ OHDNWHVWLQGLFDWHV&%3LVPLVVHW 3XPSGLHVHODQG.&OGRZQWXELQJWDNLQJUHWXUQVXSWKH,$WRIXOO\GLVSODFH7[,$ IROORZLQJWKHSXPSVHTXHQFHLPPHGLDWHO\EHORZ,IIHDVLEOHSOHDVHWDNHGLHVHO UHWXUQVWR(QGLFRWWSURGXFWLRQ 6WDJH )OXLG 9ROXPH 5DWH 7UHDWLQJ 3UHVVXUH 'LHVHO EEO PD[ 0D[SVL .&O EEO PD[ 0D[SVL 'LHVHO EEO PD[ 0D[SVL ¶¶WXELQJYROXPHWR¶0' EEOEEO.&OEEOGLHVHOFDS ¶¶[¶¶,$YROXPHIURP¶0'WRVXUIDFH EEO[WEJYROXPH EEO 6HWFHPHQWUHWDLQHULQWKHPLGGOHRIWKHMRLQWDERYH*/0(VWLPDWHGVHWGHSWK a¶0' $OOGHSWKVUHIHUHQFHDWWDFKHGWXELQJWDOO\RI Coiled Tubing RU #1 0,58&RLOHG7XELQJ8QLWDQGVSRWDQFLOODU\HTXLSPHQW 3UHVVXUHWHVW%23(WR SVL+L/RZPLQHDFKWHVW ¾ (DFKVXEVHTXHQWWHVWRIWKHOXEULFDWRUZLOOEHWR SVL+L/RZWRFRQILUP QROHDNV ¾ 1R$2*&&QRWLILFDWLRQUHTXLUHG ¾ 5HFRUG%23(WHVWUHVXOWVRQIRUP ¾ ,IZLWKLQWKHVWDQGDUGGD\WHVW%23(WHVWSHULRGIRU0LOQH3RLQWDIXOOERG\WHVW DQGIXQFWLRQWHVWRIWKHUDPVLVVXIILFLHQWWRPHHWZHHNO\%23(WHVWUHTXLUHPHQW 08VWLQJHUIRU¶¶FHPHQWUHWDLQHU 'LVSODFH&7WRGLHVHOEHIRUH5,+ /ĐĞŵĞŶƚƐƋƵĞĞǌĞͬWĞƌĨ ĚĚͬŽŶǀĞƌƚƚŽ'ĂƐ/ŶũĞĐƚŽƌ tĞůů͗EϭͲϮϭ Wd͗ϭϵϬͲϬϬϮ 6WLQJLQWRUHWDLQHU3UHVVXUHWHVW&7[7%*EDFNVLGHWRSVLWRHQVXUHUHWDLQHULVVHW 3XPSWKHIROORZLQJGRZQ&7LQWRWKH,$1RWHWKDWWKH,$KDVDOUHDG\EHHQIXOO\GLVSODFHG WR GLHVHO GXULQJ WKH SUHYLRXV VWHS ,I IHDVLEOH SOHDVH WDNH GLHVHO UHWXUQV WR (QGLFRWW SURGXFWLRQ ¾ EEOZDWHUVSDFHU ¾ EEOVFHPHQWSHUGHVLJQXQVWLQJIURPUHWDLQHUDQGOD\ODVWEEORIFHPHQWRQWRS RIUHWDLQHU ¾ &7YROXPHZDWHU 1RWH(VWLPDWHG72&LV¶0'ZKLFKLV¶0'DERYHWKHSURGXFWLRQFDVLQJOHDNDW ¶0' 322+DQG)3ZHOO Pumping $2*&&ZLWQHVVHG ¾ 0,77WRSVLWDUJHWSUHVVXUHSVLPD[DSSOLHGSUHVVXUH,IIDLOVHVWDEOLVK OLTXLGOHDNUDWHDQGFRQWDFW2( ¾ &0,77[,$WRSVLWDUJHWSUHVVXUHSVLPD[DSSOLHGSUHVVXUH,IIDLOV HVWDEOLVKOLTXLGOHDNUDWHDQGFRQWDFW2( 1RWHV&0,77[,$DQG0,77WDUJHWWHVWSUHVVXUHVZHUHFDOFXODWHGWREHWLPHVWKHPD[LPXP DQWLFLSDWHGWXELQJSUHVVXUHVHHQGXULQJJDVLQMHFWLRQRSHUDWLRQDWWKHHVWLPDWHG,$72&GHSWK RI¶0'¶79' x 7XELQJSUHVVXUHGXULQJJDVLQMHFWLRQRSHUDWLRQ#¶0'¶79' SVL o SVLPD[DQWLFLSDWHGZHOOLQMHFWLRQSUHVVXUH o SVLK\GURVWDWLFFROXPQRIJDV#SVLIWJUDGLHQW x [SVL SVL x 3RVW,$FHPHQWVTXHH]H0,77SUHVVXUHGHULYDWLRQ o SVL SVLIW ¶79'WDUJHW0,77VXUIDFHSUHVVXUH o 7DUJHW0,77VXUIDFHSUHVVXUH SVL x 3RVW,$FHPHQWVTXHH]H&0,77[,$SUHVVXUHGHULYDWLRQ o SVL SVLIW ¶79'WDUJHW&0,77[,$VXUIDFHSUHVVXUH o 7DUJHW&0,77[,$VXUIDFHSUHVVXUH SVL ÆSVLURXQGXS Wellhead 6HW%39RU7:&LQZHOO ,QVWDOOSVLWUHH 3XOO%39RU7:&DIWHUWUHHVZDS /ĐĞŵĞŶƚƐƋƵĞĞǌĞͬWĞƌĨ ĚĚͬŽŶǀĞƌƚƚŽ'ĂƐ/ŶũĞĐƚŽƌ tĞůů͗EϭͲϮϭ Wd͗ϭϵϬͲϬϬϮ Coiled Tubing RU #2 0,58&RLOHG7XELQJ8QLWDQGVSRWDQFLOODU\HTXLSPHQW 3UHVVXUHWHVW%23(WR SVL+L/RZPLQHDFKWHVW ¾ (DFKVXEVHTXHQWWHVWRIWKHOXEULFDWRUZLOOEHWR SVL+L/RZWRFRQILUP QROHDNV ¾ 1R$2*&&QRWLILFDWLRQUHTXLUHG ¾ 5HFRUG%23(WHVWUHVXOWVRQIRUP ¾ ,IZLWKLQWKHVWDQGDUGGD\WHVW%23(WHVWSHULRGIRU0LOQH3RLQWDIXOOERG\WHVW DQGIXQFWLRQWHVWRIWKHUDPVLVVXIILFLHQWWRPHHWZHHNO\%23(WHVWUHTXLUHPHQW 080RWRUDQG´0LOO0LOOVL]HFDQEHXSGDWHGXSRQUHYLHZLQJZLWK2( 0LOOWKURXJK&HPHQW5HWDLQHUDQG&%3$WWHPSWWRFLUFXODWHERWWRPVXSEHIRUHPLOOLQJ WKURXJK&%3WROLPLWFHPHQWDQGPLOOLQJGHEULVIURPHQWHULQJWKHSHUIRUDWLRQVDIWHUERWWRPV XSPLOOWKURXJK&%3DQGSXVKWR7'UHIHUHQFHVOLFNOLQH7'WDJREWDLQHGHDUOLHULQWKH SURJUDP 322+DQG)3ZHOO E-Line RU #2 58(/XQLWDQGSUHVVXUHWHVWWRSVLORZSVLKLJK 5,+DQGREWDLQD*5&&/FRUUHODWLRQSDVV 7LHLQORJ 6/%-HZHOU\ORJ*5&&/ &RQWDFW-ROHHQ2VKLURDWWRJHWILQDOSHUIGHSWKV 3HUIRUDWHSHUILQDODSSURYHGSHUIGHSWKV *XQ5XQ 3HUI7RS 3HUI%RWWRP 3HUI/HQJWK ¶0' ¶0' ¶0' ¶0' ¶0' ¶0' 7RWDO ¶0' 7DEOH(1'3URSRVHG3HUI*XQ5XQV Slickline RU #2 586/XQLWDQGSUHVVXUHWHVWWRSVLORZSVLKLJK 5XQ6&07WRORFDWH72&LQ,$VHQGORJWR-ROHHQ2VKLURIRUUHYLHZ±SGIRIORJZLOO QHHGWRJRWR$2*&&IRUDSSURYDOSULRUWRLQMHFWLRQVWDUW7LHLQORJ 6/%-HZHOU\ORJ *5&&/ 6HW$LQMHFWLRQYDOYHDW¶0' Surface ,QVWDOOYDOYHVDQGDVVRFLDWHGSLSLQJWRWLHZHOOLQWRJDVLQMHFWLRQKHDGHU Integrity Engineer $GG%LHQQLDO&0,77[,$DQG0,77WR6:,6 /ĐĞŵĞŶƚƐƋƵĞĞǌĞͬWĞƌĨ ĚĚͬŽŶǀĞƌƚƚŽ'ĂƐ/ŶũĞĐƚŽƌ tĞůů͗EϭͲϮϭ Wd͗ϭϵϬͲϬϬϮ $WWDFKPHQWV :HOOERUH6FKHPDWLF 3URSRVHG:HOOERUH6FKHPDWLF 7XELQJ7DOO\ /HDN'HWHFW/RJVLJQDWXUH /ĐĞŵĞŶƚƐƋƵĞĞǌĞͬWĞƌĨ ĚĚͬŽŶǀĞƌƚƚŽ'ĂƐ/ŶũĞĐƚŽƌ tĞůů͗EϭͲϮϭ Wd͗ϭϵϬͲϬϬϮ /ĐĞŵĞŶƚƐƋƵĞĞǌĞͬWĞƌĨ ĚĚͬŽŶǀĞƌƚƚŽ'ĂƐ/ŶũĞĐƚŽƌ tĞůů͗EϭͲϮϭ Wd͗ϭϵϬͲϬϬϮ 9835' TVD 6367' TVD FG 5137 psi 7895'TVD /ĐĞŵĞŶƚƐƋƵĞĞǌĞͬWĞƌĨ ĚĚͬŽŶǀĞƌƚƚŽ'ĂƐ/ŶũĞĐƚŽƌ tĞůů͗EϭͲϮϭ Wd͗ϭϵϬͲϬϬϮ /ĐĞŵĞŶƚƐƋƵĞĞǌĞͬWĞƌĨ ĚĚͬŽŶǀĞƌƚƚŽ'ĂƐ/ŶũĞĐƚŽƌ tĞůů͗EϭͲϮϭ Wd͗ϭϵϬͲϬϬϮ 1 Carlisle, Samantha J (OGC) From:Rixse, Melvin G (OGC) Sent:Friday, December 31, 2021 5:49 PM To:Joleen Oshiro Subject: PTD190-002, Sundry Request 321-648. Duck Island MPI 1-21 SC Additional variance justification Joleen, As Hilcorp requested a variance to: 25 AAC 20.412 (b) which states: “ a well used for injection must be equipped with tubing and a packer, or with other equipment that isolates pressure to the injection interval, unless the commission approves the operator's use of alternate means to ensure that injection of fluid is limited to the injection zone……….” So, AOGCC will want additional assurance that injection is limited to the Endicott Oil Pool. Of concern is the integrity and monitorability of the IA cement packer and 9‐5/8” casing below the new TOC. A significant amount of monitorable annulus will be sacrificed with a cement packer that may or may not provide pressure isolation from the zones above the confining zone. Stringers of cement may provide pressure isolation for a monitorable annulus above, but hide what may be leaking below to zones above the confining zone. As per regulation: A variance from any requirement provides at least an equally effective means of complying with the requirement. To justify an equally effective means of compliance with 25 AAC 20.412(b), AOGCC suggests Hilcorp could discuss further methods that could provide : ‐ Assurance that the cemented IA, which will be unmonitorable, is impermeable to tubing injection pressures and will not allow communication to the existing 9‐5/8” casing leak or a future 9‐5/8” casing leak. and ‐ If the 9‐5/8” casing would leak to formation below the TOC in the Tx9‐5/8” annulus, assurance that all zones from the Endicott confining zones to the surface casing shoe would have no permeability and would not be subject to gas pressures above their fracture gradient, i.e., all gas going to the reservoir even if there is a leak. Some of the possible supporting information which may help to assure ‘equal effectiveness’ might include: 1. A written and interpreted cement bond log from your logging service provider that assures that IA cement is not masking a T X IA X 9‐5/8”‐annulus leak and that a future leak from T‐IA‐9‐5/8”‐annulus (which will no longer be monitorable) will not allow injection gas to be injected out of the reservoir. 2. A pressure analysis inclusive of a fracture gradient description for the zones from the top of the reservoir, external to the 9‐5/8” casing to the surface casing shoe that demonstrates a hidden gas leak would not fracture any possible exposed formations above the reservoir. 3. Miscellaneous additional supporting information Hilcorp understands as relevant. Also, as per 20 AAC 25.412 (d) The operator shall provide a cement quality log or other well data approved by the commission to demonstrate isolation of the injected fluids to the approved interval…….. Is there a CBL on the 9‐5/8” casing to assure isolation across all annuli from the new IA TOC to the 9‐5/8” shoe? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 2 907‐793‐1231 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.gov). From: Rixse, Melvin G (OGC) Sent: Wednesday, December 29, 2021 5:55 PM To: Joleen Oshiro <joleen.oshiro@hilcorp.com> Subject: PTD190‐002, Sundry Request 321‐648. MPI 1‐21 Header Injection Pressure Joleen, What is the planned maximum header injection pressure for this well when going to GINJ? 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.gov). From:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: DIU MPI 1-21 (PTD# 190002) Not Operable: Failed MIT-IA Date:Thursday, November 18, 2021 10:42:42 AM Attachments:image001.png image002.png image004.png From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Monday, November 1, 2021 11:06 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: DIU MPI 1-21 (PTD# 190002) Not Operable: Failed MIT-IA Mr. Wallace, DIU MPI 1-21 (PTD# 190002) was previously made NOT OPERABLE due to it being offline for its regular 4-year MIT-IA. As part of work to convert the well from a water injector to a gas injector under sundry #321-447. AOGCC witnessed pressure testing was executed on 10/30/2021 where 1-21 passed an MIT-T to 4500 psi, but failed an MIT-IA. The well is currently secured with a tubing plug and will remain shut-in and NOT OPERABLE until diagnostics, repair and testing can be completed. Please call with any questions or concerns. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Darci Horner - (C) <dhorner@hilcorp.com> Sent: Wednesday, July 10, 2019 2:36 PM To: 'Regg, James B (DOA)' <jim.regg@alaska.gov>; 'Brooks, Phoebe L (CED)' <phoebe.brooks@alaska.gov>; doa.aogcc.prudhoe.bay@alaska.gov; 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Wyatt Rivard <wrivard@hilcorp.com>; Wilf Hyland <whyland@hilcorp.com> Subject: pre-AOGCC MIT-IA of Endicott well 1-21 All, Endicott well 1-21 (PTD # 1900020) successfully passed a pre-AOGCC witnessed MIT-IA on July 4, 2019 in preparation for it’s regular 4-year MIT. However, this test proved unnecessary because the well is not planned to be put back on injection and will instead be added to the long term shut-in list and will be tested again when appropriate. Please call myself or Wyatt Rivard (777-8547) with any questions. Regards, Darci Horner (Northern Solutions) Technologist Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Office: (907) 777-8406 Cell: (907) 227-3036 Email: dhorner@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if youhave received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us byreturn email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachmentswill not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM TO: Jim Regg ) P.I. Supervisor FROM: Brian Bixby Petroleum Inspector rl��G�i��z'ZI NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, November 9, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC 1-21 DUCK IS UNIT MPI 1-21 Src: Inspector Reviewed By: P.I. Suprv�— Comm Well Name DUCK IS UNIT MPI 1-21 API Well Number 50-029-22005-00-00 Inspector Name: Brian Bixby Permit Number: 190-002-0 Inspection Date: 10/30/2021 ✓ Insp Num: mitBDB211031042309 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1-21 "Type Inj N, TVD 9464 Tubing 429 4697 4624 4578 4556 ' PTD 1900020 Type Test SPT' Test psi 4500 IA 29 175 169 - 165 - 162 BBL Pumped: 6 BBL Returned: 1.4 - OA 20 20 20 20 20 Interval] OTHER P/F P Notes: MIT -T to 4500psi as per SUNDRY 321-447. The bbls returned was lower because it was only bled back to 3775 psi. Tuesday, November 9, 2021 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor�� FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, November 9, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC 1-21 DUCK IS UNIT MPI 1-21 Src: Inspector Reviewed B P.I. Supry Comm Well Name DUCK IS UNIT MPI 1-21 API Well Number 50-029-22005-00-00 Inspector Name: Brian Bixby Permit Number: 190-002-0 Inspection Date: 10/30/2021 Insp Num: mitBDB211031043206 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1-21 Type Inj N TVD 9464 - Tubing 3775 PTD 1900020 IType Test SPT Test psi 2500 IA 134 BBL Pumped: 19 BBL Returned: OA 20 Interval OTHER P/F F Notes: MITIA as per SUNDRY 321-447. Hilcorp wanted to test to 4500psi. At 3100psi and 19 bbls of fluid pumped it quit pressuring up. Stopped pump and blocked in well to monitor. Pressure on the IA dropped from 3100psi to 2800psi in 5 minutes. Tubing was at 3946 due to expansion and stay there. OA pressure remained at 20 psi. Stopped operation pending review form their engineers. Tuesday, November 9, 2021 Page 1 of 1 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Convert to Gas Injector 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 14,100'13,850 (Fill) Casing Collapse Conductor N/A Surface 2,260psi Intermediate 4,760psi Intermediate 5,080psi Liner 7,820psi Liner 6,280psi Liner 7,500psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: David Gorm Operations Manager Contact Email: Contact Phone: 777-8333 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng dgorm@hilcorp.com COMMISSION USE ONLY Authorized Name: 8,430psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312828 & ADL034633 190-002 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22005-00-00 Hilcorp Alaska LLC Length Size 10,306' 13,850' 10,093' 3,000 N/A ENDICOTT / ENDICOTT OIL TVD Burst 13,138' 9,690psi MD N/A 8,150psi 2,509' 8,311' 9,808' 2,509' 11,260' 131' 131'131' 30" 13-3/8" 9-5/8" 2,509' 9-5/8"2,227' 11,260' 9/30/2021 14,035'903' 4-1/2" 10,250' Perforation Depth MD (ft): See Schematic 4-1/2" See Schematic 12.6# / 13Cr80 / Vam Top 4.5" S-3 Hydroset & 7" (C-2)ZXP and 4.5" A1 Injection Valve 13,020(MD)/ 9,464(TVD) & 13,089(MD)/ 9,513(TVD) and 1,519(MD)/ 1,519(TVD) Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 14,085' 19' 869' 10,293' Authorized Signature: 5-1/2" 13,132' 9,544' 7,740psi DUCK IS UNIT MPI 1-21 C.O. 462.007 13,488' 7" 5,020psi 6,870psi Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 1:49 pm, Sep 03, 2021 321-447 Chad Helgeson (1517) 2021.09.03 13:39:40 - 08'00' 10-404 DSR-9/3/21DLB 09/03/2021 MGR17SEP2021 AOGCC to witness MIT-T to 4500 psi. MIT-IA to 2500 psi. X dts 9/21/2021 JLC 9/21/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.21 13:54:00 -08'00' RBDMS HEW 9/22/2021 Conversion to Gas Injector /Perforation add Well: END 1-21 PTD: 1900020 Well Name:1-21 API Number: 50-029-22005-00 Current Status:SI – PWI Rig:E-line Estimated Start Date:September 30th Estimated Duration:3 days Reg.Approval Req’std?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts 777-8398 Permit to Drill Number:1900020 First Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Second Call Engineer:Joleen Oshiro (907) 777-4608 (O) (650)-483-4774 (M) Current Bottom Hole Pressure:4,000 psi @ 10,000’ TVD (Based on SBHPS on 1-09A 07/25/21) Maximum Expected BHP:4,000 psi @ 10,000’ TVD (Based on SBHPS on 1-09A 07/25/21) Max. Anticipated Surface Pressure:3,000 psi (Based on 0.1 psi/ft. gas gradient) Last WHP:2,261 psi Taken on 08/30/2021 Reference Log:1-21 Jewelry Log – GR/CCL 18-Apr-2008 Brief Well Summary: Endicott 1-21 was a production well open to the K1 and K2A. The well’s bottom hole location is near the crest of the formation in the gas cap. Due to this, the well had an extremely high GOR and was determined not to be a competitive cycle well. To increase pressure support to the K1, END 1-21 was converted to a produced water injector and put in service on 6/28/2015. END 1-21 was on water injection until injection was stopped on 8/24/2018 when it was determined the water injection was not supplying the pressure support as intended and was flooding the offset producers. Wellbore Status: x Last MIT-IA: 7/04/2019 – Pressure Tested to 2,400 psi x Sundry 314-550 – 10/29/2014 Approved Conversion to Injector x Targeting 50 -80 MMCF gas Injection at 4,500 psi surface injection pressure x Variance to 20AAC25.412(b) for existing packer setting depth approved under Sundry# 314-550 x Gas Injection Under AIO-001 Endicott Field x GLV Dummied x Objective: Convert the surface equipment and tie END 1-21 into the gas injection header to complete the conversion of the well to a Gas injector. Add perforations to the K2A. Gun Run # Perf Top Perf Bottom Perf Length 1 ±13,748 ±13,768 ±20 2 ±13,625 ±13,645 ±20 3 ±13,525 ±13,545 ±20 4 ±13,475 ±13,495 ±20 Total ±80 Table 1: END 1-21 Proposed Perf Gun Runs -00 DLB Conversion to Gas Injector /Perforation add Well: END 1-21 PTD: 1900020 Pre-Sundry Well Work Slickline 1. MIRU SL unit. 2. Pressure test to 300psi low and 3,200 psi high. 3. Pull 4-1/2” A1 Injection Valve from 1,519’. 4. Drift with a 20’ 3-3/8” dummy gun to 13,850’ MD. 5. Conduct a Pre injection MIT-IA to 2,500 psi. a. Notify AOGCC 24 hrs. prior to the Pre-Injection MIT-IA for witness. 6. Bleed tubing and IA pressures to 0 psi. 7. RDMO Sundry Procedure (Approval Required to Proceed): Eline 1. RU EL unit and pressure test to 250psi low 3,500 psi high. 2. RIH and obtain a GR correlation pass,Contact OE David Gorm at 1(505) 215-2819 to review the correlation pass. 3. MU perforating tool string with 3-3/8” or 2-7/8”, 6spf, 60 deg phasing guns. 4. Perforate the first of 4 intervals, run #1- 20’ interval (±13,748’ - ±13,768’) as per Table 1: END 1-21 Proposed Perf Gun Runs. POOH. a. Note any tubing pressure change in WSR. 5. Repeat steps #3 and #4 for the gun runs 2 thru 4 to completed perforating the 3 separate (20’) intervals. 6. POOH Slickline Work 7. MIRU SL unit. 8. Pressure test to 300 psi low and 3,200 psi high. 9. Set 4-1/2” A1 Injection valve at 1,519’ md. 10. RDMO. 11. Conduct SVS testing as per 20AAC 25.265. Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. TIO Pressure Plot last time well on injection 8. Set a plug in the TBG XN Profile at 13,086’, load the TBG with fluid and MIT the TBG to 4,500 psi to ensure TBG integrity prior to gas injection. _____________________________________________________________________________________ Revised By: TDF 7/25/2017 SCHEMATIC Duck Island Unit Well: END 1-21 Last Completed: 3/29/2008 PTD: 190-002 TD =14,100’ (MD) / TD =10,306’(TVD) 30” RT Elev.: 55.1’/ BF Elev.: 16.05 7” 3 6 7 8 15 14 9 9-5/8” 1 2 10 11 12 & 13 PBTD = 13,920’(MD) / PBTD =10,152’(TVD) 4 7” Marker Jt @ 13,607’ 13-3/8” 5 Fish – 1-1/2” WRP Rubber Element & 1 Broken WRP Slip – 2 Pieces, 1” x 1” Each – 5/3/2014 TOF @ 13,850’ CTU 5/6/2017 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 30" Conductor N/A / N/A / N/A N/A Surface 131’ N/A 13-3/8” Surface 68/ NT80/ Btrs 12.415 Surface 2,509 0.150 9-5/8" Intermediate 47 / NT80 / NSCC 8.681 Surface 11,260 0.0732 9-5/8" Intermediate 47/ NT95HS/ NSCC 8.681 11,260 13,488’ 0.0732 7" Liner 29/ SM-110/ Btrs 6.184 13,216’ 14,085’ 0.0372 5-1/2” Liner 17/ 13CR-80/ Vam Top 4.892 13,113’ 13,132’ 0.0233 4-1/2” Liner 12.6/13CR-80/NSCT 3.958 13,132’ 14,035’ 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6/13CR-80/Vam Top 3.958 Surface 13,138’ 0.0152 JEWELRY DETAIL No Depth Item 1 1,519’ 4-1/2” A1 Injection Valve HXO SVLN, ID= 3.813 GLM Detail –410 SS MMG w/ DV and RK Latch 2 4,068’ST 4: Port= 0, Dev.= 45, TVD= 3,915’, 3/10/2015 3 8,048’ST 3: Port= 0, Dev.= 54, TVD= 6,396’, 3/10/2015 4 10,762’ST 2: Port= 0, Dev.= 51, TVD= 7,995’, 4/23/2015 5 12,908’ST 1: Port= 0, Dev.= 45, TVD= 9,383’, 3/30/2008 6 12,989’ 4-1/2” HES X Nipple, ID= 3.813” 7 13,020’ 9-5/8” x 4-1/2” Baker S-3 Packer, ID= 3.875” 8 13,055’ 4-1/2” HES X Nipple, ID= 3.813” 9 13,086’ 4-1/2” HES XN Nipple,ID= 3.725” 10 13,089’ 9-5/8” x 7” Baker C-2 LTP, ID= 6.28” 11 13,106’ 9-5/8” x 7” HMC Liner Hanger, ID= 6.360” 12 13,113’ 7” x 5-1/2” XO, ID= 4.81” 13 13,132’ 5-1/2” x 4-1/2” XO, ID=3.875” 14 13,138’ 4-1/2” Muleshoe, ID= 3.958” –TVD= 9,548 15 13,216’ 9-5/8” x 7” Liner Hanger PERFORATION DETAIL END Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Shot Date Current Size K2A 13,700 13,740 9,973’ 10,005’ 40 7/13/2017 Open 2-7/8” 13,745’ 13,765’ 10,009’ 10,024’ 20 12/26/1993 Squeezed 2-1/8” 13,748’ 13,768’ 10,013 10,024 20 5/25/2017 Open 3-3/8” 13,765’ 13,769’ 10,024’ 10,028’ 4 8/17/1997 Open 2-1/8” 13,765’ 13,770’ 10,024’ 10,028’ 10 2/19/1990 Open 3-3/8” K1 13,841’ 13,893’ 10,086’ 10,129’ 52 12/7/1990 Open 5” 13,841’ 13,893’ 10,086’ 10,129’ 52 6/23/2008 Open 3-3/8” 13,842’ 13,894’ 10,086’ 10,130’ 52 4/21/2008 Open 3-3/8” Ref Log: LDT/CNL/BR – 2/1/1990. Angle at Top Perf= 38 Deg @ 13,765’ OPEN HOLE / CEMENT DETAIL 13-3/8” 3,729 cu/ft Permafrost in 17.5” Hole 9-5/8" 575 cu/ft Class ‘G’ in a 12-1/4” Hole 7” 331 cu/ft Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL Max Hole Angle = 56 deg. @ 9,407’ TREE & WELLHEAD Tree 4-1/16” CIW 5K Wellhead FMC GENERAL WELL INFO API: 50-029-22005-00-00 Initial Completion by Doyon 15- 2/8/1990 RWO by Doyon 16 – 3/29/2008 Set WFD / WRD – 2/8/2012 GLV C/O - 7/27/2013 Pull WRP / Fish DH – 5/7/2014 Convert to WINJ – 6/16/2015 Perf Add – 5/25/2017 Perf Add – 7/13/2017 NOTE: MINIMUM ID= 3.725 @ 13,086’ 4-1/2 XN Nipple _____________________________________________________________________________________ Revised By: TDF 8/25/2021 PROPOSED Duck Island Unit Well: END 1-21 Last Completed: 3/29/2008 PTD: 190-002 TD = 14,100’ (MD) / TD =10,306’(TVD) 30” RT Elev.: 55.1’/ BF Elev.: 16.05 7” 3 6 7 8 15 14 9 9-5/8” 1 2 10 11 12 & 13 PBTD =13,920’ (MD) / PBTD =10,152’(TVD) 4 7” Marker Jt @ 13,607’ 13- 5 Fish– 1-1/2” WRP Rubber Element & 1 Broken WRP Slip – 2 Pieces, 1” x 1” Each – 5/3/2014 TOF @ 13,850’ CTU 5/6/2017 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 30" Conductor N/A / N/A / N/A N/A Surface 131’ N/A 13-3/8” Surface 68/ NT80/ Btrs 12.415 Surface 2,509 0.150 9-5/8" Intermediate 47 / NT80 / NSCC 8.681 Surface 11,260 0.0732 9-5/8" Intermediate 47/ NT95HS/ NSCC 8.681 11,260 13,488’ 0.0732 7" Liner 29/ SM-110/ Btrs 6.184 13,216’ 14,085’ 0.0372 5-1/2” Liner 17/ 13CR-80/ Vam Top 4.892 13,113’ 13,132’ 0.0233 4-1/2” Liner 12.6/13CR-80/NSCT 3.958 13,132’ 14,035’ 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6/13CR-80/Vam Top 3.958 Surface 13,138’ 0.0152 JEWELRY DETAIL No Depth Item 1 1,519’ 4-1/2” A1 Injection Valve HXO SVLN, ID= 3.813 GLM Detail – 410 SS MMG w/ DV and RK Latch 24,068’ST 4: Port= 0, Dev.= 45, TVD= 3,915’, 3/10/2015 38,048’ST 3: Port= 0, Dev.= 54, TVD= 6,396’, 3/10/2015 4 10,762’ST 2: Port= 0, Dev.= 51, TVD= 7,995’, 4/23/2015 5 12,908’ST 1: Port= 0, Dev.= 45, TVD= 9,383’, 3/30/2008 6 12,989’ 4-1/2” HES X Nipple, ID= 3.813” 7 13,020’ 9-5/8” x 4-1/2” Baker S-3 Packer, ID= 3.875” 8 13,055’ 4-1/2” HES X Nipple, ID= 3.813” 9 13,086’ 4-1/2” HES XN Nipple,ID= 3.725” 10 13,089’ 9-5/8” x 7” Baker C-2 ZXP LTP, ID= 6.28” 11 13,106’ 9-5/8” x 7” HMC Liner Hanger, ID= 6.360” 12 13,113’ 7” x 5-1/2” XO, ID= 4.81” 13 13,132’ 5-1/2” x 4-1/2” XO, ID=3.875” 14 13,138’ 4-1/2” Muleshoe, ID= 3.958” –TVD= 9,548 15 13,216’ 9-5/8” x 7” Liner Hanger PERFORATION DETAIL END Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Shot Date Current Size K2A ±13,475’ ±13,495’ ±9,800’ ±9,816’ ±20 Future Pending 3-3/8” ±13,525’ ±13,545’ ±9,839’ ±9,854’ ±20 Future Pending 3-3/8” ±13,625’ ±13,645’ ±9,916’ ±9,932’ ±20 Future Pending 3-3/8” 13,700 13,740 9,973’ 10,005’ 40 7/13/2017 Open 2-7/8” 13,745’ 13,765’ 10,009’ 10,024’ 20 12/26/1993 Squeezed 2-1/8” ±13,748’ ±13,768’ ±10,013' ±10,029’ ±20 Future Pending 3-3/8” 13,748’ 13,768’ 10,013’ 10,029’ 20 5/25/2017 Open 3-3/8” 13,765’ 13,769’ 10,024’ 10,028’ 4 8/17/1997 Open 2-1/8” 13,765’ 13,770’ 10,024’ 10,028’ 10 2/19/1990 Open 3-3/8” K1 13,841’ 13,893’ 10,086’ 10,129’ 52 12/7/1990 Open 5” 13,841’ 13,893’ 10,086’ 10,129’ 52 6/23/2008 Open 3-3/8” 13,842’ 13,894’ 10,086’ 10,130’ 52 4/21/2008 Open 3-3/8” OPEN HOLE / CEMENT DETAIL 13-3/8” 3,729 cu/ft Permafrost in 17.5” Hole 9-5/8" 575 cu/ft Class ‘G’ in a 12-1/4” Hole 7” 331 cu/ft Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL Max Hole Angle = 56 deg. @ 9,407’ TREE & WELLHEAD Tree 4-1/16” CIW 5K Wellhead FMC GENERAL WELL INFO API: 50-029-22005-00-00 Initial Completion by Doyon 15- 2/8/1990 RWO by Doyon 16 – 3/29/2008 Set WFD / WRD – 2/8/2012 GLV C/O - 7/27/2013 Pull WRP / Fish DH – 5/7/2014 Convert to WINJ – 6/16/2015 Perf Add – 5/25/2017 Perf Add – 7/13/2017 NOTE: MINIMUM ID= 3.725 @ 13,086’ 4-1/2 XN Nipple Bleeds:Date Annulus Start Press End Press RemarksDate Range: 08/01/2015 - 08/31/2019Well: MPI 1-21Desc: PWIPermit to drill: 1900020Admin Approval:API: 50-029-22005-00-0005001,0001,5002,0002,5003,0003,5004,00005001,0001,5002,0002,5003,00008/31/201907/30/201906/28/201905/27/201904/25/201903/24/201902/20/201901/19/201912/18/201811/16/201810/15/201809/13/201808/12/201807/11/201806/09/201805/08/201804/06/201803/05/201802/01/201812/31/201711/29/201710/28/201709/26/201708/25/201707/24/201706/22/201705/21/201704/19/201703/18/201702/14/201701/13/201712/12/201611/10/201610/09/201609/07/201608/06/201607/05/201606/03/201605/02/201603/31/201602/28/201601/27/201612/26/201511/24/201510/23/201509/21/201508/20/2015VolumePressureMPI 1-21 TIO PlotTubingIAOAWater Inj Dltti ( -z- ( Regg, James B (CED) Prit Ig060u From: Brooks, Phoebe L (CED) Sent: Tuesday, July 16, 2019 3:52 PM To: Darci Horner - (C) Cc: Regg, James B (CED) Subject: RE: pre-AOGCC MIT -IA of Endicott well 1-21 Attachments: MIT END MPI 1-21 07-04-19 Revised.xlsx Darci, Attached is a revised report changing the Type Inj to "N" and interval type to "0" based on the Notes. Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe brooks@alaska.eov. From: Darci Horner - (C) <dhorner@hilcorp.com> Sent: Wednesday, July 10, 2019 2:36 PM To: Regg, James B (CED) <jim.regg@alaska.gov>; Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov>; Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Wyatt Rivard <wrivard@hilcorp.com>; Wilf Hyland <whyland@hilcorp.com> Subject: pre-AOGCC MIT -IA of Endicott well 1-21 All, Endicott well 1-21 (PTD # 1900020) successfully passed a pre-AOGCC witnessed MIT -IA on July 4, 2019 in preparation for it's regular 4 -year MIT. However, this test proved unnecessary because the well is not planned to be put back on injection and will instead be added to the long term shut-in list and will be tested again when appropriate. Please call myself or Wyatt Rivard (777-8547) with any questions. Regards, Darci Horner (Northern Solutions) Technologist Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Office: (907) 777-8406 Cell: (907) 227-3036 Email: dhorner@hilcorp.com The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Submit to: an re000a1aska.aov: OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test A(D13CC.Inspectonuttalaus"oony, Phoetie,brooks0alasoyaov Hilcorp Alaska LLC Endicott I DIU I MPI Chars walltuttuirithti,skeom Well 131 - I Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 50 Min. 0= 0Ner (tlewlbe in Nobs) 4=Four Year Cede PTD 1900020 Type Inj N Tubing 50 50 50 50 50 50 ' Type Test P Packer TVD 9464- BBL Pump 5.7 IA 275 - 2414 2405— 2399 2396 2394 Interval O Test psi 2366 BBL Relum 5.6 OA 60 75 75 75 - 75 - 75 - Result I P Notes: Well not on injection AOGCC Rep. Austin McLeod waived option to witness State asked that we re-request when well is back on injection and stable. Well Pressures'. Pretest Initial 15 Min. 30 Min. 45 Min. W Min. PTD Type lnl Tubing Type Test P—..kerTVDI I BBL Pump IA Interval Test psi BBL Return OA Result Noce.: Well Pressures: Pretest Initial 15 Min. W Min. 45 Min. W Min. PTD Type Inj Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result Notes: Wolf Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing FE Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Int Tubing Type Test Packer ND BBL Pump IA interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min, 45 Min. 60 Min. PTD Type Inj Tubing Type Test Pecker ND BBL Pump IA Interval Test psi BBL Return OA Result Not Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result Nolen: Wsll Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result Nates: TYPE INU Codes TYPE TEST Cooke INTERVAL Codes Result Code. W=Water P=Preaeum Test 1=Inial Ten P=Pan G - Gas 0= 0Ner (tlewlbe in Nobs) 4=Four Year Cede F=Fol S=Slurry V=Rent by Venence 1=lmmo,luelve =IMobee[Wanewamr 0=Diner (eescacenr note.) N= Not Injecting FOM 10-426 (Revised 0112017) xpte-07p4_mlT_Dlu_t-xt P7b (qCW 2,o Regg, James B (CED) From: Darci Horner - (C) <dhorner@hilcorp.com>� C 77 J(� Sent: Wednesday, July 10, 2019 2:36 PM r 1 To: Regg, James B (CED); Brooks, Phoebe L (CED); DOA AOGCC Prudhoe Bay; Wallace, Chris D (CED) Cc: Wyatt Rivard; Wilf Hyland Subject: pre-AOGCC MIT -IA of Endicott well 1-21 Attachments: pre-AOGCC MIT END MPI 1-21 7-04-19.xlsx All, Endicott well 1-21 (PTD # 1900020) successfully passed a pre-AOGCC witnessed MIT -IA on July 4, 2019 in preparation for it's regular 4 -year MIT. However, this test proved unnecessary because the well is not planned to be put back on injection and will instead be added to the long term shut-in list and will be tested again when appropriate. Please call myself or Wyatt Rivard (777-8547) with any questions. Regards, Darci Horner (Northern Solutions) Technologist H ilcorp Alaska, LLC 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Office: (907) 777-8406 Cell: (907) 227-3036 Email: dhorner@hilcorp.com The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: Im recm@alaskegov. AOGCC Inspectorshipalaska coy- Phoebe brooksAalaska. oov OPERATOR: H'Icom Alaska LLC FIELD/UNIT/PAD: Entlicott/DIU/MPI DATE: 07/04/19 OPERATOR REP: Win Hyland AO= REP: waived ends wallace0a1aska.aov Well 1.21 INTERVAL Codes Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1900020 Type Inj W Tubing 50 50 50 50 50 Type Test P Packer TVD W64 BELL Pump 5.7 IA 72715F#2114 2405 2399 2396 2394 Interval 4 Test psi 2366 BBL Retum 5.6 OA 605 75 75 75 1 75 1 Result P Notes: Well not on initiation. AOOCC Rep. Austin McLeod waived option to witness. State asked that we re-request at well is back on injection and stable. Well Pressures: Pretest Initial 15 Min. W Min. 45 Min. 60 Min. PTD Typa Inj Tubing Type Test Packer WD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures'. Pretest Initial 15 Min. W Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer WD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBLPumpj I IA I Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer WD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well pr Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer WD BBL Pump IA Interval Test psi B8L Return OA Result Notes: WellPressures: Pretest Initial 15 Min. 30 Min 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer WD BBL Pump IA Interval Test psi BBL Return OA Result Ni Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer WD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE 1. Cases TYPE TEST Codes INTERVAL Codes W=Water P=Pressure Test 1=ini TOO G=Gas O=Other oeaci in Novel 4=Four Year cycle s =slur, V = Reyuireu by Variance 1= Indianan Wastewater 0=Chat oescnhe in notes) N = Not lyrical, Forth 10-425 (Revised 01/2017) preo-AOGCC MIT ENO MPI 1-211714.19 Result Codes P=Free F=Far 1=Inconclusive STATE OF ALASKA ALIIL OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LJ Plug Perforations LJ Fracture Stimulate H Pull Tubing H Operations shutdown U Performed: Suspend ❑ Perforate 2 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑ Exploratory ❑ 190-002 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑✓ 6.API Number: AK 99503 50-029-22005-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0312828&ADL034633 DUCK IS UNIT MPI 1-21 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Endicott Field/ Endicott Oil Pool 11.Present Well Condition Summary: Total Depth measured 14,100 feet Plugs measured N/A RECEIVED true vertical 10,306 feet Junk measured 13,850(Fill) feet JUL 2 5 2017 Effective Depth measured 13,850 feet Packer measured 13,020&13,089 feet true vertical 10,093 feet true vertical 9,464&9,513 feet AOG C Casing Length Size MD TVD Burst Collapse Conductor 131' 30" 131' 131' N/A N/A Surface 2,509' 13-3/8" 2,509' 2,509' 5,020psi 2,260psi Intermediate 11,260' 9-5/8" 11,260' 8,311' . 6,870psi 4,760psi Intermediate 2,227' 9-5/8" 13,488' 9,808' 8,150psi 5,080psi Liner 869' 7" 14,085' 10,293' 9,690psi 7,820psi Liner 19' 5-1/2" 13,132' 9,544' 7,740psi 6,280psi Liner 903' 4-1/2" 14,035' 10,250' h 8,430psi 7,500psi Perforation depth Measured depth See Schematic feet SCA� A� 16 2Q 1( True Vertical depth See Schematic feet G Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/13Cr80/Vam Top 13,138' 9,548' 4.5"S-3 Hydroset 4.5"Al Injection 1,519(MD) Packers and SSSV(type,measured and true vertical depth) 9-5/8"x 7"C-2 ZXP Valve HXO SVLN See Above 1,519(TVD) 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 473 250 2,225 Subsequent to operation: 0 0 220 350 2,189 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory Development❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ Q 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: 317-293 Authorized Name: Bo York Contact Name: Taylor Wellman Authorized Title: Operations Manager Contact Email: twellman(C�hilcorp.com Authorized Signature: Dat7/24/2017 Contact Phone: 777-8449 Form 10 401 Rcv. 2017 Submit Original Only ii7 3•7'/? RBDMS \," JUL 2 7 2017 • 410 Duck Island Unit Well: SCHEMATIC astComplet d: 3/29/2008 ua.„n, :sIaa,:�.I,Lc PTD: 190-002 TREE&WELLHEAD RT Elev.:55.1'/BF Elev.:16.05 Tree 4-1/16"CIW SK Wellhead FMC 30"41 OPEN HOLE/CEMENT DETAIL 13-3/8" 3,729 cu/ft Permafrost in 17.5"Hole 1 9-5/8" 575 cu/ft Class'G'in a 12-1/4"Hole 7" 331 cu/ft Class"G"in 8-1/2"Hole 13 3/8" CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 30" Conductor N/A/N/A/N/A N/A Surface 131' N/A 13-3/8" Surface 68/NT80/Btrs 12.415 Surface 2,509 0.150 E'; 2 9-5/8" Intermediate 47/NT80/NSCC 8.681 Surface 11,260 0.0732 9-5/8" Intermediate 47/NT95HS/NSCC 8.681 11,260 13,488' 0.0732 7" Liner 29/SM-110/Btrs 6.184 13,216' 14,085' 0.0372 5-1/2" Liner 17/13CR-80/Vam Top 4.892 13,113' 13,132' 0.0233 4-1/2" Liner 12.6/13CR-80/NSCT 3.958 13,132' 14,035' 0.0152 3 TUBING DETAIL 4-1/2" Tubing I 12.6/13CR-80/Vam Top I 3.958 Surface 13,138' 0.0152 WELL INCLINATION DETAIL 4 Max Hole Angle=56 deg. @ 9,407' JEWELRY DETAIL VOTE: MINIMUM ID= No Depth Item if 1 5 3.725 @ 13,086' 1 1,519' 4-1/2"Al Injection Valve HXO SVLN,ID=3.813 6 ^ 4-1/2 XN Nipple GLM Detail-410 SS MMG w/DV and RK Latch 2 4,068' ST 4:Port=0,Dev.=45,TVD= 3,915',3/10/2015 7 3 8,048' ST 3:Port=0,Dev.=54,TVD= 6,396',3/10/2015 4 10,762' ST 2:Port=0,Dev.=51,TVD= 7,995', 4/23/2015 _ 8 5 12,908' ST 1:Port=0,Dev.=45,TVD= 9,383',3/30/2008 9 A 6 12,989' 4-1/2"HES X Nipple,ID=3.813" 10 7 13,020' 9-5/8"x 4-1/2"Baker S-3 Packer,ID=3.875" 11 4111,4 8 13,055' 4-1/2"HES X Nipple,ID=3.813" 12&13 9 13,086' 4-1/2"HES XN Nipple,ID=3.725" 14 10 13,089' 9-5/8"x 7"Baker C-2 LTP,ID=6.28" _ 11 13,106' 9-5/8"x 7"HMC Liner Hanger,ID=6.360" 12 13,113' 7"x 5-1/2"XO,ID=4.81" 13 13,132' 5-1/2"x 4-1/2"XO,ID=3.875" 14 13,138' 4-1/2"Muleshoe,ID=3.958"-TVD=9,548 15 13,216' 9-5/8"x 7"Liner Hanger PERFORATION DETAIL E. 1)4 15 END Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Shot Date Current Size 13,700 13,740 9,973' 10,005' 40 7/13/2017' Open 2-7/8" 13,745' 13,765' 10,009' 10,024' 20 12/26/1993 Squeezed 2-1/8" 95/8" K2A 13,748' 13,768' 10,013 10,024 20 5/25/2017 Open 3-3/8" 13,765' 13,769' 10,024' 10,028' 4 8/17/1997 ' Open 2-1/8" 7"Markerit 13,765' 13,770' 10,024' 10,028' 10 2/19/1990 Open 3-3/8" TOF@ A--@13,607' 13,841' 13,893' 10,086' 10,129' 52 12/7/1990 Open 5" K1 13,841' 13,893' 10,086' 10,129' 52 6/23/2008 Open 3-3/8" 13,850'CTU 13,842' 13,894' 10,086' 10,130' 52 4/21/2008 Open 3-3/8" 5/6/2017 Ref Log:LDT/CNL/BR-2/1/1990. Angle at Top Perf=38 Deg @ 13,765' Fish-i-]/Y'WRP GENERAL WELL INFO Rubber Element& API:50-029-22005-00-00 1 Broken WRPSIip Initial Completion by Doyon 15-2/8/1990 -2 Pieces, 1"x 1"��--* - RWO by Doyon 16-3/29/2008 Each 5/3/2014r Aiti ' Set WFD/WRD-2/8/2012 GLV C/O-7/27/2013 TD=14,100'(MD)/TD=10,306'(1VD) Pull WRP/Fish DH-5/7/2014 PBTD=13,920'(MD)/PBTD=10,152'(TVD) Convert to W I N1-6/16/2015 Perf Add-5/25/2017 Perf Add-7/13/2017 Revised By:TDF 7/25/2017 • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 1-21 Slickline 50-029-22005-00-00 190-002 7/10/17 7/14/17 Daily Operations: 7/5/2017 -Wednesday No activity to report. 7/6/2017-Thursday No activity to report. 7/7/2017- Friday No activity to report. 7/8/2017 -Saturday No activity to report. 7/9/2017-Sunday No activity to report. 7/10/2017 - Monday PT PCE 250#-LOW/2,600#-HIGH. PULLED 4-1/2" Al INJECTION VALVE (ser#HAS-297) FROM HXO SVLN AT 1,497'SLM (1,519' MD). DRIFT TBG W/20' x 3-3/8" DMY PERF GUNS TO TD AT 13,902' SLM. P/U WEIGHT 1,450#. WELL LEFT SHUT-IN ON DEPARTURE, DSO NOTIFIED. 7/11/2017-Tuesday No activity to report. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 1-21 Slickline 50-029-22005-00-00 190-002 7/10/17 7/14/17 Daily Operations: 7/12/2017 -Wednesday No activity to report. 7/13/2017 -Thursday WELL ON INJECTION UPON ARRIVAL(Eline adperf). MADE TWO GUN RUNS & PERFORATED INTERVAL @ 13,700' - 13,740' WI 2-7/8" 6 SPF RAZOR DP GUNS.TIED INTO SLB JEWELRY LOG DATED 18-APRIL-2008. RETURNED WELL TO OPS TO PUT ON INJECTION - NOTIFIED PAD OP OF DEPARTURE.JOB COMPLETE. 7/14/2017 - Friday WELL ON INJECTION UPON ARRIVAL(set sssv). PT PCE 250#-LOW/2,600#-HIGH. SET 4-1/2" Al INJECTION SSSV(HAS-297) IN HXO SVLN AT 1,519' MD (1 set of std pkg w/o-ring). PERFORMED SUCCESFUL DRAWDOWN TEST ON Al INJECTING SSSV. WELL LEFT SHUT-IN ON DEPARTURE, DSO NOTIFIED. 7/15/2017 -Saturday No activity to report. 7/16/2017 -Sunday No activity to report. 7/17/2017 - Monday No activity to report. 7/18/2017 -Tuesday No activity to report. ID • V OF T�� 4,1** �y/ s THE STATE Alaska Oil and Gas �_�►�_' �-�_�=i�, ®f A ern Conservation Commission 'Witt 333 West Seventh Avenue T,. t GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OFAe. Main: 907.279.1433 ALAS* Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC At! 1 4 2C 17. 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Endicott Field,Endicott Oil Pool,DIU MPI 1-21 Permit to Drill Number: 190-002 Sundry Number: 317-293 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080,within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, )pJ • Daniel T. Seamount,Jr. Commissioner DATED this 27\24 June,2017. RBDMS t/v, JUN 2 8 2017 • • RECEIVED • STATE OF ALASKA SUN 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AC, GCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate Q • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ 190-002 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service 6.API Number: Anchorage Alaska 99503 ,,),S,17 50-029-22005-00-00 ' 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 462.007 ' Will planned perforations require a spacing exception? Yes ❑ No ❑, • DUCK IS UNIT MPI 1-21 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): AI>i-03'(:233 ADL0312828 AIN ,'2 17 Endicott Field/Endicott Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 14,100' ` 10,306' ' 13,850' 10,093' 2,950 N/A 13,850(Fill) Casing Length Size MD TVD Burst Collapse Conductor 131' 30" 131' 131' N/A N/A Surface 2,509' 13-3/8" 2,509' 2,509' 5,020psi 2,260psi Intermediate 11,260' 9-5/8" 11,260' 8,311' 6,870psi 4,760psi Intermediate 2,227' 9-5/8" 13,488' 9,808' 8,150psi 5,080psi Liner 869' 7" 14,085' 10,293' 9,690psi 7,820psi Liner 19' 5-1/2" 13,132' 9,544' 7,740psi 6,280psi Liner 903' 4-1/2" 14,035' 10,250' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 4-1/2" 12.6#/13Cr80/Vam Top 13,138' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 4.5"S-3 Hydroset& 7"(C-2)ZXP and 4.5"Al Injection Valve 13,020(MD)/9,464(TVD)&13,089(MD)/9,513(TVD)and 1,519(MD)/1,519(TVD) 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0 ' 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ Q • WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. IA. Authorized Name: Bo York Contact Name: Wyatt Rivard Authorized Title: Operations Manager Contact Email: wrivard p hiIcorp.com Contact Phone: 777-8547 Authorized Signature: 2.'",,, Date: 6/22/2017 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 ❑ 14Sr (O I 211 1 1 Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No V Subsequent Form Required: I U•-ki Oil RBDMS L-' JUN 2 8 2017 Approved by1,---. 2 APPROVED BY //'? 'COMMISSIONER THE COMMISSION Date: j 17 Submit Form and Form 10-403 Revised 4/2017 0 RfitioitstiAts valid for 12 721s from the date of approval. Attachments in Duplicate • • Re/Add Perf Well: END 1-21 PTD: 1900020 iiacon)Alaska.1.1,1 API: 50-029-22005-00-00 Well Name: END 1-21 API Number: 50-029-22005-00-00 Current Status: On Injection Field: Endicott Estimated Start Date: July 10, 2017 Rig: E-Line, Slickline Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 1900020 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Wyatt Rivard (907) 777-8547 (0) (509) 670-8001 (M) AFE Number: WeIIEZ Input Required? Yes Current BHP(LSZ K1): 3,947 psi @ 10,000'TVD (Based on BHP taken on 05/01/14) Maximum Expected BHP: 3,947 psi @ 10,000'TVD (Based on BHP taken on 05/01/14) MPSP: 2,950 psi Based on 0.1 psi/ft.gas gradient Last SI WHP: 2,350 psi Taken 5/28/2017 Min ID: 3.725" ID in 4-1/2"XN Nip at 13,068 Max Deviation: 56 deg at 9,407' Correlation Log: SLB Jewelry Log GR/CCL dated 18-April-2008 Brief Well Summary: The DIU Endicott 1-21 well was originally drilled as a production well in the K1 in Febuary of 1990. Perforations were added in the K2A in December of 1993. A gas shut off(GSO) was completed in 1997 across the K2A.The well was shut in in September 1999 due to TxIA communication until a RWO returned the well to production in 2008.The well was shut in in 2013 due to high GOR.The well was converted as a gas cap WINJ well in July 2015. The main target for this injection was the lower K2A. In December 2015, slickline drifted the well due to lack of injection. Schmoo/fill was encountered at 13,800'MD, indicating the K1 was unlikely taking any injection and only the 5ft remaining perfs in the K2A were able to be injected into at—460bwpd.The well had a coil fill cleanout performed on 5/6/17 to 13,840' MD and an additional 20 ft of perforations shot on 5/25/17 with a minimal improvement in injection rate.An additional 40 ft of^perforations will be added to increase iniection to, the K2A. Objective: Perforate the following intervals enclosed in the table below. Gun Run# Perf Top Perf Bottom Perf Length Formation 1 ±13,720' ±13,740' 20' K2A 2 ±13,700' ±13,720' 20' K2A Total 40' Table 1: END 1-21 Proposed Perf Gun Runs Note: Final depths to be confirmed in "Final Approved Perf Sheet" Non sundried operations Slickline 1. RU SL unit and pressure test to 250psi low/3,000psi. 2. RIH and pull the 4-1/2" Al Injection SSSV from 1,519' md. 3. RD SL unit. Sundried Operations(Approved Sundry required prior to proceeding) E-Line 4. RU EL unit and pressure test to 250psi low 3,000psi high. • • Re/Add Perf Well: END 1-21 PTD: 1900020 kora Alaska,LL API: 50-029-22005-00-00 5. MU perforating tool string with 20' of 2-7/8" or 3-1/8" guns. 6. RIH and correlate 15t gun run to Tie-In Log. Contact OE Taylor Wellman or OE Wyatt Rivard (contact info above) prior to perforating for final approval of tie in. 7. Perforate as per Table 1: END 1-21 Proposed Perf Gun Runs. POOH. a. Correlation Log: SLB Jewelry Log GR/CCL dated 18-April-2008 b. Note any tubing pressure change in WSR. 8. Repeat previous step for Gun Run#2 9. RD Eline. Slickline 10. RU SL unit and pressure test to 250psi low/3,000psi. 11. RIH and set 4-1/2" Al Injection SSSV at 1,519'md. a. Description of last SSSV set on 5/28/17: SET 4.5" A-1 INJ VALVE SER# HAS-297, 1.50" Bean. See WSR for full details. 12. RD SL unit. Attachments:Wellbore Schematic& Proposed Wellbore Schematic • • 0 Duck Island Unit II Well: END 1-21 SCHEMATIC Last Completed: 2/8/1990 ile„e,�nlaska,IAA:IAA: PTD: 190-002 >Ei TREE&WELLHEAD RT Elev.:55.1'/BF Elev.:16.05 Tree 4-1/16"CIW 5K Wellhead FMC 3cin� ; OPEN HOLE/CEMENT DETAIL il ,! 13-3/8" 3,729 cu/ft Permafrost in 17.5"Hole v 1 8r 9-5/8" 575 cu/ft Class'G'in a 12-1/4"Hole 7" 331 cu/ft Class"G"in 8-1/2"Hole 13-3/8"jit''' CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 30" Conductor N/A/N/A/N/A N/A Surface 131' N/A 13-3/8" Surface 68/NT80/Btrs 12.415 Surface 2,509 0.150 2 9-5/8" Intermediate 47/NT80/NSCC 8.681 Surface 11,260 0.0732 9-5/8" Intermediate 47/NT95HS/NSCC 8.681 11,260 13,488' 0.0732 7" Liner 29/SM-110/Btrs 6.184 13,216' 14,085' 0.0372 5-1/2" Liner 17/13CR-80/Vam Top 4.892 13,113' 13,132' 0.0233 4-1/2" Liner 12.6/13CR-80/NSCT 3.958 13,132' 14,035' 0.0152 3 TUBING DETAIL 4-1/2" Tubing 12.6/13CR-80/Vam Top 3.958 Surface 13,138' 0.0152 WELL INCLINATION DETAIL 4 Max Hole Angle=56 deg. @ 9,407' NOTE: JEWELRY DETAIL MINIMUM ID= No Depth Item 5 is 3.725 @ 13,068' 1 1,519' 4-1/2"HXO SVLN,ID=3.813 6 4-1/2 XN Nipple GLM Detail-MMG w/DV and RK Latch .I 2 4,068' ST 4:Port=0,Dev.=45,TVD= 3,915',3/10/2015 ten_ e 7 3 8,048' ST 3:Port=0,Dev.=54,TVD= 6,396',3/10/2015 4 10,762' ST 2:Port=0,Dev.=51,TVD= 7,995', 4/23/2015 d : 5 12,906' ST 1:Port=0,Dev.=45,TVD= 9,383',3/30/2008 g 6 12,989' 4-1/2"HES X Nipple,ID=3.813" 10 7 13,020' 9-5/8"x 4-1/2"Baker S-3 Packer,ID=3.875" 19\ 11 8 13,055' 4-1/2"HES X Nipple,ID=3.813" 12813 9 13,086' 4-1/2"HES XN Nipple,ID=3.725" 14 10 13,089' 9-5/8"x 7"Baker C-2 LTP,ID=6.28" 11 13,106' 9-5/8"x 7"HMC Liner Hanger,ID=6.360" 12 13,113' 7"x 5-1/2"X0,ID=4.81" 13 13,132' 5-1/2"x 4-1/2"XO,ID=3.875" 14 13,138' 4-1/2"Muleshoe,ID=3.958"-TVD=9,548 15 13,216' 9-5/8"x 7"Liner Hanger PERFORATION DETAIL 7E5) IID 15 END Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Shot Date Current Size 13,745' 13,765' 10,009' 10,024' 20 12/26/1993 Squeezed 2-1/8" K2A 13,748' 13,768' 10,013 10,024 20 5/25/2017 Open 3-3/8" 13,765' 13,769' 10,024' 10,028' 4 8/17/1997 Open 2-1/8" 9-5/8" 1 , , 13,765' 13,770' 10,024' 10,028' 10 2/19/1990 Open 3-3/8" 7"Marker.lt 13,841' 13,893' 10,086' 10,129' 52 12/7/1990 Open 5" TOF@ .&@13,607' K1 13,841' 13,893' 10,086' 10,129' 52 6/23/2008 Open 3-3/8" 13,850 CTU 13,842' 13,894' 10,086' 10,130' 52 4/21/2008 Open 3-3/8" 5/6/2017 Ref Log:LDT/CNL/BR-2/1/1990. Angle at Top Perf=38 Deg @ 13,765' GENERAL WELL INFO Fish-1-1/2 WRP ,, API:50-029-22005-00-00 Rubber Element& "° X•, , Initial Completion by Doyon 15-2/8/1990 1 Broken WRP_lip R WO by Doyon 16-3/30/2008 -2 Pieces, 1"xl"_ . � Set WFD/WRD-2/8/2012 Each-5/3/2014 GLV C/O-7/27/2013 7 `', `I. Pull WRP/Fish DH-5/7/2014 TD=14,100'(MD)/TD=10,306'(TVD) Convert to WINJ-6/16/2015 PBTD=13,920'(MD)/PBTD=10,152'(TVD) Perf Add-5/25/2017 Revised By:TDF 6/1/2017 • • Duck Island Unit J 11 Well: END 1-21 PROPOSED Last Completed: 2/8/1990 Hilcorn Alaska,1.l. PTD: 190-002 TREE&WELLHEAD RT Elev.:55.1'/BF Elev.:16.05 Tree 4-1/16"CIW 5K Wellhead FMC 30 `: [ 1, OPEN HOLE/CEMENT DETAIL 13-3/8" 3,729 cu/ft Permafrost in 17.5"Hole AS 1 9-5/8" 575 cu/ft Class'G'in a 12-1/4"Hole 7" 331 cu/ft Class"G"in 8-1/2"Hole 13 3/8 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 30" Conductor N/A/N/A/N/A N/A Surface 131' N/A 13-3/8" Surface 68/NT80/Btrs 12.415 Surface 2,509 0.150 2 9-5/8" Intermediate 47/NT80/NSCC 8.681 Surface 11,260 0.0732 9-5/8" Intermediate 47/NT95HS/NSCC 8.681 11,260 13,488' 0.0732 7" Liner 29/SM-110/Btrs 6.184 13,216' 14,085' 0.0372 5-1/2" Liner 17/13CR-80/Vam Top 4.892 13,113' 13,132' 0.0233 4-1/2" Liner 12.6/13CR-80/NSCT 3.958 13,132' 14,035' 0.0152 ,'; 3 TUBING DETAIL 4-1/2" Tubing 12.6/13CR-80/Vam Top I 3.958 Surface I 13,138' 0.0152 WELL INCLINATION DETAIL f 4 Max Hole Angle=56 deg. @ 9,407' JEWELRY DETAIL t» No Depth Item MINIMUM ID= 5 3.725 @ 13,068' 1 1,519' 4-1/2"HXO SVLN,ID=3.813 6 4-1/2 XN Nipple GLM Detail-MMG w/DV and RK Latch 2 4,068' ST 4:Port=0,Dev.=45,ND= 3,915',3/10/2015 -> ` r5K 7 3 8,048' ST 3:Port=0,Dev.=54,ND= 6,396',3/10/2015 4 10,762' ST 2:Port=0,Dev.=51,TVD= 7,995', 4/23/2015 1 8 5 12,906' ST 1:Port=0,Dev.=45,TVD= 9,383',3/30/2008 -,: 9 6 12,989' 4-1/2"HES X Nipple,ID=3.813" of 10 7 13,020' 9-5/8"x 4-1/2"Baker S-3 Packer,ID=3.875" ii 8 13,055' 4-1/2"HES X Nipple,ID=3.813" 12&13 9 13,086' 4-1/2"HES XN Nipple,ID=3.725" 14 10 13,089' 9-5/8"x 7"Baker C-2 LTP,ID=6.28" 11 13,106' 9-5/8"x 7"HMC Liner Hanger,ID=6.360" 12 13,113' 7"x 5-1/2"XO,ID=4.81" 13 13,132' 5-1/2"x 4-1/2"X0,ID=3.875" 14 13,138' 4-1/2"Muleshoe,ID=3.958"-ND=9,548 15 13,216' 9-5/8"x 7"Liner Hanger PERFORATION DETAIL ' 15 END Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Shot Date Current Size ±13,700 ±13,740 ±9,973' ±10,005' ±40 Future Future TBD 13,745' 13,765' 10,009' 10,024' 20 12/26/1993 Squeezed 2-1/8" K2A 13,748' 13,768' 10,013 10,024 20 5/25/2017 Open 3-3/8" 9-5/8 A 111 13,765' 13,769' 10,024' 10,028' 4 8/17/1997 Open 2-1/8" 7"Markerit 13,765' 13,770' 10,024' 10,028' 10 2/19/1990 Open 3-3/8" TOF@ A'@13,607' 13,841' 13,893' 10,086' 10,129' 52 12/7/1990 Open 5" - K1 13,841' 13,893' 10,086' 10,129' 52 6/23/2008 Open 3-3/8" 13,854 CiU ;-• 13,842' 13,894' 10,086' 10,130' 52 4/21/2008 Open 3-3/8" 5/6/2017 Ref Log:LDT/CNL/BR-2/1/1990. Angle at Top Pe �� kLNro Fish-1-1/2"WRP API:50-029-22005-00-00 Rubber Element& •' 1 Broken WRPSgip Initial Completion by Doyon 15-2/8/1990 x 1"1 -2 Pieces, 1" . RWO by Doyon 16-3/30/2008 Each-5/3/2014 Set W F D/W R D-2/8/2012 GLV C/O-7/27/2013 7 Pull WRP/Fish DH-5/7/2014 TD=14,100'(MD)/TD=10,306'(ND) Convert to W I NJ-6/16/2015 PBTD=13 920'(MD)/PBTD=10,152'(TVD) Perf Add-5/25/2017 Revised By:TDF 6/20/2017 STATE OF ALASKA * AL A OIL AND GAS CONSERVATION COIISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑., Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑ Exploratory ❑ 190-002 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic Service ❑✓ 6.API Number: AK 99503 50-029-22005-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0312828 DUCK IS UNIT MPI 1-21 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Endicott Field/Endicott Oil Pool 11.Present Well Condition Summary: Total Depth measured 14,100 feet Plugs measured N/A fe D E l V E D true vertical 10,306 feet Junk measured 13,850(Fill) feet JUN 0 2 2017 Effective Depth measured 13,850 feet Packer measured 13,020&13,089 feet true vertical 10,093 feet true vertical 9,464&9,513 feet AOGCC Casing Length Size MD TVD Burst Collapse Conductor 131' 30" 131' 131' N/A N/A Surface 2,509' 13-3/8" 2,509' 2,509' 5,020psi 2,260psi Intermediate 11,260' 9-5/8" 11,260' 8,311' 6,870psi 4,760psi Intermediate 2,227' 9-5/8" 13,488' 9,808' 8,150psi 5,080psi Liner 869' 7" 14,085' 10,293' 9,690psi 7,820psi Liner 19' 5-1/2" 13,132' 9,544' 7,740psi 6,280psi Liner 903' 4-1/2" 14,035' 10,250' 8,430psi 7,500psi •, N 2 9 0.11'7 Perforation depth Measured depth See Schematic feet ��® ,;��1� .� �,,w v True Vertical depth See Schematic feet IfI Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/13Cr80/Vam Top 13,138' 9,548' 4.5"S-3 Hydroset 1,519(MD) Packers and SSSV(type,measured and true vertical depth) 7"ZXP 4.5"Al SCSSSV See Above 1,519(TVD) 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 460 300 2,454 Subsequent to operation: 0 0 429 250 2,344 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2 Exploratory Development Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ 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: 316-549 I. Authorized Name: Bo York Contact Name: Taylor Wellman` � Authorized Title: Operations Manager Contact Email: twellman@hilcorp.com Authorized Signaturee7 Data 6/1/2017 Contact Phone: 777-8449 Form 10 1'1 Rcvi' 1 201715---/7 BDMS L tsuri nal gn • • Duck Island Unit Well: END 1-21 SCHEMATIC Last Completed: 2/8/1990 Hilcori,Alaska,1.1.A; PTD: 190-002 TREE&WELLHEAD RT Elev.:55.1'/BF Elev.:16.05 Tree 4-1/16"CIW 5K i., Wellhead FMC 30° OPEN HOLE/CEMENT DETAIL d4 13-3/8" 3,729 cu/ft Permafrost in 17.5"Hole 1 9-5/8" 575 cu/ft Class'G'in a 12-1/4"Hole a 7" 331 cu/ft Class"G"in 8-1/2"Hole 13-3/8", r" CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 30" Cond actor N/A/N/A/N/A N/A Surface 131' N/A 13-3/8" Surface 68/NT80/Btrs 12.415 Surface 2,509 0.150 2 9-5/8" Intermediate 47/NT80/NSCC 8.681 Surface 11,260 0.0732 9-5/8" Intermediate 47/NT95HS/NSCC 8.681 11,260 13,488' 0.0732 7" Liner 29/SM-110/Btrs 6.184 13,216' 14,085' 0.0372 5-1/2" Liner 17/13CR-80/Vam Top 4.892 13,113' 13,132' 0.0233 4-1/2" Liner 12.6/13CR-80/NSCT 3.958 13,132' 14,035' 0.0152 3 TUBING DETAIL I 4-1/2" Tubing 12.6/13CR-80/Vam Top 3.958 Surface 13,138' 0.0152 WELL INCLINATION DETAIL 4 Max Hole Angle=56 deg. @ 9,407' I�' NOTE: JEWELRY DETAIL 1 MINIMUM ID= No Depth Item 5 3.725 @ 13,068' 1 1,519' 4-1/2"HXO SVLN,ID=3.813 6 4-1/2 XN Nipple GLM Detail-MMG w/DV and RK Latch w I 2 4,068' ST 4:Port=0,Dev.=45,ND= 3,915',3/10/2015 7 3 8,048' ST 3:Port=0,Dev.=54,TVD= 6,396',3/10/2015 4 10,762' ST 2:Port=0,Dev.=51,ND= 7,995', 4/23/2015 6 5 12,906' ST 1:Port=0,Dev.=45,TVD= 9,383',3/30/2008 9 6 12,989' 4-1/2"HES X Nipple,ID=3.813" i I I4.1. nr,. 10 7 13,020' 9-5/8"x 4-1/2"Baker S-3 Packer,ID=3.875" ''Ii'' .;.r 0 11 8 13,055' 4-1/2"HES X Nipple,ID=3.813" ,1 i ,, 12&13 9 13,086' 4-1/2"HES XN Nipple,ID=3.725" c6.,,,; °10 13,089' 9-5/8"x 7"Baker C-2 LTP,ID=6.28" t f ' f^,' 11 13,106' 9-5/8"x 7"HMC Liner Hanger,ID=6.360" ' t' 12 13,113' 7"x 5-1/2"XO,ID=4.81" 1 i 13 13,132' 5-1/2"x 4-1/2"X0,10=3.875" 0. Jti 14 13,138' 4-1/2"Muleshoe,ID 3.958"-TVD=9,548 a ';�si 15 13,216' 9-5/8"x 7"Liner Hanger I > y �' 915 PERFORATION DETAIL END Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Shot Date Current Size x, ,r r" 13,745' 13,765' 10,009' 10,024' 20 12/26/1993 Squeezed 2-1/8" K2A 13,748' 13,768' 10,013 10,024 20 5/25/2017 Future 3-3/8" 95/8 , ' '. 13,765' 13,769' 10,024' 10,028' 4 8/17/1997 Open 2-1/8" 13,765' 13,770' 10,024' 10,028' 10 2/19/1990 Open 3-3/8" F A 7"MarkerJt 13,841' 13,893' 10,086' 10,129' 52 12/7/1990 Open 5" TCF @ `,, @ 13,607' K1 13,841' 13,893' 10,086' 10,129' 52 6/23/2008 Open 3-3/8" .. 13,842' 13,894' 10,086' 10,130' 52 4/21/2008 Open 3-3/8" 13,850 CTU i. Ref Log:LDT/CNL/BR-2/1/1990. Angle at Top Perf=38 Deg @ 13,765' 5/6/2017 Fish-1-1/2"WRP ' a 0 Iri GENERAL WELL INFO Rubber Element& '. s.,1 API:50-029-22005-00-00 1 Broken WRP Slip : `m' Initial Completion by Doyon 15-2/8/1990 -2Pieces, 1xl *°"1- --' RWO by Doyon 16-3/30/2008 Each F- ', Set WFD/WRD-2/8/2012 7„ .,i. r4' GLV C/O-7/27/2013 Pull WRP/Fish DH-5/7/2014 TD=14,100'(MD)/TD=10,3061TVD) Convert to WINJ-6/16/2015 PBTD=13,920'(MD)/PBTD=10,152'(TVD) Perf Add-5/25/2017 Revised By:TDF 6/1/2017 • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 1-21 Eline 50-029-22005-00-00 190-002 2/24/17 5/27/17 Daily Operations: 5/24/2017 -Wednesday PRESSURE TEST 250/3,000 PSI. PERFORATE 13,748'-13,768' with 3-3/8" 6 SPF RAZOR DP GUNS.Tool Shorted out. 5/25/2017 -Thursday PRESSURE TEST 250/3,000 PSI. PERFORATE 13,748-113,768' with 3-3/8" 6 SPF RAZOR DP GUNS.TOOLS STUCK AFTER FIRING GUNS. PULLED OUT OF HEAD @ 3,420 LBS LINE TENSION. ALL WIRE RECOVERED. 5/26/2017- Friday No activity to report. 5/27/2017 -Saturday FISH E-LINE TOOL STRING AND PERF GUN ), PT 250/3,000 PSI. RAN LIB AND TAGGED TOP OF FISH @ 13,703' SLM AFTER TAPPING DOWN TWO TIMES, [LINE TOOL STRING FELL DOWN HOLE TO 13,873' SLM. RAN 3.6" BELL GUIDE, 2.0" SB AND PULLED FISH @ 13,873' SLM. ALL SHOTS FIRED IN PERF GUN. 5/28/2017 -Sunday No activity to report. 5/29/2017 - Monday No activity to report. 5/30/2017-Tuesday No activity to report. • • yOFTy • y* N \��,� v THE STATE Alaska Oil and Gas ir ja t, of/\ T Ac K /`J1�I1 Conservation Commission = 11L �,; 4W 333 West Seventh Avenue GOVERNOR BILL WALKER —"""'-- Anchorage, Alaska 99501-3572 (4' Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Mike Dunn Operations Manager SCANNED MAR 0 2U!74 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, DIU MPI 1-21 Permit to Drill Number: 190-002 Sundry Number: 316-549 Dear Mr. Dunn: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a7-67 Cathy P. Foerster � , Chair �� DATED this day of October, 2016. RBDMS (/� ()CI 2 8 2016 REcEivED , • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 2 4 2016 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGGC 1.Type of Request: Abandon 0 Plug Perforations❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend ❑ Perforate Q • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing ❑ Other: 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska LLC Exploratory ❑ Development 9 190-002 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service Q. 6.API Number: Anchorage Alaska 99503 50-029-22005-00-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 462 • Will planned perforations require a spacing exception? Yes ❑ No ❑, DUCK IS UNIT MPI 1-21 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0312828 • Endicott Field/Endicott Oil Pool, 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 14,100' • 10,306' . 13,800' 10,052' 13,800' 13,800' Casing Length Size MD TVD Burst Collapse Conductor 131' 30" 131' 131' WA NIA Surface 2,509' 13-3/8" 2,509' 2,509' 5,020psi 2260psi Intermediate 11,260' 9-5/8" 11,260' 8,311' 6,870psi 4,760psi Intermediate 2,227' 9-5/8" 13,488' 9,808' 8,150psi 5,080psi Liner 869' 7" 14,085' 10,293' 9,690psi 7,820psi Liner 19' 5-1/2" 13,132' 9,544' 7,740psi 6,280psi Liner 903' 4-1/2" 14,035' 10,250' 8,430psi 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6#/13Cr80/Vam Top 13,138' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 4.5"S-3 Hydroset&7"ZXP and 4.5"Al SCSSSV 13,020 MD/9,464 TVD&13,089 MD/9,513 TVD and 1,519 MD/1,519 TVD 12.Attachments: Proposal Summary-r Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory 0 Stratigraphic ❑ Development❑ Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: I I /5 f I(o OIL 0 WINJ Q • WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS 9 WAG ❑ GSTOR 0 SPLUG 9 Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Taylor Wellman Tir.4J Email twellmanahilcom.com Printed Name e` e Dunn Title Operations Manager Signature 41F /r/' / Phone 777-8382 Date 1� //6 C 6 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 9 Other: RBDMS OCT 2 8 2016 Post Initial Injection MIT Req'd? Yes 0 No 44 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: / c "' 0 SSP' °Z'iZ..Sii6 APPROVED BY Approved by: - —— COMMISSIONER THE COMMISSION Date: A 1 CFnhnr1— Form 10-403 Re ised 11/20150J3frGdfTIJaAflt.Ialidfor 12 months from the date of approval. ttachments in Duplicate Its 26 11'1 4,, , eV,r �4, • • Re/Add Perf 111 Well: DIU MDI 1-21 PTD:190-002 Hiteory Alaska,LG API:50-029-22005-00 Well Name: DIU PSI 1-21 API Number: 50-029-22005-00 Current Status: On Injection Field: Endicott Estimated Start Date: Nov 5, 2016 Rig: E-Line Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 202-238 First Call Engineer: Taylor Wellman (907)777-8449 (0) (907)947-9533 (M) Second Call Engineer: Wyatt Rivard (907)777-8547 (0) (509) 670-8001 (M) AFE Number: WeIIEZ Input Required? Yes Current BHP (LSZ K1): 3,947 psi @ 10,000' TVD (Based on BHP taken on 05/01/14) MPSP: 2,200 psi SI pressure on 12/22/15 Reference Log: SLB Jewelry Log GR/CCL dated 18-April-2008 Brief Well Summary: The DIU Endicott 1-21 well was originally drilled as a production well in the K1 in Febuary of 1990. Perforations were added in the K2A in December of 1993. converted to gas cap water injection in July 2015. A gas shut off (GSO)was completed in 1997.The well was shut in in September 1999 due to TxIA communication until a RWO returned the well to production in 2008.The well was shut in in 2013 due to high GOR.The well was converted as a gas cap WINJ well in July 2015.The main target for this injection was the lower K2A. In December 2015, slickline drifted the well due to lack of injection. Schmoo/fill was encountered at 13,800'MD, indicating the K1 was unlikely taking any injection and only the 5ft remaining perfs in the K2A were able to be injected into at "460bwpd. Objective: Perforate the following intervals enclosed in the table below. Gun Run# Perf Top Perf Bottom Perf Length Formation 1 ±13,748' • ±13,768' 20' K2A Total 20' Table 1: END 1-21 Proposed Perf Gun Runs Note: Final depths to be confirmed in "Final Approved Perf Sheet" Non sundried operations Slickline 1. RU SL unit and pressure test to 250psi low/3,000psi. 2. RIH and pull the 4-1/2" Al Injection SSSV from 1,519' md. 3. Drift and tag w/3-3/8" dummy gun. a. Target depth is 13,790' md. 4. RD SL unit. Sundried Operations(Approved Sundry required prior to proceeding) E-Line 5. RU EL unit and pressure test to 250psi low 3,000psi high. 6. MU perforating tool string with 10'of 2-7/8" -3-3/8"guns. . 7. RIH and correlate 1st gun run to Tie-In Log. Contact OE Taylor Wellman or OE Wyatt Rivard (contact info above) prior to perforating for final approval of tie in. 8. Perforate as per Table 1: END 1-21 Proposed Perf Gun Runs. POOH. • Re/Add Pelf Well: DIU MDI 1-21 PTD: 190-002 Hilcora Alaska,LU API:50-029-22005-00 a. Note any tubing pressure change in WSR. 9. RD Eline. Slickline 10. RU SL unit and pressure test to 250psi low/3,000psi. 11. RIH and set 4-1/2" Al Injection SSSV at 1519' md. a. Description of last SSSV set on 12/22/15: 4.5—X-LOCK, CARRIER, Al INJ VALVE (SER#HAS-297) 1.5""ORIFICE. See WSR for full details. 12. RD SL unit. • H H . • Duck Island Unit Well: END 1-21 SCHEMATIC Last Completed: 2/8/1990 I10oorp Alaska.11.1.C. PTD: 190-002 RTElev.:55.1'/BFElev.:16.05 TREE&WELLHEAD Tree 4-1/16"CIW 5K i Wellhead FMC OPEN HOLE/CEMENT DETAIL V la 1 13-3/8" 3,729 cu/ft Permafrost in 17.5"Hole 14 ' 9-5/8" 575 cu/ft Class'G'in a 12-1/4"Hole 3/g' 7" 331 cu/ft Class"G"in 8-1/2"Hole ill 1 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 30" Conductor N/A/N/A/N/A N/A Surface 131' N/A 2 13-3/8" Surface 68/NT80/Btrs 12.415 Surface 2,509 0.150 9-5/8" Intermediate 47/NT80/NSCC 8.681 Surface 11,260 0.0732 9-5/8" Intermediate 47/NT95HS/NSCC 8.681 11,260 13,488' 0.0732 7" Liner 29/SM-110/Btrs 6.184 13,216' 14,085' 0.0372 5-1/2" Liner 17/13CR-80/Vam Top 4.892 13,113' 13,132' 0.0233 3 4-1/2" Liner 12.6/13CR-80/NSCT 3.958 13,132' 14,035' 0.0152 I TUBING DETAIL 4-1/2" Tubing 12.6/13CR-80/Vam Top 3.958 Surface 13,138' I 0.0152 4 WELL INCLINATION DETAIL Max Hole Angle=56 deg. @ 9,407' NOTE: MINIMUM ID= JEWELRY DETAIL 5 � I6 3.725 @ 13,068' No Depth Item " $ 4-1/2 XN Ni le PP 1 1,519' 4-1/2"HXO SVLN,ID=3.813 I `! GLM Detail-MMG w/DV and RK Latch ...7.. ^" 7 2 4,068' ST 4:Port=0,Dev.=45,TVD= 3,915',3/10/2015OP 3 8,048' ST 3:Port=0,Dev.=54,TVD= 6,396',3/10/2015 6 1, 8 ;# 4 10,762' ST 2:Port=0,Dev.=51,TVD= 7,995', 4/23/2015 9 5 12,906' ST 1:Port=0,Dev.=45,TVD= 9,383',3/30/2008 a -4 .4 10 6 12,989' 4-1/2"HES X Nipple,ID=3.813" "1'4. 11 7 13,020' 9-5/8"x 4-1/2"Baker S-3 Packer,ID=3.875" +' 12&13 8 13,055' 4-1/2"HES X Nipple,ID=3.813" 9 13,086' 4-1/2"HES XN Nipple,ID=3.725" 10 13,089' 9-5/8"x 7"Baker C-2 LTP,ID=6.28" 11 13,106' 9-5/8"x 7"HMC Liner Hanger,ID=6.360" 12 13,113' 7"x 5-1/2"X0,ID=4.81" 13 13,132' 5-1/2"x 4-1/2"X0,ID=3.875" 14 13,138' 4-1/2"Muleshoe,ID=3.958"-TVD=9,548 15 13,216' 9-5/8"x 7"Liner Hanger i* - 15 PERFORATION DETAIL END Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Shot Date Current Size N/A 13,745' 13,765' 10,009' 10,024' 20 12/26/1993 Squeezed 2-1/8" 9-5/8" a 1. K2A 13,765' 13,769' 10,024' 10,028' 4 8/17/1997 Open 2-1/8" • 13,765' 13,770' 10,024' 10,028' 10 2/19/1990 Open 3-3/8" 7'Marker Jt 13,841' 13,893' 10,086' 10,129' 52 12/7/1990 Open 5" Fish-1-1/2"WRP ".@i3, K1 13,841' 13,893' 10,086' 10,129' 52 6/23/2008 Open 3-3/8" Rubber Element& 13,842' 13,894' 10,086' 10,130' 52 4/21/2008 Open 3-3/8" 1 Broken WRP Slip Ref Log:LDT/CNL/BR-2/1/1990. Angle at Top Perf=38 Deg @ 13,765' -2 Pieces, 1"x1" TOF@ Each-5/3/2014 13,800'SLM GENERAL WELL INFO 12/22/2015 API:50-029-22005-00-00 Initial Completion by Doyon 15-2/8/1990 RWO by Doyon 16-3/30/2008 Set WED/WRD-2/8/2012 7"y 1 GLV C/O-7/27/2013 Pull WRP/Fish DH-5/7/2014 TD=14,100'(MD)/TD=10,306'(ND) Convert to WI NJ-6/16/2015 PBTD=13,920'(MD)/PBTD=10,152'(TVD) Revised By:TDF 11/17/2015 40 Duckll:IslandEND Unit1-21 We r PROPOSED Last Completed: 2/8/1990 Hamra Alaska.tax: PTD: 190-002 TREE&WELLHEAD RT Elev.:55.1'/BF Elev.:16.05 Tree 4-1/16"CIW 5K Wellhead FMC 30 I 1 1 1.,LOPEN HOLE/CEMENT DETAIL 13-3/8" 3,729 cu/ft Permafrost in 17.5"Hole IAAl 1 9-5/8" 575 cu/ft Class'G'in a 12-1/4"Hole 7" 331 cu/ft Class"G"in 8-1/2"Hole 13-3/8" CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 30" Conductor N/A/N/A/N/A N/A Surface 131' N/A I; 13-3/8" Surface 68/NT80/Btrs 12.415 Surface 2,509 0.150 2 9-5/8" Intermediate 47/NT80/NSCC 8.681 Surface 11,260 0.0732 9-5/8" Intermediate 47/NT95HS/NSCC 8.681 11,260 13,488' 0.0732 7" Liner 29/SM-110/Btrs 6.184 13,216' 14,085' 0.0372 5-1/2" Liner 17/13CR-80/Vam Top 4.892 13,113' 13,132' 0.0233 } 4-1/2" Liner 12.6/13CR-80/NSCT 3.958 13,132' 14,035' 0.0152 3-'if3 TUBING DETAIL 4-1/2" 1 Tubing 12.6/13CR-80/Vam Top 3.958 Surface 13,138' 0.0152 I WELL INCLINATION DETAIL ) 1 4 Max Hole Angle=56 deg. @ 9,407' NOTE: JEWELRY DETAIL MINIMUM ID= No Depth Item 5 3.725 @ 13,068' 1 1,519' 4-1/2"HXO SVLN,ID=3.813 -6 4-1/2 XN Nipple GLM Detail-MMG w/DV and RK Latch 2 4,068' ST 4:Port=0,Dev.=45,ND= 3,915',3/10/2015 i►� �P 7 3 8,048' ST 3:Port=0,Dev.=54,TVD= 6,396',3/10/2015 I 4 10,762' ST 2:Port=0,Dev.=51,TVD= 7,995', 4/23/2015 E=- 8 i 5 12,906' ST 1:Port=0,Dev.=45,TVD= 9,383',3/30/2008 L9 6 12,989' 4-1/2"HES X Nipple,ID=3.813" iler. 10 7 13,020' 9-5/8"x 4-1/2"Baker S-3 Packer,ID=3.875" 11 8 13,055' 4-1/r HES X Nipple,ID=3.813" 12&13 9 13,086' 4-1/2"HES XN Nipple,ID=3.725" G 14 10 13,089' 9-5/8"x 7"Baker C-2 LIP,ID=6.28" 11 13,106' 9-5/8"x 7"HMC Liner Hanger,ID=6.360" 12 13,113' 7"x 5-1/2"XO,ID=4.81" 13 13,132' 5-1/2"x 4-1/2"XO,ID=3.875" 14 13,138' 4-1/2"Muleshoe,ID=3.958"-TVD=9,548 15 13,216' 9-5/8"x 7"Liner Hanger PERFORATION DETAIL `: 15 END Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Shot Date Current Size 13,745' 13,765' 10,009' 10,024' 20 12/26/1993 Squeezed 2-1/8" ±13,748' ±13,768' ±10,013 ±10,024 ±20 Future Future 3-1/8" K2A 13,765' 13,769' 10,024' 10,028' 4 8/17/1997 Open 2-1/8" 9-5/8't II 13,765' 13,770' 10,024' 10,028' 10 2/19/1990 Open 3-3/8" 7"Marker it 13,841' 13,893' 10,086' 10,129' 52 12/7/1990 Open 5" A--@13,607' K1 13,841' 13,893' 10,086' 10,129' 52 6/23/2008 Open 3-3/8" Fish 1-1/2 WRP 13,842' 13,894' 10,086' 10,130' 52 4/21/2008 Open 3-3/8" Rubber Element& Ref Log:LDT/CNL/BR-2/1/1990. Angle at Top Perf=38 Deg @ 13,765' 1Broken WRP Slip 4 TOF@ GENERAL WELL INFO -2 Pieces, 1"x 1" 13,800 SLM 12/22/2015 API:50-029-22005-00-00 Each 5/3/2014 Initial Completion by Doyon 15-2/8/1990 RWO by Doyon 16-3/30/2008 Set WFD/WRD-2/8/2012 . GLV C/O-7/27/2013 7' Pull WRP/Fish DH-5/7/2014 TD=14,100'(MD)/TD=10,306'(TVD) Convert to WINJ-6/16/2015 PBTD=13,920'(MD)/PBTD=10,152'(TVD) Revised By:TDF 10/18/2016 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMIPSION SEP 2 3 2015 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon LI Perforations Li Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Remove and Replace TreeE 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development❑., Exploratory ❑ 190-002 3.Address: Stratigraphic El Service ❑ 6.API Number: • 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22005-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0312828 ' DUCK IS UNIT MPI 1-21/K25 ' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Endicott Field/Endicott Oil Pool • 11.Present Well Condition Summary: Total Depth measured 14,100 feet Plugs measured 13,920 feet true vertical 10,306 • feet Junk measured ±13,900 feet Effective Depth measured 13,920 feet Packer measured 13,020/13,089 feet true vertical 10,152 feet true vertical 9,464'/9,513 feet Casing Length Size MD ND Burst Collapse Conductor 131' 30 131' 131' N/A N/A Surface 2,509' 13-3/8" 2,509' 2,509' 5,020psi 2,260psi Intermediate 11,260' 9-5/8" 11,260' 8,311' 6,870psi 4,760psi Intermediate 2,227' 9-5/8" 13,487' 9,808' 8,150psi 5,080psi Liner 869' 7 14,085' 10,293' 9,690psi 7,820psi Liner 19' 5-1/2" 13,132' 9,544' 7,740psi 6,280psi Liner 903' 4-1/2" 14,035' 10,250' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic feet CONED True Vertical depth See Attached Schematic feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/13Cr80/Vam Top 13,138' 9,548' 4.5"S-3 Hydroset 13,020'/9,464' Packers and SSSV(type,measured and true vertical depth) 7"ZXP 4.5"BBE SCSSSV 13,089'/9,513' 1,532'/1,532' 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 1,134 450 2,317 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory❑ Development❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas LI WDSPL U Printed and Electronic Fracture Stimulation Data ❑ 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: 315-082 /3i�r- , Contact Taylor Wellman Email twellmanhilcorp.com Printed Name Taylor Wellman Title Operations Engineer Signature Ay,,-Cr`rid: Phone 777-8449 Date 9/23/2015 Form 10-404 Revised 5/2015 ii(Sto--- `0,,,r S. -1--- Submit Original Only /0 RBDMS SPP 2 5 2015 READINGS _ . � SitT31D= , END 1 -21 N&G *EL U, ' ACTUATOR= AXELS0 A SSSV"""CHROMETBG&LMR'" RT B_EV= 55.1' BF ELEV= 16.05' ,----'-P KOP= 1619' —14-1/2' LN,D=3.813" I Max Angle 56"r.9407' 20"CONDUCTOR. 110' r L , J . Datum MD= 13804' D=? `i Datum TVD= 10000'SS 13-3/8'CSG,68#,NT-80 CYI-E H 2509' 0 BUTT,D=12.415" / GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT_ 4 4068 3915 45 MMG i/,A, RK 16 0727/13'1 3 8048 6396 54 kW /• RK 16 07/27/13 9-5/8"CSG,47#,11T805 XO —{ 11260' fX X 2 10762 7995 51 IVM3 1 FE 20 07/27/13 TO NT95t S SCC 1 12906 9385 45 P. /7 RK 0 03/30/08) Minimum ID =3.725"@ 13086' 1 12989' —14-112"HES X NP,D=3.813' 4-112" HES XN NIPPLE X ,_ 13020' H9-5/8"X 4-1/2'BKR S-3 P1CR,13=3.875" 1 13055' —4-12"HES XNP,D=3.813' I 13086' --{4-1/2"HES XN NP,ID=3.725" 5-1/2"LMR,17#,13CR 80 VAM TOP, — 13132' 13089' —9-5/8"X 7'BKRC-2 LTP,D=6.28" .0232 bpf,D=4.892' Ail 4-1/2"TBG,12.6#,13CR 80 VAM TOP, —{ 13138' G � 13106' _95/8"X 7"HMC LNR HGR,ID=6.360" i ^ .0152 bpf,D=3.958" ; ... 13113' —{7'X 5-1/2"XO,D=4.81- 4 TOP OF 7'LNR 13216' �� ►4, 13132' H5-1/2"X4-1/2'XO,13=3.875'44 _ 9-5/8'CSG,47#,NT951-S NSCC, 13= 8.681" — 13488' 7.• ►•• 13138' H MULESHOE,112"MULHOE D=3.958' 4�. 1.. 1.1 ORATION SUMMARY 4.iii REF LOG: LDT/CNJBR ON 02/01/90 4, ANGLE AT TOP PERF: 38'Q 13765' �. �4� , Note:Refer to Production DB for historical pert data �. �� SIZE SPF INTERVAL OpnlSgz SHOT SQZ I4� �4�t 1360T Hr.MARKB2 JOM INTERVAL 2-1/8" 4 13745 13765 S 12/26/9312/04/96 44 ,• 4' 2-1/8' 6 13765-13769 0 08/17/97 41 �4,, 3-3/8' 6 13765-13770 0 02/19/12 4j 5" 4 13841-13893 C 12/07/90 1'4 4'� 3-3/8' 6 13841-13893 C 06/23/08 1. 3-3/7 6 13842-13894 C 04/21/08 444, 4 ),1 116 I ? FSH-1-1/2'WRP RUBBER ELBMONT 81 BROKEN 4-1/7 UR 12.6#,L-80 BT, H 14035' 4 - - 1 WRPSLP-2 FECES,1"X V EA(5/3/14) .0152 bpf,D=3.958' .. i •'•-*"•-� i -920'CTM H TOP OF CEMENT(04/12/97) PBTD — 1396T 1.••••••4 7"LN2,29#,NT95HS BUTT, I-114085' • ►�•�•�•�•�•�•�, .0371 bpf,D=6.184" DATE REV BY COMMENTS DATE FEV BY COMMENTS B'DICOTT UNIT 02/08/90 D15 COMPLETION WELL: 1-21/K-25 03/30108 D16 MO PB AF No: 1900020 02/15/12 SRD/JMD SET WFD 1M D(02108/12) API No: 50-029-22005-00 02/20/12 JTC/JMD ADPBiF(02/19/12) SEC 36,T12N,R16E,2011'AL&2082'FEL 08/13/13 JMIWJND GLV ClO(0727/13) Hilcorp Alaska LLC 05/07/14 DM PJC ALL WRP/ASH DH(5/3-5!44/14) • • Hilcorp Alaska, LLC I liletupAlat..kat. Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date END 1-21 50-029-22005-00-00 190-002 3/8/2015 5/9/2015 Daily Operations: 3/4/15-Wednesday No operations to report. 3/5/15-Thursday No operations to report. 3/6/15-Friday No operations to report. 3/7/15-Saturday No operations to report. 3/8/15-Sunday MIRU Slickline unit. Pressure test lubricator to 300psi low/2,500psi high. RIH w/3.60" bell guide and 2-1/2"JDC. Latch and pull PX prong from 13,056'slm. Run and set prong at 13,056'slm.Secure well. Bleed down tubing to 1,900psi. Lay down for night. Ongoing. 3/9/15-Monday RU and pressure test lubricator to 300psi low/2,500psi high.Set catcher at 13,050'slm. Pull RK-OLGV from Station#2 (1,0762' md). Pull RK-OLGV from Station#3 (8,048' md). Pull RK-OLGV from Station#4(4,068' md).Secure well and lay down for night. Ongoing. 3/10/15-Tuesday RU slickline unit. Pressure test lubricator to 300psi low/2,500psi high.Set RK-DLGV in Station#4(4,068' md). Set RK- DLGV in Station#3 (8,048' md). Pull catcher sub.Secure well and rig down. • S Hilcorp Alaska, LLC Ilikor, Akv.ka, LL( Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date END 1-21 50-029-22005-00-00 190-002 3/8/2015 5/9/2015 Daily Operations: 4/1/15-Wednesday No operations to report. 4/2/15-Thursday No operations to report. 4/3/15-Friday No operations to report. 4/4/15-Saturday No operations to report. 4/5/15-Sunday No operations to report. 4/6/15-Monday No operations to report. 4/7/15-Tuesday PRESSURE TEST LINES TO 300PSI LOW/2,000PSI HIGH. PUMP DOWN IA WHILE TAKING RETURNS UP TUBING AND DOWN FLOWLINE. PUMP 867BBLS OF SEAWATER FOLLOWED BY 7OBBLS OF DIESEL.ALLOW TO U-TUBE. RIG DOWN. - • • Hilcorp Alaska, LLC ilikorp.112u,kat.IAA. Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date END 1-21 50-029-22005-00-00 190-002 3/8/2015 5/9/2015 Daily Operations: 4/29/15-Wednesday No operations to report. 4/30/15-Thursday No operations to report. 5/1/15-Friday No operations to report. 5/2/15-Saturday No operations to report. 5/3/15-Sunday No operations to report. 5/4/15-Monday No operations to report. 5/5/15-Tuesday Set BPV. ND tree. Inspect and replace ring groove. Install ciw 4-1/16"5,000lb tree from well 1-09. • • Hilcorp Alaska, LLC !Meng,Alaska. LL( Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date END 1-09A 50-029-21743-01-00 197-029 3/10/2015 5/9/2015 Daily Operations: 5/6/15-Wednesday Pressure test tree against TWC to 6,300psi for 30 min-passed. Bleed pressure to 0 psi.Test tubing hanger,test void to 6,000psi-passed. Bleed pressure from void. pull TWC and RD from well. 5/7/15-Thursday No operations to report. 5/8/15-Friday Pressure test lubricator to 2,100psi. Run#1-ran a 3.6 bell guide,2.5 RS. Pulled prong at 11,493md (14,436's/1) Run#2-ran a 4.5gs, pulled plug body at 11,493md (14,442s/1). Secure well. Plug missing 5 pieces of packing, one nubbing missing as well. 5/9/15-Saturday No operations to report. 5/10/15-Sunday No operations to report. 5/11/15-Monday No operations to report. 5/12/15-Tuesday No operations to report. RECEIVED STATE OF ALASKA A KA OIL AND GAS CONSERVATION COM SION SEP 2 3 2015 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Plug Perforations U Fracture Stimulate ❑ Pull TubingU ❑ Operations shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool El Repair Well ❑ Re-enter Susp Well❑ Convert to WINJ❑✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development.1 , Exploratory ❑ 190-002 . 3.Address: Stratigraphic Service 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22005-00-00. 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0312828 • DUCK IS UNIT MPI 1-21/K25 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Endicott Field/Endicott Oil Pool • 11.Present Well Condition Summary: Total Depth measured 14,100 feet Plugs measured 13,920 feet true vertical 10,306 feet Junk measured ±13,900 feet Effective Depth measured 13,920 feet Packer measured 13,020/13,089 feet true vertical 10,152 feet true vertical 9,464'/9,513 feet Casing Length Size MD ND Burst Collapse Conductor 131' 30 131' 131' N/A N/A Surface 2,509' 13-3/8" 2,509' 2,509' 5,020psi 2,260psi Intermediate 11,260' 9-5/8" 11,260' 8,311' 6,870psi 4,760psi Intermediate 2,227' 9-5/8" 13,487' 9,808' 8,150psi 5,080psi Liner 869' 7 14,085' 10,293' 9,690psi 7,820psi Liner 19' 5-1/2" 13,132' 9,544' 7,740psi 6,280psi Liner 903' 4-1/2" 14,035' 10,250' �1 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic feet �.A$PEL True Vertical depth See Attached Schematic feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/13Cr80/Vam Top 13,138' 9,548' 4.5"S-3 Hydroset 13,020'/9,464' Packers and SSSV(type,measured and true vertical depth) 7"ZXP 4.5"BBE SCSSSV 13,089'/9,513' 1,532'/1,532' 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 1,134 450 2,317 ' 14.Attachments(required per 20 AAC 25.070.,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development Service ❑✓ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Li Gas ❑ WDSPL U Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ SUSP 0 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: 314-550 Contact Taylor Wellman Email twellmanCchilcorp.com Printed Name / Taylor Wellman Title Operations Engineer Signature ' ,t, for te, Phone 777-8449 Date 9/23/2015 Form 10-404 Revised 5/2015 411/0/A•- „%_,v, /c-/J'-1 RBDM� \ FP 2 5J 205 Submit Original Only • Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date END 1-21 50-029-22005-00-00 190-002 6/16/2015 6/16/2015 Daily Operations: 6/10/15-Wednesday No operations to report. 6/11/15-Thursday No operations to report. 6/12/15-Friday No operations to report. 6/13/15-Saturday No operations to report. 6/14/15-Sunday No operations to report. 6/15/15-Monday No operations to report. 6/16/15-Tuesday "DRIFTED AND BRUSHED TO HXO NIP @ 1,495'SLM 1,519' MD. PURGED CONTROL AND BALANCE LINES W/HYDRAULIC FLUIDSET X-LOCK,CARRIER,A-1 VALVE (ser#HABS-0468) 1.50" bean 3 sets std pkg(OAL=61") @ 1,494'CLOSURE TEST 2,850 TO 2,500 PASSED. RDMO E 230-260 W � ELLHD FMCJ AEND 1 _2 1 AIL&GAS INTREE= CNV JECTORS WELL REQUIRES ACTUATOR= AXELSO_ I A SSSV`**CHROME TBG&LNR*"* RT.ELEV= 55.1' BF.REV= 16.05' KOP= 1519' —4-1/2'H39_SV ,115---3.813" Max Angle= 56°@ 940T 20"CONDUCTOR, — 110' O11 Datum MD= 13804' D=? A- I Datum TVD= 10000'SS 13-3/8"CSG,68#,NT-80 CYHE H 2509' GAS LIFT MANDRELS BUTT,D=12.415" ST Mt) TVD DEV TYPE VLV LATCH PORT DATE 4 4068 3915 45 MG DO RK 16 07/27/13 3 8048 6396 54 MMG RK 16 07/27/13 9-5/8"CSG,47#,NTT30S XO —{ 11260' X X 2 10762 7995 51 MAG RK 20 07/27/13 TO NT95HS NSCC 1 12906 9385 45 MMG DMY RK 0 03/30/08 pi's Minimum ID = 3.725" @ 13086' 1 1 - 12989' —14-1/2"HES XNIP,D=3.813" 4-1/2" HES XN NIPPLE X X 13020' —9-5/8"X 4-1/2"BKR 5-3 A<R,D=3.875" 1 1 13055' —14-1/2"HES X NP,D=3.813" 1 1 - 13086' H4-1/7 HES XN NP,ID=3.725" 5-1/2"LNR,17#,13CR-80 VAM TOP, H 13132' 13089' —{3-5/8"X 7"BKR G2 LIP,ID=6.28" .0232 bpf,D=4.892" , V 2 A 13106' H9-5/8"X 7"HNC LNR HGR,D=6.360' 4-1/2"TBG, 12.6#,13CR-80 VAM TOP, — 13138' �4 All .0152 bpf,D=3.958" / 9 13113' —i 7"X 5-1/2"X0,113=4.81" TOP OF7"LNR -I 13216' �� 1' 13132' H5-1/TX4-1/2"XO,13=3.875" 19-5/8"CSG,47#,NT95HS NSCC, D= 8.681" — 13488' N 111 — �� 11 13138' H4-1/2"MULESHOE,D=3.958" i+1 41 PERFORATION SUMMARY 41 11 REF LOG: LDT/CNJBR ON 02/01/90 i1 111 ANGLE AT TOP FERF: 38°@ 13765' 41 11 , Note:Refer to Production DB for historical perf data X11 1 111 1 SIZE SPF INTERVAL Opn/Sqz SHOT SOZ 111 11 13607' 7"MARKER JOINT 2-1/8" 4 13745-13765 S 12/26/93 12/04/96 i.1. 14 2-1/8" 6 13765- 13769 0 08/17/97 ,.11 14 3-3/8" 6 13765-13770 0 02/19/12 t11 5" 4 13841-13893 C 12/07/90 41 3-3/8" 6 13841- 13893 C 06/23/08 4. Sli 41 11., 3-3/8" 6 13842-13894 C 04/21/08 4. 11 ? FISH- 1-1/2"WRP RUBBER ELENBIT&1 BROKEN 4-1/2"LNR,12.6#,L-80 BT, —{ 14035' X11 WRP SLP-2 PECES,1"X 1"EA(5/3/14) .0152 bpf,D=3.958" 4�1 e VI• 11'11W1 13920'CTM H TOP OF CEMENT(04/12197) , PBTD H 13957' &•• AIM 7"LNR 29#,NT95HS BUTT, — 14085' .0371 bpf,D=6.184" DATE REV BY COMMENTS ATE REV BY COMMENTS E DICOTT UNIT 02/08/90 015 COMPLETION WELL: 1-21/K-25 03/30/08 016 RWO PERMT No: '1900020 02/15/12 SRD/JM) SET WFD WRD(02/08/12) API No: 50-029-22005-00 02/20/12 JTC1JIMD ADPERF(02/19/12) SEC 36,T12N,R16E,2011'FN-&2082'FEL 08/13/13 JMwJM) GLV GO(07/27/13) Hilcorp Alaska LLC 05/07/14 DLI-11 PJC FULL WRP/FISH DH(5/3-5/44/14) ' • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,August 13,2015 TO: Jim Reggali� P.I.Supervisor I\eF� SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 1-21/K25 FROM: Jeff Jones DUCK IS UNIT MPI 1-21/K25 Petroleum Inspector maE I1 /,,',1i--„ Src: Inspector Reviewed By: P.I.Supry Trp p NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 1-21/K25 API Well Number 50-029-22005-00-00 Inspector Name: Jeff Jones Permit Number: 190-002-0 Inspection Date: 7/4/2015 Insp Num: mitJJ150813090320 Rel lnsp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1-21/K25 - Type Inj W" TVD 9464 Tubing 2380 -- 2400 2420 - 2410 - PTD 1900020 ' Type Test SPT Test psi 2366 rt IA 2032 2600 2598 2597 Interval INITAL P/F P I OA 250 - 250 250 250 - 1 L Notes: Initial MIT post producer to injector conversion. , ) r 5,e ci 44 t eJ ' tc-,,c C l 1311.1 re-,aa. Thursday,August 13,2015 Page 1 of 1 r • PrN iqOL Regg, James B (DOA) c-x. .4.0 J splapt *L Mk IF I50I309032. From: Wyatt Rivard <wrivard@hilcorp.com> 1` �/ /. Sent: Thursday, August 13, 2015 4:40 PM To: Regg, James B (DOA) Subject: RE: Endicott 1-21 (PTD 1900020) Attachments: END1-21 TIO 8-13-15.xlsx Jim, As of this morning, the T/I/0 pressures for END1-21 were 1880/650/100 (TIO plot attached). Prior to the AOGCC witnessed MIT-IA on 7/4/15 there was roughly 2000 psi left on the inner annulus from fluid packing ,v and a passing pre-MIT conducted on 7/2/15. Following the AOGCC witnessed test on 7-4-15,the pressure was bled back to roughly 700 psi where it has remained since, +/- 100 psi. Thank You, Wyatt Rivard { 'Well Integrity Engineer 0: (907) 777-8547 I C. ( 08)670 43001 I wrivardithilcorp.com 3000 Cent erpoint.Drive,Suite 1400 I Anchorage,AK 99350:3 II frit ' liter, t.LCa From: Regg, James B (DOA) [mailto:jim.reqg@alaska.gov] Sent: Thursday, August 13, 2015 2:45 PM To: Wyatt Rivard Subject: Endicott 1-21 (PTD 1900020) Reason for high IA pressure (pre-initial MIT)? What are current pressures (TIO plot)? Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. 1 S 14 RECEIVE' `' Post Office Box 244027 Anchorage,AK 99524-4027 JUL 41 n Hilcorp Alaska,LLC 201rJ G013800 Centerpoint Drive Suite 100 AOACC Anchorage,AK 99503 Phone: 907/777-8300 July 29, 2015 Fax: 907/777.-8301 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 + go - o o Anchorage, AK 99501 J..1 Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "I" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD # 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/134" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp 1----• Orig New API_Wel1No PermitNumber WellName WellNumber WellNumber 50029218010000 1880370 DUCK IS UNIT MPI 1-01/J19 1-01 50029226010000 1951500 DUCK IS UNIT MPI 1-03/P16 1-03 50029216050000 1861060 DUCK IS UNIT MPI 1-05/020 1-05 50029217430000 1870810 DUCK IS UNIT MPI 1-09/J18 1-09 50029217430100 1970290 DUCK IS UNIT MPI 1-09A/L21 1-09A 50029221070000 1901570 DUCK IS UNIT MPI 1-11/SN4 1-11 50029223610000 1930560 DUCK IS UNIT MPI 1-15/P25 1-15 50029221000000 1901500 DUCK IS UNIT MPI 1-17/SN2 1-17 50029221000100 1961990 DUCK IS UNIT MPI 1-17A/117 1-17A 50029225690000 1950930 DUCK IS UNIT MPI 1-19/118 1-19 •50029220050000 1900020 DUCK IS UNIT MPI 1-21/K25 1-21 50029225100000 1941280 DUCK IS UNIT MPI 1-23/015 1-23 50029217220000 1870420 DUCK IS UNIT MPI 1-25/N22 1-25 50029217220100 1970750 DUCK IS UNIT MPI 1-25A/K22 1-25A 50029216930000 1870090 DUCK IS UNIT MPI 1-27/P20 1-27 50029216690000 1861810 DUCK IS UNIT MPI 1-29/M25 1-29 50029225620000 1950720 DUCK IS UNIT MPI 1-31/M21 1-31 50029225770000 1951070 DUCK IS UNIT MPI 1-33/M23 1-33 50029225770100 1980870 DUCK IS UNIT MPI 1-33A/L24 1-33A 50029225770200 1982550 DUCK IS UNIT MPI 1-33B/L24 1-33B 50029225770300 2050040 DUCK IS UNIT MPI 1-33C/M24XX 1-33CXX 50029216720000 1861840 DUCK IS UNIT MPI 1-35/025 1-35 50029217480000 1870900 DUCK IS UNIT MPI 1-37/P24 1-37 50029218270000 1880630 DUCK IS UNIT MPI 1-39/P17 1-39 50029218270100 2061870 DUCK IS UNIT MPI 1-39A/N-16 1-39A 50029217130000 1870320 DUCK IS UNIT MPI 1-41/023 1-41 50029218640000 1881050 DUCK IS UNIT MPI 1-43/P26 1-43 50029219910000 1891240 DUCK IS UNIT MPI 1-45/026 1-45 50029216250000 1861310 DUCK IS UNIT MPI 1-47/021 1-47 50029216250100 1972030 DUCK IS UNIT MPI 1-47A/M20 1-47A 50029218410000 1880780 DUCK IS UNIT MPI 1-49/P21 1-49 50029223040000 1921190 DUCK IS UNIT MPI 1-51/V20 1-51 50029225010000 1941120 DUCK IS UNIT MPI 1-53/Q20 1-53 50029217880000 1880210 DUCK IS UNIT MPI 1-55/R25 1-55 50029218730000 1881140 DUCK IS UNIT MPI 1-57/R23 1-57 50029226440000 1960220 DUCK IS UNIT MPI 1-59/024 1-59 50029225200000 1941420 DUCK IS UNIT MPI 1-61/Q20 1-61 50029219050000 1890060 DUCK IS UNIT MPI 1-63/T22 1-63 50029226270000 1951880 DUCK IS UNIT MPI 1-65/N25 1-65 50029226270100 2032120 DUCK IS UNIT MPI 1-65A/N27 1-65A 50029219850000 1891140 DUCK IS UNIT MPI 1-67/T20 1-67 50029220200000 1900290 DUCK IS UNIT MPI 1-69/V19 1-69 50029215680000 1860630 DUCK IS UNIT MPI 2-02/P18 2-02 50029215850000 1860820 DUCK IS UNIT MPI 2-04/M19 2-04 50029216990000 1870180 DUCK IS UNIT MPI 2-06/J22 2-06 50029217710000 1880040 DUCK IS UNIT MPI 2-08/K16 2-08 50029223020000 1921170 DUCK IS UNIT MPI 2-12/016 2-12 50029216390000 1861490 DUCK IS UNIT MPI 2-14/016 2-14 50029218850000 1881340 DUCK IS UNIT MPI 2-16/M16 2-16 50029220320000 1900430 DUCK IS UNIT MPI 2-18/L16 2-18 50029220480000 1900600 DUCK IS UNIT MPI 2-20/L15 2-20 50029219310000 11890340 DUCK IS UNIT MPI 2-22/L14 2-22 Brooks, Phoebe L (DOA) pro-. L9oaw2,p From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Monday, July 06, 2015 12:19 PM To: Brooks, Phoebe L (DOA) Subject: RE: MITs END1-09A (PTD# 1970290) and END1-21 (PTD# 1900020) Attachments: image001jpg; END 1-09A PROPOSED 4-28-2015.doc; 1-21.pdf Phoebe, Here are schematics for these two recent injector conversions showing packer MD depths. Thank You, Wyatt Rivard JUL 1 0 2015 From: Wyatt Rivard Sent: Monday, July 06, 2015 12:13 PM To: 'chris.wallace@alaska.gov'; 'phoebe.brooks@alaska.gov'; 'jim.regg@alaska.gov'; 'doa.aogcc.prudhoe.bay@alaska.gov' Cc: Alaska NS - Endicott - Field Foreman; Taylor Wellman; Alaska NS - Endicott - Operations Leads Subject: MITs END1-09A (PTD # 1970290) and END1-21 (PTD# 1900020) All, Gas Injector END1-09A (PTD# 1970290) and water injector END1-21 (PTD# 1900020) had passing AOGCC witnessed MIT- lAs on 7/4/15. END1-09A was shut-in after a failing injection valve test just prior to the MIT-IA.Two attempts were required before stabilization was observed by operations and AOGCC inspector.The MIT forms are attached for reference. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@ hilcorp.com 3800 Centerpoint Drive, Suite 1400 ( Anchorage,AK 99503 Hileorp %bs*ka.EEC 1 TREE= aw _ VVELLFEAD= FtvE1 E N D I -21 ., NOTES:ICS READINGS AVERAGE 230-260 PPM ON A/L&GAS INJECTORS***WELL REQUIRES MCTUATOR= AXaSC A SSSV***CHROME TBG&LNR*** RT.ELEV= 55.1' I BF.ELEV= 16.05' _ KOP= 1519' H4-1/2"HMO SVLN,D' 3.813" Max Angle= 56°@ 9407' 20'CONDUCTOR H l.... ) Datum MD= 13804' ID=? . Datum TVD= 10000'SS 13-3/8"CSG,60#,NT-80 CYHE H 22:01: j 11 GAS LFT MANDRELS BUTT,ID=12.415" ST MD TVD DEV TY PE VLV LATCH PORT DATE 4 4068 3915 45 WING DOME RS 16 07/27/13 3 8048 6396 54 MNG DONE F4( 16 07/27/13 9-5/8"CSG,47#,NISOS XO --.1 11260' X — X 2 10762 7995 51 MNG SO RK 20 07/27/13 TO NT95HS NSCC 1 12906 9385 45 MAG DMY FE 0 03/30/08 Minimum ID =3.725" @ 13086' I I 12989 -14-1/2"FES X ,ID=3.813" 4-1/2" HES XN NIPPLE 7‹ 13020' —9-5/8"X 4-1/2"BKR S-3 FKR,13=3,875" I 13055' —4-1/2"FES X NP,ID=3.813" I I 13086' —4-1/2"FES XN NP,ID=3.725" 5-1/2"LNR,17#,13CR-80 VAM TOP, 13132' 13089' H9-5/8"X 7"BKR C-2 LIP,ID=6.28" .0232 bpi,(3=4.892' V V A A 13106' --19-5/8"X 7"MC LNR HGR ID=6.360" 4-1/2"TBG, 12.6#,13CR-80 VAM TOP, 13138 * 4a .0152 bpf,ID=3.958* ... ____....--- ,,,,r 13113' —7"X 5-1/2"XO,0=4.81", V. TOP OF 7"LNR 13216' •* t 13132' —5-1/2"X 4-1/2"XO,0=3.875" 9-5/8"CSG,47#,NT95HS NSCC, 0"" 8.681" --I 13488' • 1 13138' —4-1/2'IVLLESHOE,ID=3.958" 1 * * PERFORATION SLIVIMARY REF LOG: LDT/C14./BR ON 02/01/90 1 k ANGLE AT TOP PERE: 38°@ 13765 *' * 1 * Note:Refer to Production DB for historical perf data 1 * 13607' —ir mARKER JOINT SIZE SPF INTERVAL OpniSgz SHOT SQZ 2-1/8" 4 13745-13765 S 12/26/93 12/04/96 • I(' t 2-1/8' 6 13765-13769 0 08/17/97 * v 3-3/8" 6 13765-13770 0 02/19/12 *4 5" 4 13841-13893 C 12/07/90 3-3/8" 6 13841-13893 C 06/23/08 * 3-3/8" 6 13842- 13894 C 04/21/08 * # ?9" 1 —FISH- 1-1/2"WRP RUBBER ELEMBYT&1 BROKEN 4-1/2"LTC,12.6#,L-80 ET, ---1 14035' • KAI WF 'SLP-2 PECES,1"X 1"EA(5/3/14) .0152 bpf,ID=3.958" It .... vA 13920'CTM --1TOP OF CE3431T(04/12/97) PBTD H 1395T ••••• • 4..64,4 • -•- •-• •• 7"LMT,29#,NT95HS BUTT, --I 14085' .•• •,•..••, .0371 bpf,(3=6.184' DATE REV BY ODIVINENTS DATE REV BY COMNENTS 13\DICOTT UMT 02/08/90 D15 COMPLETION , WELL: 1-21/K-25 03/30108 D.16 RWO PERIVIT No: r1900020 02/15/12 SRD/JIVD SET WED MD(02/08/12) AR No: 50-029-22005-00 02/20/12 JTC/JMD ADPERF(02/19/12) SEC 36,T12N,R16E,2011'FM_&2082'FEL 08/13/13 JMNYJNID GLV C/O(07/27/13) 05/07/14 DLH1 PJC FULL WRR FISH DH(5/3-5/44/14) BP Exploration(Alaska) I ti OF Tjit yw\��\��j,�s THE STATE Alaska Oil and Gas i.?,w '-s��='a of T Conservation Commission M A j\ J(j\ " }#x=-Z--It-74-::.,:z __. _= 333 West Seventh Avenue wti GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS'CI. Fax. 907 276 7542 U. www.aogcc.alaska.gov Taylor Wellman Operations Engineer Q 09__Hilcorp Alaska, LLC I 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Endicott Field, Endicott Oil Pool, DIU MPI 1-21/K25 Sundry Number: 315-082 Dear Mr. Wellman: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, )t:33.1...„2cri-e-...—_ Cathy P. oerster Chair, Commissioner -- DATED this Z day of March, 2015 Encl. RECEIVED • STATE OF ALASKA FEB 13 2015 , ALASKA OIL AND GAS CONSERVATION COMMISSION • APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Red rill ❑ Perforate New Pool❑ Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing❑ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other. Remove and Replace Tree Q . 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development El . 190-002 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22005-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 462 • Will planned perforations require a spacing exception? Yes ❑ No 2 DUCK IS UNIT MPI 1-21/K25' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0312828 • Endicott Field/Endicott Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 14,100 ' 10,306 ' 13,920 10,152 13,920' ±13,900' Casing Length Size MD TVD Burst Collapse Conductor 131' 30" 131' 131' N/A N/A Surface 2,509' 13-3/8" 2,509' 2,509' 5,020psi 2,260psi Intermediate 11,260' 9-5/8" 11,260' 8,311' 6,870psi 4,760psi Intermediate 2,227' 9-5/8" 13,487' 9,808' 8,150psi 5,080psi Liner 869' 7" 14,085' 10,293' 9,690psi 7,820psi Liner 19' 5-1/2" 13,132' 9,544' 7,740psi 6,280psi Liner 903' 4-1/2" 14,035' 10,250' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6/13Cr80/Vam Top 13,138 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): 4.5"Baker S-3 Hydroset Packer&7"ZXP Packer 9,473MD/7,225TVD&9,521 MD/7,252ND and 4.5"BBE SCSSSV and 1,532MD/1,532ND 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Q Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 2/20/2015 Oil Q . Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Taylor Wellman Email twellman@hilcorp.com Printed Name Taylor Wellman Title Operations Engineer Signature lPhone 777-8449 Date 2/13/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 l S ^ o5?/._ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ 11, OtherFe11- / lit.1/ Fe c- 0hV /' 5—/ 0-11 `/ fD (. vamoi;r Ivt (ra c-f6Xl_ . J r ; i Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0 — U y' • co APPROVED BY 7 Q Approved by:Gyy[y/ R+G1ffg SI• .7-I ,�% s .,.. 2. 7 Tree Swap&Conversion Well: 1-21 PTD: 1900020 Hilcory Alaska,LL, API: 50-029-22005-00 Well Name: 1-21 API Number: 50-029-22005-00 Current Status: SI—Convert to PWI Rig: SL&Tree/WH Crew Estimated Start Date: February 12, 2015 Estimated Duration: 4 days Reg.Approval Req'std? Yes Date Reg.Approval Rec'vd: 11/07/2014 Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 1900020 First Call Engineer: Taylor Wellman (907)777-8449 (0) (907)947-9533 (M) Second Call Engineer: Chris Kanyer (907)777-8377 (0) (907)250-0374(M) Current Bottom Hole Pressure: 3948psi @ 10,000' TVD (Based on SBHPS on 1-21 05/01/14) Maximum Expected BHP: 3948psi @ 10,000' TVD (Based on SBHPS on 1-21 05/01/14) Max.Anticipated Surface Pressure: 2,950psi (Based on 0.1 psi/ft. gas gradient) Last WHP: 2800psi Taken on 10/07/14 Reference Log: 1-21 Jewelry Log—GR/CCL 18-Apr-2008 Brief Well Summary: Endicott 1-21 is a production well open to the K1 and K2A. The well's bottom hole location is near the crest of the formation in the gas cap. Due to this,the well has an extremely high GOR and is not a competitive cycle well. To allow pressure support to the K1,this well has been approved for conversion to produced water - injection. This is to pull the 4-1/2" BBE in the well and replace with a 4-1/2" MCX Injection SSSV. ,,K6V.3 Objective: To prepare the well for injectionsurface and subsurface steps will be required. For downhole work,the GLV's in the well will need to be dummied off and the IA liquid packed. The surface requirements are a tree swap which will require a downhole plug and BPV to establish barriers. Procedure: Slickline and Pumping 1. MIRU SL unit. 2. Pressure test to 300psi low and 3200psi high. 3. Pull 4-1/2" BBE SSSV from 1519'. 4. Set PXN plug at 13086' md. 5. Bleed tubing and inflow test the plug to 1800 psi for 15 minutes. a. If inflow test indicates a good set, move to next step. If not, pull and re-set plug. 6. Pull GLV's from station station #4 (4068' md), #3 (8048' md), &station #2 (10762' md). 7. Set DGLV's in station #4 (4068' md) &#3 (8048' md). 8. Circulate seawater down the IA while taking returns to the flowline (775 bbls total). Follow with 70 bbls of diesel. 9. Attach jumper line from the IA to the tubing and allow pressure to equalize. 10. Set DGLV in station #2 (10762' md). 11. Conduct an MIT-IA to 2500psi and MIT-T to 2500psi. a. Passing criteria: Less than 10% overall loss in 30 min and demonstrating a stabilizing pressure trend. Record 15 min and 30 min pressure reads of the tubing, IA, and OA. Tree Swap&Conversion Well: 1-21 PTD: 1900020 Hilcorp Alaska,LL, API: 50-029-22005-00 12. Bleed tubing and IA pressures to 0 psi. Tree&Wellhead Work 1. Verify that tubing above the SSSV and IA pressures have been bled to 0 psi and that the BUR is 0 psi. a. The tubing and IA are both full with seawater and 1000' tvd of diesel. Both the tubing and IA are^'400psi overbalanced. 2. Set 4" H Profile BPV in the tubing hanger. 3. Attach lifting sub to the tree and pick up tree as per Cameron recommendation. 4. Nipple down and pick up tree. 5. Stack back tree in preparation for swap with tree from well 1-09. 6. Inspect ring groove and replace ring gasket and seals as needed. 7. Install tree from well 1-09. 8. Pull BPV from the tree hanger. Install TWC. 9. Rig up the BPV lubricator and pressure test to 5000psi. 10. Pull the TWC and RD from the well. Slickline Work 1. MIRU SL unit. 2. Pressure test to 300psi low and 2200psi high. 3. Pull PXN Plug from 13086' md. 4. Set 4-1/2" MCX SSSV at 1519' md. 5. RDMO. Attachments: As-built Well Schematic, Deviation Survey,Tubing Tally,Approved Sundry 314-550 \\hilcorp.com\share\Alaska\Fields\Endicott\Wells\MPI\1-21\Projects\1-21 Tree Swap and Conversion Prep 02-09-15 TREE= D= F I END1 -21 &GA; CI AV ELL R QUIRES ACTUATOR= AXELSO A SSSV***CFROME TBG&LNR*** 'RT.ELEV= 55.1' I BF.ELEV= 16.05' 2 KOP= 1519' —4-1/2'HXOSVLN,ID=3.813" Max Angle= 56°@ 940T 20"CONDUCTOR — 110' Datum MD= 13804' D=? Datum TVD= 10000'SS 13-3/8"CSG,68#,NT-80 CYHE H 2509' GAS LFT MANDRELS BUTT,D=12.415" ST MD IVO DEV TYPE VLV LATCH PORT DATE 4 4068 3915 45 WAS DOME RK 16 07/27/13 3 8048 6396 54 MAG DOME RK 16 07/27/13 9-5/8"CSG,47#,NT81---X0S XO — 11260' 1---X X 2 10762 7995 51 MAG SO RK 20 07/27/13 TO NT95HS NSCC 1 12906 9385 45 MIG DAY RK 0 03/30/08 Minimum 10 =3.725" @ 13086' 1 1 12989' H4-1/2"HES XNP,D=3.813" 4-1/2" HES XN NIPPLE X 13020' H 9-5/8"X 4-1/2"BKR S-3 PCR,ID=3.875" i 1 13055' —4-1/2"HES XNP,D=3.813" 1 1 13086' H4-1/2"FES XN NP,D=3.725" 5-1/2"LNR,17#,13CR-80 VAM TOP, 13132' 13089' —9.5/8"X 7"BKRC-2 LTP,ID=6.28" .0232 bpf,D=4.892' vl 4-1/2"TBG,12.6#,13CR-80 VAM TOP, —{ 13138' t . 41 A 13106' —{9-5/8"X 7"I9V LNR HGR,D=6.360" .0152 bpf,D=3.958" -- 1 13113' -T X 5-1/2"XO,D=4.81" TOP OF7"LNR 13216' ��' �' 13132' H5-1/2"X4-1/2"XO,D=3.875" 9-5/8"CSG,47#,NT95HS NSCC, D= 8.681" H 13488' �� . 13138' H4-1/T MULESHOE D=3.958" PERFORATION SUMutARY REF LOG: LDT/CNJBR ON 02/01/90 .# .�� ANGLE AT TOP PERF: 38°@ 13765' i#4 •• , Note:Refer to Production 08 for historical pert data j# . 4 •. 4 1360T —7"MARKER JOINT SIZE SPF INTERVAL Opn/Sqz SHOT SOZ .. # 2-1/8" 4 13745-13765 S 12/26/93 12/04/96 .� .i. 2-1/8" 6 13765-13769 0 08/17/97 1. �� 3-3/8" 6 13765-13770 0 02/19/12 ## 5" 4 13841-13893 C 12/07/90 •'1 �'� 3-3/8" 6 13841-13893 C 06/23/08 3-3/8" 6 13842-13894 C 04/21/08 �� 4. 4i Lai ? FISH-1-1/2"MP RUBBER ELEMENT&1 BROKEN 4-1/2"LNR 12.6#,L-80 BT, H 14035' r' WRP SLP -2 PIECES,1"X 1"EA(5/3/14) .0152 bpf,1)=3.958" 7* ire ►-VI-I-I-VI-I -920'CTM —{TOP OF CEMENT(04/12/97) PBTD H 13957' 6•••••••••••••1 T LNR 29#,NT95HS BUTT, H 14085' .0371 bpf,D=6.184" DATE REV BY COMMENTS DATE REV BY OOM ENTS B•DICOTT UNIT 02/08190 D15 COMPLETION VVELL: 1-21/K-25 03/30/08 D16 RWO PERAK No: '1900020 02/15/12 SRD/JMD SET WFD VVRD(02/08/12) AR No: 50-029-22005-00 02/20/12 JTC/JMD ADPB2F(02/19/12) SEC 36,T12N,R16E,2011'FTI..&2082'FEL 08/13/13 JMIWJMD GLV C/O(07/27/13) Hilcorp Alaska LLC 05/07/14 DLW PJC PULL WRR RSH DH(5/3-5/44/14) • 13 5/8 X 4 1/16 r END 1-21 FMC tubing hanger • 4"H BPV profile Tree cap,O[is4 1/16 6500 PSI N uu. ran uiu- Valve,Swab,CIW 4 1/16 6500 PSI HWO NI 1 II,!Lid m ri ''' ,41.14:' 4 j Valve, 1/ Wing,,w.4, Ali CIW 41 , 665II00 PSI FE HWO,DD trim 1111.1.1.11 lin wipmLiz low 110 SSV CIW 4 1/16 6500 PSI w/Baker oper, III um III 1111111.111 4111.1 or m L. maser ve P 94 CIW 41/16t65001PSI HWO l'OIC� E�(,3^ 6b�ate.sk U V 62.00 P •��5'S c` 1.111.1 Hu ,��ha o'10 MI pcepQ iim=ii1—rr NM 135/83MX13585M FMC , �� I •. I I Pa- • Valve,OCT-20,31/8 SM FE, Tubing spool i.,� : �I �I HWO Illa " i :,. ... 4 !Hi ...1110:,-..„1,111... Valve,OCT-20,21/165M FE, 0 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. i ~ 0 ~'0(~ File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED Logs of various kinds Other Complete COMMENTS: Scanned by: ~ Bren Vincent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: Is~ NOTScanned.wpd • • bp BP Exploration (Alaska) Inc. ,k Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 a, 40410 t1 T May 22, 2012 Mr. Jim Regg O ®p- Alaska Oil and Gas Conservation Commission 6 1 333 West 7 Avenue Anchorage, Alaska 99501 012 I — Subject: Corrosion Inhibitor Treatments of Endicott Row 1 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 1 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Endicott Row 1 Date: 09/24/2010 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal END1 -01 /J -19 1880370 50029218010000 1.5 0.3 0.5 9/2/2010 0.85 9/23/2010 END1 -03 / P -16 1951500 50029226018000 4.0 3.5 0.5 9/2/2010 5.10 9/23/2010 END1-05 / 0 -20 1861060 50029216050000 0.3 NA 0.3 NA 1.70 9/23/2010 END1 -09 / L -21 1970290 50029217430100 6.0 5.0 0.5 8/28/2010 3.40 9/23/2010 END1 -15 / P -25 1930560 50029223610000 4.0 3.0 0.5 9/2/2010 6.80 9/23/2010 END1 -17 /1-17 1961990 50029221000100 8.0 4.3 0.5 9/2/2010 2.55 9/23/2010 END1 -19 /1-18 1950930 50029225690000 7.0 9.3 0.5 9/2/2010 4.25 9/23/2010 �9 END1 -21 / K -25 1900020 50029220050000 2.5 1.5 0.5 9/2/2010 1.70 9/23/2010 END1 -23 / 0 -15 1941280 50029225100000 12.0 12.5 0.5 9/2/2010 1.70 9/23/2010 END1 -25 / K -22 1970750 50029217220100 5.0 1.5 0.5 9/2/2010 5.10 9/23/2010 END1 -27 / P -20 1870090 50029216930000 8.0 4.3 0.5 9/2/2010 2.55 9/23/2010 END1 -29 / M -25 1861810 50029216690000 2.0 1.3 0.5 9/2/2010 1.70 9/23/2010 END1 -31 / M -21 1950720 50029225620000 5.0 1.8 0.5 9/2/2010 13.60 9/23/2010 END1 -33 / L -24 1982550 50029225770200 1.5 0.3 0.5 9/2/2010 3.40 9/23/2010 END1 -35 / 0-25 1861840 50029216720000 8.0 4.8 0.5 9/2/2010 3.40 9/23/2010 END1 -37 / P -24 1870900 50029217480000 0.5 NA 0.5 NA 4.25 9/23/2010 END1 -39A / N -16 2061870 50029218270100 0.5 NA 0.5 NA 6.80 9/23/2010 END1 -41 / 0 -23 1870320 50029217130000 8.0 5.2 0.5 9/2/2010 4.25 9/23/2010 END1 -43 / P -26 1881050 50029218640000 2.0 0.5 0.5 9/2/2010 3.40 9/23/2010 END1 -45 / 0-26 1891240 50029219910000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1 -47A / M -20 1972030 50029216250100 1.0 0.1 0.5 9/2/2010 3.40 9/24/2010 END1 -49 / P -21 1880780 50029218410000 1.0 0.8 0.5 9/2/2010 3.40 9/24/2010 END1 -51 / V -20 1921190 50029223040000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1-53 / 0-20 1941120 50029225010000 9.0 4.2 0.5 9/2/2010 1.70 9/24/2010 END1 -55 / R -25 1880210 50029217880000 1.3 0.1 0.5 9/2/2010 1.70 9/24/2010 END1 -57 / R -23 1881140 50029218730000 3.0 1.3 0.5 9/2/2010 5.10 9/24/2010 END1 -59 / 0 -24 1960220 50029226440000 3.0 1.3 0.5 9/2/2010 0.85 9/24/2010 END1 -61 / 0-20 1941420 50029225200000 8.0 6.8 0.5 9/2/2010 2.55 9/24/2010 END1 -63 / T -22 1890060 50029219050000 8.0 4.1 0.5 9/2/2010 2.55 9/24/2010 END1 -65A / N -27 2032120 50029226270100 8.0 5.8 0.5 9/2/2010 3.40 9/24/2010 END1 -67 / T -20 1891140 50029219850000 0.5 NA 0.5 NA 1.70 9/24/2010 END1 -69 / V -19 1900290 50029220200000 15.0 10.3 0.5 9/2/2010 0.85 9/24/2010 DATE: 17- May -12 Stephanie Pacillo TRANS#: 5958 -b Data Delivery Services Technician PV1 tkanaTt Bender Schlumberger Oilfield Services . , .N a P—f a Re :,ux e echr :clan H Data & Consulting Services .- ' t'; . �. - C .: ,- -,, ;' 2525 Gambell St, Ste. 400 Anchorage, AK 99503 iir: Office: (907) 273 -1770 WELL SERVICE OH RESERV CNL MECH LOG DESCRIPTION DATE B/W COLOR CD's t D . P PRINTS i NAME ORDER DIST DIST D�'t°, 'i' C -32C BLPO -00117 X LDWG EDIT OF MCNL 6- Jul -11 1 1 CD GC -2E BYS4 -00011 X LDWG EDIT OF RST/WFL 6- Dec -11 1 1 CD F -06A BSM4 -00011 X LDWG EDIT OF RST 2- Jul -11 1 1 CD 03 -30 BINC -00081 X LDWG EDIT RST 16- Nov -11 1 1 CD F-45B BUTT -00013 X LDWG EDIT OF MCNL 29- Aug -11 1 1 CD A-43 BG4H -00086 X LDWG EDIT OF RST 10- Sep -11 1 1 CD N -16 BCRD -00032 X LDWG EDIT OF RST 5- Jul -10 1 1 CD MPI -18 BG4H -00107 X LDWG EDIT OF IBC 25- Dec -11 1 1 CD MPB -50 BCRJ -00096 X LDWG EDIT OF RST/WFL 16- Jul -11 1 1 CD 1- 21/K -25 BG4H -00113 P -01A BD88 -00193 X LDWG EDIT OF RST 18- Feb -12 1 1 CD X LDWG EDIT OF PDC -GR - - 15- Jan -12 1 1 CD Y -19 BINC -00091 X LDWG EDIT OF PDC -GR 9- Jan -12 1 1 CD S x x Please return a signed copy to: Please return a signed copy to: BP PDC LR2 -1 . DCS 2525 Gambell St, Suite 400 900 E Benson Blvd Anchorage AK 99503 Anchorage AK 99508 ' I(A '_) , � � i 1 6.1 9 CA8 N STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COMMI ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations 0 Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate Ir I Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development IN Exploratory ❑ - 190 -0020 3. Address: P.O. Box 196612 Stratigraphic❑ Service p 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22005 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: _ ADLO- 312828 END 1- 21/K -25 10. Field /Pool(s): _ ENDICOTT FIELD / ENDICOTT OIL POOL 11. Present Well Condition Summary: Total Depth measured 14100 feet �W 1 Atka (measured) 13808 feet true vertical 10306 feet`.: Junk (measured) None feet Effective Depth measured 13957 feet Packer (measured) 13020 13089 feet true vertical 10183 feet (true vertical) 9464 9513 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 92' 30" 39 - 131 39 - 131 Surface 2471' 13- 3/8 "68# NT -80 38 - 2509 38 - 2509 5020 2270 Production 11223' 9 -5/8" 47# NT -80 37 - 11260 37 - 8311 6870 4760 Production 1228' 9 -5/8" 47# NT -95 11260 - 13488 8311 - 9809 8150 5080 Liner 903' 4 -1/2" 12.6# L -80 13132 - 14035 9544 - 10250 8430 7500 Liner 869' 7" 29# NT -95 13216 - 14085 9605 - 10293 9690 7820 Perforation depth: Measured depth: SEE ATTACHED - _ _ - True Vertical depth: _ - Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 39 - 13138 39 - 9548 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker S -3 Packer ' 13020 9464 7" Baker C -2 LTP E IS 1 089 9513 0 12. Stimulation or cement squeeze summary: ��R nL i Intervals treated (measured): ; Gas Cons. Commission Treatment descriptions including volumes used and final pressure: AnC`3r6� g 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 8 6232 53 327 Subsequent to operation: 202 14824 13 1337 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil _ 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Nita Summerhays Printed Name Nita Summerh Title Data Manager Signatur: �, i / /` / / /Y/ / / Phone 564 -4035 Date 3/7/2012 Form 10 -404 Revised 10/2010 MOMS MAR 0 9 In' / ; / Submit Original Only 1-21/K-25 190 -002 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 1- 21/K -25 2/7/90 PER 13,841. 13,893. 10,085.61 10,128.91 1- 21/K -25 12/26/93 APF 13,745. 13,765. 10,008.57 10,024.35 1- 21/K -25 12/4/96 SQZ 13,745. 13,765. 10,008.57 10,024.35 1- 21/K -25 8/17/97 APF 13,765. 13,769. 10,024.35 10,027.51 1- 21/K -25 7/11/00 BPS 13,205. 13,766. 9,596.82 10,025.14 1- 21/K -25 10/27/03 BPP 13,205. 13,766. 9,596.82 10,025.14 1- 21/K -25 10/27/03 BPS 13,180. 13,185. 9,578.57 9,582.21 1- 21/K -25 11/1/03 BPS 13,106. 13,110. 9,525.03 9,527.91 1- 21/K -25 3/29/08 BPP 13,106. 13,110. 9,525.03 9,527.91 1- 21/K -25 3/30/08 BPP 13,180. 13,185. 9,578.57 9,582.21 • 1- 21/K -25 4/20/08 RPF 13,842. 13,862. 10,086.43 10,103. 1- 21/K -25 4/20/08 RPF 13,862. 13,882. 10,103. 10,119.69 1- 21/K -25 4/21/08 RPF 13,882. 13,894. 10,119.69 10,129.75 1- 21/K -25 6/23/08 APF 13,841. 13,853. 10,085.61 10,095.53 1- 21/K -25 6/23/08 APF 13,853. 13,873. 10,095.53 10,112.16 1- 21/K -25 6/23/08 APF 13,873. 13,893. 10,112.16 10,128.91 1- 21/K -25 2/8/12 BPS 13,808. 13,894. 10,058.66 10,129.75 1- 21/K -25 2/19/12 APF 13,765. 13,770. 10,024.35 10,028.3 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE • MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • 1- 21/K -25 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY RS A t Y AT. E Yw f'r:� r> : , : ' ,..5 s.;tAS .:4: ;s :T'u , . za; .t* bx ,:, ,4 1/21/2012 ** *WELL SHUT IN ON ARRIVAL ** *(add perf) TAG SSSV W/ 3.84" GAUGE RING @ 1496' SLM. PULLED 4 -1/2" BBE (SER #BB -480) FROM HXO NIP @ 1496' SLM. DRIFT WITH 3.70" WRP DRIFT SAT DOWN @ 3211' SLM. DRIFT WITH 3.50" CENTRALIZER & SAMPLE BAILER TO 3240' SLM.(SAMPLE OF PARAFFIN) DRIFT WITH 2.25" CENTRALIZER TO 13905' SLM. LRS PUMPED TOTAL OF 170 BBLS DIESEL. B &F TUBING WITH 2 7/8" BLB/ 2 1/2" GAUGE RING, 3 1/2 "BLB/ 2 1/2" GAUGE RING & 4 1/2" BLB/ 3 1/2" GAUGE RING TO 6000' SLM ** *JOB CONTINUED 1/22/12 * ** 1/22/2012 * * *WSR continued from 01- 21 -12 * ** Assist Slickline, Brush & Flush ( Paraffins ) Pumped an additional 4 bbls (167 total) 180* diesel down Tbg while Slickline worked brush. FWHP's =0 +/940/140 Slickline in control of well upon departure. IA & = Gtified. 1/22/2012 ** *JOB OA CONTINUED OT. Well FROM Tender 1/21/12 no * ** DRIFT W/ 3.70 "x40" DMY WRP & TAG TD @ 13904' SLM. ** *WELL TURNED OVER TO WELL TENDER * ** 2/4/2012 ;T /I /O= SSV/760/120. Temp =SI. WHP's IA FL (Pre E- line). AL is SI @ casing i . valve, ALP =2200 psi. IA FL @ 30'. SV,WV,SSV= closed. MV =open. IA & OA =open to gauge. 15:22. 2/6/2012 T /I /0= 950/970/50 Temp =S /I Load & Kill pre -E -Line (Laod & Kill) Pumped 10 bbls 60/40 meth spear followed by 314 1% KCL down Tbg to kill well. Freeze protected Tbg with 12 bbls 60/40 methanol. SV, WV, SSV= C MV= 0 IA, OA= j OTG FWHP's= 440/960/50 2/7/2012 ***WELL SHUT IN ON ARRIVAL * ** (E -LINE WRP) INITIAL T /I /0= 700/0/700 SSV /SWAB/WING= CLOSED, MASTER OPEN RIG UP WRP ** *JOB CONTINUED ON 8 -FEB- 2012 * ** 2/8/2012. ** *JOB CONTINUED FROM 7 -FEB -2012 FINAL T /I /0= 700/0/700 SET WFD WRP ME AT 13808' BTM PLUG AT 13810', CCL TO ME = 8.9' CCL STOP DEPTH AT 13799.1' NOTIFY DSO OF VALVE POSITIONS SSV /SWAB/WING= CLOSED, MASTER OPEN LEAVE LOCATION WELL SHUT IN ' ** *JOB COMPLETE * ** • • . . 2/8/2012 T /I /0= 750/750/20. CMIT TxIA Bleeding IA pressure down flowline of well 1 -25 (continued on 2 -9 -12) 2/9/2012; ** *WSR Continued from 2/8/12 * ** Continue bleeding IA, DHD shoots fluid level, rig down bleed, job postponed. Swab, Wing & SSV closed. Master open. Annulus valves open to gauges. FWHP= 780/410/120. 2/9/2012 TWO = 750/410/120. Temp = SI. WHPs IA & Tbg FL. AL SI @ casing valve, ALP = 2150 psi. IA FL @ 10762' (SO 576 bbls), Tbg FL @ 12451' (190 bbls). LRS in charge of well. 03:30 2/11/2012 T /I /O = 760/450/140. Temp = SI. Bleed IAP to 50 psi & TBGP to 450 psi (Add pert). AL is SI @ casing valve, ALP @ 2150 psi. TBG FL @ 12451' (190 bbls). IA FL @ 10762' (sta # 2 so, 576 bbls). Bled IAP from 450 psi to 280 psi (gas, to production) in 1 hour, swapped to UR & continued to bled IAP to 50 psi in 3 hours. Bled TBGP from 760 psi to 450 psi (to production) in 30 min. TBG & IA FL unchanged. Monitior for 30 min. TBGP & IAP unchanged. FWHP's = :450/50/140. Job Complete. SV, WV = C. SSV, MV = 0. IA, OA = OTG. 02:10. 2/11/2012 T/I/O= 266/0/50 Load IA & TBG (Perforating) Pumped 30 bbls inhibited 60/40 meth, 674 bbls inhibited 1% KCL and 60 bbls inhibited 60/40 meth down the IA, up the TBG, taking returns to the plant. Bleed gas off TBG and IA. ** *Job continued on 2 -12 -12 WSR * ** 2/12/2012 ***Job continued from 2 -11 -12 WSR * ** Continue to bleed gas off IA. CMIT -TxIA ;PASSED to 2500 psi - post WRP set (Perforating) Pumped 18.3 bbls Inhibited ;60/40 down IA to achieve test pressure for CMIT -TxIA. T /IA lost 4/2 psi in the 1st 15 min and lost 0/1 psi in the 2nd 15 min for a total pressure loss of 4/3 psi in 30 :min test. Bled Tbg and IA to 380 psi. SV & WV closed. SSV & MV open. AL ;closed. CVs OTG. Well Tender notified and on location to blow down Flowline for FP. FWHP= 380/380/0. 2/17/2012 ** *WELL SHUT IN UPON ARRIVAL * ** (E- LINE:RST) INITIAL TWO = 600/500/0 PSI ARRIVE TO LOCATION AND GOT PERMIT SIGNED BY CONTROL ROOM AND WELL TENDER. PROCEEDED TO SPOT THE EQUIPMENT AND HOLD .SAFETY MEETING. PROCEED WITH RIG UP ** *JOB IN PROGRESS * ** TO BE CONTINUED 18 -FEB -2012 2/18/2012 ** *JOB IN PROGRESS * ** (E -LINE: RST) COMPLETED PRESSURE TEST AND RIH WITH TOOLSTRING. TURNED MINITRON ABOVE LOGGING INTERVAL AT 13300' AND WAITED FOR IT TO STABILIZE. CONTINUED TO RIH, TAGGED WRP AT 13808' AND ;PERFORMED 2 UP LOGGING PASSES AT 60 FPM AND 1 AT 30 FPM FROM TD TO 13450'. CONFIRMED GOOD DATA (OBSERVED ANOMALY BETWEEN 13543' - 13582'). POOH. CLOSE SWAB AND SSV. LAY DOWN AND SECURED WELL. LEAVE LOCATION. ARRIVE TO LOCATION AND RESUME WORK FOR 2ND PART OF THE JOB (3 -3/8" 5' PERF). RIG UP. SAFETY MEETING. PRESSURE TESTED THE LUBRICATOR AND PROCEEDED TO UNSTAB AND MAKE UP TOOLSTRING. HOT CHECKED AND GOT READY TO ARM. ' ** *JOB IN PROGRESS * ** TO BE CONTINUED 19 -FEB -2012 • • 2/19/2012 ** *JOB IN PROGRESS*** (E -LINE: PERFORATING) RIH WITH ELINE TOOLSTRING W/ 5' x 3 -3/8" OD GUN (3406 POWERJET, HMX HSD GUN) . PERFORMED TIE IN PASS AND CORRELATED TO SLB JEWELRY LOG DATED 18- APR -2008. PERFORATED 5' INTERVAL = 13765' - 13770' (CCL TO TOP SHOT = 7.7' 'CCL STOP DEPTH = 13757.3') WHEN PERFORATING THE TBG PRESSURE DROPPED 850 PSI, LOST 300 LBS OF TENSION, & TOOLS WERE SHORTED OUT, INDICATING TOOL STRING FORCED OFF LINE DUE TO PLUG BELOW RELEASING OR IN OVERBALANCE CONDITION. ONCE AT SURFACE CONFIRMED THAT : TOOLSTRING WAS DOWNHOLE ' * ** *FISHING DATA: TOTAL LENGTH OF SLB TOOLS LEFT DOWNHOLE = :21.5', FISHING NECK OF SLB HEAD = 1.375" O.D. - MAX OD OF SLB TOOLS 3 -5/8" FINAL T /I /O = 56/250/0 PSI ** *JOB COMPLETE * ** WELL SHUT IN UPON DEPARTURE - NOTIFIED WELL TENDER OF STATUS 2/21/2012 ** *WELL SHUT IN ON ARRIVAL * ** RIG UP SLICKLINE ** *JOB CONTINUED ON 2/22/12 * ** 2/22/2012 : ** *JOB CONTINUED FROM 2/21/12 * ** TAG FISH @ 13,779' SLM W/ 3.50" LIB ;PULLED E -LINE TOOLSTRING FROM 13,779' SLM TAG X -NIP W/ 3.805 GAUGE RING @ 12,792' SLM/ 12,989' MD TAG XN -NIP W/ 3.75 CENT@ 13,070' SLM / 13,086' MD TAG WRP W/ 3.50 CENT @ 13,802' SLM SET 4 -1/2" BBE (serial # NBB -30) WITH SECONDARY LOCKDOWN@ 1496' :SLM / 1519' MD `PERFORM PASSING CLOSURE TEST ** *WELL LEFT SHUT IN ON DEPARTURE, WELL TENDER NOTIFIED OF STATUS * ** FLUIDS PUMPED BBLS 173 DIESEL 117 60/40 METH 988 1% KCL 18.3 60/40 INHIBITED 5 METH 1301.3 TOTAL TREE= OW 1111 S HTS READINGS AV ERAGE 230 - 260 - WELLHEAD = FMC E N D 1 -2 1 PPM ON AIL & GAS INJECTORS. WELL REQUIRES A ACTUATOR : 2------ ARLES-6(4 SSSV. ***CHROME TEG, LNR & NIPPLES*** RT. ELEV; 551'' 1 BE ELEV = 16.05' KOP = , I 1619' 1H4-1/2" HXO SVLN, ID = 3.813" j ma x. !k 6 n g .. : ,,, '6. 6":;iij' ay. coND, 110' III datum MD = '1 J664. ID . ? Datum - 6/D= - 10000' SS 13-3/8" CSG, 68#, NT-80 CY HE -1 2509 I GAS LIFT MANDRELS BUTT, ID = 12.415" ST MD ND DEV TYPE VLV LATCH FORT DATE 10 4 4068 3915 45 MING DOME RK 16 04/04/08 3 8048 6396 54 MMG DOME RP 16 04/04/08 2 10762 7995 51 MMG SO RP 20 04/04/08 9-5/8" CSG, 47#, NT8OS X0 -I 11260' TO NT95HS NSCC 1 12906 9385 45 NM DMY RP 0 03/30/08 Minimum ID = 3.725" @ 13086' 1 1 12989' H4-1/2" HES X NIP, ID = 3.813" I 4-1/2" HES XN NIPPLE IC IMI 13020' 1-19-5/8" X4-1/2' BKR S-3 PKR, ID = 3.875" • I 13055' H • _ 1 / 2" HES X NIP, ID = 3.813" I • 13086' H 4- 1 /2 ' HES XN NIP, ID = 3.725" 1 5-1/2" LNR 17#, 13CR-80 VAM TOP. H 13132' 13089' H 9_ 543- X 7" BKR C-2 LTP, ID= 6.28" I .0232 bpf , ID = 4.897' A AA 13106' - 19 - 5/8" X 7" HMC LNR HGR, ID = 6.360" 4-112" TEC, 12.6#, 13CR-80 VAM TOP, H 13138' kg ,1 ; 0152 bpi, ID = 3.958" *Au 13113' 1--17" X 5-1/2" X0,16 = 4.81" . 1 IN 41 I TOP OF 7" LNR 13216' • a ,f , 13132' -15-1/7 X 4-1/2" X0, ID = 3.875' 1 * 4 •■ 14 ISI....1 9-5/8" CSG, 47#, NT95HS NSCC, -1 13488' *4 -.• ■■ r. 13138' I-14-1/2" MULESHOE, ID = 3.958" I * *4 ID .7:- 8.681" re 44 ** 4* te 41 PERFORATION SUMMARY * *4 oe 41 * *4 REF LOG: LDT/CNL/BR ON 02/01/90 o* ■04 ** *4 ). ■•■ ANGLE AT TOP FERF: 38° ,?.! 13745' ** ** ■• 4 Note: Refer to Production 013 for historical perf data * *4 t 0 t* 13607' HT' MARKER JOINT SIZE SPF INTERVAL Opn/Sqz DATE 0* ** ■ . ■ 2-1/8" 4 13745 - 13765 S 12/04/96 1 .. 't ' 4 1 2-1/8" 6 13765 - 13769 0 08/17/97 3-3/8" 8 13765 - 13770 0 02/19/12 1/4. 1* * *.* oe • . I 13808' H W FD W RD (02/08/12) I 3-3/8" 6 13841 - 13893 C6/23/08 ** -111P-- V* C .91,/ ■■•... 041 3-3/8" 6 13842 - 13894 04/21/08 C- V 1111111 ** -, * ___ . - * 4-1/7 LNR 12.6#, L-80 IBT, H 14035' ■• .• .. II . # .0152 bpf, ID = 3.958 * ■.t. NA v• 13920' CTM TOP OF CEMENT (04112/97) IPBTO H 13957' 1. .. • ....., ,,, 47,-.-•-•-•-. 7" LNR, 29#, NT95HS BUTT, -I 14085' ••••••• 1■••••••4 A,•,..,•,,•, .0371 bpf, ID = 6.184" DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT UNIT 02/08/90 015 COMPLETION 02/16/11 MB/JMD AWED SSSV SAFETY NOTE VVELL: 1-21 / K-25 03/30/08 016 RWO 08/12/11 MAID A DDED112S SAFETY NOTE PERMIT No: '1900020 04/15/08 JLJ/PJC ' GLV C/0 (04/04/08) 02/15/12 SRD/JMD SET VVFDIARD (02/08/12) AR No: 50-029-22005-00 05/05/08 TEL/PJC PERF (04/21/08) 02/20/12 JTC/JMD ADPERF (02/19/12) SEC 36, T12N, R16E, 2011' FNL & 2082' FEL 1 , 1 06/26/08 RRD/PJC PERFS (06/23/08) 1 1 08/13/09 ' AVVIJMD DRLG DRAFT CORRECTIONS ' BP Exploration (Alaska) 05/13/08 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .Inh !k N0. 4702 Company: State of Alaska ~i t~~ i €± ~~~~ Alaska Oil & Gas Cons Comm ~t~~~ t~ ~ ~ ~ ~ .. OCR ~ /~/ Attn: Christine Mahnken ~~ /~~. ~~ Anchorage`, AKv99501te 1(10 i i .... n,. ...:,. MPS-11 12017492 CEMENT & CORROSION LOG ~(j~-/ /~ /~ 04/22/08 v i V1 1v 1-21/K-25 12061694 PRODUCTION LOG ~~ wC~ ~ ,,~/~j~ 04!18/08 1 1 GNI-04 12057606 STEP RATE INJECTIVI'r r 1 t~ I U'~G / ~jC/ 04/23/08 1 1 L-220 11975763 USIT 04/22/08 1 1 MPS-31 11962598 USIT C 05/03/08 1 1 X-17 12034894 USIT - / • /(o ~~ 05/03/08 1 1 04-47 11978458 MEM LDL l~j~(--(f ~ 05/01/08 1 1 Y-07A 11966254 TEMP & PRESS LOG ,aU~-- / 05/02/08 1 1 L5-36 11975768 PRODUCTION PROFILE W/FSI -U f 04/28/08 1 1 Z-112 40016350 OH MWD/LWD EDIT ~- 02/15/08 2 1 Z-112 PB 40016350 OH MWD/LWD EDIT p'~-. J 02/11/08 2 1 Y-07A 11962781 CH EDIT PDC GR ISCMT) ~y.;~ ~C~S `(p~~l-( 02/03/08 1 L2-16 11975760 RST (=~%~!'} ~~ ~-`~~ 03!31/08 1 1 L2-33 11998999 RST ~ 04/01/08 1 1 Li-14 11999000 RST ~ 04/02/08 1 1 D-266 40016518 OH MWD/LWD EDIT S 02/21/08 1 1 at F4SF Ar`Kn~n~nn cnr_c oo nnnr ov ~~n. u..~n w.~r.., BP Exploration (Alaska) Inc. _ - . -......•M v.-~ vv, ~^v" ~ v~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 - Date Delivered: "'ix t' ~~s~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 , Anchorage, AK 99503-2838 ~ ATTN: Beth Received by: • f ~~ 1-21 time Line after POP Maunder, Thomas E (DOA) Page 1 of 2 From: Maunder, Thomas E (DOA) Sent: Thursday, May 08, 2008 2:28 PM To: 'Soto, Jose A' Cc: END/BAD Area Manager; Varble, Doug A Subject: RE: 1-21/K-25 (190-002} time Line after POP Jose, Thanks for the call and message. Based on the activities that have occurred, t would start the 14 day clock on April 30. Day 14 would be May 14. Keep us informed as to your ability to run the safety valve. I am aware that the winds are blowing on the slope. Call or message with any questions. Tom Maunder, PE AOGCC Also, when you send a message regarding a well please include the permit number. From: Soto, Jose A [mailto:jose.soto@bp.com] Sent: Thursday, May 08, 2008 2:22 PM ~~~~~ MAY 4 ~ 2008 To: Maunder, Thomas E (DOA) Cc: END/BAD Area Manager; Varble, Doug A Subject: 1-21 time Line after POP ~ ~ ~e- Tom: The following is the time line for well 1-21. We would like to provide you with our view on the 14 days clock for this well. It did not show signs of flow right after perforated and opened in 4-23, so it was SI on 4-25 for f-uid level determination. Fluid level took a bit more than expected (2). We had a Plant SD on 4-27. Total active days until today are 11 counting green and blue. We are waiting now for the wind to slow down with the slick-line unit in stand by to set the SSSV. What is the longest we can wait considering current status to SI the well? If the wind doesn't come down before 5- 11, should we SI the well and wait? 5/8/2008 1-21 time Line after POP APRIL S M T 1N T F S 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 1E~ 1? 1$ 19 ?0 ~t -- 23 24 25 26 27 28 29 30 MAY S M T W T F S 1 a 3 a 5 s z 8 9 1a 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 1-21 0 penned well. Trying kick off wellwith gas lift. Plant Shut Down DHD -Fluid Levels an IAand Tubing. UVell flawing to test separator. Regards, Jose Soto PE -Endicott Field -ACT East BP Exploration (Alaska) Inc. Off: 907 564 5972 Mob: 907 244 0529 Page 2 of 2 5/8/2008 ~®f~~~~' STATE OF ALASKA V ter'°8 RECEIVE` A~ OIL AND GAS CONSERVATION COMION REPORT OF SUNDRY WELL OPERATION Y~APR 2 ~ 2008 Alaska Orl R r~~ ~__ _ 1. Operations Performed: R11SSI ~ ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-E ~~~~'~~ided Well ® Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ®Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 190-002 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22005-00-00 - 7. KB Elevation (ft): 55.1 - 9• Well Name and Number: END 1-21IK-25 ' 8. Property Designation: 10. Field /Pool(s): ADL 312828 ' Endicott Field / Endicott Pool 11. Present well condition summary Total depth: measured 14100 - feet true vertical 10306 ~ feet Plugs (measured) None Effective depth: measured 14000 feet Junk (measured) None true vertical 10220 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 131' 30" 131' 131' Surface 2506' 13-3/8" 2509' 2509' 5020 2270 Intermediate 11260' 9-5/8" 11260' 8311' 6870 4760 Production 2227' 9-5/8" 11260' - 13487' 8311' - 9808' 8150 5080 Liner 869' 7" 13216' - 14085' 9605' - 10293' 11220 8510 Scab Liner 946' 5-112" x 4-1 /2" 13089' - 14035' 9513' - 10250' 7740 ! 8430 6280 / 7500 ~~11~ APR 2 3 2008 Perforation Depth MD (ft): 13765' - 13893' Perforation Depth TVD (ft): 10025' - 10129' 4-1/2", 12.6# 13Cr80 13138' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker S-3 Packer 13020' 9-5/8" x 7" Baker C-2 XPLT Packer 13089' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Cut and pull tubing. Run Scab Liner 5-1 /2" x 4-1 /2" (17# x 12.6#, 13Cr80 / L-80) from 13089' - 14035'. Cement w/ 32 bbls Class 'G' w/ Gas-Blok 180 cu ft / 154 sx . Clean out and run new Chrome tubin . 13. Re resentative Dail Avera a Production or ln'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 450 0 Subsequent to operation: 0 0 0 0 0 14. Attachments:. ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory. ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or WA ff C.O. Exempt: Contact Aras Worthington, 564-4102 308-029 Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number: ' Sig r Phone 564-4750 Date ~'~ "~,~ ondra Stewman, 564-4750 Form 10-404 Revised 04/2006 (-"~ ~ ~) ~ ~ ~ ~ A ~ ~~ Submit Original Only m REE: 4-1/16"- 5,OOOpsi, C~ CUATOR: Otis ELLHEAD: 13-5/8"- 5,OOOpsi, FMC T ELEV: 55.1 ft. F ELEV: 16.05 ft. MAX. DEV. = 56:20 9400' MD T80CYHE. BTRS. 2509' __. END1-21 lVkkN k[3 = 3.725" 13U8B' 4112" OTkS XN NkPPLE ~SA FECY' 1 ~.. 1519' 4-112" SSSVLN, HES HXC} id = 3.813" GAS LIFT MANORE1a^ 5T rv» ~rv© n~ 1 r_v LATCH ~ aATr= 4 ,~~ ~ , . , - ~s oa;o410$ 3 ~ F , ~ t6 441U410$ 2 ~' 20 04113-010$ 1 ,. ~~,, 0 0313014$ TUBING: 4-1/2", 12.6#, 13Cr-80, Vam Top I.D. = 3.958" Drift = 3.833" 1298g• HES X-Nipple !d= 3.813" Capacity = 0.0152 bbllft 13020' ~-5r8" x =t-tie" BAi<~ ® S-3 9Gr FM{R, !d = 3,875" 9-5/8" 47#/ft NT80S, NSCC --~ ~ ~ 1~~ ~ F gAK _.... " ! s _ ~ d_i31" . "~ 13132' 517 x4117` 12 ixC~ ~ ID = 3.875" 1313$' 4-112" Mule Shoe TOP OF 7" 13216' -• ~ LINER 4-1/2" Cemented Liner, 12.6# 13Cr80 Vam Top I.D. = 3.958" Drift = 3.833" 9-5/8", 47#/ft, 13488' NT95HS, NCSS -~ PEftFC~RATiC3N St..rv11M RY GC3G: LQT/CS~tGFtC)fJO2~C31;9o kNGLEIR'i'TGPP~RF: 7? ~ 137G5' 1~tc: Ref~e io Praductan DB for twisloric;al serf dat SIZE SPF M1ER`JAL •: DP~'TE ~-718" 4 13745 ~1376'S 5 2-1!$" 6 '13765 -137&9 is 4$d171f17 S" 4 13841 - 13$33 [JPC *" K1=Y': p = OPE3J l C = CLOS@ ~9~8' 7", 29#/ft, NT95HS, TKC 14085' ~- MARKER 13607' t7V1TE REV BY 17JNMEN7S PATE REV BY C~Inm~tFlvTS ~2I2$l9tF JLFI OFitGfNAL COMt'L, 03/3fl/0$ CYI6 RWO 44!15!0$ JL,tiSPJG GL'J G'G (040i04;GE) Digital'Well File Well: 1-21 Well History Well Date END1-21 2/4/2008 END1-21 2{412008 • • Summary T/I/0= 500/1280/280 Temp= S/I Ice Plug (PRE RWO) Pumped 2.7 bbls meth to free Tbg of obstruction. Final WHPs 400/1280/280 ( IA/OA casing valves open to gauges, swab shut, needle valve open to gauge at time of departure) *"`WELL S/I ON ARRIVAL*** {PRE-RWO} ICE PLUG IN TREE CANNOT PASS THROUGH RIG DOWN NOTIFY DSO **LEFT WELL SHUT IN W/LEAVE HEATER ON TREE*' END1-21 2/6/2008 ***WELL S/I ON ARRIVAL*** (pre rwo) RAN 2.725" TUBING SWEDGE (RAN THRU RESTRICTION @ 3981' W/ NO PROBLEMS) TAGGED _ _ PLUG BODY C~ 13 095' SLM. AN 2.63" CENT. 2' OF 1 718" STEM W7 2.74" G- RING TO RESTRICTION C~ 3,981' SLM. (COULD NOT PASS THRU) RAN 2.5" CENT. 2' OF 1.5" STEM & 2.708" BLIND BOX TO 3,981' SLM. (SETS DOWN BUT WILL PASS THRU THROUGH IF RUNNING AT APPROX 250 FPM) ***LEFT WELL S/I NOTIFY DSO*** END1-21 2/8/2008 *** WELL SHUT IN ON ARRIVAL*** (fish Chem cutter) FISHED OUT ELINE TOOLSTRING & CHEMICAL CUTTER W/ 2.60" BELL GUIDE W/ 2" JUS PULLING TOOL C~ 13,095' SLM ***LEFT WELL S/I NOTIFY DSO*** END1-21 2/8/2008 WELL SHUT IN ON ARRIVAL. INITIAL T/I/O = 300/1300/280 PSI CUT 3.5" TUBING AT 13106.3' WITH 2.5" POWER CUTTER UN E ED ERS E OOL. LEFT 1-3/8" OTIS #2 FISHING NECK LOOKING UPHOLE. TOOL LEFT IN HOLE: ERS FISHIN NECK / CCL / 2"x4' WT BAR / 2"x4' WT BAR / 2 2"x2' SHOCK SUBS WITH 3" GEMCO ON EACH ONE /JET CUT FIRING ADAPTER / 2.5" POWER CUTTER (SHOT). LENGTH = 16.5', MAX OD = 2.5" FINAL T/I/O = 325/1300/280 PSI WELL LEFT SHUT IN AND READY FOR SLICKLINE TO FISH. ***JOB COMPLETE**' END1-21 2/11/2008 T/I/0= 400/1320/300 Circ out, CMIT TxIA to 3000 psi, MIT OA to 2000 psi. (Pre RWO) Rig up on well- Stand by for 9.2 brine/meth ***Continued on 2-12-08*** END1-21 2/12/2008 ***Continued from 2-11-OS*** Circ out, CMIT TxIA PASSED to 30~00psi ,MIT OA PASSED to 2000 psi . (Pre RWO) Pumped 5 bbls neat meth fo owe~c ~y i'3tS3'6 sGl~.'~ ppg 5rin'~ eT g, uT6~7~faTang returns down flowline. Pumped 30 bbls 80*F diesel down Tbg and U-Tubed into IA to freeze protect. Pumped 10 bbls 60*F diesel down F/L to freeze protect CMIT Tx IA to 3000 psi. Pumped 7.2 bbls diesel down IA to reach test pressure. T/IA lost 0120 psi in 15 min's, 0/0 psi in 2nd 15 min's for a total loss of 0/20 psi in 30 min's. Bled Tbg &IAP. MIT OA to 2000 psi. Pumped 7.9 bbls diesel down OA to reach test pressure. OA lost 20 psi in 15 min's, 20 psi in 2nd 15 min's for a total loss of 40 psi in 30 min's .Bled OAP. FWP's=240/10/100 ***Wellhead valves checked for position and tags hung upon departure*** Note: DHD will bleed whp's to 0 psi END1-21 2/13/2008 T/IA/OA= 300/0/400 Temp:warm PPPOT-T (PASS) PPPOT-IC (unable to test) (PRE RWO) PPPOT-T RU 2 HP bleed tools onto THA 700 psi to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 4950/ 30 minutes. Bleed void to 0 psi, RD test equipment, re installed Alemite cap. Cycle LDS "ET style" all functioned properly and are in good condition. PPPOT-IC (2) 1/2" plugs installed into IC test ports, during RWO need to replace with Alemite test fittings. Cycled LDS "ET style" all functioned properly and are in good condition. END1-21 2/17/2008 T/I/0=250/30/450. Temp=Sl. Bleed WHP's to 0 psi (pre - RWO). No AL. TBG FL near surface. IA FL is C~ surface. OA FL is @ surface. Bled TBGP to bleed trailer from 250 psi to 0 psi in 1 hr (all gas). During 76G bleed IAP decreased to 0 psi. Bled OAP from 450 psi to 0 psi in 45 mins (all fluid). Monitor for 30 mins. TBGP increased 50 psi. Bled TBGP from 50 psi to 0 psi. Final WHPs= 0/0/0. END1-21 2/25/2008 Gat 4" riw hnv thr ~ tr _ or ricLwork Set 2" fmc yr plugs in I/A and O/A~ p g work END1-21 3/15/2008 PullP~ 4" [:Iw "H" RPV thr ~ tr -P after Dovon 16 mov d over well. T=O. 1 - 2' extension used. Tag at 102". No problems. http:/ldigitalwellfile.bpweb.bp.com/WIInfo/ReportsJReportViewer.aspx Page 1 of 2 4/19/2008 Digital ~VVell File ~ ~~~ C. `~ END1-21 3/17/2008 Pull TWC st BOP t T/I/O si t 0/0/0 = . po es . p END1-21 3/26/2008 T/I/O = 0/0(150 Pulled blind set 2 1/6 "CIW O/A valve pulled V!R plug with lubricator. **** COMPLETE**** END1-21 3/30/2008 T/I/0=0/0/0; PULLED 4-1/16" "H" TWC THRU TREE; 1-2' EXT. USED, TAGGED @ 102"; ***COMPLETE*** (BEST/WORTHAM) END1-21 3(30/2008 set 4" CIW BPV C 102" w/ 2' exten. for post rig work,Doyon 16. END1-21 4/2/2008 pulled 4" CIW BPV# 251 thru tree, post rig,tagged @ 102"w/2' exten. END1-21 4/3/2008 ***WELL SHUT IN ON ARRIVAL*** (post rwo) DRIFTED W/ 3.84" NO-GO CENTTO DSSSV AT 1519'MD, PULL DSSSV FROM 1519'MD. PULL B & R FROM RHC-M PLUG BODY AT 13,055'MD PULLED RK-DGLV FROM STA# 2(10,762'MD)STA# 3(8048'MD)RKP-DCR FROM STA# 4 (4068'MD) ***CONT WSR ON 4/4/08*** END1-21 4/4/2008 ***CONT WSR FROM 4/3/08***(post rwo) SET RK- LGLV IN STA# 4 (4068' MD), STA# 3 (8,048' MD) SET.RK-S/O GLV STA# 2 (10,762'MD) CURRENTLY POOH W/4-1/2" RHC-M PLUG BODY ***CONT WSR ON 4/5/08** END1-21 4/5/2008 ***CONT WSR FROM 4/4/08*** PULLED 4-1/2" RHC-M PLUG BODY FROM X-NIPPLE AT 13,055' MD. DRIFT WITH 3 3/8" DMY GUN,T.E.L, AND SAMPLE BAILER.LOC T.T. AT 13,123' SLM / 13,138' CORRECTED SAT DOWN AT 13152' SLM. FISH 3 3/8 DMY. GUN FROM 13,269' SLM. DRIFT WITH 3.70 GAUGE RING AND TAG HARD BOTTOM AT 13,929' CORRECTED DRIFT WITH 3 3/8 DMY GUN. TAG HARD BOTTOM @ 13,929' CORRECTED MD. TARGET DEPTH WAS 13,893' MD. NO TIGHT SPOTS NOTED. ***WELL LEFT S/I***DSO NOTIFIED END1-21 4/8/2008 Tested frontside I/A valve to 4500 psi. Pulled VR plug from I/A. 1/A = 0 psi ***job complete*** END1-21 4/14/2008 T/I/O = 310/1480/140. Temp = S/I. T & IA FL (for E-Line). TBG FL @ 1992'. IA FL @ 5990' END1-21 4/16/2008 T/I/0=1410/1430/10. Temp=Sl. T & IA FL's (pre ad-pert). A/LP=2100 psi, SI @ companion. T FL C~ 4100' (just below sta #4). IA FL @ 10762' (sta #2, SO). END1-21 4/17/2008 T/I/0=1300/1330/0, Temp=Sl. PPPOT-T (PASS). Repair leaking control line nipple (FO call in). Adjusted leaking control line nipple gland nut. Stung into test port on THA (1000 psi). Pressure would not bleed off. Tightened/ torqued LDS (ET style). Bled off void pressure. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Leaks mitigated, bled void to 0 psi. END1-21 4/17/2008 T/I/0=1420/1520/200. Temp= SI. TBG & IA FL's (pre-adperf). A/L online @ 1520 psi. T FL @ 9506' (between sta # 2 & 3). IA FL Ca? 10762' (sta # 2, SO). **Balance control line leaking @ fitting on tree.** END1-21 4/17/2008 ***WELL SHUT-IN ON ARRIVAL***INITIAL WHP 15001140010 ARRIVED AT END 1-21. BEGAN RU E-LINE FOR PERFORATION AND STATIC P/T LOG. *** CONTINUE AWGRS ON 18-APR-08 **** END1-21 4/18/2008 *** CONTINUE AWGRS FROM 17-APR-2008 *** INITIAL WHP 1500/1400/0 RAN P/T/GRADIO LOG FROM SURFACE TO TD TO DETERMINE BHP P/T AND FLUID LEVEL. RIH WITH 20' GUN WITH PRESSURE AND TEMPERATURE. BROUGHT ON GAS LIFT AND PREPARED TO PUMP 60/40 DOWN TUBING TO OBTAIN 200PSI UNDER BALANCE. *** CONTINUE AWGRS ON 19-APR-08 *** END1-21 4/18/2008 T/I/0= 1600/1450/250 Temp= SI Assist E-line (Post RWO) Pumped 5 bbls 60/40 meth down tbg to load. *** Job continued on 4-19-08 WSR*** END1-21 4/19/2008 *** Job continued from 4/18/08 WSR*** Assist E-line (Post RWO) Pumped 30 bbls 60/40 meth down Tbg to load. Final WHPs 1800/1400/0 (IA/OA casing valves open to gauges t time of departure) Print Date: 4/19/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.coin/WIInfo/Reports/ReportViewer. aspx Page 2 of 2 4/19/2008 • • BP EXPLORATION Page 1 of 13 Operations Summary Report Legal Well Name: 1-21/K-25 Common Well Name: 1-21/K-25 Spud Date: 1/10/1990 Event Name: WORKOVER Start: 3/19/2008 End: 4/17/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/30/2008 Rig Name: DOYON 16 Rig Number: ~ I Phase ~ Description of Operations Task Code ~ NPT Date I From - To Hours .. ~ - 3/15/2008 _ 00:00 - 03:00 3.00 - RIGD P PRE Continue to R/D rig floor and prepare to move off END 1-67. R/D circulating lines. PJSM with Endicott Well Tender and rig crew. Discuss moving off well in close proximity of neighboring wells. Discuss Endicott and Doyon policies. Blow down lines, R/D circulating manifold and lines. Remove rig equipment from tree and install blank flanges, OA ad IA valves and tree guages. Secure well. 03:30 - 05:30 2.00 RIGD P PRE Move rig off Endicott 1-67 with Well Tender present. UD Herculite and set rig mats for R/U on Endicott 1-21. 05:30 - 08:00 2.50 RIGU P PRE Move rig over Endicott 1-21, shim up and set rig down on mats with Well Tender present. 08:00 - 11:30 3.50 RIGU P PRE Set Slop Tank, #4 Generator, and Mud Pump Skid. Rig up circulating manifold and Choke and Kill lines in Cellar. Take on 120-F 9.2-ppg brine to Pits. Accept rig at 0900-hours. Warm up Cellar and continue to take on hot 9.2-ppg brine to Pits. 11:30 - 13:30 2.00 WHSUR P DECOMP P/U DSM Lubricator install on tree and test to 500-psi. Latch pulling rod into BPV and ull. The well went onto a small vacuum, for a few seconds then was dead. Pull the BPV, shut master valve, UD the DSM lubricator. Drain diesel from Tree. R/U to circulate 120-F, 9.2-ppg brine kill fluid. Continue to take on 9.2 brine. Wait on last brine truck to start well kill circulation. 13:30 - 17:30 4.00 KILL P DECOMP Hold PJSM with Rig Crew, Truck drivers, MI Mud Engineer, Toolpusher, and WSL to discuss the well-kill and staging the trucks during the well-kill. Start pumps at 3-1/2-BPM and 400-psi. Lead with HiVis sweep. Increase pumps to 7-1/2BPM and 1,400-psi. Circulate for full wellbore volume, 914-Bbls, taking returns to the Slop Tank. Get back -10-15-Bbls of diesel freeze protect fluid. 17:30 - 18:30 1.00 KILL P DECOMP Monitor well. R/D circulating equipment and clear floor. 18:30 - 20:30 2.00 BOPSU P DECOMP R/U and set TWC. R/U and test TWC to 3500 psi from above. hold test for 10 charted minutes) ood test. R/U and test TWC to 2500 psi from below, hold test for 30 charted min e test. R/D testing equipment. 20:30 - 21:00 0.50 BOPSU P DECOMP Continue to R/D circulating equipment and prepare to N/D Tree. 21:00 - 22:30 1.50 BOPSU P DECOMP N/D Tree and adapter flange. 22:30 - 23:00 0.50 BOPSU P DECOMP FMC Tech inspected hanger and threads. M/U X/O into hanger with 9.5 turns. 23:00 - 00:00 1.00 BOPSU P DECOMP N/U BOPE stack onto wellhead. 3/16/2008 00:00 - 03:30 3.50 BOPSU P DECOMP Continue to install and NiD BOPE. Install choke and kill lines. Install riser and flow line. 03:30 - 04:00 0.50 BOPSU P DECOMP R/U rig floor and equipment for testing BOPE. Fill Stack and lines. 04:00 - 13:00 9.00 BOPSU P DECOMP Test BOPE 250-psi low and 3,500-psi high. Change out upper set of variable pipe rams to 2-7/8" x 5". Continue BOPE Testing. Successfully tested all of the Choke and Kill Manifold valves 13:00 - 16:00 3.00 BOPSU P DECOMP Continue to test BOPE 250-psi low and 3,500-psi high. Attem t to test low pipe rams and could not get any test to hold, although the leakoff rates were low. Repositioned an retested landing joints to no avail. Called DSM to change out the TWC. 16:00 - 17:00 1.00 BOPSU P DECOMP P/U DSM lubricator and RIH to pull the TWC. 10-psi under the Printed: 4/11/2008 12:29:24 PM BP EXPLORATION Page 2 of 13 Operations Summary Report Legal W ell Name: 1-21/K-25 Common Well Name: 1-21/K-25 Spud Date: 1/10/1990 Event Name: WORKOVER Start: 3/19/2008 End: 4/17/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/30/2008 Rig Name: DOYON 16 Rig Number: Date I From - To Hours Task Code ~ NPT ~ Phase I Description of Operations 3/16/2008 16:00 - 17:00 1.00 BOPSU P DECOMP TWC, but no pressure on IA, since it was open to check for any leaks. The 10-psi bled off immediately through a needle valve. Installed another TWC and tested underneath to 2500-psi. Blow down lines. 17:00 - 23:00 6.00 BOPSU P DECOMP Resume testing BOPE. P/U 4-1/2" test joint. Fill stack and warm water and apply steam to stack. Attempt to test bottom ~ set of variable pipe rams without success. Tested upper pipe rams and annular w/ 4-1/2" test joint. L/D 4-1/2" test joint and P/U 3-1/2" test joint. Test upper variable pipe rams and annular with 3-1/2" test joint. Attempt to test low pipe rams without success. Work function lower rams and attempt to retest without success. 23:00 - 00:00 1.00 BOPSU P DECOMP Open lower pipe ram doors and change out 3-1/2" x 6" variable pipe rams with 3-1/2" standard pipe rams. 3/17/2008 00:00 - 02:00 2.00 BOPSU P DECOMP Continue to change out lower pipe rams replacing 3-1/2" x 6" variable pipe rams with 3-1/2" standard pipe rams. 02:00 - 03:00 1.00 BOPSU P DECOMP Install 3-1/2" test joint and attempt to test 3-1/2" lower pipe . rams. No success. Notice very slight amount of flow coming from sides of pipe rams. 03:00 - 05:30 2.50 BOPSU P DECOMP Open lower pipe ram doors. Inspect ram seals and wear plate seals. Replace the 3-1/2" fixed rams with the re-dressed (replaced the upper seal plate) 3-1/2" x 6" variable rams. Check 3-1/2" and 4-1/2" test joints for roundness and find no eccentricity. 05:30 - 08:30 3.00 BOPSU P DECOMP RIH with 3-112" donut test joint. Test at 250-psi low and 3,500- si hi h. Hi h test does not hold. Discuss with FMC tech and decide to increase the torque on the LDSs from 450-Ib-ft to 550-Ib-ft and retest. Pull 3-1/2" test joint and P/U and RIH with 4-1/2" donut test joint. Test Lower VBRs to 250-asi low and 3 500- si hi h. Good tests. Pull 4-112" test 'oint and RIH with 3-1/2" test'o'nt - 08:30 - 09:30 1.00 BOPSU P DECOMP P/U DSM lubricator and install in BOP stack. Test to 500-psi. Screw into TWC and pull from hanger. Tubing on slight vacuum, IA has slight flow--well is slightly out of balance as stack is draining into tubing. 09:30 - 10:30 1.00 PULL P DECOMP R/U to pull tubing hanger to floor. Hold PJSM with rig crew, FMC tech, Schlumberger Spooler Techs (one is from Schlumberger's Product Services Group--Oklahoma City), Toolpusher and WSL. FMC and one Floorhand BOLDSs. P/U landing joint and M/U to XO and RIH and screw into hanger for 9-1/2 turns. M/U Top Drive to landing joint. P/U to 103,000-Ibs and hanger comes free easily; increase to 125,000-Ibs and string comes free with drag up to 135,000-Ibs. When Hanger is at floor, the FMC tech pointed out a damaged area on the top of the sealing element on the hanger. 10:30 - 13:30 3.00 PULL P DECOMP Circulate Bottoms up 11.5-BPM at 1820-psi. Start getting some gas breakout after 800-Bbls so decrease circulation to 8-BPM, 11 DO-psi. S/D after a total of 1900-Bbls (two full wellbore volumes) pumped to monitor well. 13:30 - 13:45 0.25 PULL P DECOMP Gas breaking out from fluid inside the Drilling Riser, but fluid level slowly dropping. Call ADW Engineering and Workover Superintendent and decide to continue wellbore circulation. 13:45 - 15:15 1.50 PULL P DECOMP Gas breakout stopped after 210-Bb1s pumped 8-BPM at Printed: 4/11/2008 12:29:24 PM BP EXPLORATION Page 3 of 13 Operations Summary Report Legal Well Name: 1-21/K-25 Common Well Name: 1-21/K-25 Spud Date: 1/10/1990 Event Name: WORKOVER Start: 3/19/2008 End: 4/17/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/30/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations ~ 3/17/2008 13:45 - 15:15 1.50 -- PULL P -- _ DECOMP -_ 1100-psi. Continue for additional 600-Bbls, and S/D to monitor well. 15:15 - 16:00 0.75 PULL P DECOMP No gas breakout at surface. Well is dead. There was no fluid loss or gain during the entire circulation process after the anger was pulled to the Rig Floor. Blow down Top Drive and prepare to POH with 3-1/2" tubing. 16:00 - 00:00 8.00 PULL P DECOMP POH and UD 3-1/2" completion string. Recover 257 joints of 3-1/2" tubing at 23:30 hrs. Tubing condition is good with no visible signs of corrosion. Recovered tubing hanger assembly, SSSV assembly with 3 stainless steel band and 22 clamps, and 1 GLM assembly. 3/18/2008 00:00 - 04:00 4.00 PULL P DECOMP Continue to POH and UD 3-1/2" completion string. Tubing condition is good with only slight visible signs of internal corrosion. 04:00 - 04:30 0.50 PULL P DECOMP WSL and Toolpusher manually increased flow indicator and increased trip tank level to simulate a kick while tripping. Rig crew response was good. After stabbing the TIW valve and simulating securing the well, the rig team held a drill evaluation. Discussed what went right and where improvement could be made. Discussed any question the rig hands had about there individual assignments or situation. 04:30 - 05:00 0.50 PULL P DECOMP Continue to POH and UD 3-1/2" completion string. Tubing condition is good with only slight visible signs of internal corrosion. Final recovery: 412 joints of 3-1/2" tubing and 1 cut off joint joint of 8.98', 4 GLM assemblies, 1 SSSV assembly, 1 tubing hanger assembly, 3 bands, and 22 clamps. Jet cut was clean with 4-1/16" flair. 05:00 - 06:00 1.00 PULL P DECOMP Clear and clean rig floor. Gather Baker fishing tools. 06:00 - 08:00 2.00 CLEAN P DECOMP M/U BHA #1 to pull the SBR/Anchor assembly. Hollow Mill with 3-1/2" Insert Mill, O/S Bowl with 3-1/2" Grapple. XO Bushing, O/S Bowl with 3-1/2" Grapple, Extension, O/S Top Sub, XO Sub, Bumper, Jar, XO, 9 DC's (6-1/4"), XO, Intensifier, Pump Out Sub, XO. Total Length = 331.11 ft 08:00 - 20:00 12.00 CLEAN P DECOMP RIH with BHA #1 on 4" HT-38 drill pipe. P/U 402 joints of drill i e 1x1 from i e shed of 13,033'. 20:00 - 21:00 1.00 CLEAN P DECOMP Slip and cut 104' of drilling line. Service rig and inspect saver sub. 21:00 - 00:00 3.00 CLEAN P DECOMP Establish SPR. Establish fishing parameters of Up Wt- 212,000Ibs; Down Wt- 166,000 Ibs; Rotating Wt- 193,000 Ibs at 50 rpm with 7000 ft-Ibs free torque; Pump Pressure at 480 psi at 4 bpm. P/U joints 403 and 404. Tag top of tubing stump at 13,086'. P/U and confirm tag. Dress o ared tubing stub to 13,087' at 50 rpm and 9000 ft-Ibs torque and 1000 Ibs WOB. Pump rate at 4 bpm with 525 psi. Stop rotation and slide over tubing stump. P/U joint #405 and continue swallow 11' total of the tubing stump to engage grapple and confirm set with 50,000 Ibs overpull. Slack off to 210,000 Ibs and rotate 18 turns with 10,000 tt-Ibs torque at surface. Release torque and P/U to 235,000 Ibs where grapple slipped. Reset grapple with 250,000 Ibs up weight. S/O to 205,000 Ibs and attempt to release anchor latch with 17 turns and 10,000 ft-Ibs torque, release torque. P/U to 235,000 Ibs. S/O to cock jars and hit with jars at 250,000 Ibs for 3 cycles. S/O to 210,000 Ibs and Printed: 4/11/2008 12:29:24 PM BP EXPLORATION Page 4 of 13 Operations Summary Report Legal Well Name: 1-21/K-25 Common Well Name: 1-21/K-25 Spud Date: 1/10/1990 Event Name: WORKOVER Start: 3/19/2008 End: 4/17/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/30/2008 Rig Name: DOYON 16 Rig Number: Date I From - To Hours ', Task Code NPT Phase ~ Description of Operations 3/18/2008 21:00 - 00:00 3.00 CLEAN P DECOMP attempt to rotate out anchor latch with 12,000 ft-Ibs torque 3 times. P/U and jar on SBR and anchor latch at 275,000 Ibs pull for 3 cycles. Repeat 2 more cycles at 310,000 pull. S/O and attempt to rotate out anchor latch with up to 13,000 ft-Ibs torque 4 times. P/U and jar on fish 4 more cycles at 325,000 Ibs up weight (113,000 Ibs overpull). S/O and attempt to rotate out anchor latch with up to 19,000 ft-Ibs torque at surface. Continue jarring on fish at 325,000 Ibs up weight and dead puling to 400,000 Ibs and attempting to release anchor latch. 3/19/2008 00:00 - 03:30 3.50 CLEAN P DECOMP Continue to jar on fish with 325,000 Ibs up weight (113,000 Ibs overpull) and dead pulling to 350,000 and 400,000 Ibs. Attempt to release anchor latch with up to 19,000 Ibs torque at surface. Continue to work torque to 18,000 ft-Ibs and hold torque. Work torque to fish several times. Make several cycles. Fish came free with 1800 psi at .5 bpm. Drill string held pressure with pump off. Bleed off pressure at surface. Break connection, drop ball and rod to open circ sub. Monitor well. Well stable. 03:30 - 04:00 0.50 CLEAN P DECOMP Allow ball and rod to reach circ sub. Open circ sub with 1000 psi. 04:00 - 05:00 1.00 CLEAN P DECOMP CBU at 11.5 bpm with 3120 psi. Bottoms up was clean with no qas or crude. No losses/No Gains. 05:00 - 05:30 0.50 CLEAN P DECOMP Monitor well. Pump slug and blow down top drive. 05:30 - 11:00 5.50 CLEAN P DECOMP POOH standing back 4" HT-38 drill pipe in derrick. 11:00 - 12:00 1.00 CLEAN P DECOMP UD Intensifier, Stand Back DC's, and UD Bumper Sub and Jars. 12:00 - 14:00 2.00 CLEAN P DECOMP Review tbg punch procedures with crew. B/O and UD 3-1/2" Tbg Fish. Recovered remaining cut joint, 10 ft Pup Joint, Sliding Sleeve, 10 ft Pup Joint, and 6 ft Pup Joint. Tbg was sever) cork screwed. Above the Sliding Sleeve Tbg was full of a dark grey colored sludge. Unknown what sludge is, has the consistancy of tooth paste. Tbg was punched several times above the Sliding Sleeve and once below Sliding Sleeve. Unable to B/O Tbg with rig tongs due to its geometry, cut tubing with manual pipe cutter to managable sizes. 14:00 - 14:30 0.50 CLEAN P DECOMP Clear and Clean Rig Floor 14:30 - 16:00 1.50 CLEAN P DECOMP M/U BHA #2. 8-3/8" x 7-1/4" Rotary Shoe, 8-3/8"x7-1/2" Wash Pipe, XO Bushing, Drive Bushing, Float Sub with Ported Float, 3 Boot Baskets, Bumper Sub, Jars, 9 Dc's (6-1/4") Pump Out Sub. Total Length = 352.6 ft 16:00 - 21:00 5.00 CLEAN P DECOMP RIH with Rotary Shoe BHA on 134 stands of 4" HT-38 drill pipe from derrick to 13,055' 21:00 - 21:30 0.50 CLEAN P DECOMP Perform Kick while tripping drill with WSL and Toolpusher present. Crew response time was good. Each rig hand performed the task he was responsible for. Crew held drill evaluation meeting with Toolpusher and WSL. Discussed the response of the crew, the things that went right and the things that did not. Discussed the importance of getting the well shut in quickly. Discuss the importance of physically making sure that each valve is lined up correctly. Made sure that each crew member understood his role and the importance of understanding the reasons for the actions. 21:30 - 22:30 1.00 CLEAN P DECOMP Slip and cut 60' of drill line. Printed: 4/11/2008 12:29:24 PM • • BP EXPLORATION Operations Summary Report Legal W el I Name: 1-21 /K-25 Common Well Name: 1-21/K-25 Event Name: WORKOVER Start: 3/19/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/30/2008 Rig Name: DOYON 16 Rig Number: Date ~ From - To Hours Task 'Code NPT 3/19/2008 122:30 - 23:30 1.00 CLEAN P 23:30 - 00:00 3/20/2008 00:00 - 01:00 01:00 - 06:00 06:00 - 07:30 07:30 - 08:00 08:00 - 13:00 13:00 - 21:00 0.50 CLEAN P 1.00 CLEAN P 5.00 CLEAN P 1.50 CLEAN P 0.50 CLEAN P 5.00 CLEAN P 8.00 CLEAN P 21:00 - 21:30 0.50 CLEAN P 21:30 - 00:00 2.50 CLEAN P 3/21 /2008 100:00 - 02:30 02:30 - 03:00 2.501 CLEAN I P 0.501 CLEAN I P Page 5 of 13 Spud Date: 1 /10/1990 End: 4/17/2008 Phase ~ Description of Operations DECOMP Establish parameters of Up Wt- 223,000 Ibs; Down Wt- 164,000Ibs; Rotating Wt- 194,000 Ibs at 50 rpm with 7000 ft-Ibs free torque; Pump Rate- 5 bpm with 700 psi. Continue RIH. Dry tag top of crossover sub at 13,139'. P/U and reconfirm tag. Launch high visc sweep. Wash and ream over x/o and SBR barrel to 13,148' without any weight on bit or excess torque. P/U single and make connection. Continue wash and ream over SBR. Tag fill at 13,151'. Wash and ream through fill with - 9,000 to 10,000 Ibs torque and 5000 Ibs WOB. Increase pump rate to 7.5 bpm with 1650 psi. Continue wash and reaming to 13,154'. Launch second high visc sweep. DECOMP Circulate high visc sweeps at 11 bpm with 3600 psi. First sweep brought back a noticeable increase of a thick paraffin type substance at the shakers. Second sweep did not have any noticeable increase in junk at the shakers. DECOMP Circulate high visc sweeps at 11 bpm with 3600 psi. First sweep brought back a noticeable increase in a thick paraffin type substance at the shakers. Second sweep did not have any noticeable increase in junk at the shakers. DECOMP POOH with rotary shoe assembly standing back 4" HT-38 drill pipe in derrick. DECOMP Stand Back DC's and L/D BHA #2. Empty Boot Baskets, recovered -4 gallons on what looks like mostly formation sand with some metal shavings mixed in. Rotary Shoe still in great shape, hardly any wear. DECOMP M/U BHA #3. Short Catch Overshot with 4-1/2" Nominal Grapple, Bumper, Jars, 9 DC's (6-1/4") Intensifier, and Pump Out Sub. Total Length = 319.96' DECOMP RIH w/ BHA#3 on 4" HT-38 drill pipe from derrick. DECOMP Establish SPR. Establish fishing parameters of Up Wt- 223,000Ibs; Down Wt- 163,000 Ibs; Rotating Wt- 190,000 Ibs at 40 rpm with 7500 ft-lbs free torque; Pump Pressure at 430 psi at 4 bpm. Tag top of tubing stump at 13,139'. P/U to engage grapple with 25,000 Ibs overpull. Let jars bleed off and attempt to rotate out anchor latch. Grapple slipped off immediately. S/O again and engage fish. P/U and attempt to jar SBR free starting with 25,000 Ibs overpull and worked up to 102,000 Ibs overpull. Dead pull with 152,000 Ibs overpull. Continue to make periodical attempts to rotate out anchor latch with up to 16,500 ft-Ibs surface torque before stalling out. No success rotating anchor latch out or jarring SBR free made 7 attempts total. Consult town rig team. Decision made to release from fish and run with washpipe and burn over PKR. DECOMP Slack off and set 15,000 Ibs down. Rotate to the right and stalled out at 15,000 ft-Ibs. On second attempt the grapple released with 8000 ft-Ibs of torque. Monitor well and pump slug. Blow down top drive. DECOMP POOH with overshot and grapple standing back 4" HT-38 drill pipe in derrick. DECOMP Continue to POOH with overshot and grapple standing back 4" HT-38 drill pipe in derrick DECOMP POOH with BHA #3 (overshot and grapple assembly). Stand Printed: 4/11/2008 12:29:24 PM • 0.50 CLEAN P 1.00 CLEAN P 6.00 CLEAN P BP EXPLORATION Operations Summary Report Legal Well Name: 1-21/K-25 Common Well Name: 1-21 /K-25 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 i Date From - To Hours Task ,Code NPT 3/21 /2008 102:30 - 03:00 03:00 - 04:00 04:00 - 10:00 10:00 - 11:00 1.00 CLEAN P 11:00 - 21:00 10.00 CLEAN P 21:00 - 21:30 Page 6 of 13 Spud Date: 1/10/1990 Start: 3/19/2008 End: 4/17/2008 Rig Release: 3/30/2008 Rig Number: Phase Description of Operations DECOMP back 3 stands of 6-1/4" drill collars and UD intensifiers, overshot and grapple. DECOMP P/U BHA #4 (Rotary Mill with washpipe extensions) consisting of rotary shoe, 2 joints of washpipe extensions, x/o bushing, drive sub, x/o sub, (3) 7" OD boot baskets, bit sub, bumper sub, jars, x/o sub, 3 stands of 6-1/4" drill collars from derrick, x/o sub, pump out sub, and x/o sub back to HT-38 drill pipe. Total length of BHA #4- 352.06'. DECOMP RIH with rotary mill assembly on 4" HT-38 drill pipe from derrick. DECOMP Slip and Cut 88' of Drilling Line. Service Dynamatic Spline and Saver Sub. DECOMP M/U Top Drive and Establish Parameters. Up Wt = 217,000 Ibs Dw Wt = 169,000 Ibs Rot Wt = 195,000 Ibs ~ 60 rpm's and 7,000 ft- Ibs free torque. Pump Rate 6 bpm and 1040 psi. Tag Up on Top of Packer at 13153'. Burn Over TIW packer with 7,000 - 15,000 Ib WOB, 40-70 RPM's and 7,000-14,000 ft-Ibs torque. Vary Pump Rate from 2.5 bpm with 250 psi to 8 bpm and 1700 psi. Pump 20 bbl High Visc Sweeps to help sweep cuttings. Sweeps broght back minor amounts of fine metal shavings. Continue milling with varied parameters to 19:52 hrs and 13,155' where the well started taking fluid at a rate of 9 b h. Continue milling and monitoring losses. Packer ave wa at - 13,155.5' . Well still taking fluid. 0.50 CLEAN P DECOMP Chase Packer Down Hole to top of 7" liner to confirm free. Top of fish at 13.176'. oacker at 13,192', bottom of tail pipe 21:30 - 22:00 0.50 CLEAN N DPRB DECOMP Observe it ain of 11 bbls and flow increase from 23% to 42%. Shut down pump and visually check for flow, well flowing and churnin .Shut in well and line u on closed choke, allow pressures to stabilize. SIDPP ~ 0 psi, SICP 120 psi. Total pit ain- 17 bbls. 22:00 - 00:00 2.00 CLEAN N DECOMP Roll pump and observe no SIDPP while opening float. Bring pump #2 up to 4 bpm while maintaining constant casing pressure at 120 psi to ICP of 250 psi. Maintain 250 psi while circulating gas out of well. Increase pump rate to 6 bpm while maintaining constant casing pressure to circulating pressure of 750 psi. Allow pressure to stabilize. Bring pump rate up to 7 bpm maintaining constant casing pressure to circulating pressure of 1000 psi. Continue to circulate at 7 bpm. Lower pump rate back to 6 bpm while maintaining constant casing pressure due to choke being 100% open and drill pipe pressure rising due to gas is being circulated out of the casing. Maintain rate of 6 bpm and 950 psi for the rest of the kill operation. Notified Lou Grimaldi with AOGCC of current Well Control O eration at 22:30 hrs. Discussed the plan forward of testing BOPE used in this Well Control Situation. Lou asked to be notified if weighting up brine was necessary and to let him know when the well was stable if weighting up was needed. '3/22/2008 00:00 - 01:00 1.00 CLEAN P DECOMP Continue to circulate at 6 bpm and 950 psi. Circulated a total of 866 bbls to account for bottoms up and losses. 01:00 - 01:30 0.50 CLEAN P DECOMP Shut down mud pump and monitor well for flow. No flow. Confirm choke 100% open and open annular preventer. Small Printed: 4/11/2008 12:29:24 PM BP EXPLORATION Operations Summary Report Legal W el I Name: 1-21 /K-25 Page 7 of 13 Common Well Name: 1-21/K-25 Spud Date: 1/10/1990 Event Name: WORKOVER Start: 3/19/2008 End: 4/17/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/30/2008 Rig Name: DOYON 16 Rig Number: Date ~ From - To I Hours i Task Code NPT Phase Description of Operations 3/22/2008 01:00 - 01:30 0.50 CLEAN P DECOMP amount of gas still braking out at surface. 01:30 - 03:00 1.50 CLEAN P DECOMP Pump 40 bbl high visc sweep at 11.3 bpm with 2570 psi. Monitor well for gas though out the circulation. Gas stopped braking out shortly after start of circulation. Sweep did not bring any noticeable junk to surface. Dynamic loss rate at 7 bph while circulating sweep. Monitor well. No gas and losing fluid at 3 bph. 03:00 - 03:30 0.50 CLEAN P DECOMP Blow down top drive and pump dry job slug. 03:30 - 07:30 4.00 CLEAN P DECOMP POOH standing back 4" HT-38 drill pipe in derrick. Fluid losses at 3 bph while POOH. 07:30 - 09:00 1.50 CLEAN P DECOMP Stand Back DC's. B/O and UD Pump Out Sub, Jars, Bumper Sub, Boot Baskels, Wash Pipe Extensions, and Rotary Shoe. Clean Out Boot Baskets, collected ~2.5 - 3 gallons of metal shavings with rubber mixed in. Rotary Shoe in good shape, it was well worn but still had carbide facing left. 09:00 - 09:30 0.50 CLEAN P DECOMP Clear off Rlg FLoor 09:30 - 10:30 1.00 BOPSU P DECOMP Pull Wear Ring. Set Test Plug. M/U Test Joint. Rig Up BOPE Test Chart and Equipment. 10:30 - 12:00 1.50 BOPSU P DECOMP Test BOPE used when circ out Qas from wellbore. Test as per AOGCC Regs to 250 psi low and 3500 psi high for 5 mins each. Test Annular with 4" and 4-112" Test Joints. Test NCR Kill and HCR Choke. 12:00 - 12:30 0.50 BOPSU P DECOMP Pull Test Plug and Set Wear Ring. 12:30 - 13:30 1.00 CLEAN P DECOMP M/U BHA #5 with 8-1/8" Short Catch Overshot with 4.5" Nominal Grapple, Bumper Sub, Jars, 9 DC's (6-1/4"), Intensifier, Pump Out Sub. 13:30 - 18:00 4.50 CLEAN P DECOMP RIH with 135 stand of 4" HT-38 drill pipe to 13,118'. 18:00 - 19:00 1.00 CLEAN P DECOMP Establish fishing parameters of Up Wt- 229,000 Ibs; Down Wt- 163,000Ibs; Rotating Wt- 197,000 Ibs with 7000 ft-Ibs free torque; Pump Rate- 4 bpm with 400 psi. Continue pumping at 4 bpm while continue RIH to ta4 fish at 13,176'. Stack out 15,000 Ibs on fish, pump pressure increased to 1800 psi. P/U 14' with no overpull. Set back down on fish with pressure increase. P/U with 20,000 Ibs overpull. Set back down and confirm set with 7000 Ibs overpull. Break connection and drop ball and dart to open pump out sub. Pump dart to sub at 2 bpm with 210 psi. and open circ sub. Confirm fish on overshot and grapple by P/U to next tool joint with 70,000 Ibs overpull. 19:00 - 20:30 1.50 CLEAN P DECOMP Circulate bottoms up at 10.4 bpm with 2180 psi losing fluid at 5 bph. 20:30 - 00:00 3.50 CLEAN P DECOMP POOH standing back 4" HT-38 drill pipe in derrick. Overpull up to 70,000 Ibs was noticed several times while POOH. 3/23/2008 00:00 - 02:00 2.00 CLEAN P DECOMP POOH standing back 4" HT-38 drill pipe in derrick. Overpull up to 70,000 Ibs was noticed several times while POOH. 02:00 - 03:00 1.00 CLEAN P DECOMP POOH with overshot/grapple BHA. Stand back 3 stands of drill collars. UD Jars, bumper sub, intensifier, and subs. 03:00 - 05:00 2.00 CLEAN P DECOMP PJSM with rig crew covering doyon procedures for punching tubing pulled out of hole. POOH with full recovery. Recovered 4-1/2" x 3-1/2" X/O, overshot seal assembly, TIW HBBP PKR, 5-1/2" millout extension, 5-1/2" x 3-1/2" X/O, 1 full joint of 3-1/2" TBG, (4) 3-1/2" pup joints, (1) 3-1/2" X-nipple with xx plug, (1) 3-1/2" XN-nipple, WLEG, and 1 bow spring centralizer around the WLEG. The tubing above the x-nipple was filled with the Printed: 4/11/2008 12:29:24 PM • BP EXPLORATION Operations Summary Report Page 8 of 13 Legal Well Name: 1-21 /K-25 Common Well Name: 1-21/K-25 Spud Date: 1/10/1990 Event Name: WORKOVER Start: 3/19/2008 End: 4/17/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/30/2008 Rig Name: DOYON 16 Rig Number: Date I From - To Hours ' Task I Code I NPT 3/23/2008 03:00 - 05:00 2.00 ~ CLEAN P 05:00 - 06:00 I 1.00 I CLEAN I P 06:00 - 08:00 I 2.001 CLEAN I P 08:00 - 11:00 3.00 CLEAN P 11:00 - 13:30 2.50 CLEAN P 13:30 - 16:00 2.50 CLEAN P 16:00 - 16:30 ~ 0.501 CLEAN ~ P 16:30 - 17:30 1.00 CLEAN P 17:30 - 19:30 2.00 CLEAN P 19:30 - 20:30 I 1.00 I CLEAN i P 20:30 - 21:30 1.001 CLEAN ~ P 21:30 - 00:00 I 2.501 CLEAN P 3/24/2008 ~ 00:00 - 02:00 ~ 2.00 ~ CLEAN ~ P 02:00 - 03:30 I 1.501 CLEAN I P 03:30 - 04:00 0.50 CLEAN P 04:00 - 05:00 1.00 CLEAN P 05:00 - 06:30 1.50 CLEAN N WAIT 06:30 - 09:00 2.50 CLEAN N WAIT 09:00 - 15:00 I 6.001 CLEAN I P Phase ' Description of Operations DECOMP same gray paste found in prior fish brought to surface. Most of the tubulars were in good shape. SBR barrel was partially separated from the shear pins below. Total length of fish- 95.66' DECOMP Clear and clean rig floor. Gather Subs and pieces for CLean Out BHA. DECOMP M/U BHA #6. 6" Bit, 7" Csg Scraper, (2) 4-3/4" Boot Baskets, X/O Sub, Bumper Sub, Jars, Pump Out Sub, X/O Sub, (12) 4-3/4" Drill Collars, 16 Joints of 4" HT-38 DP, X/O Sub, X/O Sub, 9-5/8" Csg Scraper, X/O Sub. Total Length = 914.03' DECOMP RIH with 4" HT-38 Drill Pipe from Derrick. DECOMP PJU 4" HT-38 Drill Pipe from Pipe Shed and Continue to RIH. DECOMP M/U Top Drive. Establish Parameters; Up Wt = 215,000 Ibs Dw Wt = 165,000 Ibs Rot Wt = 187,000 Ibs with 50 rpms and 7,000 ft-Ibs free torque. Pump Rate 8.3 bpm at 1710 psi. Wash and Ream from 13,776' - 13,973'. From 13,973' to 14,040' Drill Cement and Shoe Track. Pump Multiple High Visc Sweeps while Drilling Cement. Work Multiple Times from 14,040'to 13,950'. Wlth Bit at 14,040' 9-5/8" Casing Scraper at 13,125'. Cement drill relative easliy, required 5-8K Ibs WOB and 10-12K ft-Ibs torque to drill cement. First sweep bought in increase in fine metal cuttings to surface. The rest of the sweeps did not bring a noticeable increase in cuttings to surface. DECOMP PJSM with rig Crews and Vac Truck drivers on displacement to clean brine. DECOMP Off load pits 1, 2, 4 and take on clean brine. DECOMP Pump 20 bbl High Visc Sweep/Spacer and Chase with Clean 9.2 ppg at 80 deg F at 9 bpm with 2200 psi. DECOMP Blow down top drive and drop 2.25" hollow drill pipe drift. POOH to the top of the 7" Liner racking back 11 stands of 4' HT-38 drill pipe in derrick. DECOMP PJSM covering Doyon procedures for Slip and Cutting drill line. Slip and cut 75' of drill line. DECOMP POOH with clean out assembly standing back 4" HT-38 drill pipe in derrick. DECOMP POOH with clean out assembly standing back 4" HT-38 drill pipe in derrick. DECOMP POOH with clean out assembly (BHA #6) standing back 4" HT-38 drill pipe. UD 4-3/4" drill collars, jars, bumper sub, x/o subs, scrapers, boot baskets, and bit. Boot baskets had -1/2 gallon of cement various metal debris including 2 pieces of bow spring centralizer. DECOMP Clear and clean rig floor. Clear floor of Baker fishing tools. DECOMP R/D flow line and riser on top of BOPE stack. P/U and N/U shooting flange. DECOMP Wait on SWS. DECOMP Make call to AOGCC and give 1 hour notice of BOPE test. N/D and R/D shooting flange from BOPE. P/U and N/U flow line and riser. P/U landing joint and pull wear ring. Set test plug. R/U to test BOPE. DECOMP Test BOPE to 250 psi low pressure and 3500 psi high pressure. Each test was held for 5 charted minutes. Pipe Printed: 4/11/2008 12:29:24 PM • BP EXPLORATION Page 9 of 13 Operations Summary Report Legal Well Name: 1-21 /K-25 Common Well Name: 1-21/K-25 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task I Code NPT 3/24/2008 109:00 - 15:00 6.00 CLEAN~~ 15:00 - 15:30 0.50 CLEAN P 15:30 - 16:00 0.50 CLEAN P 16:00 - 17:00 1.00 CLEAN P 17:00 - 22:00 5.00 EVAL P 22:00 - 00:00 2.00 EVAL P 3/25/2008 00:00 - 05:00 05:00 - 07:00 07:00 - 08:00 08:00 - 09:30 5.00 EVAL P 2.00 EVAL P 1.00 EVAL P 1.50 CASE P Spud Date: 1 /10/1990 Start: 3/19/2008 End: 4/17/2008 Rig Release: 3/30/2008 Rig Number: Phase Description of Operations DECOMP rams were tested with 2-7/8", 4", and 4-1/2" test joints. Test were witnessed by AOGCC inspector Bob Noble and Doyon toolpusher and BPX WSL. DECOMP R/D BOPE testing equipment and blow down lines. DECOMP P/U landing joint and pull test plug. Set wear ring. DECOMP R/D flow line and riser on top of BOPE Stack. P/U and N/U shooting flange. DECOMP PJSM with SWS cover Doyon rigging up procedures. Discuss part, component, and hazards of SWS E-Line and BOPE equipment. R/U SWS USIT logging tools. R/U SWS E-line with full pressure control of lubricator, extension, BOPE, pump in sub, and grease head with line wiper. Pressure test to 3500 psi, good test. DECOMP RIH with SWS USIT logging equipment at 100 fpm logging fluid properties to 13,175'. Begin logging up at 80 fpm in cement/corrosion mode with 5 deg per 6 inch resolution. DECOMP continue with SWS USIT logging equipment at 100 fpm ,logging fluid properties to 13,175'. Begin logging up at 80 fpm in cement/corrosion mode with 5 deg per 6 inch resolution. DECOMP i PJSM with SWS, cover rigging down SWS tools and equipment. POOH with SWS USIT logging tool. R/D SWS. DECOMP N/D Shooting Flange and N/U Flow Riser TIEB1 PJSM on Running Liner. R/U to Run Liner. Rig Up Power Tongs, Long Bails, Compensator, Single Joint P/U Sling, and Torque Turn. 09:30 - 13:30 4.00 CASE P TIEB1 M/U 4-1/2" Liner and RIH filling every five joints. 4-1/2" HES Cement Shoe, Jt of 4-112" L-80 IBT w/ Centrilizer, HES Float Collar, Jt of 4-1/2" L-80 w/ Centrilizer, Baker Landing Collar, Jt of 4-1/2" L-80 with w/ Centrilizer and NSCT Box, 20 Jts of 4-1/2" 12.6# 13Cr80 NSCT w/ 1 centri{izer per jt, 4-112" NSCT Pin x 5-1/2" Vam Top Box XO, (2) 5-1/2" 17# 13Cr80 Vam Top Pup Jts, 5-1/2" Vam Top Pin x 7" BTC-M Box XO, Baker 'HMC' 7" x 9-5/8" Liner Hanger, Baker "C-2" ZXP 7"x9-5/8" Liner Top Packer. Total Length = 946.4 ft 13:30 - 14:00 0.50 CASE P TIEB1 Rig Down Torque Turn, Compensator, Single Joint P/U Sling, and Floor Valve 14:00 - 14:30 0.50 CASE P TIEB1 Rig Up Bails and elevators for RIH with Drill Pipe. 14:30 - 22:30 8.00 CASE P TIE61 RIH with 4-1/2" Liner on 4" DP from Derrick. Break Girculation on First Stand. Up Wt = 51,000 Ibs Dn Wt = 58,000 lbs. Continue to RIH with 4" DP filling every 10 stands. Weights at TOL Up Wt = 230,000 Ibs Dn Wt = 135,000 Ibs. Saw TOL at 13,212'. RIH inside 7", work through tight spot at 13,944. RIH to 14,038' 22:30 - 00:00 1.50 CASE P TIEB1 R/U Baker cementing head and circulating hoses. Tag bottom , at 14,040' P/U 5' off bottom. Break circulation at 6 bpm with 1,320 psi. HES Cmt Shoe at 14035'. 3/26/2008 00:00 - 02:00 2.00 CEMT P TIEB1 PJSM with all personnel involved. Pump 5 bbls of water. Pressure test lines to 4,500 psi. Pump 32 bbls of 15.8 ppg class G cement. Initial circulating pressure 5 bpm at 1,286 psi, ending circulating pressure 5 bpm at 751 psi. Kick out plug and displace with 154 bbls of brine. Pump at 6 bpm with 330 psi. Caught cement at 30 bbls away. 5 bpm at 830 psi. Did not see latch. Bumped plug with 1,000 psi increased pressure to 3,600 Printed: 4/11/2008 12:29:24 PM • • BP EXPLORATION Page 10 of 13 Operations Summary Report Legal Well Name: 1-21/K-25 Common Well Name: 1-21/K-25 Spud Date: 1/10/1990 Event Name: WORKOVER Start: 3/1912008 End: 4/17/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/30/2008 Rig Name: DOYON 16 Rig Number: Date ~~ From - To Hours I, Task I Code II NPT I Phase ~, Description of Operations 3/26/2008 00:00 - 02:00 2.00 CEMT P TIEB1 psi and set hanger. Slack off 40,000 Ibs and insure that hanger is set. Bleed off pressure and check floats, floats holding. CIP at 01:30 hours. 02:00 - 03:00 1.00 CASE P TIEB1 Rotate 23 turns to the right and release running tool, P/U 10' and expose locking dogs. Rotate down at 15 RPM and set down with 40,000 Ibs. Saw positive indication that packer set. Repeat 2 more times. 03:00 - 04:00 1.00 CASE P TIEB1 Pressure up to 1,000 psi and P/U until pressure dropped. Closed rams and reverse circulated at 6 bpm with 1,680 psi. 8 - 04:00 - 05:30 1.50 CASE P TIE61 Pump 20 bbl biozan sweep around at 12 bpm with 3,040 psi. No cement returns, some sand in returns. 05:30 - 09:30 4.00 CASE P TIEB1 POOH with Liner Running Tool & stand back 4" DP. 09:30 - 10:30 1.00 CASE P TIEB1 L/D Baker "C-2" Liner Running Tool, Rotating Dog Sub, Sleeve Pack Off and DP Pup Jt. 10:30 - 11:00 0.50 WHSUR P TIEB1 R/U and Pull Wear Ring. 11:00 - 12:00 1.00 WHSUR P TIEB1 M/U Pulling Tool for Pack Off. RIH and Engage 9-5/8" FMC Mandrel Pack Off. Check Pressures on OA through needle valve -confirm dead, OA has been open to bleed since intial circ out. Back Out Lock Down Screws. 12:00 - 12:30 0.50 WHSUR P TIEB1 FMC Confirmed all Lock Down Screws Backed Out. P/U on Pack Off and work up to 65,000 Ibs then slack back off to Block Wt. Repeat three times working up to 65,000 Ibs. See small bit of movement. P/U on Pack Off and work up to 75,000 Ibs and then slack back to Block Wt. Repeat three times. Pack Off still not moving. P/U to 80,000 Ibs (40,000 Ibs over) and Pack Off started to inch up. Slowly work Pack Off up -1 ft. Notice bubbling diesel in Stack. Slack Back Off with Pack Off and Re-Seat, bubbling diesel subsided. No gas alarms or H2S alarms tripped. 12:30 - 15:30 3.00 WHSUR N TIEB1 Check OA Pressure off needle valve again, no pressure. Contact BP RWO Supt, DRLG HSE Advsior, Town Engineers, and Wells Manager. Addressed all of findings. Talked with FMC and Valve Shop on what the problem might be. Confirm that Vavles not frozen -all are warm from heater and steaming well head prior to pulling Pack Off. Question Valve Shop of possible VR Plug. Pit Watcher mentioned did not feel well after diverting return line on shakers, head ache and nausea. Said he got a good whiff of diesel. Was sent to medic as percautionary measure. Issued O/C medication for headache and told to rest -First Aide. 15:30 - 19:00 3.50 WHSUR N TIEB1 Verify VR plug installed with DSM and FMC wellhead tech. Install 2-1/16" valve on OA outlet. R/U lubricator and pull VR plug, R/D lubricator. 19:00 - 20:00 1.00 WHSUR N TIE61 N/U double valve and 2" high pressure line to slop tank. Pressure test line to 1,000 psi. Good test. 20:00 - 22:30 2.50 WHSUR N TIEB1 Open up OA to bleed. Bled off quickly -5 gallons of fluid and little gas. Let OA vent, no futher signs of gas or fluid for 1-1/2 hours. 22:30 - 23:00 0.50 WHSUR N TIEB1 Held PJSM with all workers involved. Verify no pressure on OA. Pulled 9-5/8" packoff. No sign of flow or bubbling. Run in new 9-5/8" packoff. Printed: 4/11/2008 12:29:24 PM • • BP EXPLORATION Page 11 of 13 ~ Operations Summary Report Legal Well Name: 1-21/K-25 Common Well Name: 1-21/K-25 Spud Date: 1/10/1990 Event Name: WORKOVER Start: 3/19/2008 End: 4/17/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/30/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task j Code NPT Phase Description of Operations 3/26/2008 23:00 - 00:00 1.00 WHSUR N TIEB1 Run in lock down screws on 9-5/8" packoff. Test packoff to 3,360 psi for 30 minutes. 3/27/2008 00:00 - 00:30 0.50 WHSUR P TIEB1 Continue to test packoff to 3,360 psi for 30 minutes. Good test. 00:30 - 01:00 0.50 WHSUR P TIEB1 Install wear bushing. 01:00 - 01:30 0.50 CASE P TIE61 Service Top Drive, drawworks and skate. 01:30 - 04:00 2.50 CASE P TIEB1 M/U Liner Clean Out BHA. 3.70" Bladed Mill, (2) 3.5" Boot Baskets, XO, Oil Jar, XO, (9) 2.875" PAC DC's, (21) 2.875" PAC DP, XO, XO Total lenght= 922.72' 04:00 - 07:30 3.50 CASE P TIE61 RIH with Clean out BHA on 4" DP from Derrick. Tag TOL at 13,093' 07:30 - 08:30 1.00 CASE P TIEB1 RIH and tag at 13,890'. Establish parameters, Up Wt = 250,000 Ibs Dn Wt = 140,000 Ibs, Rotating Wt = 165,000 Ibs, pump rate 4.5 bpm with 2110 psi. 08:30 - 09:00 0.50 CASE P TIEB1 Wash down to 13,909'. 4.5 bpm with 2,110 psi. 09:00 - 10:30 1.50 CASE P TIEB1 Blow down Top Drive, RIU circulating head and hose. Pressure test casing to 3 360 psi for 30 minutes on the chart. Good test. R/D circulating head. 10:30 - 11:00 0.50 CASE P TIEB1 Wash down from 13,909' tag Landing Collar at 13,948' 11:00 - 14:00 3.00 CASE P TIEB1 Reverse circulate 20 bbl Biozan Sweep at 6.5 bpm with 3,210 psi. Saw good amount of frac prop over shakers. 14:00 - 15:00 1.00 CASE P TIEB1 POOH laying down 4" DP from 13,948' to 12,958' 15:00 - 16:00 1.00 CASE P TIE61 Slip and cut 69' of drilling line. 16:00 - 00:00 8.00 CASE P TIEB1 POOH laying down 4" DP from 12,958'to 3,843' 3/28/2008 00:00 - 02:00 2.00 CASE P TIEB1 Continue to UD 4" DP from 3,843' to 922' 02:00 - 03:30 1.50 CASE P TIEB1 UD 2-7/8" PAC DP and clean out BHA. 03:30 - 04:00 0.50 CASE P TIEB1 Rig Down Handling Tools for 2-7/8" PAC DP. 04:00 - 06:00 2.00 BUNCO RUNCMP Pull Wear Ring. R/U to run 4-1/2" tubing. R/U handling equipment, R/U stacked tubing tongs and Torque Turn equipment. 06:00 - 06:30 0.50 BUNCO RUNCMP PJSM with Rig Crew, Doyon Casing Hand, and Baker Completion Hand. 06:30 - 20:00 13.50 BUNCO P RUNCMP P/U and RIH with 4-1/2", 12.6#, 13Cr80 Vam Top Completion. P/U Mule Shoe, XN Nipple, X Nipple, Baker S-3 Packer, X Nipple, 4 GLM's, 305 Joints of Tbg, and SSSV. 20:00 - 21:30 1.50 BUNCO RUNCMP R/U Control Liner Spoolers and Sheave. Purge Control Line with Hydraulic Fluid. Pressure Test Control Line to 5000 psi for 15 mins. 21:30 - 00:00 2.50 BUNCO RUNCMP Continue to Run in Hole with 4-1/2" 12.6# 13Cr Vam Top Tubing and Dual 1/4" Control Line. Band Control Line to Tbg with Stainless Steel Bands. 1 Band on Pup Joint Above SSSV and 1 Band per Joint above that. 3/29/2008 00:00 - 01:00 1.00 BUNCO RUNCMP M/U Tbg Jt #305 and 306. Up Wt = 180,000 Ibs Dw Wt = 120,000 Ibs. S/O and Stack Out at 13141'. P/U 35' and Make 1/2 rotation. S/O again at 13141'. P/U and repeat once more with 1/2 rotation to confirm No-Go Depth. Tag at 13141'. UD Jt 306. Found Control Line Kinked and Twisted but No Pressure Loss. Make Splice and Pressure Test Pressure Up to 5000 psi and Pressure Test for 10 mins, No Leaks and No Pressure Loss. UD Jt 305. P/U 4 ft of Space Out Pups and then M/U Jt 305 again. 01:00 - 01:30 0.50 BUNCO RUNCMP M/U FMC Tbg Hanger with 4-1/2" TCII Lift Threads. M/U 4-1/2" TCII Landing Joint. 01:30 - 03:30 2.00 BUNCO SFAL RUNCMP Run Control Lines Through Hanger and M/U Pack Offs Thru Printed: 4/11/2008 12:29:24 PM r~ u BP EXPLORATION Page 12 Of 13 Operations Summary Report Legal Well Name: 1-21/K-25 Common Well Name: 1-21/K-25 Spud Date: 1/10/1990 Event Name: WORKOVER Start: 3/19/2008 End: 4/17/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3130/2008 Rig Name: DOYON 16 Rig Number: Date ~, From - To ,Hours ! Task Code NPT Phase ~~ Description of Operations 3/29/2008 01:30 - 03:30 2.00 BUNCO SFAL RUNCMP Hanger. Fittings very tight against control line, had to fight to get fittings on. Consult Halliburton on issue. 03:30 - 04:30 1.00 BUNCO RUNCMP Able to Get Control Line Made Up to Thru Hanger. Test Pack Offs to 5000 psi for 15 mins each. Terminate Ends of Control Line and M/U Splices above Hanger. Wrap Control Line around Hanger and Connect Back to Spools. Pressure Test Control Line to 5000 psi for 15 mins. 04:30 - 05:00 0.50 BUNCO RUNCMP Maintain Pressure on Control Line and S/O w/ Hanger and Land. RILDS. Maintain Pressure Test of 5000psi on Control Lines for 15 mins after Hanger Landed. 05:00 - 05:30 0.50 BUNCO RUNCMP R/U to Reverse Circ 9.2 ppg Brine and Corrosion Inhibitor. PdSM with Vac Truck Drivers and Crews. 05:30 - 12:00 6.50 BUNCO RUNCMP Pressure test all circulation lines to 3500 psi. Reverse Circulate 200 bbls 9.2 ppg brine, followed with 700 bbls of Corrosion Inhibited Brine. Circulate C~ 3 bpm / 270 psi. 12:00 - 14:00 2.00 BUNCO RUNCMP Drop Ball & Rod and allow to fall for 15 minutes. Seat ball & rod and pressure up on tubing to 3500 psi. Chart test for 3.0 minutes. Bleed tubing pressure to 1500 psi. Pressure uo to 3360 si on annulus. Hold annulus pressure for 30 minutes, charting test. r Both tests were successful. Bleed pressure off of Tbg and shear DCR valve. Establish circulation both directions to confirm shear. 14:00 - 14:30 0.50 BUNCO RUNCMP Blow down all necessary lines. Lay down the Tbg hanger landing jt. 14:30 - 17:00 2.50 BUNCO RUNCMP FMC Re Set TWC. Pressure Test TWC from below to 1500 si for 30 mins and then Test to above to 3360 si for 10 mins. All Tests Charted. 17:00 - 17:30 0.50 BUNCO RUNCMP Blow down Choke & Kill lines & Cellar Manifold. Use rig vac system to suck out BOP stack and drip pan. 17:30 - 23:00 5.50 BUNCO RUNCMP Remove blind shear rams and upper pipe rams from double gate. Make service break between double gate and the mud cross for later removal from stack. ND and stand back BOPE. Tie back lines in preparation for upcoming rig move. 23:00 - 00:00 1.00 RUNGO RUNCMP Terminate and pressure test control lines per Ha{liburton rep. Test to 5000 psi and hold for 10 minutes to establish integrity. Successful test. 3130/2008 00:00 - 01:30 1.50 BUNCO RUNCMP NU tree. Endicott Rep confirm orientation of tree for production & pointed out that orientation of the hydraulic actuator for the Wing valve was incorrect. The actuator was positioned parallel to ground level and should have been installed perpendicular to the ground as required by Endicott. Apply Loctite to studs and bolt up adapter flange using Sweeney wrench. 01:30 - 02:30 1.00 WHSUR P RUNCMP Loosen and reposition wing hydraulic actuator. Install pressure gauges and needle valves on control lines. 02:30 - 03:30 1.00 WHSUR P RUNCMP Test Adapter flange per FMC rep to 5000 psi and hold for 15 minutes to assure integrity. 03:30 - 07:30 4.00 WHSUR P RUNCMP Test production tree per FMC rep to 5000 psi and hold for 30 minutes. Pressure Up Tree multiple Times to 5,000 psi. Slow, steady leak off observed. Visually check all needle valves and flanges for leaks. Annulus not showing any signs of pressure. Cycle Valves and Attempt to Pressure Test. A good test was achieved after 12 attempts. Bleed Down Pressure. 07:30 - 08:30 1.00 WHSUR P RUNCMP R/U DSM Lubricator. M/U to Tree and Pressure Test to 500 Printed: 4/11/2008 12:29:24 PM BP EXPLORATION Operations Summary Report Legal Well Name: 1-21/K-25 Common Well Name: 1-21/K-25 Event Name: WORKOVER Start: 3/19/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/30/2008 Rig Name: DOYON 16 Rig Number: Page 13 of 13 Spud Date: 1 /10/1990 End: 4/17/2008 Date From - To Hours Task Code ~ NPT Phase i Description of Operations 3/30/2008 07:30 - 08:30 1.00 WHSUR P RUNCMP psi. Pull TWC. L/D Lubricator and TWC. 08:30 - 09:30 1.00 WHSUR P RUNCMP Move In Little Red and PJSM. Rig Up Little Red and PT Lines. Pump 15 bbls of Diesel Freeze Protect in IA. 09:30 - 10:00 0.50 WHSUR P RUNCMP U-Tube Diesel Freeze Protect. 10:00 - 11:00 1.00 WHSUR P RUNCMP P/U DSM Lubricator and CIW H BPV. Set BPV and L/D Lubricator. Pressure Test BPV from below with Little Red, 1500 psi for 15 mins. 11:00 - 12:00 1.00 WHSUR P RUNCMP R/D Little Red. R/D Circulating Lines and Hoses. 12:00 - 13:00 1.00 WHSUR P RUNCMP R/D Secondary IA Valve. Install Needle Valves and Gauges. 13:00 - 14:00 1.00 WHSUR N RUNCMP Wait on Endicott Wells Operations to remove scaffolding from adjacent well before rig could be moved. Release Rig at 14:00 hrs. Printed: 4/11/2008 12:29:24 PM 04/09/08 wu d d~,~~~mU~ir~~. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~~ ~~ ~F ti .~ ~ Gt~U~ ~ .... ne~...:..f:..., rlafo RI NO. 4657 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Endicott, Orion Cnlnr C[) 03-10 12045070 USIT -~ 03!24/08 1 1 1-21/K-25 11998996 USIT 03/25/08 1 1 V-223 12061688 CEMENT EVALUATION LOG /(p 03/23/08 1 1 V-214 11978449 MI INJECTOR V - ~ (p C O 04/01/08 1 1 18-138 12061689 PRODUCTION PROFILE ~_'-( '~ 03/27/08 1 1 E-10A 11998994 USIT (~ '~ 03/28/08 1 1 02-128 11628789 MCNL a / ! U _ 08/21/07 1 1 15-456 11963079 MCNL (~ 02/14/08 1 1 V-220 12031459 CH EDIT PDC GR (USIT)~(S~ <(o Q 03/07/08 1 V-214 40016214 OH MWD/LWD 04/01/08 2 1 ~c~ 7C ~ 1 PLEASt AGKNUWLtU(at HtGtIP I tlY 51liNIIVG HrvV Fit! urirvuvu yrvc ~.~ri cri~,n ~ v: BP Exploration (Alaska) Inc. , Petrotechnical Data Center LR2-1 _ 900 E. Benson Blvd. Anchorage, Alaska 99508 , r ~ ~ ~~, ~~ .'' ~~ I~~,r.~ Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-28 ATTN: Beth Received b • r End 1-21 • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E {DOA) Sent: Wednesday, February 20, 2008 1:57 PM To: 'Worthington, Aras J' Cc: Reem, David C Subject: RE: End 1-21 (190-002) Aras, I confirm our conversation. The pressure rating issue has been encountered before. In this as well as the other case, you do have better knowledge regarding the possible BHP that could be encountered. The .1 psi/ft is designed to be conservative with the surface pressure calculation. 1 do not see there being an issue with proceeding with the work authorized by (308-029). Call or message with any questions. Tom Maunder, PE AOGCC From: Worthington, Aras ] [mailto:Aras.Worthington@bp.com] Sent: Wednesday, February 20, 2008 11:07 AM To: Maunder, Thomas E (DOA) Cc: Reem, David C ~~~~~ ~~B ~ ~ 2~~$ Subject: End 1-21 Tom, As per phone conversation on this issue: End 1-21 has an estimate bottomhole pressure of 4366 psi @ 9836' TVD. This pressure is gleaned from a static bottomhole pressure survey (SBHPS) on an adjoining well End 1-33. Note that a SBHPS on End 1-21 was not possible due to plugs in the well that were not retrievable due to an obstruction in the tubing. Using the State's method of determining the maximum anticipated surface pressure (MASP) of BHP minus a 0.1 psi/ft gas gradient the MASP is 3382 psi. The bottom flange of the tbg head is rated to 3360 psi. Since the tubing hanger will be pulled during the rig workover and the casing packoffs canno# be tested above 3360 psi, this flange could possibly be exposed to wellbore pressures during the rig warkover. The issue this creates is that the bottom tubing head flange is rated to X20 psi less than the State's method for calcula#ing MASP, however unlikely ar impossible it may be for the well to naturally provide a pure column of gas 0.1 psi/ft. Of note is that there is no way that we can perform this rig workover without either abandoning the perforations and redrilling the well or going ahead knowing that we are potentially out of compliance to the best of pur knowledge. We request that you give us approval to perform this workover as planned cunently (outlined in approved Sundry #308-029). Aras Worthington 2i2oi2oos • ~P ~ ~ ~ s ,:'.e 44y ., ~ ~ j £ ` ~ g{ }} '+, { i ~ ! F 1i - ~~~~~, } t I~mJ ~,f ~ 1 ~ ~ t ~ 1 SARAH PALIN, GOVERNOR SSA OIL A11TD GAS COI~SERVATI011T COMMISSIOK David Reem Engineering Team Leader BP Exploration Alaska, Inc. PO Box 196612 Anchorage, Alaska 99519-6612 O~~" Re: Endicott Field, Endicott Oil Pool, END 1-21 / K-25 Sundry Number: 308-029 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thi~ day of January, 2008 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Encl. Sincerely, (~~~A ~ OF ALASKA ~~~~ ..~ Via. • ~ ALASKA OIL AND GAS CONSERVATION COM ION APPLICATION FOR SUNDRY APPROVAL ~'`' 20 AAC 25.280 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Tit i~ ~~~~ ^ Alter Casing ~ ®Repair Well ^ Plug Perforations ^ Stimul Qi [~}~~"j ~~J1t~r S pende~ Well„ 8~~ t i~S Q i 'f S ~ '~ OBS. L I fl® U!! tk t7 t l 8 4P3 ! l ^ Change Approved Program -® Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other Ao7Ch®raglr 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 190-002 3. Address: ^ Service ^ Stratigraphic 6. API Number: , P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22005-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: END 1-211K-25 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): , ADL 312828 - 55.1 ~ Endicott Field / Endicott Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14100 10306 - 14000 10220 13139',13221' None asin Len th Size MD TVD Burst Colla se Structural C nductor 131' 30" 131' 131' Surface 2506' 13-3/8" 2509' 2509' 5020 2270 Intermediate 11260' 9-5/8" 11260' 8311' 6870 4760 Produc i n 2227' 9-5/8" 11260' - 13487' 8311' - 9808' 8150 5080 Liner 869' 7" 13216' - 14085' 9605' - 10293' 11220 8510 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13766' - 13893' 10025' - 10129' 3-1/2", 9.2# L-80 13254 Packers and SSSV Type: 9-5/8" TIW (HBBP) Packers and SSSV MD (ft): 13175 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: February 1, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington, 564-4102 Printed Name vid Reem Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-5743 Date ~-z3._sg Sondra Stewman, 564-4750 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance other: 3 S~ ~~~ 3~~ ~S~ Subsequent Form Required: ~v~ APPROVED BY ~f / ~ ~O A roved B ISSIONER THE COMMISS-ON Date js Form 10-403 Revised 06/2006 OR~INAL Submit In Duplicate ' ~~ ~'~., ,p~~~ ~. L0013 by DS Endicott 1-21 Rig Workover • Scope of Work: Pull 3 %2" L-80 completion, mill and retrieve packer, Run 4 1/2" 13Cr-80 scab liner from 13,100' to -14,000' and and cement. Change out 9 5/8" casing packoffs. Run 4 %2" 13Cr-80 completion. MASP: 3500 psi Well Type: Kekiktuk Producer Estimated Start Date: February, 2008 Pre-rig prep work: S 1 Drift down to obstruction @ 3990' and w/ 2.70" blind box and beat down on the obstruction, attem t to knock it loose or lod a it firm) in Iace.SBHPS. C 2 RU CTU and mill on obstruction w/ 2.70" 5-bladed concave junk mill (no side cutters!). Attempt to ush it down to the PX lu 13,077'. ~~ C ~ S 3 Drift down to 13,077' and for 'et cut. F 4 MITOA to 3000 si. CMIT to 3000 si. E 5 Power Jet cut @ 13,112' md, in the middle of the first full joint above the production packer - leave ~15' of stub lookin u above collar below Ref: 2/6/90 tubin tall W 6 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). Well should be secured at this time with a Fasdril lu PPPOT-T & IC. F 4 Circulate well with seawater. Circulate well with 9.2 ppg KW brine. FP w/ diesel to 200'. Bleed WHP's to 0 si. W 5 Set a BPV. Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU BOPE configured for 3000+ psi MASP (4 preventers). Pressure test to 3500 psi. Annular preventer tested to 3500 psi. Circulate out freeze protection fluid and circulate well to clean kill weight brine through the cut. 2. Pull and LD 3'h" tubing string to the cut. 3. Retrieve SBR, anchor-seal, and mill/retrieve production packer. Clean out wellbore to 14,000' md. 4. Run and fully cement 41/2" 13Cr80 scab liner from 13,100' to -14,000' and (will tie back into 9 5/8" casing via ZXP liner hanger/packer). 5. Change-out and test casing packoffs. 6. Drill out shoe-track and PT liner/casing to 3500 psi f/30-minutes. 7. Run 4 '/s" 13Cr-80 completion with 9 5/8" x 4 %z" packer set 13,000' md. 8. Displace the IA to packer fluid and set the packer. 9. Test tubing and IA to 3500 psi. Freeze protect to 200' MD. 10. Set BPV. ND BOPE. NU and test tree. RDMO. ~la~ TREE: 4-1/16"- S,000psi, CIW ACUATOR: Otis WELLHEAD: 13-5/8"- 5,000psi, FMC RT ELEV: 55.1 ft. BF ELEV: 16.05 ft. MAX. DEV. = 56:20 9400' MD END1-21 SSSV Landing Nipple 1564, Otis, (2.750" Min. I.D.) NT80CYHE, BTRS. 2509' _~, MIN ID = 2.635" @ 13242' 3-1/2" OTIS XN NIPPLE TUBING: TDS, Non-IPC I.D. = 2.992" Drift = 2.867" Capacity = 0.00871 bbl/ft GAS LIFT MANDRELS fMERLAI ST MD TVD VLV LAT PORT DATE 4 4009 3817 DMY RA 0 05/16/07 3 8741 6753 EMPTY - 0 05!16/07 2 11889 8654 DMY RA 0 05/16/07 1 13077 9449 DMY RA 0 05/16/07 13139' H SLIDNJG SLV, ID = 2. 13139' PX PLUG (11/01/03) 9-5/8" 47#/ft NT80S, NSCC --~ TOP OF 7" 13216' -~ LINER SealAssy.(TIW) 13160' (SBR, 12' Long) (5.438" O.D.) 9-5/8" Packer 13175' TIW (HBBP) (4.00" I.D.) 3-1/2", 9.2#/ft, L-80, TDS, Tailpipe 13221' 3-1/2" OTIS X NIP, ID = 2.75" 13221' 3-1/2" XX TTP (10/27103) 13242' 3-112" OTIS XN NIP, ID = 2.635" 9-5/8", 47#/ft, 13488' NT95HS, NCSS --~- PERFORATION SUMMARY REF LOG: LDT/CNUGR ON 02/01!90 ANGLE AT TOP PERF: ?? @ 13765' Note: Refer Yo Production DB for historical perf data SIZE SPF INTERVAL ** DATE 2-118" 4 13745 - 13765 S 2-1/8" 6 13765 - 13769 C 08/17/97 5" 4 13841 - 13893 DPC '- KtY: V = VPtlV r (: _ (;LVJtU / JGtL=JQUEEZEV PBTD 14000' -~-~ NT95HS, TKC 14085' 13254' I-~!2" WLEG (LANDED IN LNR HNGR TIE BACK SLV 13253' ELMD TT LOGGED ??I??I?? MARKER 13607' DATE REV BY COMMENTS DATE REV BY COMMENTS 02/23/90 JLH ORIGINAL COMPL. 06/17/06 JCM/TLH PXN PLUG CORRECTION 12/04/96 GM SANDBACK 05/16!07 MGS/TL GLV GO 07/09/97 GM POST SANDBACK CO 07/02/07 RCT/PJC PX PLUG CORRECTION 03/18/98 DB TBG TAIL ELMD 9/26/05 ORITLH XN 8 XX TTP (2003) ENDICOTT UNff WELL: 1-21 i K-25 PERMR No: 1900020 API No: 50-029-22005-00 SEC 36, T-12N, R-16E BP Exploratwn (Alaska) v TREE: 4-1/16"- S,000psi,L"~~ ACUATOR: Otis WELLHEAD: 13-5/8"- 5,000psi, FMC RT ELEV: 55.1 ft. BF ELEV: 16.05 ft. MAX. DEV. = 56:20 9400' MD SSSV Landing Nipple 1500' Camco, (3.813" Min. I.D.) NT80CYHE, BTRS. 2509' _~ END1-21 Proposed MIN ID = 3.725" (~ xxxx' 4-112" OTIS XN NIPPLE TUB{NG: 4-1/2", 12.6#, 13Cr-80, Vam Top I.D. = 3.958" Drift = 3.833" Capacity = 0.0152 bbl/ft PERFORATION SUMIMRY R~ LOG: LDT/CNL/GR ON 02/011J0 ANGLEAT TOP P62F: ?? ~ 13766' Note: Refer to Roduetion DB for Fdstor~al pert data S¢E SPF INTERVAL •• DATE 21/8" 4 13745 -13766 S 2-1/8" 6 13766 -13769 C 08/17/97 5" 4 13841 -13!;'90 OPC HES ~N~pb ID= 3.813" -73,000' 95/8" x 412' S-3 Cr Packer HES X-Nipple ID= 3.813" H~ XN~Newle ID= 3.725" 9-5/8" 47#/ft NT80S, NSCC ~ 9-5/8" x 7" ZXP Packer -13100' T' x 41 f2" XO (Crl TOP OF 7" 13216' • LINER 4-1/2" Cemented Liner, 12.6# 13Cr80 Vam Top I.D. = 3.958" Drift = 3.833" 9-5/8", 47#/ft, 13488' NT95HS, NCSS -~ ~ ID:Y: O s 0P9V I G = CLW®- BGY® GAS LIFE MANDT~S IMMGI ST MD ND VLV LA PORT DATE 4 4047 DCR 0 3 8055 DMY 0 2 10770 DMY 0 1 129;10 DMY 0 MARKER 13607' PBTD 14000' 7", 29#/ft, ' NT95HS, TKC 14085 DATE REV 8Y C~IINBVTS DATE REV BY COMHBdTS ENDICOTT UNIT 2/20180 JlH OR{dNAL COMPL. 06J17AD8 JCNITLH FXN PUX3 OORRECTION WELL: 1-21 / K-25 2104/96 GM SANDBACK 05/16107 MGS/TL GLV GO PERMR No: '1900020 7!09197 GM PDST SANDBACK CO 07/02107 RCTlPJC PX PLUG CORRECTION AR No: 50-029-2'1005.00 8198 DB TBG TAIL ELMD SEC 36, T 12N, R-16E MORRLH PKN 8 XX TTP (2003) BP Exploresion (Alaalw) Schlumberger NO. 4001 Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage. AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave. Suite 100 Anchorage, AK 99501 ¡c;o -OOd Field: Prudhoe Bay Well Job# Loa DescriDtion Date BL Color CD 1-21/K-25 11226008 LDL 10102/06 1 B-27A 11414394 LDL 09/30106 1 M-24A 11216213 MEM PROD PROFILE 09/30/06 1 MPB-09 11212889 PROD PROF/GLS 10106/06 1 X-08A 11414278 US IT 09/26/06 1 C-01A 11414279 US IT 09/27/06 1 K-11 11414765 USIT 10/01/06 1 A-17A 11414283 USIT 10/02/06 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 ~- 1'. ;{~ lJ Alaska Data & Consulting 2525 Gambell Street, S . Anchorage. AK 99503- ATTN: Beth ~¡f'^~NE~J >:,yV.T\ Date Delivered: Received by: (\'~f:í\' '"!!".,,,)'" (\~Ii.<~t\r;f~~\ç~\r!5 ;\~ 10/19/06 . . THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27, 2000 P E E L E W ATE R IA L U N D E TH IS M A.R K ER R STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMISr REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well__ Perforate__ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.qe, Alaska 99519-6612 4. Location of well at surface 2012'SNL, 2081' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development .. Exploratory __ Stratigraphic Service __ 6. Datum elevation (DF or KB) KBE = 55.1 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-21/K-25 MPI feet At top of productive interval 2040' SNL, 4380' WEL, Sec. 32, T12N, R17E At effective depth 2124' SNL, 4077' WEL, Sec. 32, T12N, R17E At total depth 2131' SNL, 4024' WEL, Sec. 32, T12N, R17E 9. Permit number/approval number 90-02~Not Required 10. APl number 50- 029-22005 11. Field/Pool Endicett Off Peol 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 14100 feet 10306 BKB feet 14000 feet 10220 BKB feet Plugs (measured) Junk (measured) XXN Plug @ 13205' ORIGINAL Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 92' 30" Driven 2470' 3-3/8" 3729 c.f. Permafrost 13448' 9-5/8" 575 c.f. Class G Measured depth BKB 131' 2509' 13487' measured 869' 7" 331 c.f. Class G 13841' ~ 13893' (open) 13745' - 13765' (squeezed) true vertical (subsea) 10031'- 10074' (open) 9954' - 9969' (squeezed) 13216'-14085' Tubing (size, grade, and measured depth) 3-1/2" 9.2# L-80 with 3-1/2" tailpipe to 13254'. True verticaldepth BKB 131' 2509' 9809' 9605'-10293' Packers and SSSV (type and measured depth) 9-5/8" packer at 13175'; 3-1/2" SSSVat 1564' 13. Stimulation or cement squeeze summary Intervals treated (measured) Set XXN Plug at 13205' MD Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 64 1O208 I 0 Tubing Pressure 910 . 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, Si~lned ~'~. ~~. ~ ,~'~2.~,_~. Lc'~d-~-~ Title senior Technic, l~t~.~i~tarttlV Form 10-404 Rev 06/15J8~8 Date 12/30/96 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department OPERATIONS REPORT DATE: 07-11-00 WELL N-°: 1-21/K-25 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: SET XXN PLUG M. SAUVE HES / JORDAN DATE/TIME ~ OPERATIONS SUMMARY =WHFP: SI WHFT: SI SIP:2650# IA:2650# OA:125 08:00 iRIH W/XXN PLUG W/12" FILL EXTENSION 2.745 NO-GO TO XNLN @ 13205' ~ WLM. SET. 11:00 !POOH. BLEED 300# OFF TUBING HOLD 15 MINS. GOOD SET. 12:00 J RDMO. SUMMARY: SET XXN PLUG IN XNLN 13205 WLM. GOOD TEST. SIP 2650#. Plug set to temporarily suspend well due to tubing- annulus communication and no immediate well work plans. DBR. SSSV:OUT · SLATE OF ALASKA ALAS ~OIL AND GAS CONSERVATION COMMIS' ;~ REPORT L.: SUNDRY WELL OP,-.RATIONS 1. Operations performed: Operation shutdown_ Stimulate Plugging Pull tubing Alter casing Repair well Perforate X Other 2. Name of Operator BP Ex/~loration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.cle, Alaska 99519-6612 4. Location of well at surface 2012' SNL, 2081' WEL, Sec. 36, T12N, R16E At top of productive interval 2040' SNL, 4380' WEL, Sec. 32, T12N, R17E At effective depth 2124' SNL, 4077' WEL, Sec. 32, T12N, R17E At total depth 2131' SNL, 4024' WEL, Sec. 32, T12N, R17E 5. Type of Well: Development .. Exploratory ~ Stratigraphic Service , 6. Datum elevation (DF or KB) KBE = 55.1 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-21/K-25 MPI 9. Permit number/approval number 90-02/Not Rec/uired 10. APl number 50- O29-22OO5 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 14100 feet Plugs (measured) 10306 BKB feet 14000 feet Junk (measured) 10220 BKB feet Size Cemented Measured depth BKB 92' 30" Driven 131' 2470' 13-3/8" 3729 c.f. Permafrost 2509' 13448' 9-5/8" 575 c.f. Class G 13487' 869' 7" 331 c.f. Class G 13216'- 14085' measured 13765'- 13769', 13841'- 13893' (open) 13745'- 13765' (squeezed) True vertical depth BKB 131' 2509' 9809' 9605'- 10293' true vertical (subsea) 9969'- 9972', 10031'- 10074' (open) 9954'- 9969' (squeezed) Tubing (size, grade, and measured depth) 3-1/2" 9.2# L-80 with 3-1/2" tailpipe to 13254'. Packers and SSSV (type and measured depth) 9-5/8" packer at 13175'; 3-1/2" SSSVat 1564' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL :--,,P 25 ]99?' ~laska 0ii & Gas Cons. Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 846 4374 17 0 853 4921 151 0 Tubing Pressure 309 313 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended ,. Service 17. I hereb_,y_c,,ertify tl'~t t,J~'foregoing is true and correct to the best of my knowledge. Signed ~~,~~ Form 10-40~¢,¢{ev 06/15/88 - Date 9/22/97 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department DATE: 8/17/97 WELL N°: 1-21/K-25 BP EXPLORATION REP: SERVICE COMPANY: Additional Perforations R. Clump SWS (S. Deckert) DATE/TIME OPERATIONS SUMMARY 0800 MIRU. Choke @ 104 beans, FWHP= 275 psig, FWHT= 100 deg F, GLR= 2.2 mmscf IAP= 1375 psig, & OAP= 175 psig 0835 SI choke & wing. Allow gas-lift to stack out. Call for radio silence on MPI. Notify rig no welding - no radio traffic. 0919 Arm gun #1. 0945 PT lubricator to SIWHP= 1300 psig. RIH w/gun #1 (SWS 2-1/8" x 4' EJ, RDX, 6spf) & CCL. Distance from MP to TS= 4.8'. See fluid level @ 2500' while going in the hole. 1045 Tie in to CBT dated 2/5/90 from 13400' to tbg tail (-6'). See tbg tail @ 13254' md bkb. Drop down to 13700 & log past shortjts. On depth. RIH to 13815'. Log into place @ CCL depth of 13760.2'. 1223 Shoot gun #1 from 13765'-13769' MDBKB. See WHP increase from 1325 psi to 1350 psi. After log off, WHP= 1400 psi. Pooh. 1245 OOH. Whp='1650 psi. 1315 Confirm all shots fired. RDMO SWS. End radio silence. 1330 Whp= 1900 psi. POP well. Schedule for well test. PERFORATION SUMMARY: GUN INTERVAL(CBT) FEET SUBZONE 1 13,765'-13,769' 4 2A All intervals were shot using 2-1/8" guns at 6 spf, 0 degree phasing & random orientation. Shot against closed choke due to pressure differential between the 2A & Zone 1. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown__ Stimulate X Pull tubing Alter casing Repair well 2. Name of Operator I 5. Type of Well: J Development X ARCO Alaska, Inc. I Exploratory 3. Address I Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 I Service 4. Location of well at surface 2538' FNL, 120' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 1363' FSL, 1203' FEL, Sec. 26, T12N, R8E, UM At effective depth 1101' FSL, 1262' FEL, Sec. 26, T12N, R8E, UM At total depth 993' FSL, 1283' FEL, Sec. 26, T12N, R8E, UM 12. Present well condition summary Total Depth: measured 9650' feet true vertical 6032' feet Plugging Plugs (measured) None Perforate Other 6. Datum elevation (DF or KB) 90' RKB 7. unit or Property name Kuparuk River Unit 8. Well number 3G-18 9. Permit number/approval number 90-1 25 10. APl number 50-1 03-201 42 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 9539' fe et true vertical 5841' feet Junk (measured) None Casing Le n gth Size Structural Conductor 115' I 6" Surface 4600' 9 - 5 / 8" Intermediate Production 9627' 7" Liner Perforation depth: measured 9380'-9430', true vertical 5892'-5901 ', Cemented Measured depth True vertical depth 214 Sx AS I 1 15' 1 15' 1050 Sx AS III & 4600' 31 67' 650 Sx Class G 225 Sx Class G 9627' 6022' 9310'-9330', 5882'-5892', 9138' 9226'-9240' 5841'-5848' Tubing (size, grade, and measured depth) 3-1,5" 9.3#, EUE, ABMOD, @ 01 IGiNAL Packers and SSSV (type and measured depth) SSSV: Otis FMX (1810'), Packer: Camco HRP-I-SP (9055') 13. Stimulation or cement squeeze summary "A" SANDS REFRACT, 8/4/97 Intervals treated (measured) 9226'-9236', 9310'-9340', 9380'-9400' Treatment description including volumes used and final pressure "A" SAND REFRAC COMPLETED THRU FLUSH. INJECTED 228404# OF PROP IN THE FORMATION W/11.9# PPA OF #10/14 @ THE PERFS. MAXIMUM PRESSURE 7000 PSI AND F.G. (.75). FREEZE PROTECTED TUBING W/DIESEL 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation -488- -1515- -176- -1013- -165- Subsequent to operation -517- -1197- -169- -899- -165- 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ~ Water Injector Daily Report of Well Operations X Oil X Gas ~ Suspended 17.' I he~'~rtify that the foregoing is true and correct to the best of my knowledge. Service Form 1~-~ -R-~v'"'0~/'5/88-' / D a t e~:~,~-~.~;~p SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT '~, WELL SERVICE REPORT '~ K1 (3G-1 8(W4-6)) ,, WELL JOB SCOPE JOB NUMBER 3G-18 FRAC, FRAC SUPPORT 0726970825.4 DATE DAILY WORK UNIT NUMBER 08/04/97 "A" SAND REFRAC , , DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 5 (~) Yes O NoJ (~) Yes O No DS-GALLEGOS ...C,H~.'~EY FIELD "~AFC# CC~ DALLY COST ACCUM COST SiCnjed. ESTIMATE KDl181 230DS36GL $137,387 $164,648 .,/~,/f~, Initial Tb.q Press Final Tb_cl Press Initial Inner Ann Final Inner Ann I Initial Oufer'Ann I-Final Outer~'Cn 1200 PSI 1 500 PSI 100 PSI 500 PSII 25 PSII /I 00 PSI DALLY SUMMARY "A" SAND REFRAC COMPLETED THRU FLUSH. INJECTED 228404 LBS OF PROP IN THE FORMATION W/11.9 # PPA OF #10/14 @ THE PERF'S. MAXIMUM PRESSURE 7000 PSI AND F.G. (.75) FREEZE PROTECTED TBG W/DIESEL. TIME 07:00 09:30 09:45 10:55 12:00 LOG ENTRY MIRU DOWELL FRAC EQUIP, LRS HOT OIL UNIT, & APC VAC TRK. HELD SAFETY MEETING (15 ON LOCATION) PT'D BACKSIDE LINES TO 4000 PSI AND RAISED THE INNER CSG AS REQUIRED. SET TREESAVER AND PT'D THE HIGH PRESSURE LINES TO 9000 PSI. PUMP BREAKDOWN W/50# DELAYED XL GW @ 25 TO 15BPM. VOLUME PUMPED 400 BBLS. USED 7009 LBS OF #20/40 PROP. MAXIMUM PRESSURE 7000 PSI AND ENDING PRESSURE 2950 PSI. S/D AND OBTAINED ISlP OF 1555 PSI W/F.G. @ (.71). STOOD-BY AND MONITORED WHTP. PULSED TO DETERMINE CLOSURE.(CLOSURE TIME APP: +/- 20 MINS) PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. VOLUME PUMPED 194' BBLS. MAXIMUM PRESSURE 5600 PSI AND ENDING PRESSURE 3150 PSI. S/D AND OBTAINED ISIP OF 1812 PSI W/F.G. @ (.75). STOOD-BY AND MONITORED WHTP FOR CLOSURE. (cLOSURE TIME 21 MINS) PUMP FRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. COMPLETED THRU FLUSH. S/D AND MONITORED WHTP FOR 5 MINS. VOLUME PUMPED 1531 BBLS. MAXIMUM PRESSURE 6200 PSI AND ENDING PRESSURE 3200 PSI. PUMPED 229045 LBS OF PROP (23009 LBS OF #20/40, 199000 LBS OF #12/18, AND 7036 LBS OF #10/14). INJECTED 228404 LBS OF PROP IN THE FORMATION W/11.9 # PPA OF #10/14 @ THE PERF'S. LEFT 641 LBS OOF PROP IN THE WELLBORE. FREEZE PROTECTED TBG DOWN TO 3100' W/DIESEL. 14:00 STARTED R/D. DEPRESSURED THE INNER CSG TO 500 PSI AND R/D LRS HOT OIL UNIT. 15:00 16:00 REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D R/D COMPLETE AND DOWELL LEAVING LOCATION. WELL SECURED AND DSO NOTIFIED OF STATUS. SERVICE COMPANY- SERVICE DAILY COST ACCUM TOTAL $0.00 $1,258.00 APC $5,600.00 $9,200.00 D I ES E L $200.00 $325.00 DOWELL $129,607.00 $135,421.00 HALLI§URTON $0.00 $9,204.00 LITTLE RED $1,980.00 $9,240.00 TOTAL FIELD ESTIMATE $137,387.00 $164,648.00 STATE OF ALASKA ,-,LASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate__ Plugging__ Perforate__ Pull tubing Alter casing __ Repair well __ Other X. 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2012' SNL, 2081' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 55.1 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-21/K-25 MPI At top of productive interval 2040' SNL, 4380' WEL, Sec. 32, T12N, R17E At effective depth 2124'SNL, 4077' WEL, Sec. 32, T12N, R17E At total depth 2131' SNL, 4024' WEL, Sec. 32, T12N, R17E 9. Permit number/approval number 90-02/Not Required 10. APl number 50- 029-22005 11. Field/Pool Endicott Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 14100 feet 10306 BKB feet 14000 feet 10220 BKB feet Plugs (measured) Junk (measured) ORIGINAL Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 92' 30" Driven 2470' 13-3/8" 3729 c.f. Permafrost 13448' 9-5/8" 575 c.f. Class G measured 869' 7" 331 c.f. Class G 13841' - 13893' (open) 13745'- 13765' (squeezed) true vertical (subsea) 10031'- 10074' (open) 9954'- 9969' (squeezed) Tubing (size, grade, and measured depth) Measured depth BKB True vertical depth BKB 131' 131' 2509' 2509' 13487' 9809' 3-1/2" 9.2# L-80 with 3-1/2" tailpipe to 13254'. 13216'-14085' 9605'-10293' Ct:ivED JAN 02 1997 Packers and SSSV (type and measured depth) 9-5/8" packer at 13175'; 3-1/2" SSS V at 1564A~I~ (~j & GaS C0115, ~ 13. Stimulation or cement squeeze summary Gas shut off/Cement squeeze 11/28 - 12/4/96 Intervals treated (measured) 13841'- 13893'; 13745'- 13765' · ~ ,~--,aescrlnt~on, , .~, u~nc~ua~n'" volumes used and final pressure 202 bbls meOH; 1550 bbls 2% KCLW; 20 bbls biozn, 20 bbls FIoPro; Treatment 12.5 bbls cement. FSlWHP=n/a 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 974 16103 38 0 2036 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas,__ Suspended Service 17. I hereby certify that th/e.!oregoing is true and correct to the best of my knowledge. Form 10-4~ Rev 06/15/88 ' - Date 12/30/96 SUBMIT IN DUPLICATE End 1-21 Sandback/Cmt Sqz Nov. 28 - Dec. 4, 1996 Page 8 ,I I BPM I I I vo . I oonzl rtns I Remarks Fluids Pumped II Cement Summary B'BLS Description 15.8 ppg Class"G" Lab TT: 6 h 44 min cement @ 170 BHCT 202 MeOH. 0.05% D047 Lab Fluid Loss: Field Fluid Loss: 26.5 mi in 30 min 25 ml/30min 1550 2% KCLW 0.4% D065 Lab Calc. APl FL: Field Calc APl FL: 53 mi in 30 min 50 ml/30min 20 B iozan 0.6% D156 Lab APl filter cake:0.5 in PV 75 = 50 @ 75 °F 20 FIoPro 0.04% Dl10 Field APl filter cake:0.54 tY 75 = 12 @ 75°F 12,5 Cement 14 bbl mix- 12.5 bbl Live cell loss: N/A PV 170 = 77 @ 170 ;F Pumped Extrap. LC loss: N/A tY 170 = 20 @ 170 °F 10bbl recovered Live cell cake: N/A 2.5 bbl behind pipe Oil & G~m Cons. Commi,~Sion STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIb...~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate .. Plugging Perforate × Pull tubing Alter casing Repair well Other ¢ ~.~,.~ , 6. Datum elevation (DF or i~~' KBE = 55.1 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2012' SNL, 2081' WEL, Sec. 36, T12N, R16E At top of productive interval 5. Type of Well: Development :x Exploratory, Stratigraphic Service RECEIVED 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-21/K-25 MPI 9. Permit number/approval number 2040' SNL, 4380' WEL, Sec. 32, T12N, R17E At effective depth 2124'SNL, 4077' WEL, Sec. 32, T12N, R17E At total depth 2131' SNL, 4024' WEL, Sec. 32, T12N, R17E ,?,,~:,~..~'- ~'" 0~[ & ~s Cons. Cornmission A~chorage 90.02/Not Required 10. APl number 50- 029-22005 11. Field/Pool Endicott Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 14100 feet 10306 BKB feet 14000 feet 10220 BKB feet Plugs (measured) Junk (measured) Casing Length Size Cemented Structural Conductor 92' 30" Driven Surface 2470' 13-3/8" 3729 c.f. Permafrost Intermediate 13448' 9-5/8" 575 c.f. Class G Production Liner 869' 7" 331 c.f. Class G Perforation depth: measured 13841'- 13893', 13745'- 13765' Measured de~h BKB 131' 25O9' 13487' 13216'-14085' True ve~lde~h 131' 2509' 9809' 9605'-10293' true vertical (subsea) 10031'- 10074', 9954'- 9969' Tubing (size, grade, and measured depth) 3-1/2" 9.2# L-80 with 3-1/2" tailpipe to 13254'. Packers and SSSV (type and measured depth) 9-5/8"packer at 13175'; 3-1/2" SSSVat 1564' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 634 ~,"~890 13 0 2841 ~ 14066 11 0 Tubing Pressure 289 768 15. Attachments Copies of Logs and Surveys run . Daily Report of Well Operations X 17. I hereby certify that the foregoing is true, and correct to the best of my knowledge. Signed ~~- "~/_~/~ ~'~, · Title Senior Technical Assistant II Form 10-49/4/Rev 06/15/88 16. Status of well classification as: Oil x Gas Suspended Service SUBMIT IN DOPLICAT~~; i Endicott Production Engineering ,Department Additional Perforations DATE: 12/26/93 WELL N°: 1-21/K-25 BP EXPLORATION REP: KIMMET/HOBBS SERVICE COMPANY: ATLAS RECEIVED NOTE: INSURE THAT THE WELL SITE AREA, WELL HOUSE AND PRODO'I~T-iON TREE ARE KEPT FREE OF CRUDE OIL, EQUIPMENT LEAKS OR TRASH. CLEAN UP ANY CRUDE/HYDRAULIC OIL LEAKS BEFORE LEAVING THE JOB SITE. , , DATE/TIME OPERATIONS SUMMARY 0730 RU. Post radio silence signs at the entrance to island and next to well site. 0~4,5 ESTABLISH RADIO SILENCE AND ARM GUNS (Notify security). 0900 Install SSV fusible cap. FWHP = 350 psig. WHT = 70 deg F. IAP = 500 psig. OAP = 100 psig. Choke = 104 Beans. 0950 Pressure test lubricator to wellhead pressure. 1150 RIH with Gu..n #! (20 feet), sIYVHP = 840 psig. 1200 Open wing valve and set pr.oduction chOke to 45 beans. 1220 Tie in to DLL dated 1/31/90. All of the depths listed below are from the open hole reference log. FWHP = 320 psig @ 45 /104 bean choke. · , 1223 Shoot gun #1 from 13745-13765' MDBKB and flow well. FWHP = ..... 550 psig. 1230 SI well and POOH. 1402 At surface. SIWHP = 1386 psig. Confirm all shots fired. 1416 End radio silence. 1420 RD. POP. PERFORATION SUMMARY: GUN !NTERVAL(DLL) ~BL DEPTH FEET SUBZQNE ! 13,745-13,765 20 2A All intervals were shot using 2-1/8" guns at 4. spf, 180 degree phasing and 90° orientation. ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 21 January 1994 RE: Transmittal of Data ECC #: 6096.01 Data: NONE Dear Sir/Madam, Reference: . BP 1-21/K-25 d~0 _~0~2- ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: Sent by U.S. MAIL PFC/CCL FINAL BL PFC/CCL FINAL RF Run # 1 Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, ~ 99518 Attn. Rodney D. Paulson Received by: ~~ ~ Date: ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 8 December 1993 RE: Transmittal of Data ECC #: 6096.00 Data: PDK-PORO Dear Sir/Madam, Reference: BP 1-21/K-25 END I COTT /O~d)~ NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 Sent by U.S. MAIL ~ PDK LDWG TAPE+LISTER Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 7 December 1993 RE: Transmittal of Data ECC #: 6096.00 Data: PDK-PORO Dear Sir/Madam, Reference: 1-21/K-25 ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 1 Sent by U.S. MAIL PDK/GR/CCL FINAL RF PDK/GR/CCL FINAL BL Run # 1 Run # 1 Received by: Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Date: ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 19, 1992 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Report of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION WELL ACTION 1A-28 Stimulate 1G-13 Perforate 1G-13 Stimulate · 1R-17 Conversion - 1 R-19 Conversion , 1 R-23 Conversion · 1R-26 Conversion · 1Q-02 Conversion 2E- 13 Stimulate 2E- 15 Stimulate 2E-16 Stimulate 2U-15 Stimulate 2Z-02 Stimulate 2Z-19 Stimulate 2Z-29 Stimulate 3A-09 Stimulate 3G-23 Conversion 3H-03 Stimulate 3H-11 Stimulate 3H-20 Stimulate 3Q-01 Conversion · 3Q-08 Conversion 3R-10A Conversion --3R-15 Conversion 3R-20 Conversion 3R-22 Cancel 3R-22 Conversion If you have any questions, please call me at 263-4281. Sincerely, C. W. Strickland Engineer Kuparuk Petroleum Engineering V. L. Ferguson,[~,~ ATO-1370 (w/o attachments) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ,, ALA~SKA OIL AND GAS CONSERVATION COMMIbolON REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown __ Pull tubing ~ Alter casing Stimulate X Plugging Perforate Repair well O t h e r 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 587' FSL, 309' FWL, Sec.5, T11N, R10E, UM At top of productive interval 161' FNL, 2342' FEL, Sec.17, T11N, R10E, UM At effective depth 614' FNL, 2166' FEL, Sec.17, T11N, R10E, UM At total depth 699' FNL, 2143' FEL, Sec.17, T11N, R10E, UM 12. Present well condition summary Total Depth: measured 1 0 0 2 5 true vertical 6 4 9 9 Effective depth: measured 9 91 6 true vertical 6 4 3 5 feet feet feet feet 6. Datum elevation (DF or KB) RKB 102 7, Unit or Property name Kuparuk River Unit feet 8. Well number 1A-28 9. Permit number 90-02 10, APl number 5o-029-221 26 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool , Plugs (measured) None Junk (measured) None Casing Length Size Structural 1 1 5' 1 6" Conductor 5 3 73' 9 - 5 / 8" Surface Intermediate Production 9 96 9' 7" Liner Perforation depth: measured 9330'-9370', 9370'-9390', true vertical 6103'-6126', 6126'-6137', Cemented Measured depth True vertical depth 222 SX AS I 1 1 5' 1 1 5' 1268 SX AS III & 5413' 3861' 507 SX Class G 300 SX Class G 1 0005' 6488' 9619'-9633', 6265'-6273', 9649'-9712' 6282'-6318' Tubing (size, grade, and measured depth 4" 11# J-55 3991'; 3.5" 9.3# J-55 3991'-9252'; 3.5" 9.3# L-80 9252'-9416'; 2.875" 6.5# J-55 9416'-9503' Packers and SSSV (type and measured depth) PKR: Baker HB @ 9246', PKR: TIW Locator @ 9416', SSSV: Camco TRDP-4A ~ 1769' 13. Stimulation or cement squeeze summary Fracture stimulation of "C" Sands on 10/1/92 Intervals treated (measured) 9330'-9390' Treatment description including volumes used and final pressure Placed 132 MLBS of 16/20 and 12/18 ceramic proppant..Final treating pressure was 7500 psi. 14. ReDresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 500 450 1500 1100 190 Subsequent to operation 3000 230 10 1100 160 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. .~icjned 0'~., ~/ Title Form 10-404 Rev 09/12/90 Service ARCOAlaska, Inc" ~ Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT CONTRACTOR //~//"J,- ~'/- ~ w REMARKS OPERATION AT REPORT TIME ?.c-/5 ,o ,~ % o o ~ ~ /e f ~L ["-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemP'Report OF Chill Fact°r I VisibilitY°F, miles Iwind ~el' knots ISigned''~ ~ ~_~/~-.~ / , Alaska Oil Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 907-219-1433 To'- Receipt of the following material which was transmitted via is hereby acknowledged: Quanti~ Description RECEIVED AUG 12 ]99]- Alaska Oil & Gas Cons. Commission Anchorage Dated: ~--~/~ ~ ? (.' Copy sentto sender: Yes ~ No~ BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 22, 1991 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle' Enclosed please find one sepia and one blueline print for the well logs run in the following Endicott wells' .WELL 1-01/J-19 TDT-P 11640'-12249' SCHLUMBERGER 2/13/91 RUN THREE WELL 1-09/J-! TDT-P 11200'-12160' SCHLUMBERGER 2/24/91 RUN THREE WELL 1-21/K-25 J TEMP 9600'-13984' WELL 1-;~7/P-20 CL 9700'-10680' ATLAS WIRELINE PROD-F '/ 10350'-10948' 1 2/1 3/90 ~"'" RUN ONE 12/23/90 RUN ONE 2/12/91 RUN ONE BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 17, 1990 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle' Enclosed please find one sepia and one blueline print for the well logs run in the following Endicott wells: WELL 1-21/K-25 STATIC TEMPERATURE SURVEY 13500'-13950' CAMCO 8/14/90 RUN ONE WELL 1-29/M-25 TDT-P 13100'-14081' SCHLUMBERGER 9/9/90 RUN TWO WELL 1-37/P-24 TEMPERATURE SURVEY 12098'-12650' HALLIBURTON LOGGIN SERVICES WELL 1-39/P-17 ,/DUAL STATIC SURVEY 10300'-10300' SCHLUMBERGER 8/16/90 RUN ONE 8/11/9O RUN ONE I ECEIVED SEp 7 8 1990 ,~laska.oil.& Gas Cons..Commission '_Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 6, 1990 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Endicott Field - Bottom-Hole Pressure Reports Dear Sirs: Enclosed are Bottom Hole Pressure Reports for the following wells Well Name Date 1-21/K-25 8-14-90 1-67/T-20 8/12/90 2-26/N-14 8-12-90 2-36/0-14 7/14-15/90 2-46/Q- 15 8-13-90 2-52/S-14 8-13-90 3-41/K-39 8-11-90 4-18/S-30 8-13-90 4-26/0-34 8/11/90 4-42/P-38 8/10/90 4-46/N-39 8/12/90 5-01/Sag Delta #7 8/10/90 5-02/Sag Delta #10 8/15/90 If there are any questions regarding this data, please 564-5225. Sincerely, ~,e'anne L. Haas contact Jeanne Haas at R'E'C. EIVED SEP 11 1990 A/asEa.0Jj & Gas Cons. uommission ~chorage BP EXPLORATION BP Exploration (Alaska) Inc, 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 26, 1990 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle' Enclosed please find one sepia and one blueline print for the well logs run in the following EndicOtt wells: WELL 1-05/O-20 *INJECTION PROFILE 10300' - 11121' Camco 5/22/90 Run No. 1 WELL 1-21/K-25 6/10/90 *PRODUCTION PROFILE SURVEY 13600' - 13984' Run No. 1 Camco WELL 1-27/P-20 6/17/90 *COMPENSATED NEUTRON LOG 9945' - 10703' Run No. 2 Schlumberger WELL 1-43/P-26 *INJECTION PROFILE 13600' - 14070' Camco 5/19/90 Run No. 1 WELL 1-57/R-23 ,. 6/1/90. *TEMPERATURE SURVEY 11600' - 12390' Run No. 1 HRS BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 April 24, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn' Mr. C. V. Chatterton Well 1-21/K-25 (Endicott) Enclosed, in duplicate, is form 10-407, our Report of Well Completion for the above named well. This information reflects the current condition and status of the well. Enclosed are two copies each of daily drilling reports, directional and gyroscopic surveys. The open hole logs were sent under separate cover by the Endicott Development Group. Yours very truly, M. E. Miller Endicott Lead Engineer MEM/KTH Enclosures (3) J. Oldenburg (MB 7-1) Endicott WlO's w/4 Well File STATE OF ALASKA ALAS~ OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 90-02 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22005 4. Location of well at surface~ ,.U~ ~i~~~ ~ i 9. Unit or Lease Name 10. Well Number 2012' SNL, 2081' WEL, SEC. 36, T12N, R 16E ~ ~L~i~i i7~'3~ Duck Island Unit/Endicott 2040' SNL, 4380' WEL, SEC. 32, T12N, R17E ~, - VEP. IFI~ j~ i ~'~';~"~---~ 1-21/K-25 MPI ~' , ~ 11. Field and Pool Endicott At Total Depth Fie/d/Endicott Pool 2131' SNL, 4024' WEL, SEC. 32, T12N, R17E 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 55.1 , I ADL 312828 12. Date Spudded 13. Date T.D. Reached !4. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 01-10-90 01-31-90 02-08-90I 6-12 feet MSL I ONE 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 14100'MD/IO305'TVD 14000'MD/10220'TVD YES [] NO []I 1564' feet MD I 1466' 22. Type Electric or Other Logs Run SDL//CNS/GR, DLI_/GR/MSFL, DLL/GR/MSFL, RFT 23. CASING, LINER AND CEMENTING RECOF~ SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMI~mNG REC(:~D AMOUNT PULLED 30" Struct. Drive Pipe Surface 131' 13-3/8" 68" Butt Surface 2509' 17-1/2" 3729 cu ft Permafrost 9-5/8, 47# NT80-S Surface 11260' 12-1/4" 9-5/8" 47# NT95HS 11260' 13487' 12-1/4" 575 cu ft Class G 7" 29# SM110 13216' 14085' 8-1/2" 331 cuff C/ass G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Schlumberger 5" @ 4 spf 3-1/2" 9.2# L-80 13254' 13175' MD TVDss 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 13841 '- 13893' 10030,- 10074' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13-3/8' X 9-5/8" Downsqueezed Annulus w/150 bblsd Dry Crude 27. PRODUCTION TEST Date First Production IMethod of Operation {Flowing, gas lift, etc.) February 7, 1990 I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF ~/ATER-BBL CHOKE SIZE IGAS-OIL RATIO ~' i'EST PERIOD I~ I Flow Tubing Casing Pressure 3,ALCULATED OIL-BBL GAS-MCF NATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 ~INUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKERS F ~f,~ATION TESTS NAME ,, Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top HRZ 13092' 9515' Itkiliyariak - Missing LCU 13468' 9792' Top Kekiktuk 13468' 9 792' · 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,' ,',, Title Endicott Lead Engineer ,,Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP EXPLOR,~ION Daily Drilling Report-- ENDICOTT January 11, 1990 at 0600 hrs Rig: DOYON 15 Well: 1-21/K-25 (MPI) AFE # 717576 APl: 50-029-22005 AFE Amount: Current Amount: 0600 Depth: 2150' Day: 1 24- HourFtg: 2150' Current Operation: Drilling 17-1/2" hole. Accept rig on Well 1-21/K-25 at 0700 hrs. 1-10-90. Spud well at 1100 hrs. on 1-10-90. Drill and survey 17.1/2" hole to 2150'. Mud Type: SPUD WT: 9.5 SURVEY MD ANGLE 4 1931 .5 VIS' 154 PV: 17 YP: 50 FL: 15.8 Solids: 8 Temp: DIRECTION TVD SECTION COORDINATES NO5E 1931 - N1 - 57°F DLS 0.1 BP EXPLORA]'iON Daily Drilling Report -- ENDICOTT January 12, 1990 at 0600 hrs Rig: DOYON 15 Well: 1-21/K-25 (MPI) AFE # 717576 API: 50-029-22005 AFE Amount: Current Amount: 0600 Depth: 2525' Day: 2 24- Hour Ftg: 375' Current Operation: WOC. Drill 17-1/2" hole to 2525'. Run and cement 13-3/8" casing; shoe at 2509'. Mud Type: LSND WT: 9.3 SURVEY MD ANGLE 5 2499 1 VIS' 55 PV: 10 YP:21 FL:22 DIRE~ION TVD SECTION S80E 2499 4 Solids: 7 Temp: 65 °F COORDINATES DLS N4 W4 0.1 BP EXPLORATION Daily Drilling Report -- ENDICOTT January 16, 1990 at 0600 hrs Rig: DOYON 15 Well: 1-21/K-25 (MPI) AFE # 717576 API: 50-029-22005 AFE Amount: Current Amount: 0600 Depth: 7005' Day: 6 24- Hour Ftg: 1705' Current Operation: Drilling. Drill and survey 12-1/4" hole to 7005'. Mud Type: LSN'D WT: 9.7 SURVEY MD ANGLE 23 5754 50.1 28 6706 50.6 VIS: 40 PV: 9 YP: 9 FL: 7.2 DIRECTION TVD SECTION N83E 4954 1897 N83E 5568 2618 Solids: 9 Temp: 72 °F COORDINATES DLS N287 E1894 0.5 N388 E2615 0.3 BP EXPLORATION Daily Drilling Report -- ENDICOTT January 15, 1990 at 0600 hrs Rig: DOYON 15 Well: 1-21/K-25 (MPI) AFE # 717576 API: 50-029-22005 AFE Amount: Current Amount: 0600 Depth: 5300' Day: 5 72- Hour Ftg: 2775' Current Operation: Drilling. Test 13-3/8" casing to 3000 psi - OK. Drill out cement and shoe. Drill and survey 12-1/4" hole to 5300'. Mud Type: LSND SURVEY 11 14 19 3478 4052 4993 WT: 9.3 VIS: 45 PV: 8 YP: 15 FL: 10.4 ANGLE DIRECTION TVD SE~IION 28.9 N81E 3436 248 43.9 N79E 3905 570 52.9 N82E 4481 1306 Solids: 7 Temp: 70 °F COORDINATES DLS N23 E247 N101 E569 N213 E1303 2.4 3.7 0.4 BP EXPLORATION Daily Drilling Report -- ENDICOTT January 17, 1990 at 0600 hrs Rig: DOYON 15 Well: 1-21/K-25 (MPI) AFE # 717576 API: 50-029-22005 AFE Amount: Current Amount: 0600 Depth: 8045' Day: 7 24- Hour Ftg: 1040' Current Operation: Drilling. Drill and survey 12-1/4" hole to 8045'. Mud Type: LSND WT: 9.7 SURVEY ,MD. ANGLE 31 7281 52.1 34 7836 53.1 VIS' 38 PV: 8 DIRECTION TVD YP: 10 FL: 7 SECTION N83E 5927 3063 N84E 6266 3500 Solids: 8 Temp: 72 °F COORDINATES DLS N448 E3060 N498 E3496 0.5 0.3 BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: ENDICOTT UNIT As of 0600 Hrs. Thursday, January 18, 1990 WELL: 1-21/K-25 APl No. 50-029-22005 Day: 8 Depth at 0600 Hrs. = 8506' 24 Hour Footage = 461' Rig: AFE Number: AFE Amount = Current Field Costs = Doyon Rig #15 717576 Current Operation: Tripping. Summary of Last 24 Hours: Drill and survey 12-1/4" hole to 8506'. Wells Shut-in For Drill-By: Mud Type Mud Weight Viscosity LIGNO 9.7 #/gal 37 Sec. PV YP Fluid Loss Solids Temp 8 8 7.0 cc 8% 76 °F Survey Depth Angle ..D. irectionTVD 36 8,230 54.00 N85E 6,500 N-S E-W..Dog Leg Section Coordinate .Coor¢inate °/100' 3,817 N527 E3812 0.20 Reviewed By' BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: ENDICOTT UNIT As of 0600 Hrs. Friday, January 19, 1990 WELL: 1-21/K-25 APl No. 50-029-22005 Day' 9 Depth at 0600 Hrs. = 9255' 24 Hour Footage = 749' Rig: AFE Number: AFE Amount = Current Field Costs = Doyon Rig #15 717576 Current Operation: Drilling. Summary_ of Last 24 Hours: Drill and survey 12-1/4" hole to 9255'. Wells Shut-in For Drill-By: Mud Type Mud Weight Viscosity LIGNO 9.8 #/gal 39 Sec. P V Y._EP Fluid Loss Solids 1 2 1 2 6.8 cc 9% Temp 78 °F Survey Depth Angle Direction TVD. 40 8,975 55.30 S87E 6,930 N-S E-W Section Coordinate Coordinate 4,418 N517 E4413 Dog .Leg 0/100' 0.70 Reviewed By' /,~'/~ BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: ENDICOTT UNIT As of 0600 Hrs. Monday, January 22, 1990 WELL: 1-21/K-25 APl No. 50-029-22005 Day: 1 2 Depth at 0600 Hrs. = 11 020' 72 Hour Footage = 1765' Rig: AFE Number: AFE Amount = Current Field Costs = Doyon Rig #15 717576 Current Operation: Drilling. Summary_ of Last 72. Hours: Drill and survey 12-1/4" hole to 11020'. Wells Shut-in For Drill-BY: Mud Type Mud Weight .Viscosity' LIGNO 10.0 g/gal 40 Sec. PV. YE Fluid LOSS Solids 15 10 5.2 cc 10% .T. emp 90 OF Survey Depth Angle Direction TVD 43 9,432 56..40 S86E 7,196 47 10,216 52.80 S85E 7,651 50 10,771 51.60 S84E 7,991 N-S E-W Section Coordinate Coordinate 4,795 N512 E4790 5,430 N463 E5426 5,868 N426 E5864 Dog Leg o/100' 0.40 O.5O 0.90 Reviewed By: BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: .ENDICOTT UNIT As of 0600 Hrs. Tuesday, January 23, 1990 WELL: 1-21/K-25 APl No. 5O-029-220O5 Day: 13 Depth at 0600 Hrs. = 11223 24 Hour Footage = 203 Rig: AFE Number: AFE Amount = Current Field Costs = Doyon Rig #15 717576 Current Operation: Tripping. Summary_ of Last 24 Hog,rs: Drill & Survey 12-1/4" hole to 11223'. .. Wells Shut-in FQr Drill-By; Mud Type . Mud Weight LIGNO ., 10.1 #/gal ,, ,, , ,, Viscosity 41 Sec. PV YP Fluid Loss Solids 16 13 5.3 cc 11% Temp 91 °F Survey Depth Angle D_JL.e..¢., JJ.g~ TVD 52 11,113 50.30 S85E 8,208 N-S E-W Section Coordinate Coordinate 6,128 N380 E6126 Dog Leg °/100! 0.30 Reviewed By: ,.I~,,~...~_ BP EXPLORATION DAILY DRILLING REPORT: ENDICOTT As of 0600 Hrs. Wednesday, January 24, 1990 WELL: 1-21/K-25 UNIT RIG' DOYON RIG #15 Day: 1 4 Depth at 0600 Hrs. = 11765' 24 Hour Footage = 542' APl No. AFE Number: AFE Amount = Current Field Costs = 50-029-22005 717576 Current Operation: Drilling Summary of Last 24 Hours: Drill and survey 12-1/4" hole to 11765'. Wells Shut-in For Drill,By: Mud Type .Mud Weight Viscosity FW/LIG 10.2 Cf/gal 38 Sec. PV YP Fluid Loss Solids 1 5 1 1 5.0 cc 1 2% Temp 92 OF Survey Depth Angle Directi0n TVD. 54 11,524 50.80 S85E 8,470 N-S E-W Section Coordinate Coordinate 6,443 N355 W6442 Dog Leg °/100: 0.40 Reviewed By: BP EXPLORATION DAILy DRILLING REPORT: ENDICOTT As of 0600 Hrs. Thursday, January 25, 1990 WELL: 1-21/K-25 UNIT RIG: DOYON RIG #15 Day' 1 5 Depth at 0600 Hrs. = 11962' 24 Hour Footage = 197' APl No. AFE Number: AFE Amount = Current Field Costs = 50-029-22005 717576 Current Operation' Tripping. Summary of Last 24 Hours: Drill and survey 12-1/4" hole to 11962'. Wells Shut-in For Drill-By: Mud Type Mud Weight Vi$¢0'sity LW/LIG 10.2 lC/gal 38 Sec. PV YP Fluid LOSS Solids' 16 12 5.2 cc 12% Temp oF Survey Depth Angle Direction 'TVD 55 11,718 51.40 S85E 8,592 N-S E-W Section Coordinate Coordinate 6,594 N342 E6592 Dog Leg o/100' 0.3.0 Reviewed By' BP EXPLORATION DAILY DRILLING REPORT: ENDICOTT As of 0600 Hrs. Friday, January 26, 1990 WELL: 1-21/K-25 UNIT RIG: DOYON RIG #15 Day' 1 6 Depth at 0600 Hrs. = 12245' 24 Hour Footage = 283' APl No. AFE Number: AFE Amount = Current Field Costs = 50-029-22005 717576 Current Operation' Drilling. Summary of Last 24 Hours' Drill and survey 12-1/4" hole to 12245'. Wells Shut-in For Drill-By: Mud. Type FW/LIG Mud Weight Viscosity 10.2 Cf/gal 38 Sec. PV YP. Fluid Loss Solids 15 10 5.1 cc 13% Temo oF Survey Depth Angle 56 11,915 51.30 Direction TVD S84E 8,715 N-S E-W Section 0Qordinate Coordinate 6,747 N327 E6745 Dog Leg °/100' 0.30 Reviewed By: /¢r/~ BP EXPLORATION DAILY DRILLING REPORT: ENDICOTT As of 0600 Hrs. Monday, January 29, 1990 WELL: 1-21/K-25 UNIT RIG: DOYON RIG #15 Day: 1 9 Depth at 0600 Hrs. = 13494' 72 Hour Footage = 1249' APl No. AFE Number: AFE Amount = Current Field Costs = 50-029-22005 717576 Current Operation' POH to run 9-5/8" casing. Summary of Last 72 Hours: Drill and survey to 12-1/4" hole TD at 13494'. Condition hole. Wells Shut-in For Drill-By: Mud Type Mud Weight Viscosity P V YP FW/LIG 10.4 #/gal 38 Sec. 1 4 1 0 Fluid Loss .Solids 5.0 cc 14% Temp 86 OF Survey Depth Angle Direction TVD_ 58 12,231 49.30 S83E 8,917 62 12,836 45.70 S79E 9,325 66 13,494 39.50 S71E 9,805 N-S E-W Section Coordinate Coordinate 6,988 N301 E6987 7,429 N235 E7429 7,865 N129 E7865 Dog Leg °/100' O.8O 1.30 1.60 Reviewed By: /~-~~ BP EXPLORATION DAILY DRILLING REPORT: ENDICOTT As of 0600 Hrs. Tuesday, January 30, 1990 WELL: 1-21/K-25 UNIT RIG' DOYON #15 Day' 20 Depth at 0600 Hrs. = 24 Hour Footage = 0 13494' APl No. AFE Number: AFE Amount = Current Field Costs = 50-029-22005 717576 Current Operation: P/U 8-1/2" BHA. Summary of Last 24 Hours: Run and cement 9-5/8" casing - shoe at 13488'. Install packoff. Wells Shut-in For Drill-By: Mud Type Mud Weight Viscosity .P..V .YP. Fluid Loss Solids .Temp FW/LIG 10.4 #/gal 38 Sec. 1 4 1 4 5.0 cc 1 4% °F Survey Depth Angle Direction TVD N-S E-W Dog Leg Section Coordinate Coordinate "/100' Reviewed By: ,,~~ BP EXPLORATION DAILY DRILLING REPORT: ENDICOTT As of 0600 Hrs. Wednesday, January 31, 1990 WELL: 1-21/K-25 UNIT RIG: DOYON #15 Day: 21 Depth at 0600 Hrs. = 14035' 24 Hour Footage = 541' APl No. AFE Number: AFE Amount = Current Field Costs = 50-029-22005 717576 Current Operation: Drilling. Summary of Last 24 Hours: Test 9-5/8" casing to 3000 psi. - OK. Drill out cement and shoe. Drill 8-1/2" hole to 14035'. Wells Shut-in For Drill-By: Mud Type FW/LIG Mud Weight Viscosity P.V YP Fluid Loss Solids Temp 9.7 Cf/gal 37 Sec. 8 8 6.8 cc 8% 96 °F Survey Depth Angle Direction N-S E-W Dog Leg TVD Section Coordinate Coordinate °/100' Reviewed By: BP EXPLORATION DAILY DRILLING REPORT: ENDICOTT As of 0600 Hrs. Thursday, February 1, 1990 WELL: 1-21/K-25 UNIT RIG: DOYON #15 Day: 22 Depth at 0600 Hrs. = 14,100' 24 Hour Footage = 66 APl No. AFE Number: AFE Amount = Current Field Costs = 50-029-22005 717576 Current Operation: Logging. Summary of Last 24 Hours: Drill 8-1/2" hole to TD at 14100'. Condition hole. POH for logs. Wells Shut-in For Drill-By: , Mud Tvoe Mud Weiaht Viscosity . . _ Ligno 9.7 #/gal 37 Sec. Angle J2LE¢.¢,2[¢~ TVD PV yp, ~ Solids 11 7 5.8 cc 8% N-$ E-W Section Coordinate Coordinate Temo · oF Dog Leg °/100' Reviewed By: ~¢-,~¢~' BP EXPLORATION DAILY DRILLING REPORT: ENDICOTT As of 0600 Hrs. Friday, February 2, 1990 WELL: 1-21/K-25 UNIT RIG: DOYON #15 Day: 23 Depth at 0600 Hrs. = 1 4,100' 24 Hour Footage = 0 APl No. AFE Number: AFE Amount = Current Field Costs = 50-029-22005 717576 Current Operation' POH. Summary of Last 24 Hours: Run open hole logs. Make wiper trip for 7" liner. Wells Shut-in For Drill-By: Mud Tvoe Ligno Survey Anale Mud Weight Viscosity P V 9.7 #/gal 37 Sec. 9 yp ~ Sol~ds 7 6.6 cc 8% N-S E-W Section Coordinate Coordinate Temo 86 OF Dog Leg °/10g_' Reviewed By: /~¢~ BP EXPLORATION DAILY DRILLING REPORT: ENDICOTT As of 0600 Hrs. Monday, February 5, 1990 WELL: 1-21/K-25 UNIT RIG: DOYON #15 Day: 26 Depth at 0600 Hrs. = 14,000' PBTD 72 Hour Footage = 0 APl No. AFE Number: AFE Amount = Current Field Costs = 50-029-22005 717576 Current Operation' Running cased hole logs. Summary of Last 72 Hours: Run and cement 7" liner; shoe at 14085'. Ddli out cement. Displace well to 9.4 ppg filtered brine. Test liner to 3000 psi - ok. Wells Shut-in For Drill-By: MudTv.De Mud Weight Viscosity P V ,Yp ~ Solids Temp Brine 9.4 #/gal Sec. cc °F Suwey ~ Angle J~EC_CJ.[¢~ TVD N-$ E-W Dog Leg Section Coordinate Coordipate °/100' Reviewed By: ~'~~ BP EXPLORATION DAILY DRILLING REPORT: ENDICOTT As of 0600 Hrs. Tuesday, February 6, 1990 WELL: 1-21/K-25 UNIT RIG: DOYON #15 Day' 27 Depth at 0600 Hrs. = 24 Hour Footage = 0 14000' PBTD APl No. AFE Number: AFE Amount = Current Field Costs = 50-029-22005 717576 Current Operation' Perforating well. Summary of Last 24 Hours: Run bond longs and gyro. RIH with driilpipe conveyed perforating guns. Log guns into place. Test surface equipment. Wells Shut-in For Drill-By: MudType Mud Weight Viscosity_ P.,.V. YP ,F!ufd Loss Solids BRINE 9.4 Cf/gal Sec. cc Survey Depth Temp oF Anale -- Direction .TVD, N-S E-W Dog Leg Section Coordinate .Coordinate °/100' Reviewed By:/~~ BP EXPLORATION DAILY DRILLING REPORT: ENDICOTT As of 0600 Hrs. Wednesday, February 7, 1990 WELL: 1-21/K-25 UNIT RIG: DOYON #15 Day: 28 Depth at 0600 Hrs. = 24 Hour Footage = 0 14,000 PBTD AP! No. AFE Number: AFE Amount = Current Field Costs = 50-029-22005 717576 Current Operation: Run 3-1/2" tubing. Summary of Last 24 Hours: Perforate well and flow to surface. Kill well. POH. Wells Shut-in For Drill-By: Mud Type Mud Weight Viscosity P V NaCL 9.4 Cf/gal Sec. YP. Fluid Loss Solids Temp cc °F Survey Depth Angle Direction N-S E-W Dog Leg TVD. Section Coordinate Coordinate °/100' Reviewed By: ,¢¢'~¢,~-. BP EXPLORATION DAILY DRILLING REPORT: ENDICOTT As of 0600 Hrs. Thursday, February 8, 1990 WELL: 1-21/K-25 UNIT RIG: DOYON #15 Day' 29 Depth at 0600 Hrs. = -! 4,000' 24 Hour Footage = 0' APl No. AFE Number: AFE Amount = Current Field Costs = 50-029-22005 717576 Current Operation' Rig released. Summary of Last 24 Hours' Run 3-1/2" completion string. Install tree and test to 5000 psi. Set packer and test tubing to 3000 psi. Test annulus to 2500 psi. Displace tubing to diesel and install BPV. Release rig from well 1-21/K-25 at 0600 hrs on 2/8/90. Wells Shut-in For Drill.-By: Mud Type NaCL Mud Weight Viscosity P V .YP. Fluid Loss Solids Temp 9.4 Cf/gal Sec. cc °F Survey Depth ~,ngle Direction TVD N-S.. E-W Dog Leg SectiQn Coordinate Coordinate 0/100, Reviewed By: /¢~"'~~ GREAT LAND DIRECTIONAL DRILLING INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY m wmmmm~mmmmmm BP EXPLORATION COMPANY MPI # 1-21/K-25 WEST EILEEN, ALASKA LOCATION AL-1-90-D2 MWD 1/31/90 m m m m m m m m mm mmm mmm mmmmmmmmmm m mmm mm m mmm mmmmmmmm mmmmmm m mmmm mmm~mmm JOB NUMBER TYPE SURVEY DATE BRIAN WEST SUPERVISOR NAME T I TLE S I GNATURE 0 FT 13494 FT ~ DEPTH INTERVAL FROM TO 1/7/90 1/29/90 DATE SURVEY TAKEN FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. GREAT LAND DIRECTIONAL DRILLING,INC Client .............. : BP EXPLORATION Well ................ : MPI # 1-21/K-25 Vertical Section at.: N 89.59 E Magnetic Declination: 30 deg 36 min E Data file name ...... : B:MK25D.DAT RECORD OF SURVEY (Well assumed vertical to MD of 1/31/9 Computation: RADIUS OF CURVATURE Survey date: 1-10-90 Method ..... : MWD RKB Height.: 55.1 ft 0.0) MEAS DRIFT TRUVERT SUBSEA SECTION DEPTH DG MN DEPTH DEPTH DIST DIRECTION RELATIVE COORDINATES ANGLE FROM WELL-HEAD 0 481 932 1470 1931 0 0 0.00 -55.10 0 15 481.00 425.90 0 0 932.00 876.90 0 0 1470.00 1414.90 0 30 1930.99 1875.89 0.00 N 0.00 E -0.01 S 0.00 E -0.01 S 0.00 E -0.01 S 0.00 E 0.18 N 5.00 E 0.00 N 0.00 E 1.05 S 0.00 E 2.03 S 0.00 E 2.03 S 0.00 E 0.03 S 0.18 E CLOSURE DISTANCE DG MN S -- 0.00 N 0 0 0 E 1.05 S 0 0 0 E 2.03 S 0 0 0 E 2.03 S 0 0 0 E 0.18 S 80 27 16 E DOG LE deg/10 0.00 0.05 0.05 0.00 0.10 2499 2598 2631 2725 2820 1 0 2498.94 2443.84 3 0 2597.88 2542.78 4 0 2630.81 2575.71 6 30 2724.41 2669.31 9 12 2818.51 2763.41 5.45 $ 80.00 E 8.87 S 85.00 E 10.88 N 82.00 E 19.37 N 79.00 E 32.00 N 74.00 E 4.00 N 5.42 E 3.54 N 8.85 E 3.60 N 10.85 E 5.02 N 19.34 E 8.04 N 31.95 E 6.73 N 53 36 25 E 9.53 N 68 9 39 E 11.44 N 71 39 50 E 19.98 N 75 27 19 E 32.95 N 75 51 60 E 0.08 2.02 3.03 2.66 2.84 2914 12 18 2910.85 2855.75 3009 15 0 3003.16 2948.06 3104 17 12 3094.43 3039.33 3198 20 30 3183.37 3128.27 3290 24 48 3268.26 3213.16 49.14 N 81.00 E 71.33 N 82.00 E 97.52 N 85.00 E 127.81 N 86.00 E 163.14 N 85.00 E 11.84 N 49.05 E 15.15 N 71.22 E 18.13 N 97.39 E 20.51 N 127.67 E 23.29 N 162.98 E 50.46 N 76 26 1 E 72.82 N 77 59 29 E 99.07 N 79 27 14 E 129.30 N 80 52 17 E 164.63 N 81 51 58 E 3.31 2.84 2.33 3.51 4.67 3387 27 24 3355.36 3300.26 3478 28 54 3435.59 3380.49 3568 30 42 3513.69 3458.59 3682 32 12 3610.94 3555.84 3773 34 18 3687.04 3631.94 205.61 N 83.00 E 248.16 N 81.00 E 292.19 N 78.00 E 350.11 N 75.00 E 398.50 N 76.00 E 27.75 N 205.41 E 33.73 N 247.92 E 41.88 N 291.90 E 55.76 N 349.72 E 68.25 N 398.03 E 207.28 N 82 18 19 E 250.21 N 82 15 11 E 294.88 N 81 50 8 E 354.14 N 80 56 27 E 403.84 N 80 16 11 E 2.71 1.72 2.18 1.51 2.33 3864 37 0 3760.98 3705.88 3957 40 0 3833.75 3778.65 4052 43 54 3904.39 3849.29 4146 46 48 3970.45 3915.35 4240 49 48 4032.97 3977.87 450.35 N 79.00 E 507.35 N 80.00 E 569.86 N 79.00 E 635.78 N 81.00 E 705.17 N 81.00 E 79.73 N 449.80 90.28 N 506.71 101.85 N 569.14 113.46 N 634.99 124.44 N 704.30 456.81 N 79 56 54 E 514.69 N 79 53 52 E 578.18 N 79 51 15 E 645.05 M 79 52 9 E 715.21 N 79 58 49 E 3.19 3.25 4.13 3.28 3.19 MPI # 1-21/K-25 1/31/90 RECORD OF SURVEY MEAS DRIFT TRUVERT SUBSEA SECTION DEPTH DG MN DEPTH DEPTH DIST 4335 53 12 4092.10 4037.00 778.58 N 80.00 E 4425 54 48 4145.00 4089.90 850.47 N 81.00 E 4521 54 36 4200.47 4145.37 928.04 N 82.00 E 4615 54 12 4255.19 4200.09 1003.80 N 82.00 E 4710 53 54 4310.97 4255.87 1080.03 N 82.00 E DIRECTION RELATIVE COORDINATES ANGLE FROM WELL-HEAD 136.71 N 777.62 E 148.72 N 849.43 E 160.30 N 926.91 E 170.94 N 1002.60 E 181.64 N 1078.76 E 4804 53 36 4366.55 4311.45 1155.17 N 82.00 E 4899 53 18 4423.12 4368.'02 1230.90 N 83.00 E 4993 52 54 4479.56 4424.46 1305.50 N 82.00 E 5087 52 30 4536.53 4481.43 1379.62 N 82.00 E 5182 52 6 4594.62 4539.52 1454.21 N 83.00 E 192.19 N 1153.83 E 202.16 N 1229.49 E 211.97 N 1304.02 E 222.37 N 1378.06 E 232.19 N 1452.58 E 5272 51 48 4650.09 4594.99 1524.54 N 82.00 E 5369 51 30 4710.28 4655.18 1600.03 N 83.00 E 5464 51 18 4769.54 4714.44 1673.78 N 83.00 E 5559 51 0 4829.14 4774.04 1747.28 N 83.00 E 5654 50 30 4889.24 4834.14 1820.36 N 83.00 E 241.44 N 1522.85 E 251.36 N 1598.27 E 260.41 N 1671.96 E 269.43 N 1745.39 E 278.40 N 1818.41 E 5754 50 6 4953.12 4898.02 1896.79 N 83.00 E 5849 49 36 5014.38 4959.28 1968.92 N 83.00 E 5945 49 18 5076.79 5021.69 2041.31 N 82.00 E 6040 49 0 5138.92 5083.82 2112.45 N 81.00 E 6132 49 24 5199.04 5143.94 2181.32 N 81.00 E 287.77 N 1894.78 E 296.62 N 1966.85 E 306.14 N 2039.17 E 316.76 N 2110.24 E 327.66 N 2179.03 E 6225 49 36 5259.44 5204.34 2251.33 N 82.00 E 6327 49 42 5325.48 5270.38 2328.38 N 82.00 E 6423 49 54 5387.44 5332.34 2401.06 N 82.00 E 6516 50 24 5447.03 5391.93 2471.84 N 82.00 E 6611 50 24 5507.59 5452.49 2544.39 N 82.00 E 338.11 N 2248.97 E 348.93 N 2325.94 E 359.13 N 2398.56 E 369.07 N 2469.26 E 379.26 N 2541.75 E 6706 50 36 5568.02 5512.92 2617.14 N 83.00 E 6801 50 54 5628.12 5573.02 2690.22 N 83.00 E 6896 51 12 5687.84 5632.74 2763.53 N 82.00 E 6996 51 24 5750.37 5695.27 2840.98 N 83.00 E 7091 51 36 5809.51 5754.41 2914.76 N 82.00 E 388.83 N 2614.42 E 397.79 N 2687.44 E 407.44 N 2760.69 E 417.62 N 2838.06 E 427.33 N 2911.77 E CLOSURE DISTANCE DG MN S 789.54 N 80 1 45 E 862.35 N 80 4 8 E 940.67 N 80 11 17 E 1017.07 N 80 19 27 E 1093.94 N 80 26 31 E 1169.72 N 80 32 35 E 1246.00 N 80 39 46 E 1321.13 N 80 46 2 E 1395.89 N 80 50 0 E 1471.02 N 80 55 7 E 1541.87 N 80 59 28 E 1617.91 N 81 3 44 E 1692.12 N 81 8 50 E 1766.07 N 81 13 29 E 1839.60 N 81 17 45 E 1916.51 N 81 21 51 E 1989.09 N 81 25 26 E 2062.02 N 81 27 43 E 2133.88 N 81 27 48 E 2203.52 N 81 26 55 E 2274.24 N 81 27 1 E 2351.97 N 81 28 6 E 2425.29 N 81 29 4 E 2496.69 N 81 29 57 E 2569.88 N 81 30 48 E 2643.18 N 81 32 27 E 2716.72 N 81 34 49 E 2790.59 N 81 36 17 E 2868.62 N 81 37 44 E 2942.96 N 81 39 4 E DOG LE deg/10 3.64 1.92 0.72 0.42 0.31 0.31 0.74 0.79 0.42 0.77 0.76 0.70 0.21 0.31 0.52 0.40 0.52 0.67 0.67 0.43 0.66 0.09 0.20 0.53 0.00 0.66 0.31 0.71 0.64 0.68 MPI # 1-21/K-25 1/31/9o RECORD OF SURVEY MEAS DEPTH DG MN DEPTH DEPTH DIST ANGLE m m mmmmm 7186 51 54 5868.32 5813.22 2988.71 N 82.00 E 7281 52 6 5926.81 5871.71 3063.00 N 83.00 E 7382 51 36 5989.20 5934.10 3141.81 N 82.00 E 7477 51 54 6048.01 5992.91 3215.85 N 83.00 E 7552 52 18 6094.08 6038.98 3274.64 N 83.00 E mmmmm m DRIFT TRUVERT SUBSEA SECTION DIRECTION RELATIVE COORDINATES FROM WELL-HEAD m m 437.71 N 2985.65 E 447.48 N 3059.87 E 457.85 N 3138.62 E 467.58 N 3212.58 E 474.80 N 3271.32 E 7647 52 30 6152.05 6096.95 3349.48 N 84.00 E 7741 52 48 6209.08 6153.98 3423.78 N 83.00 E 7836 53 6 6266.31 6211.21 3499.17 N 84.00 E 7939 53 24 6327.94 6272.84 3581.37 N 85.00 E 8034 53 6 6384.78 6329.68 3657.25 N 85.00 E 483.32 N 3346.11 E 491.78 N 3420.35 E 500.36 N 3495.68 E 508.27 N 3577.83 E 514.90 N 3653.66 E 8135 54 0 6444.79 6389.69 3738.17 N 84.00 E 8230 54 0 6500.63 6445.53 3814.72 N 85.00 E 8386 54 0 6592.32 6537.22 3940.73 N 88.00 E 8498 52 36 6659.25 6604.15 4030.49 S 87.00 E 8591 53 6 6715.42 6660.32 4104.48 S 87.00 E 522.69 N 3734.52 E 530.06 N 3811.03 E 537.76 N 3936.98 E 536.98 N 4026.75 E 533.10 N 4100.77 E 8684 53 42 6770.87 6715.77 4179.01 S 87.00 E 8786 53 54 6831.11 6776.01 4261.18 S 87.00 E 8880 54 54 6885.83 6830.73 4337.47 S 87.00 E 8975 55 18 6940.18 6885.08 4415.25 S 87.00 E 9069 55 36 6993.49 6938.39 4492.49 S 86.00 E 529.19 N 4175.33 E 524.88 N 4257.53 E 520.88 N 4333.85 E 516.80 N 4411.66 E 512.08 N 4488.94 E 9164 55 36 7047.16 6992.06 4570.64 S 86.00 E 9265 55 48 7104.08 7048.98 4653.83 S 86.00 E 9452 56 24 7208.38 7153.28 4808.58 S 86.00 E 9534 55 48 7254.11 7199.01 4876.39 S 85.00 E 9629 55 24 7307.78 7252.68 4954.43 S 85.00 E 506.61 N 4567.13 E 500.79 N 4650.37 E 489.96 N 4805.20 E 484.62 N 4873.05 E 477.79 N 4951.14 E 9725 54 42 7362.78 7307.68 5032.83 S 86.00 E 9825 54 24 7420.78 7365.68 5114.05 S 86.00 E 9919 53 48 7475.89 7420.79 5189.91 S 85.00 E 10029 53 30 7541.09 7485.99 5278.18 S 86.00 E 10124 53 0 7597.93 7542.83. 5354.07 $ 86.00 E 471.62 N 5029.58 E 465.94 N 5110.84 E 459.96 N 5186.75 E 453.01 N 5275.07 E 447.70 N 5351.01 E CLOSURE DISTANCE DG MN S 3017.57 N 81 39 35 E 3092.42 N 81 40 48 E 3171.84 N 81 42 2 E 3246.43 N 81 43 8 E 3305.60 N 81 44 30 E 3380.83 N 81 46 51 E 3455.52 N 81 49 5 E 3531.31 N 81 51 15 E 3613.75 N 81 54 53 E 3689.76 N 81 58 42 E 3770.93 N 82 1 57 E 3847.71 N 82 4 55 E 3973.54 N 82 13 19 E 4062.39 N 82 24 15 E 4135.28 N 82 35 35 E 4208.73 N 82 46 36 E 4289.76 N 82 58 19 E 4365.04 N 83 8 48 E 4441.83 N 83 19 7 E 4518.05 N 83 29 32 E 4595.15 N 83 40 13 E 4677.25 N 83 51 13 E 4830.11 N 84 10 41 E 4897.09 N 84 19 14 E 4974.14 N 84 29 17 E 5051.64 N 84 38 35 E 5132.04 N 84 47 27 E 5207.11 N 84 55 56 E 5294.49 N 85 5 30 E 5369.70 N 85 13 3 E DOG LE deg/10 0.31 0.68 0.78 0.72 0.53 0.69 0.74 0.74 0.69 0.31 1.10 0.68 1.25 3.08 0.53 0.64 0.19 1.06 0.42 0.79 0.00 0.19 0.32 1.11 0.42 1.00 0.30 0.94 0.64 0.52 MPI # 1-21/K-25 1/31/9o RECORD OF SURVEY MEAS DEPTH DG MN DEPTH DEPTH DIST ANGLE mmmmmmmm 10217 52 48 7654.03 7598.93 5427.97 S 85.00 E 10311 52 30 7711.06 7655.96 5502.37 S 85.00 E 10405 52 12 7768.48 7713.38 5576.46 S 85.00 E 10574 52 36 7871.59 7816.49 5709.86 S 86.00 E 10670 51 54 7930.37 7875.27 5785.49 S 85.00 E mm DRIFT TRUVERT SUBSEA SECTION DIRECTION RELATIVE COORDINATES FROM WELL-HEAD mmmmmmm m mm 441.88 N 5424.95 E 435.37 N 5499.39 E 428.88 N 5573.53 E 418.38 N 5707.02 E 412.42 N 5782.69 E 10771 51 36 7992.89 7937.79 5864.38 S 84.00 E 10866 51 6 8052.23 7997.13 5938.18 S 85.00 E 10968 50 42 8116.56 8061.46 6016.98 S 85.00 E 11062 50 30 8176.22 8121.12 6089.30 S 85.00 E 11113 50 18 8208.73 8153.63 6128.42 S 85.00 E 404.82 N 5861.64 E 397.71 N 5935.49 E 390.81 N 6014.34 E 384.48 N 6086.70 E 381.05 N 6125.85 E 11230 50 6 8283.62 8228.52 6217.83 S 84.00 E 11327 50 24 8345.65 8290.55 6292.07 S 86.00 E 11429 50 48 8410.39 ~ 8355.29 6370.60 S 85.00 E 11524 50 48 8470.43 8415.33 6443e'89 S 85.00 E 11624 51 0 8533.50 8478.40 6521.08 S 84.00 E 372.44 N 6215.32 E 365.94 N 6289.61 E 359.75 N 6368.19 E 353.34 N 6441.53 E 345.90 N 6518.77 E 11718 51 24 8592.40 8537.30 6593.95 S 85.00 E 11822 51 24 8657.28 8602.18 6674.79 S 84.00 E 12009 50 54 8774.59 8719.49 6819.52 S 84.00 E 12094 50 6 8828.65 8773.55 6884.70 S 84.00 E 12231 49 42 8916.90 8861.80 6988.73 S 83.00 E 338.88 N 6591.69 E 331.09 N 6672.60 E 315.87 N 6817.43 E 309.01 N 6882.66 E 297.15 N 6986.78 E 12401 48 18 9028.42 8973.32 7115.95 S 83.00 E 12555 47 30 9131.67 9076.57 7228.98 S 81.00 E 12656 47 12 9200.10 9145.00 7302.27 S 81.00 E 12749 46. 42 9263.58 9208.48 7369.21 S 80.00 E 12836 45 42 9323.80 9268.70 7430.87 S 79.00 E 281.51 N 7114.12 E 265.61 N 7227.27 E 253.99 N 7300.64 E 242.77 N 7367.66 E 231.33 N 7429.40 E 12939 45 6 9396.12 9341.02 7502.76 S 79.00 E 13034 44 48 9463.35 9408.25 7568.55 S 79.00 E 13134 43 48 9534.92 9479.82 7636.89 S 78.00 E 13227 42 42 9602.66 9547.56 7698.87 S 76.00 E 13321 41 48 9672.24 9617.14. 7759.79 S 74.00 E 217.34 N 7501.40 E 204.53 N 7567.28 E 190.61 N 7635.72 E 176.27 N 7697.80 E 159.92 N 7758.85 E CLOSURE DISTANCE DG MN S 5442.92 N 85 20 36 E 5516.60 N 85 28 25 E 5590.01 N 85 35 59 E 5722.33 N 85 48 26 E 5797.37 N 85 55 14 E 5875.60 N 86 2 57 E 5948.80 N 86 9 60 E 6027.03 N 86 16 56 E 6098.83 N 86 23 8 E 6137.69 N 86 26 26 E 6226.47 N 86 34 15 E 6300.25 N 86 40 13 E 6378.34 N 86 45 60 E 6451.21 N 86 51 37 E 6527.94 N 86 57 45 E 6600.40 N 87 3 25 E 6680.81 N 87 9 34 E 6824.75 N 87 20 50 E 6889.59 N 87 25 46 E 6993.10 N 87 33 53 E 7119.69 N 87 44 2 E 7232.14 N 87 53 43 E 7305.05 N 88 0 27 E 7371.66 N 88 6 46 E 7433.01 N 88 12 60 E 7504.54 N 88 20 26 E 7570.04 N 88 27 6 E 7638.10 N 88 34 12 E 7699.82 N 88 41 18 E 7760.49 N 88 49 9 E DOG LE deg/10 0.71 0.31 0.31 0.44 0.97 0.67 0.82 0.39 0.21 0.39 0.53 1.26 0.70 0.00 0.63 0.77 0.58 0.26 0.94 0.51 0.82 0.87 0.29 0.78 1.29 0.58 0.31 1.10 1.54 1.34 MPI # 1-21/K-25 1/31/90 RECORD OF SURVEY MEAS DRIFT TRUVERT SUBSEA SECTION DIRECTION RELATIVE COORDINATES DEPTH DG MN DEPTH DEPTH DIST ANGLE FROM WELL-HEAD 13419 40 24 9746.09 9690.99 7821.26 S 72.00 E 141.08 N 7820.45 E 13494 39 30 9803.58 9748.48 7866.82 S 71.00 E 125.80 N 7866.12 E CLOSURE DISTANCE DG MN S 7821.72 N 88 57 59 E 7867.12 N 89 5 2 E DOG LE deg/10 1.66 1.31 MPI # 1-21/K-25 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 1/31/90 MEAS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DEPTH D IFF . CORRECT 55 55 0 0 0 155 155 100 0 0 255 255 200 0 0 355 355 300 0 0 455 455 400 0 0 555 555 500 0 0 655 655 600 0 0 755 755 700 0 0 855 855 800 0 0 955 955 900 0 0 1055 1055 1000 0 0 1155 1155 1100 0 0 1255 1255 1200 0 0 1355 1355 1300 0 0 1455 1455 1400 0 0 1555 1555 1500 0 0 1655 1655 1600 0 0 1755 1755 1700 0 0 1855 1855 1800 0 0 1955 1955 1900 0 0 2055 2055 2000 0 0 2155 2155 2100 0 0 2255 2255 2200 0 0 2355 2355 2300 0 0 2455 2455 2400 0 0 2555 2555 2500 0 0 2655 2655 2600 0 0 2756 2755 2700 i 1 2857 2855 2800 2 1 2960 2955 2900 5 3 RELATIVE COORDINATES FROM WELL-HEAD 0.12 S 0.00 E 0.34 S 0.00 E 0.56 S 0.00 E 0.77 S 0.00 E 0.99 S 0.00 E 1.21 S 0.00 E 1.43 S 0.00 E 1.65 S 0.00 E 1.87 S 0.00 E 2.03 S 0.00 E 2.03 S 0.00 E 2.03 S 0.00 E 2.03 S 0.00 E 2.03 S 0.00 E 2.03 S 0.00 E 1.66 S 0.03 E 1.23 S 0.07 E 0.79 S 0.11 E 0.36 S 0.15 E 0.14 N 0.40 E 0.85 N 1.32 E 1.56 N 2.25 E 2.27 N 3.17 E 2.98 N 4.09 E 3.68 N 5.02 E 3.74 N 7.36 E 3.97 N 13.06 E 6.00 N 23.45 E 9.55 N 38.73 E 13.42 N 59.68 E MPI # 1-21/K-25 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 1/31/9o MEAS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DEPTH D IFF. CORRECT m 3063 3055 3000 8 3 3168 3155 3100 13 5 3276 3255 3200 21 8 3387 3355 3300 32 11 3500 3455 3400 45 13 3617 3555 3500 62 17 3735 3655 3600 80 18 3857 3755 3700 102 22 3986 3855 3800 131 29 4124 3955 3900 169 38 4276 4055 4000 221 52 4442 4155 4100 287 66 4615 4255 4200 360 73 4785 4355 4300 430 70 4952 4455 4400 497 67 5117 4555 4500 562 65 5280 4655 4600 625 63 5441 4755 4700 686 61 5600 4855 4800 745 59 5757 4955 4900 802 57 5912 5055 5000 857 55 6065 5155 5100 910 53 6218 5255 5200 963 53 6373 5355 5300 1018 55 6529 5455 5400 1074 56 6686 5555 5500 1131 57 6844 5655 5600 1189 58 7004 5755 5700 1249 60 7165 5855 5800 1310 ~ 61 7327 5955 5900 1372 62 RELATIVE COORDINATES FROM WELL-HEAD 16.85 N 86.12 E 19.76 N 118.04 E 22.86 N 157.50 E 27.74 N 205.29 E 35.76 N 258.91 E 47.79 N 316.52 E 63.01N 377.75 E 78.82 N 445.68 E 93.78 N 525.58 E 110.76 N 619.69 E 129.03 N 731.74 E 150.83 N 863.54 E 170.92 N 1002.47 E 190.02 N 1138.36 E 207.71 N 1271.71 E 225.51 N 242.26 N 258.21 N 273.30 N 288.06 N 1401.89 E 1529.13 E 1654.00 E 1776.93 E 1897.11 E 302.83 N 319.70 N 337.36 N 353.81 N 370.43 N 2014.04 E 2128.75 E 2243.94 E 2360.66 E 2478.91 E 386.78 N 402.15 N 418.40 N 435.37 N 452.18 N 2598.89 E 2720.53 E 2843.96 E 2969.04 E 3095.58 E HP~' # 1-21/K-25 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 1/31/9o MEAS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DEPTH DIFF. CORRECT 12441 9055 9000 3386 52 12590 9155 9100 3435 49 12737 9255 9200 3482 47 12881 9355 9300 3526 44 13022 9455 9400 3567 41 13162 9555 9500 3607 40 13298 9655 9600 3643 36 13431 9755 9700 3676 33 RELATIVE COORDINATES FROM WELL-HEAD 277.40 N 261.63 N 244.27 N 225.27 N 206.10 N 7143.35 E 7252.39 E 7358.71 E 7460.56 E 7559.19 E 186.34 N 163.94 N 138.69 N 7654.21 E 7743.81 E 7827.61 E MPI # 1-21/K-25 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 1/31/9o MEAS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DEPTH DIFF. CORRECT 7489 6055 6000 1434 62 7652 6155 6100 1497 63 7817 6255 6200 1562 65 7984 6355 6300 1629 67 8153 6455 6400 1698 69 8323 6555 6500 1768 70 8491 6655 6600 1836 68 8658 6755 6700 1903 67 8827 6855 6800 1972 69 9001 6955 6900 2046 74 9178 7055 7000 2123 77 9356 7155 7100 2201 78 9536 7255 7200 2281 80 9712 7355 7300 2357 76 9884 7455 7400 2429 72 10052 7555 7500 2497 68 10219 7655 7600 2564 67 10383 7755 7700 2628 64 10547 7855 7800 2692 64 10710 7955 7900 2755 63 10871 8055 8000 2816 61 11029 8155 8100 2874 58 11185 8255 8200 2930 56 11342 8355 8300 2987 57 11500 8455 8400 3045 58 11658 8555 8500 3103 58 11818 8655 8600 3163 60 11978 8755 8700 3223 60 12135 8855 8800 3280 57 12289 8955 8900 3334 54 RELATIVE COORDINATES FROM WELL-HEAD 468.69 483.77 498.68 511.44 524.05 3221.62 E 3350.08 E 3480.92 E 3614.06 E 3748.65 E 534.63 N 537.03 N 530.30 N 523.13 N 515.48 N 3885.85 E 4021.18 E 4154.13 E 4291.00 E 4433.29 E 505.80 N 495.49 N 484'. 50 N 472.48 N 462.21 N 4578.74 E 4726.11 E 4874'.49 E 5018.63 E 5158.11 E 451.70 N 441.76 N 430.39 N 420.06 N 409.41 N 5293.78 E 5426.34 E 5556.26 E 5685.66 E 5813.92 E 397.40 N 386.72 N 375.72 N 365.04 N 354.98 N 5939.01 E 6061.09 E 6181.25 E 6301.09 E 6422.80 E 343.33 N 331.35 N 318.39 N 305.45 N 291.79 N 6545.51 E 6669.87 E 6793.37 E 6913.87 E 7030.40 E MPI # 1-21/K-25 DATA INTERPOLATED FOR EVEN 1000 FEET OF MEASURED DEPTH 1/31/9o MEAS. TRU VERT SUB SEA DEPTH DEPTH DEPTH 1000 1000 945 2000 2000 1945 3000 2994 2939 4000 3866 3811 5000 4484 4429 6000 5113 5058 7000 5753 5698 8000 6364 6309 9000 6954 6899 10000 7524 7469 11000. 8137 8082 12000 8769 8714 13000 9439 9384 RELATIVE COORDINATES FROM WELL-HEAD 2.03 S 0.00 E 0.46 N 0.81 E 14.84 N 69.12 E 95.52 N 534.97 E 212.74 N 1309.53 E 312.29 N 418.03 N 512.53 N 515.55 N 454.84 N 2080.32 E 2841.17 E 3626.52 E 4432.21E 5251.79 E 388.65 N 316,60 N 209 ;11 N 6038.98 E 6810.46 E 7543.70 E #arker Zdentif~catton BJ~ ND TVD DEPRT 0 0 0 i3494 9B04 7B67 PLAN VIEN BP EXPLORATION NPI # 1-21/K-25 CLOSURE: 7867 ft N 89.~ E DECLINATION: 30.60 deg E SCALE: i inch = ~500 feet DRANN : 1/3~/90 975o 9000 8250 7500 6750 6000 525O 4500 375O 3000 2250 1500 750 750 75O 750 i500 2250 3000 3750 4500 5250 6000 6750 7500 8250 75O i500 2250 3000 3750 4500 5250 T 6000 V 6750 D 7500 8250 9000 9750 i0500 ii250 i2000 i2750 i3500 -750 VERTICAL SECTION BP EXPLORATION MPI # ~-2~/K-25 SECTION AT N 89.59 E TVD SCALE: i inch = 1500 feet BEP SCALE: i inch = 1500 feet DRANN : i/3i/90 Warker Ident~ficat~on 14D TVD DEPRT ~JKa 0 0 0 B} TD i3494 9604 7667 750 t500 2250 3000 3750 4500 Departure 5250 6000 6750 7500 8250 ORIGINAL SUB. SURFACE DIRECTIONAL SURVEY ~UIDANCE ~IoNTINUOUS [-flooL , ICROFILMED Company BP EXPLORATION Well Name 1-21/K-25 MPI (2012',, SNL,2081' WEL,SEC 36,T12N,R16E) Field/Location ENDICOTT~ NORTH SLOPE~ ALASKA Job Referenc® No: 73690 Logaed By: SARBER Date,. 5-FEB-90 Computed By: KOHRING SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR BP EXPLORATION 1-Z1 /K-25 MPI ENDICOTT NORTH SLOPEr ALASKA SURVEY DATE: 05-FEB-1990 ENGINEER: SARBER METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 89 DEG Z8 MIN EAST COMPUTATION DATE= 21-FEB-90 PAGE I BP EXPLORATION 1-21 /K-25 ENDICOTT NORTH SLOPE~ ALASKA DATE OF SURVEY: 05-FEB-1990 KELLY BUSHING ELEVAT[ON: 55.10 FT ENGINEER= SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF HEASUREO DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -55.10 0 0 N 0 0 E 100.00 99.99 44.89 0 51 S 8 35 E ZO0.O0 199.99 144.89 0 38 S 15 35 W 300.00 299.98 244.88 0 33 S 12 17 W 400.00 399.98 344.88 0 33 S 21 22 W 500.00 499.98 444.88 0 18 S 21 9 W 600.00 599.98 544.88 0 16 S 5 37 W 700.00 699.98 644.88 0 7 S 12 23 E 800.00 799.98 746.88 0 3 N 43 23 E 900.00 899.98 844.88 0 6 N 17 36 W 0.00 0.00 0.00 N 0.00 E 0.03 0.62 0.93 S 0.02 E -0.01 0.12 2.03 S 0.04 W -0.25 0.46 3.15 S 0.29 W -0.59 0.48 3.98 S 0.63 W -0.73 0.90 4.49 S 0.78 W -0.81 0.47 4.88 S 0.87 W -0.86 0.70 5.13 S 0.92 W -0.86 0.50 5.23 S 0.93 W -0.86 0.58 5.26 S 0.92 W 0.00 N 0 0 E 0.93 S I 9 E 2.03 S I 5 W 3.16 S 5 16 W 4.03 S 9 4 W 4.56 S 9 53 W 4.96 S 10 6 W 5.21 S 10 11 W 5.32 S 10 4 W 5.34 S 9 57 W 1000.00 999.98 944.88 1100.00 I099.98 1044.88 1200.00 1199.98 1144.88 1300.00 1299.98 1244.88 1400.00 1399.98 1344.88 1500.00 1499.98 1444.88 1600.00 1599.98 1544.88 1700.00 1699.98 1644.88 '1800.00 1799.97 1744.87 1900.00 1899.97 1844.87 0 6 N 61 3 W 0 7 N 62 44 W 0 3 N 10 45 E 0 10 S 66 28 E 0 8 S 36 18 E 0 4 N 87 50 W 0 7 N 22 37 E 0 8 N 28 8 E 0 26 N 9 14 E 034 N 8 14 W -0.86 0.83 5.28 S 0.93 W -0.84 0.85 5.27 S 0.91 W -0.80 0.36 5.31 S 0.86 W -0.80 0.58 5.39 S 0.86 W -0.71 0.34 5.42 S 0.77 W -0.58 0.22 5.41 S 0.66 W -0.50 0.08 5.43 S 0.57 W -0.46 0.40 5.25 S 0.53 W -0.26 0.13 4.78 S 0.32 W -0.26 0.14 3.93 S 0.31 W 5.36 S 9 57 W 5.34 S 9 47 W 5.38 S 9 13 W 5.46 S 9 5 W 5.48 S 8 7 W 5.45 S 6 46 W 5.46 S 5 57 W 5.28 S 5 43 W 4.79 S 3 68 W 3.95 S 4 31 W ZO00.O0 1999.97 1944.87 2100.00 2099.96 2044.86 2200o00 2199.95 2144.85 2300.00 2299.94 2244.84 2400.00 2399.93 2344.83 2500.00 2499.91 2444.81 2600.00 2599.83 2544.73 2700.00 2699.52 2644.42 2800.00 2798.71 2743.61 0 31 N 12 36 E 0 39 N 24 51 E 0 48 N 44 33 E 0 55 N 54 8 E I I N 65 37 E I 27 N 74 48 E 2 54 N 84 29 E 5 50 N 81 15 E 8 40 N 77 30 E N 79 47 E 2900.00 2897.12 2842.02 11 45 -0.27 0.08 3.07 S 0.31 W 0.05 0.44 2.11 S 0.02 E 0.82 0.00 1.09 S 0.81 E 1.93 0.10 0.12 S 1.93 E 3.40 0.00 0.73 N 3.41 E 5.22 2.01 1.41 N 5.24 E 9.00 2.77 2.06 N 9.03 E 16.72 2.26 3.03 N 16.76 E 29.02 2.12 5.47 N Z9.09 E 46.29 4.35 8.99 N 46.40 E 3.08 S 5 4,6 W 2.11 S 0 36 E 1.36 S 36 38 E 1.93 S 86 35 E 3.48 N 77 50 E 5.42 N 74 53 E 9.26 N 77 8 E 17.03 N 79 45 E 29.59 N 79 21 E 67.27 N 79 2 E 3000.00 2994.44 2939.34 14 38 3100.00 3090.51 3035.41 17 17 3200.00 3185.15 3130.05 20 45 3300.00 3277.07 3221.97 25 4 3400.00 3366.59 3311.49 27 41 3500.00 3454.43 3399.33 29 25 3600.00 3540.80 3685.70 31 8 3700.00 3625.72 3570.62 32 37 3800.00 3708.85 3653.75 35 10 3900.00 3788.96 3733.86 38 16 N 82 14 E 68.96 3.16 N 86 43 E 96.51 2.97 N 88 27 E 128.72 4.30 N 87 4 E 167.98 3.16 N 86 42 E 212.38 2.72 N 80 25 E 259.67 2.26 N 78 0 E 309.01 1.92 N 77 23 E 360.60 1.92 N 78 30 E 416.59 2.92 N 79 36 E 473.20 3.16 12.29 N 69.12 E 70.20 N 79 55 E 15.08 N 96.70 E 97.87 N 81 8 E 16.23 N 128.93 E 129.95 N 82 50 E 17.67 N 168.21 E 169.13 N 84 0 E 20.78 N 212.65 E 213.66 N 84 25 E 26.91 N 260.02 E 261.41 N 84 6 E 36.52 N 309.48 E 311.62 N 83 16 E 47.96 N 361.02 E 364.19 N 82 26 E 59.58 N 415.35 E 419.60 N 81 50 E 70.93 N 474.11 E 479.38 N 81 29 E COMPUTATION DATE: Z1-FEB-90 PAGE 2 BP EXPLORATION 1-Z! /K-25 ENDICOTT NORTH SLOPEr ALASKA DATE OF SURVEY: 05-FEB-1990 KELLY BUSHING ELEVATION: 55.10 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE ~EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG M[N DEG MIN 4000.00 3865.54 3810044 41 54 4100.00 39~7.72 3882.62 45 34 4200.00 4005.80 3950.70 48 33 4300.00 4069.7& 4014064 52 0 4400.00 4129043 4074.33 54 17 4500.00 4187.69 4132.59 54 27 4600.00 4245.68 4190.58 54 42 4700.00 4303.89 4248.79 53 54 4800.00 4363.04 4307.94 53 36 4900.00 4422'78 4367.68 52 53 ENGINEER: SARBER 5000.00 4483.30 4428.20 52 47 5100.00 4543.73 4488.63 52 38 5200.00 4604.99 4549.89 51 59 5300000 4666.76 4611.66 51 46 5400.00 4718.87 4673.77 51 31 5500000 4791.32 4736022 51 10 5600.00 4854.25 4799.15 50 51 5700.00 4917.76 4862.66 50 19 5800.00 4981.08 4926.98 49 49 5900.00 5046.66 4991.56 49 31 VERTICAL DOG.LEG RECTANGULAR COORDINATES HORIZo DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/NEST DIST. AZIMUTH FEET OEO/lO0 FEET FEET FEET OEG MIN 6000.00 5111.97 5056.87 48 59 6100.00 5177.62 5122.52 49 3 6200.00 5242.89 5187.79 49 24 6300.00 5307.95 5252.85 49 27 6400000 5372.80 5317.70 49 40 6500.00 5437.09 5381099 50 21 6600.00 5500.99 5445.89 50 14 6700.00 5564.91 5509.81 50 24 6800.00 5618.30 5573.20 50 48 6900.00 5691.34 5636.24 51 N 80 29 E 536.36 N 81 18 E 604.52 N 82 16 E 676.87 N 82 48 E 752.96 N 83 11 E 832.45 N 83 9 E 913.04 N 83 8 E 993.79 N 83 11 E 1074.41 N 83 17 E 1154.35 N 83 27 E 1233.89 7000.00 5753.90 5698.80 51 24 7100.00 5816.Z3 5761.13 51 31 7200.00 5878.28 5823.18 51 49 7300.00 5939.98 5884.88 51 52 7400.00 6001.98 5946.88 51 35 7500.00 6063.96 6008.86 51 51 7600.00 6125.51 6070.41 52 20 7700.00 6186.47 6131.37 52 36 -7800.00 6247009 6191.99 52 50 7900.00 6307.38 6152.18 52 59 N 83 24 E 1312.85 N 83 25 E 1391088 N 83 28 E 1470.28 N 83 33 E 1548.30 N 83 38 E 1626.08 N 83 40 E 1703.58 N 83 41 E 1780.72 N 83 42 E 1857.38 N 83 44 E 1933.38 N 83 40 E 2009.17 N 83 14 E 2084.29 N 83 10 E 2159.08 N 83 7 5 2234.18 N 83 13 E 2309.47 N 83 14 E 2384.95 N 83 17 E 2460.89 N 83 29 E 2537.19 N 83 25 E 2613.47 N 83 24 E 2690.19 N 83 26 E 2767.19 N 83 28 E 2844.59 N 83 34 E 2922.17 N 83 51 E 3000.00 N 84 10 E 3078.17 N 84 38 E 3156.14 N 85 Z E 3234.21 N 85 5 E 3312.65 N 85 5 E 3391.53 N 85 4 E 3470.68 N 85 20 E 3550.10 4.19 3.30 3.28 3.40 0.88 0.28 0.69 0.26 0.35 1.18 82.02 N 537.41 E 543.63 N 81 19 E 93.03 N 605.70 E 612.80 N 81 16 E 103.41 N 678.19 E 686.03 N 81 20 E 113.34 N 754.40 E 762.87 N 81 27 E 123.17 N 834.02 5 843.07 N 81 36 E 132.81 N 914.73 E 924.3Z N 81 44 E 142.54 N 995.61 E 1005.76 N 81 51 E 152.21 N 1076.35 E 1087.06 N 81 57 E 161.74 N 1156.41 E 1167.67 N 82 2 E 170.99 N 1236.07 E 1147.84 N 82 7 E 0.11 1.61 0.58 0.43 0.15 0.45 0.45 0.35 1.08 0.49 180.12 N 1315.15 E 1327.42 N 82 12 E 189.28 N 1394.30 E 1407.08 N 82 16 E 198.34 N 147Z.81 E 1486.10 fl 82 20 E 207.24 N 1550.95 E 1564.74 N 82 23 E 215.97 N 1628.84 E 1643.09 N 82 27 E 224.61 N 1706.45 E 1721.17 N 82 30 E 233.16 N 1783.71 E 1798.88 N 82 33 E 241.68 N 1860.48 E 1876.11 N 82 36 E 250.0Z N 1936.58 E 1952.66 N 82 39 E 258.42 N 2012.47 E 20Z9.00 N 82 41 E 0o4Z 0.51 0.10 0.03 0.56 0.25 0.78 0.13 0.58 267.01 N 2087.71 E 2104.72 N 82 43 E 275.97 N 2162.61 E 2180.15 N 8,?. 44 E 285.03 N 2237.82 E 2255.90 N 82 44 E 294.05 N 2313.23 E Z331.85 N 82 45 E 303.02 N 2388.83 E 2407.97 N 82 46 E 312.03 N 2464.89 E 2484.56 N 81 47 E 320.88 N 2541.30 E 1561.48 N 82 48 E 329.63 N 2617.70 E 2638.37 N 82 49 E 338.54 N 2694.53 E 2715.71 N 82 50 E 347.44 N 2771.65 E 2793.34 N 82 51 E 0.34 0.41 0.34 0.69 0.97 0.34 0.52 0 0.68 0.50 356.34 N 2849.15 E 2871.35 N 82 52 E 365.19 N 2926.85 E 2949.54 N 82 53 E 373.76 N 3004.79 E 3027.95 N 82 55 E 381.96 N 3083.06 E 3106.63 N 82 56 E 389.67 N 3161.14 E 3185.07 N 82 58 E 396.72 N 3239.30 E 3263.50 N 83 I E 403.50 N 3317.83 E 3342.27 I~ 83 4 E 410.30 N 3396.80 E 3421.49 N 83 7 E 417.17 N 3476.04 E 3500.98 N 83 9 5 423.83 N 3555.54 E 3580.71 N 83 12 E COMPUTATION DATE: 21-FEB-90 PAGE 3 BP EXPLORATION 1-21 /K-25 ENDICOTT NORTH SLOPEr ALASKA DATE OF SUR'VEY: 05-FEB-1990 KELLY BUSHING ELEVATION: 55.10 FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF HEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEPTH 'DEG WIN DEG WIN VERTICAL OOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE' SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IOO FEET FEET FEET OEG ~IN 8000.00 6367.21 6312oll 53 29 8100.00 6426.47 6371.37 53 52 8200.00 6485.56 6430.46 53 40 8300.00 6544.65 6489.55 53 53 8&O0.O0 6603.67 6548.57 53 24 8500.00 6663.96 6608.86 52 43 8600.00 6724.42 6669.32 S2 57 8700.00 6784.20 6729.10 53 30 8800.00 6843.38 6788.28 53 56 8900.00 6901.50 6846.40 54 46 N 85 33 E 3629.88 N 85 53 5 3710.12 N 86 24 E 3790.55 N 86 50 E 3871.02 N 89 20 E 3951.63 S 86 19 E 4031.37 S 85 35 E 4110.88 S 85 22 E 4190.86 S 85 5 E 4271.27 S 85 3 E ¢35Z.42 0.45 0 0.64 0.89 3.68 1.99 1.20 0.85 1.11 0.28 430.19 N 3635.41 E 3660.77 N 83 15 E 436.23 N 3715.73 E 3741.25 N 83 18 E 441.61 N 3796.23 E 3821.83 N 83 22 E 446.40 N 3876.76 E 3902.38 N 83 26 E 449.59 N 3957.42 E 3982.88 N 83 31 E 447.19 N 4037.1¢ E &061o83 N 83 4! E 441.37 N 4116.58 E 41¢0.17 N 83 53 E 435.08 N 4196.49 E 4218.99 N 84 5 E 428.32 N 4276.82 E 4298.22 N 84 17 E 421.37 N 4357.90 E 4378.2Z N 84 29 E 9000.00 6958.71 6903.61 55 20 9100.00 7015.52 6960.42 55 29 9200.00 7072.18 7017.08 55 27 9300.00 7128.29 7073.19 56 9 9400.00 7184.08 7128.98 56 20 9500.00 7239.86 7184.76 55 41 9600.00 7296.35 7241e25 55 20 9700.00 7353.59 7298.49 54 59 9800.00 7411.46 7356.36 54 3 9900.00 7470°34 7415o24 53 47 $ 84 49 E 4434.20 S 84 50 E 4516.25 S 84 21 E 4598.37 S 83 52 E 4680.80 S 83 44 E 4763.40 S 83 49 E 4846.02 S 83 55 E 4928.16 S 84 3 E 5009.80 S 84 9 E 5091.02 S 84 16 E 5171.52 0 0.84 0.50 0.38 1 1.09 0.66 0.92 0.68 0.74 414.08 N 4439.59 E 4458.86 N 84 40 E 406.67 N 4521.55 E 4539.81 N 84 52 E 398.93 N 4603.59 E 4620.84 N 85 3 E 390.40 N 4685.92 E 4702.15 N 85 14 E 381.41 N 4768.42 E 4783.65 N 85 26 E 372.39 N 4850.93 E 4865.20 N 85 37 E 363.55 N 4932.97 E ~946.35 'N 85 47 E 354.95 N 5014.51 E 5027°06 N 85 57 E 346.56 N 5095.63 E 5107.40 N 86 7 E 338.39 N 5176.04 E 5187.09 N 86 16 E 10000.00 7529.74 7474.64 53 19 10100.00 7589.75 7534.65 52 54 10200.00 7650.18 7595.08 52 33 10300.00 7711.22 7656.12 52 21 10400.00 7772.43 7717.33 52 7 10500.00 7833.72 7778.62 52 21 10600.00 7894.79 7839.69 52 14 10700.00 7956.44 7901.34 51 37 10800.00 8018.83 7963.73 51 16 10900.00 8081.72 8026.62 50 49 S 84 21 E 5251.67 S 84 17 E 5331.35 S 84 12 E 5410.72 S 84 7 E 5489.61 S 84 I E 5568.36 S 84 I E 5647.04 S 84 6 5 5725.89 S 84 12 E 5804.30 S 84 15 E 5882.15 S 84 1~ E 5959.59 0.50 1.19 0.86 0.55 0.27 0.32 0.69 0.90 0.27 0.28 330.43 N 5256.10 E 5266.47 N 86 24 E 322°49 N 5335.69 E 5345.43 N 86 32 E 314.53 N 5414.97 5 5424.09 N 86 41 E 306.45 N 5493.77 E 5502.31 N 86 48 E 298.24 N 5572.42 E 5580.40 N 86 56 E 289.99 N 5651.00 E 5658.44 N 87 4 E 281.74 N 5729.76 E 5736.68 N 87 11 E 273.74 N 5808.08 E 5814.53 N 87 18 E 265.89 N 5885.84 E 5891.84 N 87 25 E 258.05 N 5963.19 E 5968.77 N 87 31 E '*~11000.00 8145.07 8089.97 50 31 11100.00 8208.85 8153.75 50 17 11200.00 8272.90 8217.80 50 2 11300.00 8337.03 8281.93 50 15 11400.00 8400.77 8345.67 50 32 11500.00 8464.25 8409.15 50 35 11600.00 8527.54 8472.44 50 52 11700.00 8590.37 8535.27 51 19 11800.00 8652.98 8597.88 51 10 11900.00 8715.66 8660.56 51 10 S 84 16 E 6036.67 S 84 14 5 6113.39 S 84 9 E 6189.88 S 84 0 E 6266.29 S 84 5 5 6343.01 5 84 6 E 6419.98 S 83 53 E 6497.06 S 83 48 E 6574.51 S 83 22 E 6652.09 S 83 6 5 6729.57 0.62 0.22 0.23 0.62 0.35 0.39 0.15 0.53 0 0.47 250o32 N 6040.18 E 6045.36 N 87 38 E 242.61 N 6116.81 E 6121.62 N 87 44 E 234.83 N 6193.21 E 6197.66 N 87 50 E 226.92 N 6269.53 E 6273.64 N 87 56 E 218.91 N 6346.16 E 6349.94 N 88 I .E 211.01 N 6423.03 E 6426.50 N 89 7 E 202.86 N 6500.03 E 6503.19 N 88 13 E 194.50 N 6577.37 E 6580.25 N 88 18 E 185.78 N 6654.85 E 6657.45 N 88 24 E 176.58 N 6732.23 E 6734.54 N 88 30 E COMPUTATION DATE: 21-FE8-90 PAGE BP EXPLORATION DATE OF SURVEY: 05-FEB-1990 1-21 /K-25 MPI KELLY BUSHING ELEVATION: 55.10 FT ENDICOTT NORTH SLOPEr ALASKA ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 ~EET OF'MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE MEASURED VERTICAL VERTICAL 'DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH OEPTH DEPTH DEPTH OEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET OEG MIN 12000.00 8778.46 8723.36 SO 48 12100.00 8842.24 8787.14 49 57 12200.00 8906.82 8851.72 49 35 12300.00 8972.15 8917.05 48 57 12400.00 9038.20 8983.10 48 17 12500.00 9105.09 9049.99 47 45 12600.00 9172.55 9117.45 47 24 12700.00 9240.48 9185.38 46 57 12800.00 9309.27 9254.17 46 7 12900.00 9379.04 9323.94 45 23 13000.00 9449.57 9394.47 44 58 13100.00 9520.75 9465.65 44 7 13200.00 9593.19 9538.09 43 4 13300.00 9666.8Z 9611.72 41 59 13400.00 9741.72 9686.62 40 48 13500.00 9818.14 9763.04 39 46 13600.00 9895.36 9840.26 39 13 13700.00 9973.22 9918.12 38 22 13800.00 10052.Z8 9997.18 36 30 13900.00 10134.83 10079.73 32 43 14000.00 10219.97 10164.87 31 7 14100.00 10305.59 10250.49 31 7 S 82 58 E 6806.92 S 82 44 E 6883.46 S 82 38 E 6959.30 S 82 18 E 7034.47 S 82 0 E 7108.96 S 81 34'E 7182.66 S 80 53 E 7255.75 S 80 11 E 7328.28 S 79 22 E 7399.85 S 78 54 E 7470.37 S 78 19 E 7540.03 S 77 30 E 7608.89 S 76 0 E 7676.19 S 74 37 E 7741.86 S 72 54 E 7805.71 S 72 0 E 7867.35 S 73 44 E 7928.23 S 75 53 E 7988.97 S 77 17 E 8048.76 S 77 3 E 8103.90 S 75 46 E 8154.94 S 75 46 E 8Z05.17 0.86 0.66 0.72 0.22 0.71 0.77 O.3& 1.02 0.78 0.91 0.68 1.54 0.55 1.89 1.98 0.41 1.40 2.06 5.26 2.38 0.00 0.00 167.14 N 6809.47 E 6811.52 N 88 36 E 157.58 N 6885.90 E 6887.70 N 88 41 E 147.87 N 6961.63 E 6963.2.0 N 88 47 E 137.88 N 7036.68 E 7038.03 N 88 53 E 127.65 N 7111.05 E 7112.20 N 88 58 E 117.05 N 7184.63 E 7185.58 N 89 4 E 105.78 N 7257.58 E 7258.35 N 89 10 E 93.75 N 7329.98 E 7330.58 N 89 16 E 80.82 N 7401.39 E 7401.83 N 89 22 E 67.35 N 7471.75 E 7472.06 N 89 29 E 53.35 N 7541.25 E 7541.44 N 89 36 E 38.65 N 7609.93 E 7610.03 N 89 43 E 2Z.92 N 7677.05 E 7677.08 N 89 50 E 5.80 N 7742.51 E 7742.51 N 89 57 E 12.64 S 7806.14 E 7806.15 S 89 54 E 32.36 S 7867.54 E 7867.61 S 89 46 E 51.30 S 7928.19 E 7928.36 S 89 38 E 67.75 S 7988.74 E 7989.03 S 89 31 E 81.7Z S 8048.36 E 8048.77 S 89 25 E 94.20 S 8103.36 E 8103.91 S 89 20 E 106.74 S 8154.24 E 8154.94 S 89 15 E 119.45 S 8204.33 E 8205.20 S 89 10 E COMPUTATION DATE: 21-FE8-90 PAGE 5 BP EXPLORATZON 1-21 /K-25 ENDICOTT NORTH SLOPEr ALASKA DATE OF SURVEY: 05-FEB-1990 KELLY BUSHING ELEVATION: 55.10 FT INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED OEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -55.10 0 0 1000o00 999.98 944.88 0 6 2000.00 1999.97 1944.87 0 31 3000.00 2994.44 2939.34 14 38 4000.00 3865.54 3810.44 41 54 5000.00 4483.30 4428.20 52 47 6000.00 5111.97 5056.87 48 59 7000.00 5753°90 5698.80 51 24 8000.00 6367.21 6312.11 53 29 9000.00 6958.71 6903.61 55 20 ENGINEER: SARBER 10000.00 7529.74 7474.64 53 19 11000.00 8145.07 8089.97 50 31 12000.00 8778.46 8723.36 50 48 13000.00 9449.57 9394.47 44 58 14000.00 10219.97 10[64.87 31 7 14100°00 10305.59 10250.49 31 7 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE' SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG N 0 0 E 0.00 N 61 3 W -0.86 N 12 36 E -0.27 N 82 14 E 68.96 N 80 29 E 536.36 N 83 24 E 1312.85 N 83 14 E 2084.29 N 83 28 E 2844.59 N 85 33 E 3629.88 S 84 49 E 4434.20 O.OO 0.83 0.08 3.16 4.19 0.11 0.44 0.34 0.45 0.48 0.00 N 0.00 E 0.00 N 0 0 E 5.28 S 0.93 N 5.36 S 9 57 W 3.07 S 0.31 N 3.08 S 5 46 W 12.29 N 69.12 E 70.2.0 N 79 55 E 82.02 N 537.41 E 543.63 N 81 19 E 180.11 N 1315.15 E 1327.42 N 82 12 E 267.01 N 2087.71 E 2104.72 N 82 43 E 356.34 N 2849.15 E 2871.35 N 82 52 E 430.19 N 3635.41 E 3660.77 N 83 15 E 414.08 N 4439.59 E 4458.86 N 84 40 E S 84 21 E 5251.67 S 84 16 E 6036.67 S B2 58 E 6806.92 S 78 19 E 7540.03 S 75 46 E 8154.94 S 75 46 E 8205.17 0.50 0.62 0.86 0.68 0.00 0.00 330.43 N 5256.10 E 5266.47 N 86 24 E 250.32 N 6040.18 E 6045.36 N 87 38 E 167.14 N 6809.47 E 6811.52 N 88 36 E 53.35 N 7541.25 E 7541.44 N 89 36 E 106.74 S 8154.24 E 8154.94 S 89 15 E 119.45 S 8204.33 E 8205.20 S 89 10 E COMPUTATION DATE: 21-FEB-90 PAGE 6 BP EXPLORATION 1-21 /K-25 MPI ENDICOTT NORTH SLOPE, ALASKA DATE OF SURVEY: 05-FEB-Z990 KELLY 9USHING ELEVATION: 55.10 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEa OEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -55.[0 0 0 N 0 0 E 55.t0 55.10 0.00 0 30 S 3 30 E 155.11 155.10 100.00 0 33 S 6 19 W 255.12 255.10 200.00 0 42 S 11 43 W 355.12 355.10 300.00 0 29 S 26 46 W 455.12 455.10 400.00 0 14 S 7 53 W 555.12 555.10 500.00 0 8 S 8 41 W 655.12 655.10 600.00 0 7 S 46 t W 755.12 755.10 700.00 0 9 S 23 0 W 855.12 855.10 800.00 0 6 S 32 13 E 955.12 955.10 900.00 1055.12 1055.10 1000.00 1155'12 1155.10 1100.00 1255.12 t255.10 1200.00 1355.12 1355.10 1300.00 1455.12 1455.10 1400o00 1555.12 1555.10 1500.00 1655.12 1655.10 1600.00 .1755.13 1755.10 1700.00 1855.13 1855.10 1800.00 0 5 S 70 9 E 0 6 N 79 53 E 0 7 S 54 24 E 0 7 S 31 3 W 0 Z N 49 57 W 0 7 N 49 42 E 0 7 S 82 27 E 0 5 N 5 53 E 0 20 N 24 5 E 030 N I 0 E 1955.13 1955.10 1900.00 2055.14 2055.10 2000.00 2155.14 2155.10 2100.00 2255.15 2255.10 2200.00 2355.17 2355.10 2300.00 2455.18 2455.10 2400.00 2555.22 2555.10 2500.00 2655.39 2655.10 2600.00 2755.95 2755.10 2700.00 7 24 2857.19 2855.10 2800.00 10 22 0 27 N 6 33 E 0 35 N 20 11 E 0 46 N 39 30 E 0 51 N 48 48 E I 0 N 60 35 E 1 5 N 69 30 E 2 17 N 80 5 E N 78 11 E N 78 39 E 2959.44 2955.10 2900.00 13 32 3063.00 3055.10 3000.00 16 29 3168.01 3155.10 3100.00 19 20 3275.80 3255.10 3200.00 24 17 3387.03 3355.10 3300.00 27 25 3500.78 3455.10 3400.00 29 25 3616.72 3555.10 3500.00 31 25 3735.02 3655.10 3600.00 33 22 3857.27 3755.10 3700.00 36 56 3985.97 3855.10 3800.00 41 20 ENGINEER: SARBER VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET' OEG 0.00 0.00 0.00 N 0.00 E -0.03 1.63 0.36 S 0.03 W 0.08 0.39 1.58 S 0.06 E -0.17 0.26 2.66 S 0.20 g -0.40 0.53 3.59 S 0.45 W -0.68 0.16 4'.33 S 0.73 W -0.77 0.24 4.74 S 0.82 W -0.83 0.95 5.02 S 0.90 W -0.88 0.62 5.18 S 0.95 W -0.89 0.4,5 5.27 S 0.95 W -0.88 0.50 5.31 S 0.94 -0.85 0.61 5.32 S 0.92 -0.85 0.33 5.32 S 0.92 -0.85 0.70 5.31 S 0.91 -0.71 0.27 5.37 S 0.78 -0.58 0.45 5.45 S . 0.64 -0.58 0.23 5.48 S 0.64 -0.48 0.00 5.33 S 0.55 -0.34 0.26 5.06 S 0.40 -0.23 0.04 4.35 S 0.29 0.00 N 0 0 E 0.36 S 5 32 W 1.58 S Z 21 E 2.67 S 4 23 W 3.62 S 7 4 W 4.39 S 9 35 W 4.81 S 9 52 W 5.10 S 10 7 W 5.26 S 10 22 W 5.36 S 10 15 N -0.34 0.48 3.43 S 0.38 W -0.13 0.00 2.56 S 0.16 W 0.42 0.15 1.54 S 0.40 E 1.39 0.25 0.55 S 1.38 E 2.69 0.30 0.38 N 2.69 E 4'.31 0.4'0 1.12 N 4.33 E 7.03 1.26 1.81 N 7.05 E 12.66 2.51 2.49 N 12.69 E 22.96 3.40 4.17 N 23.01 E 38.28 2.62 7.¢7 N 38.38 E 5.39 S 10 3 W 5.40 S 9 48 W 5.40 S 9 48 W 5.39 S 9 44' W 5.43 S 8 13 W 5.49 S 6 44 W 5.51 S 6 4'2 W 5.36 S 5 51 W 5.07 S 4 30 W 4.36 S 3 46 W N 82 28 E 59.20 3.02 N 84 32 E 85.83 2.04' N 88 13 E 117.76 4.20 N 87 30 E 157.87 3.55 N 85 12 E 206.38 3.05 N 80 23 E 260.05 2.26 N 77 44 E 317.4'5 1.70 N 77 46 E 378.97 2.46 N 79 7 E 4'47.65 3.21 N 80 23 E 527.15 4.23 3.4,6 S 6 21 W 2.56 S 3 32 W 1.59 S 14, 27 E 1.49 S 68 23 E 2.72 N 81 55 E 4.4'7 N 75 26 E 7.25 N 75 35 E 12.94 N 78 55 E 23.38 N 79 44' E 39.10 N 78 59 E 10.99 N 59.34' E 60.35 N 79 31 E 14.24' N 86.01 E 87.18 N 80 36 E 15.91 N 117.96 E 119.03 N 82 19 E 17.19 N 158.09 E 159.02 N 83 4,8 E 20.21 N 206.64' E 207.63 N 84 25 E 26.97 N 260.40 E 261.79 N 84 5 E 38.33 N 317.94 E 320.25 N 83 8 E 52.07 N 379.63 E 383.19 N 82 11 E 66.12 N 4'48.49 E 4'53.34' N 81 37 E 80.47 N 528.17 E 534.26 N 81 20 E COMPUTATION DATE: 21-FEt3-90 PAGE 7 BP EXPLORATION I-Z1 /K-25 ENDICOTT NORTH SLOPE~ ALASKA TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION aZIMUTH DEPTH OEPTH DEPTH OEG MIN DEG MIN DATE OF SURVEY: 05-FEB-1990 KELLY BUSHING ELEVATION: 55.10 FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG NIH 4125.06 3955.10 3900.00 46 19 4276.47 4055.10 4000.00 51 11 4444.01 4155.10 4100.00 54 22 4616.30 4255.10 4200.00 54 43 4786.62 4355.10 4300.00 53 38 4953.41 4455.10 4400.00 52 43 5118.67 4555.10 4500.00 52 26 5281o16 4655.10 4600.00 51 49 5442.09 4755.10 4700.00 51 23 5601.35 6855.10 4*800°00 50 51 N 81 36 E 622.34 N 82 43 E 734.72 N 83 14 E 867.90 N 83 9 E 1006.98 N 83 15 E 1143.66 N 83 24 E 1276.06 N 83 25 E 1406.57 N 83 31 E 1533.62 N 83 39 E 1658.75 N 83 41 E [781.76 575R.19 6955.10 4900.00 49 48 5912.99 5055.10 5000.00 49 26 6065.67 5155.10 5100.00 48 57 6218.76 5255.10 5200.00 49 25 6372.66 5355.10 5300.00 49 39 6528.22 5455.10 5400.00 50 20 6684.62 5555.10 5500.00 50 19 6842.45 5655.10 5600.00 50 54 7001.93 5755.10 5700.00 51 24 7162o56 5855.10 5800.00 51 41 N 83 47 E 1901.69 N 83 40 E 2018.97 N 83 10 E 2133.39 N 83 9 E 2248.30 N 83 15 E 2364.29 N 83 21 E 2482.43 N 83 26 E 2601.73 N 83 24 E 2722.84 N 83 28 E 2846.08 N 83 46 E 2970.81 7324.46 5955.10 5900.00 51 47 74.85.67 6055.10 6000.00 51 47 7648.47 6155.10 6100. O0 52 24 7813.26 6255.10 6200.00 52 54 7979.66 6355.10 6300.00 53 26 8148.53 6455.10 6400.,00 53 47 8317.77 6555.10 6500.00 53 59 8485.38 6655.10 6600.00 52 41 8651.18 6755.10 6700. O0 53 20 8819.99 6855.10 6800.00 54 10 N $4 14 E 3097.27 N 84 59 E 3223.01 N 85 5 E 3350.86 N 85 6 E 3481.19 N 85 30 E 3613.61 N 86 12 E 3749.18 N 86 59 E 3885.36 S 86 46 E 4019.76 S 85 32 E 4151.76 S 85 6 E 4Z87.4Z 8993.66 6955.10 6900.00 55 20 9169.89 7055.10 7000.00 55 25 934,8.03 7155.10 7100.00 55 59 9527.05 7255.10 7200.00 55 43 9702.63 7355.10 7300.00 54 59 9874.16 7455.10 7400.00 53 54 10042.36 7555.10 7500.00 53 9 10208.08 7655.10 7600. O0 52 31 10371.76 7755.10 7700.00 52 11 10535.02 7855.10 7800.00 52 24 S 84 49 E 4429.00 S 84 31 E 4573.66 S 83 4~5 E 4720.47 S 83 50 E 4868°27 S 84 3 E 5011.95 S 84 14 E 5150.74 S 84 20 E 5285.47 S 84 12 E 5417.10 S 34 Z E 5546.16 S 84 0 E 5674.66 3.01 3.53 0.51 0.62 0.24 0.38 1.40 0.30 0.5~3 0.46 0.82 0.45 0.19 0.39 0.13 0 0.55 0.48 0.33 0.73 0.30 0.53 0 0.53 0.51 1.02 1.04 2.62 0.46 1 0.48 0.64 0.78 0.57 0.95 0.28 0.34 0.66 0.64 0.16 95.69 N 623.55 E 630.85 N 81 17 E 111.02 N 736.13 E 764.4*6 N 81 25 E 127.4.0 N 869.52 E 878.81 N 81 40 E 144.13 N 1008.82 E 1019.06 N 81 52 E 160.48 N 1145.71 E [156.89 N 82 2 E 175.86 N 1278.30 E 1290.34 N 82 10 E 190.98 N 14.09.01 E 1421.89 N 82 17 E 205.57 N 1536.25 E 1549.94 N 82 23 E 219.62 N 1661.55 E 1676.01 N 82 28 E 233.27 N 1784.75 E 1799.93 N 82 33 E 246.55 N 1904.84 E 1920.73 N 82 38 E 259.51 N 2022.29 E 2038.87 N 82 41 E 272.88 N 2136.89 E 2154*.26 N 82 43 E 286.73 N 2251.97 E 2270.15 N 82 45 E 300.57 N 2368.14 E 2387.14 N 82 ~6 E 314.56 N 2486.46 E 2506.28 N 82 47 E 328.28 N 2605.94 E 2626.53 N 82 49 E 342.32 N 2727.23 E 2748.63 N 82 51 E 356.51 N 2850.65 E 2872.86 N 82 52 E 370.59 N Z975.56 E 2998.55 N 82 54 E 383.90 N 3102.19 E 3125.85 N 82 57 E 395.74 N 3228.08 E 3252.25 N 83 I E 406.79 N 3356.08 E 3380.64 N 83 5 E 418.08 N 3486.56 E 3511.54 N 83 10 E 428.92 N 3619.12 E 3646.45 N 83 14 E 638.93 N 3754.82 E 3780.39 N 83 20 E 447.16 N 3891.11 E 3916.72' N 83 27 E 447.85 N 4025.53 E 4050.37 N 83 39 E 438.19 N 4157.42 E 4180.45 N 83 59 E 426.93 N 4292.95 E 4314.13 N 86 19 E 414.55 N 4434.60 E 4653.73 N 8~ 40 E 401.34 N 4578.90 E 4596.46 N 8~ 59 E 386.10 N 4725.54 E 4741.28 N 85 20 E 369.98 N 4873.15 E 4887.17 N 85 39 E 356.72 N 5016.66 E 5029.18 N 85 57 E 340.49 N 5155.29 E 5166.52 N 86 13 E 327.08 N 5289.86 E 5299.96 N 86 28 E 313.88 N 5421.34 E 5430.42 N 86 41 E 300.57 N 5550.24 E 5558.38 N 86 54 E 287.09 N 5678.59 E 5685.84 N 87 6 E COMPUTATION DATE: 21-FEB-90 PAGE 8 BP EXPLORATION DATE OF SURVEY: 05-FEB-1990 1-2! /K-25 HPI KELLY BUSHING ELEVATION: 55o10 FT ENDICOTT NORTH SLOPEr ALASKA ENGINEER:; SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA OEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE qEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET OEG 10697.83 7955.10 7900.00 51 38 10857.79 8055.10 8000.00 50 59 11015.76 8155.10 8100.00 50 27 11172.26 8255.10 8200.00 50 6 11328.27 8355.10 8300.00 50 18 11485°59 8455.10 8400.00 50 36 11643°74 8555.10 8500.00 51 1 11803.38 8655.10 8600.00 51 10 11962.90 8755.10 8700.00 51 T 12119.96 8855.10 8800.00 49 53 12274.02 8955.10 8900.00 49 2 12425.36 9055.10 9000.00 48 9 12574.21 9155.10 9100o00 47 29 12721.37 9255.10 9200.00 46 47 12865.83 9355.10 9300.00 45 39 13007.82 9455.10 9400.00 44 56 13147.65 9555.10 9500.00 43 36 13284.21 9655.10 9600.00 42 17 13417.64 9755.10 9700.00 40 32 13547.97 9855.10 9800.00 39 24 13676.84 9955.10 9900.00 38 39 13803.51 10055.10 10000.00 36 19 13924.03 10155.10 10100.00 32 12 16041.03 10255.10 10200.00 31 7 14100.00 10305.59 10250.49 31 7 S 84 12 H 5802.61 S 84 13 E 5926.96 S 84 16 E 6048.78 S 84 10 E 6168.69 S 84 I E 6287.94 S 84 8 E 6408.89 S 83 50 E 6530.87 S 83 21 E 6654.71 S 83 1 E 6778.27 S 82 43 E 6898.63 S 82 20 E 7015.00 S 81 54 5 7127.72 S 81 3 E 7236.96 S 80 0 E 7343.67 S 79 8 E 7446.39 S 78 16 E 7545.46 S 76 55 E 7641.18 S 75 0 E 7731.62 S 72 34 E 7816.73 S 72 29 E 7896.58 S 75 21 E 7974.96 S 77 16 E 8050.80 S 76 38 E 8116.52 S 75 46 E 8175.55 S 75 46 E 8205.17 0.86 0.49 0.39 0.34 1.02 0.47 0-67 0.27 0.76 O°33 0.36 0.50 0.93 1.03 0.83 0.80 4.12 3.07 1.96 1.76 5.52 2.81 0.00 0.00 273.91 N 5806.39 E 5812.85 N 87 18 E 261.35 N 5930.59 E 5936.35 N 87 29 E 2¢9.10 N 6052.27 E 6057.39 N 87 39 E 236.99 N 6172.05 E 6176.60 N 87 /-,8 E 224.65 N 6291.16 E 6295.17 N 87 57 E 212.15 N 6411.96 E 6415.47 N 88 6 E 199.22 N 6533.79 E 6536.83 N 88 15 E 185.48 N 6657.47 E 6660.05 N 88 24 E 170.66 N 6780.87 E 6783.01 N 88 33 E 155.64 N 6901o04 E 6902°80 N 88 42 E 140.50 N 7017.14 E 7018.65 N 88 51 E 125.01 N 7129.78 E 7130.88 N 89 0 E 108.77 N 7238.83 E 7239.64 N 89 8 E 91.05 N 7345.33 E 7345.89 N 89 17 E 72.00 N 7447.82 E 7448o17 N 89 27 E 52.23 N 7546.66 E 7546.84 N 89 36 E 31.36 N 7642.13 E 7662.19 N 89 46 E 8.58 N 7732.30 E 7732.30 N 89 56 E 16.06 S 7817.12 E 7817.13 S 89 53 E 41.72 S 7896.66 E 7896.77 S 89 42 E 64.17 S 7974.77 E 7975.03 S 89 32 E 82.18 S 8050.40 E 8050.82 S 89 25 E 97.13 S 8115.93 E 8116.52 S 89 19 E 111.96 S 8174.79 E 8175.56 S 89 13 E 119.45 S 8204.33 E 8205.20 S 89 10 E BP EXPLORATION 1-21 /K-25 MPI ENDICOTT NORTH SLOPEr ALASKA HARKER GCT LAST READING PBTO DRILLER"S DEPTH COMPUTATION DATE: 21-FEB-90 PAGE 9 DATE OF SURVEY: 05-FEB-Z990 KELLY BUSHING ELEVATION: 55.10 FT ENGINEER: SARBER INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 2012e SNL & 2081~ EWLt SEC36 TZZN R16E ' MEASUREO DEPTH TVD RECTANGULAR COOROINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 13950o10 10177°25 10112o15 100.40 S 8119o15 E 14000°00 10219.97 10164.87 106o74 S 8154.Z4 E 14100°00 10305°59 10250.49 119.45 S 8204.33 E COMPUTATION DATE' Z1-FEB-90 PAGE 10 BP EXPLORATION 1-21 /K-25 MP! ENDICOTT NORTH SLOPEr ALASKA HARKER PBTO DRILLER'S DEPTH DATE OF SURVEY: 05-FEB-1990 KELLY BUSHING ELEVATION: 55.[0 FT ENGINEER: SARBER ~&~O~&O~O0~ STRATIGRAPHIC SUMMARY 00~0~00~ SURFACE LOCATION = 2012e SNL & 2081e EWL, SEC36 T12N R16E MEASURED OEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM K~: SUB-SEA NORTH/SOUTH 'EAST/WEST 14000.00 10219.97 10164.87 106.74 S 8154.Z4 E 14100.00 10305.59 10250.49 ll9.&5 S 8Z04.33 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 14100°00 10305°59 10250o~9 HOR!ZONTAL DEPARTURE DISTANCE aZIMUTH FEET DEG MIN 8205.20 S 89 10 E SCHLUMBER©ER O I REC T I ONAL SURV E Y COMPANY BP EXPLORATION WELL !-2 i /K-2S MPI FIELD END I COTT COUNTRY USA RUN ONE DATE LOOOEO OS - FEB - 90 REFERENCE 73690 WELL ' (2012~ 1-21/K-25 MPI HORIZONTAL PROJECTION SNL, 2081' WEL, SEC 36, T12N, R16E) NORTH 80OO 6000 4OOO 2000 -2000 -4000 -6000 SOUTH -8000 -400O NEST REF ?9690 SCALE = 1/2OOO IN/FT -t't'T"t"'t"i"t't'!'" i i,~ , ~ii !i~i , ~ ,,~ --'?'"?'"-t'"l'"-l"-r'~"?"?'- :: : ~ ~ : : : : ' : : ' ~ ! ! : : ~ : "'?"*"?.. ...... :-"?-'?--': ....... .'"'~."'r",*'t"+","?'*"~"?--+-?.,.--:.-..~"-r--r":. ........ i ........ ! ....... i ...... ~..i~Z:Z!ZiZ[.~i ..... i"i ....... i ....... i.-.i....i..-.i ...... ~..L.N......~:_.+...4...4 ..... 4...~._~..~...~....:..,..;..~ ...... +.+.+.~. ...... F..~..~....~......+.+.f.+....+.,....+._~ ...... .~..~.._~...~ ....... ~..+..+......, ...... :: Z ::: :: ::: Z :Z ::Z:~iZiT' Zi:::i::::i::: :::: ................................. _~' ~-Li...i-.~..£..~.4... ' .... ' · : , , · ~ ............ -T'~ ~ .:-i ~ ..' ~ ~ ..................... ,~ ~ ~:~"-~ .......... ~,~ ................ ~ -~..-~......,..~..-~..-~, ....... : ~...~.4...~ ............. T "J ~.-~ ...... ?"..4.-..i-..~ ...... 4..+--4-.-f.-- "T"t"'r"?'"'!'"i'"t.'-i ....... ?l"-,'"'~ ...... ,""7'"','"'t ........ r'"r"*,'"*~ ....... t'"i"?'..'--':---~"*-i'-'i'-'~-'-7'f"f"~"*1 ....... I'"!'"I'"i ........ r"r'T"t ...... T'T"~"-..' ....... FT'T"i ........ F"r-f-i-'~'t-t- -,--H*.~. ....... ,+-+*+-- "~'?+'+' -~ ..... ~."+""'+'+'+*~'""-+-+--~-'-~ ....... ??-+-~'-'~*'~-+'+"? ...... ~"?'r", ...... ~--'.'-'*.'--~ ...... ,'"?~.'-"! ....... ;"?'-"."-'? ....... ,"+'+"~ ........ !"+'t"! ....... i4"'"."'~ ..... -~-4..+-4-*-.-4.-4.-*-F4---' '' ' ' : ~ ........ ~ ..... : : ' ' ...;...~...~....i ....... ~...-.'...~.4 ...... ~...~...¢....i ....... ~..4....;...4 ........ i..4...~.4.....-~....'.-.,..4 ..-:...?..: ........... :...-:...-r...: .......... ~...~.......~..4.4...:..4..4....i...; ....... ~..4...~.4 ....... ~.-.4.4...~...~....~...~..4..4 ....... i-.-.~.-4..-+' ...... ~-.4.--~--4 ...... ~...?"...?"...*." ....... ?"---?"..-~.--.~ ...... ~...~----.'--..: ....... ~.4....i...~ ........ ~ ........ '~..4... m~--i.4.4 ....~..4..4....~ ....... ~.4...L4 ....... 1..2..-.;...~...,..?...~....~...½......4...~...~..4-......~...~...1...i ...... ~...L..-L..i..- ..-L-;....i,.4 ........ t...L..L4...~...,L.L..L4 ........ i...~...~.4..,t...~..-i....L..i... +.,"-.4.-+.-...4--4.-N ...... N--..i...~.-.--N-..!---.~.--...4.:-~.--~.4-.-.-.-~-.~..-~-4.--.44..-~4...L...~...~...~...~ ....... ~.4...~..4 ..... .~...~..~...~ .... : ~.: 4.-4 ~ .~ .~ ~...~...,'....;..4...;. ~,...~.-~ ....... ~...~...4...~...~...4...;...~4..- : : : : : : : · ~ : : : : ~ : : : : : . . : : : I ! : , ~ ~ : ; : : : : : : . , ~ ~ , ~ : : : : : --i-, -'~'~:'-f-: ....... ?-+.~.--f. ....... ~:.-+.-+...? ...... i"'+'--i--?'"' -~.-4 -~ ~ -~ ~ -~-4 , ~-.' -: -~; ~. ~ ~..~ ~ ~-~- ~ ~-~.+..~... ~..-~-.~-.,'..-~ ...... ~..-~..-~..-~ ....... ~-'....'...'...] ........ ........_' ....... '...~...'..~...j...~..-~...;-..~ .... : ~ : : ~ ~ , , , : ~ : ~"t .~ ? .~ ~ ? . ? . , . '} .............. "'+'+"'.'"*~ ....... i'"f'*'~'-F"~ "+"?'q-'"f ....... ~"-*.'*--,~-"i ....... ~---,~-*--F--f ....... 'f'*-F"+.' "'t ...... 'f"'f"+"j ....... !"-'i'---!"-! ....... ?.'-f...~...-~ ........ ?....?...*?..-~ ....... ~;..*4..*.'~.-ff ...... ~..-:...~.*+.- ~-4-e.*:.--?' ...... ~:--+-~?-e ....... -:..+--+.+ .....t"+'+"~'-'? +"f"'~"~ ....... f.f-+-+.-!.-*t:-.-f...t--'..' ......I ~--.~-4.--.~ ....... ~...f..-f..,: ....... ~-.-?".-4..~ ....... ~...,:...?"....i ...... F-4...-i..--~ ........ i..4-4..4......~....4..+4 "'~'"~'-*."-'~: ....... .~","-'--~-.*:' ...... ~--+---~'-*:----"+--~:----:---.~ ....... !"t't"'t--".-'e-'t-i'--~--i"'t-t"?-t ...... f"f"H ....... t-'t"f'i'-':'"f"f-'?'"'f ........ !..-i--.H..-..-.-H--..?i ........ i..-,:.--i ''-! ........ i--!-++-.-*:-+-.i-.~ ...... H-%+'-- -.,"'4...-t'i ........ H'"'i'"f":"'f'-H'"'H"t'-H'-i ....... !"T"r'"~ ....... T"r'T'"r"'TT'"i"'~ ........ N"T"::: ....... N"i'"~ ...... ."'",?'"t'"~ ....... ??"??"l"'N""i"-i ....... i"!"*~'"'i ....... i?iff ...~...,..'..?.'...~...~....~...~...~..~-..~.-;..;.~...~..4.-~.-..x..~ ........ x...~...~ ....... ~...~..~...~...-4.-.~..;.,..'. ....... ~...~..~..4 ....... ~...~-..~....~ ...... ~..~..;...~....++..~....~...x...~..-~..-~.....~....~...x ........ ~..;-~-;-. :::::::::::::::::::::::::::: iiiii!!i i!l i~iiii ~!..?...?..?..??'?'"'.,'"""~'"x"~'".~..?..?... ::'x::x::: .... :::::::::::::::::::::, : , , :::x:::x:::, ~ , ~ ~'::x:::x::::, , , ~ :::i:::::::x:::, , ~ , ::x:::x:::~ , ~ , :::x:::, , ~ , ::.,':m:', , ?-t--;. .... t"t?'t' ,, ~,, , '-i-+i--i---t--t-f-i'-i'--!"i-'i'-i'-! .... ,.,, "T"?"','.'"'.?-,'T'TT'?"' -4-~..-i...H....L~....~...~ ....... .L~.-L~..F~-.-L-i..-~ ...... L-i....L.i..4-U.4..~..~...4..44.+..-.i4.4...i......i..4..4...i ...... i444 ....... N'"i'-i ...... i4"-i'"i'"q--i""N ...... i'"i"'N'" ' ''~' ''~''~' ' '~~ ~ ~ ~ ......~ ~' *~' v'~''--~ ~ ~ ~ ~ ..... i ~ ~ ~ ~ ~''''~'e~ ~ *~ '~ ~ r ~-: ~ _~ . ._j ..~....~...~...~.. ~....j.._~.._~ ....... ~.. _, .. ~...~.......~ ...~...,_. ~ , , , , ~ ......... ...... ~...~...~...~......~...~...~ ... ~ , , , ....... t...~...~..t .._ .. ~...~..~.._~ ....... ~...~...~...~ ....... ~..~_t ..~... ::::::::::::::::::::::::: '-i"~"?i"'t"~'"i"~'-,'F-'-~--r''*'''?'''v'?''v'~'-:]T.'TT]i]i-:T il .'" ? iii7 ---*:--'4---*~'-+-~'"-i-*:'.'4'--P---4.'+.-;:..+.-.-4-.,:-.~..+.- ::::::::::::::::::::::::::::::: :::-:.:::~:::::'::::;.:::::~::i::~::'~::"-?.'--'.~'-~ ..... ~-+--,"~ ........ :"+'-- ...... ,'"-:-?'--+"';"-~'--':"- ~! -.-~....?'..*,:-.4...i..-i.-4.-..N-...--.4..4.-4..4 ...... ~--.F4..4...~.-4..-.,'...4.-.+ ...... ~..4-.4...4..- .... .... i...L.*LL.~.J,.4...L-~ .... ...... . L_i.._~ ~ r- ],.-+- '-[~-- -[r--r.-,~i ...... -i....L..L.L.LL..LL_i ...J..J.._L.L.J,...L..L.L.i ..... L..L.i...~ ..... L.J,....L.~ .... ~ ' ' '''' '' :''' '~'' -f'f'4't -'-i'-t-t-i--'--t-ff"-i'-'fti-'-?t-*'i .... LJ.4.4...i--L4..J.4 ..... ~-.-~--4---~ -.~..--~.4-~ ...... ~-.4.--f.4..~.-4-.~-4..4 ....... ~.-?'--r'? ...... ?..?..?-?--- '..?--.?74 ...... ?..-r.-4 ..... ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::........~.*.~ .... ~..,...,..;:_.., ............... '"*..'"I-?"T'~ "~"t'-t"-t'" "'-P't."-i"-r" "'f"'f'-f"r'-~--r"?'"?"'~"" · ..~,.-.,:,..~..~...~ ..-~...~,..4....4 ....... ~..4..~--~ ....... k..~,..-4-..-;,....,..~...,~...,L..~ ...... ~..4..4..4.** _..'~,~ .~iii/~i~ ,,,- ...... '"i"t't':?t'!'"t"'t"t'" ~,iiiiiiii iiii iiii ::::::::::::::::::::::::: ::~:~:[:~::.t.:~:~::~::~.'.:.. q.4-~.--i.--i-~.-~..~4----~~-~-..t-' ' ' ' ' ' ~ ' '.-~4-.? .... .-.~..i-.+.~-....,'...~++-~.++.+-?'....+?.--.....?..-.-?..-.~-.+.~ ....... ~...~-.-..-..?...~++.. ---~---~"-~'-'-~"--~'--~-'--~'-*'-'~-*'~ ~ -..~--.~--..~...~.--,.-4.-4..-P4 ........ i"4-'4'-4-'?--4-'..~..4..-~......-~.--.~..-4'..4..~ -.4..-+..4.-4.-- ::!::iii iiii iii ......... ......... ...... : ::::i:: :: :::::: :: :: :: :::'::: ::::: ::i:~ ~~~~-.::-.'".---.:.--~-~: ....... ...-~...~..--~.-.~ ....... 4,-4-..4...4..., ,.--~..-~-..-~----~ ...... ~---~.--~---*--*~ .. -~---,...-~.-.-~-.-+ .---~----~---~.-~ ...... ~..-~--..~..--~--.~.-.~--.*---..-~ ....... ~....~-.-~-.--~ ....... ~-.~*-...--*~ ...... -~.-.~-.~.--~... ~-*-~...-~..*-~.*-~ .......... -~-**.,.--, ........... ~---~-~-- . .~_.~ ...~....~...... J,....~....~..~... : ............ ~j ' i ...............! ill ii~i ~ ~ ! j i ~ I I ! I I ~ '-t'..Z:i::..":.2::::'"'f-Pt-t; ...... H'-H'-v-i'--f'i--t--~'-i'-!'ff'-i ....'-~ -...i----'~'-i' ........ i--+-.-H.- --+.-i---f.-i ...... i..-i--.H ....... i---H.--i-..'---f.-H--i.--,.--i...-i..-H.....+-f.--H..'..~..-i.-~..-H ........ q jl~''-'T''F''[''~~.'....'....'I ....... '"'"'"'"'"'"'-'"'""" ...... '"-'""'"""'"'""'"'"-' ....... T'T"F-TTT'TT'T ....... 'i"T'T"~ ....... T"?T""i ...... .?'t'--r'T'-x'r"-r-:::'""?"-r'"t"? ....... i'"'t"'t"t ...... t'"t'--r"-t'-~"-t-?-t?-- '-?'. --t'-m'-'t ...... 't--?'. --r--t-, - -'?'-'? '"t -'-i:'-'-['-?'-? --'-.,'--:,. '-' r--:.-m.--.,.--?..T.?..?..?.~.,...- ..?.-:,...~r .?-.T?-.??? ...... 't---t-?..?--, ... ,*---'t-~'t,---?--.' ,-..'t--?-?..-r....-?..-?..-t...m ....... ?.-?.-~..'? ........ :-~?-.t..-t ....... .'r.-~-.?...? ......... · ...~..4.-.L.J, ....... .L.-~....i...~ ....... i..4..J,***.i ...... i...-~..4.-i*-.. J,._~...:~....~...,~...~...~....~....i, ....... J,....i...,~..~.-. J,...*~...~ ....i...-~ ........ i...~,..*~..-~.,t. .-i.--.i. *.*i..-.~.-.-..-~..-i....~**.4..-, .4...:, ..-i..4.... :::::::::::::::::::::::::::::...H.-+-H-+-H..i'--...-+-i-.-H...H.--H.-b-+++-.i .....t H--H ....... -.t--¢-.i-..H-..i-+.~-.-~.-.-..~.-.i.-.H .....~ i..+.-i..-i ...... ~..+-.i.--i..-..+i-+~ ...... H.-~..-.;- j ! i i : : : : i i ! i ' ! i i I--4.--*.-4..--4~ ...... ~.-4..-4..,4-.-- --4-.4..-4--4..-- -4-.4.-~b-4, .4. .... ~..- 4.----~..--4-.-. ' .-4..-.~-.4--~~.--- ' .-4--4.-4.--4. ....... ~---.,i.--- ~-...-i. ...... 4.---;, --4...-.I. ...... 4...;,..-4.-..-:, ...... ;,..-4...4..-4..- ..-,,., 4... 4 ...4.... :-L4.4-4...t.4..-L44..~.4.4..-.L4..Z~.4--i.4.4 .... i ~ ~ ~, ~ i ~ ~, i ~ i ~ i ~ ~ ~ i ~ ~ ~ ~' ~ ~ ~ ~ .... ~ , : '. i~ i ~ i I I ; : : : : I : : : : : : : :! : : . : : : : : , : : ~ '. : : : : : : : .... .~'*-P"?'*-.~ ........ P"?*"?"?"i "?*"?'"?"'? ...... ~'*',~"'?"'?"* .... i..J....LJ ..... i...i.4-J.....J..4..-L..i ..... i**.i-.i..~ ...... '&..i...i..-~-...-~...i...i-4......4.4...i....i ...... i..4..4..J ...... ~..*-i-.-,:.-4.--..4....F-4-.4..-~.--4..4...4..ff....-+4.*.4..-F-. .... i.4.4.4-,'.-~.4..4..-i ...... ~.-4..4..4.4..-i..-N.-.?" ........ i.4-..-i-...?.f-t.i-.t--i ....... ?..i.-.-~.-i ..... f.i---~..-t ........ H.-i--.?'-..,-i.-t...!---.~ ....... f.-i..i..-? ...... i-t-i...i ...... ~..-;....~..~,...~....~.4..~...~...~..~...~..+..+.....+...!..+...i... .... L4....L...i ........ ;....;....~.4.....4.4.. · '?'ff"~"'t"i"~""H ....... f-i'"i'"'!'-l"-!"-["i'"'i ........ ?t't'"M"i"t'?'-i ...... i"--i'-"P-~"?--t-t--t'--t ....... t"'i'--t't ...... t'-t'-'t"'i ........ P-t""i'--'i ...... i'"t'"t"i"- ~ t~,~,, 4.-444.444...44.-.u...444...N-i444 ........ !...44444...~..4..-[.--..-N..4444.4-4...~ ....... 4.4...~...~...i...L.~4....i ........ i...~4....;.-...-~....;..-;..-t ....... i.4..i...4...m..L.:.'..-~ ...... ~...4...4...~ ...... ~...-~-.~-.~... ..4..4..+..~... :.4..4...+'.-~...,...4..+.+--~---4.-4..-~.-..~...?.' ....... i..+.+.+--'..+.4..+.-~ ...... ;..4..-i..~ ...... ~.4...J,..4..,...~..4..4...4...~...?."..4...4...~ ........ i-4..--~.-4 ...... i..4..-i---i ....... F+---~..-~ ....... 4..+4-4 :-.~...~..~.4..."...~..~...~..~..~..~.~..~...~....~..~...~.`..~..~..."..I..~..~..~.~.....~..~..~..m..~-" ...... ,.,..,..~_,...,...~...~...~ ....... ,.~...~.._x.._~...,.,., ...... ,_..,...t...~...,...~..~ ...... ................... L..i.4..x.-LJ._iJ44_[ ~ ~ -~4J ~J i~J- JJ .-LL~.i_i-~ i -J ~ J4 ,~ LLi ~- ~ i ~.iJ-L[ ;-L L i-i-!-;~ !!.~ .--+-+-+-+- --i.'-.+.+-+-fi-.*.'---f:.-+-+-+-+.+.+-+-...--+..~--+--~ ...... i--+-+e ...... f'"f"t'"t"'"t'"i'"'i""i"-r""i"t"t'""~"T'ff"";."'i"'f ..... f"":"'t:'"f ...... f'"~"t"i"' .... ~ ........ :: ,.:..;.., ,..,..;-;...:~::~::~::::~::J: ::J:::::i:::!:::J:i::i:::t:::i:~:::'"~'"*+-~ ..... ~....~.+-~...~.+.,.~..,+.**~...~"'"~"'?"':'+'":""?"?: ...... ...... .:T.:.'.'~:~.:: ::T]:T~:::::~::~::-?'.::T ::~:]:::i.-:~:::::.-q::-~..~..]~..~..~-.. ~::: :'t-f!'+1-fS't'i'"i"t-i"t-H--i"i"-H--4'-i-t-f-'ri'-'f,'-i-i ...... t-"t"'.:."'t..:'-I'-rt:..""?"i ....... t"i"'i-'f'i"-i"i"i"i ...... f'i"'f'i"i-i"i"i? .-!-..i444444...~ ........ L.L~.44....:L..L.i....~ ....... !4.4..~...~4444...',...-L.N4 ....... -'.,444' ..... .:"4-44.-.!4444 ...... -J..-.i----i..-.!4 ....... i....i4 ........ !4-...14-j ....... i44 .... .~---i--+-4 ...... ~.4....~..-i...~.4.-..!-...i...-i.-..i..-N....i....i ....... i..4.4..4.....4..4..4-~...i.4..4.4--.?' ...... ~....~..-.;.'...+...'..+...i....i....i ...... 4...4....i....~ ........ i...4....~....i..-'....~....~....i....i ....... ~..-~...~....i ........ ~..+...~..-i ....... ~...4...4...4 .....I '~"+'"~'"'~"' ~ . , : i :' : ? ~ ~ ?'T*I' T"T"?'"q'.. ....... ?*'*~*"?""t.'"-'T'-'T'"'[.."'? ...... ? ?"?"'[ ' ~ ~*~ 'i'.. [ ! i ['* r ..... [ T i". : ":"'t"? ....... :"-t ..... : ..... 7' ':*'t-*t"- '--t--!f-t-t--'---t--t'--t'--t'--i---?-t'-tt-t''-'i--t-t ........ !'--t'-'t---t'-t't-"t"t'-i"-"-i--?--'t'-i-t't'--t-'-t"'t ...... t-'-t'-'t'--t-t-t-'-t'-'t---t ........ ?t""i"'t"i""r'":'"t'"t ........ i"t-':.'-"r'"!-"f'",."'t"i ....... f..!'..!...f..f..i...i.--f.'.i... i i i i ~ ! ! i i i i ii ~ i i ii i i i i { i i i i i i i ! ' J i i i : : i ; j i i j~ i : : : : ' : ; : : ; , : : : : : : " : : : ' : : : : :::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 2:];::2? -4:..+--.F+.-~.--.F+---i--i ...... .?"..-~-.--i.-..i ...... i--+---i---~ ........ i.-..i....i...~.4....i...?".4...4 ....... N.-.!...4 ......4 4.4...N...;..4-.4.-..i.--4.4-..4--.:N....i ....... -!--.4..4.--.F-':-.i.-.-~...-!..4 ...... N4-4 ....... N-+4 ..q-..~-?.4J ~ ~ i-}f i i ~ .... ~,.--i...~,.-4.-* ..-}..-.}..4..J,..-.~ ~ i it i ! i i"4'-~*'4"'~'-- -4-.4...4..4 ! i i iii i i i'L"'L'4*'4 ...... .i,..-L.4..J,..~..4--~,...~.-4 i ~ ~ ! , ! i i i ....... 4,...4,..4..4 i i i itl i ! i~i""i-'~"'~' ....... 4...4..4..i i ! i Ii i ~ i 4 ...... i....L...i...-i ....... i ! i I! i i ~ !i"4""i'"'i ....... i..4...~.. 4 ...... ; Ii,l!"-i ...i....i ...... ~...~-..i-4 ~ i i i "' .... H...H..-~...i..*......-H...~....i...i....H4...~..~....H...:....H...H...N...i....H ........ !-.--H-.--i---~--..H.--H ....... H-..H-.-i...-H--.H.--'...-!...!..-.i--..H...-H...-~-.-.i ........ N....H...f..-H..-.H...f..H.-.i...! ...... !..-.i..-i...i .... · 'fi'ti'ff"']~.'ff"-?-f'ff ........................................ ....... t.t.:.~-~-]~...~..~...?.....*-~...*...~...4...-;...~..~...+...4.-.~....-.~...4....4....* .....~. ~'"*'"~'"~ ....... *'"f"i'"'~ ..... t"~'"*'"? ...... ?'"'"'"ff""~ ...... I,'~'"i""?'"~ ............. .......... f-~""~"t"i'"4."'t"'i ......l i"'4."'4."'4. ...... 4.'-~"*""~_~.. .... -T'TT% ...... .'.'-T"i"'T, ..... *..'"I"'I"I" -T'T"!"*.:-~"T"T"I"T 'T'T'T"I'"' 'TT'T.""T' "T"T-TT' r"T'"?"T'T"I"T"i"'.',"'T ....... F'FT'"! ...... 7'i'"'7"~ ....... T'T'"TT'T'"?T'? ....... T'"~'"?"? ...... I" F'T'"~ .... -2000 0 2000 4000 6000 8000 10000 12000 EAST WELL' 1-21/K-2§ MPI VERTICAL PROJECTION (2012' SNL~; 2081' WEL, SEC 36, T12N, R16E) 271. -4000 -2000 0 0 2000 4000 6000 8000 ! 0000 ..i.~4...-J.-~..i.4..-LJ. ...... 1.4...','..4 ....... L-i...i....L-..J,...i_.L.L_-14..i ~ .-i 14. ~ ....... i..J...-L~ ...... ;..-J--L-J ....... i.-L~...-~ ....... 1.4...i..~ ....... L.4....L4 ...... .b-i....i....~ ........ L,.L...i....L.~..J....i....~ ............ '--J""I:."T"!"~J "'i'"'I'- i'"'?' "' '"I'-'?"1'"'! ....... l"'?"'!:'-t ........ :.-.H.4...4. ....... H+.-,--+-- .-~.--H4.--! ........ ~'"-r-'i'"? ....... ?."T'T'7 ...... ?--r--.?.-.,' ....... F-:'"l"'f ....... ~'"'F"r"! ...... 1."'T"I"-~ ....... VT-?1 -', '"!'"!'. 1.-7 ....... -';.--.t-f.+.~.--';,---i-+-~ ..... ~"'i"'+'~ ....... ~.-4-+-4.-'+-~,~.~--H%.4..4 ..... ~.-4--i--4 ...... i.-4..+-4 ...... e.-~'.-+.4.--~.--H4.-4--4...-..-+'-~..-+~ ....... !..+-..b-.! ...... i"-! ....... ~ ...... k.,?'--i..+.-:..+.4..+..'; ........ · ..4....b-4...4 ....... 4..-',.4...4 ...... 4....4.....;.4. ....... ~...4....i....4. ....... i..4..4...4. ........ i...¢.-L.4 ....... k..4...-p.4. ........ ~--k'-H4. ....... k--:"~".4 ........ F-+--?'-'-i ....... '~....L.4....; ........ i-'-i'-';"4. ....... !"-.~-"i-'"r"/-i.-'H'-i-...! ..... +-4-4.....; ....... '~--! '-f"-i .... .... k.~.4..4.--.~-4-44... 4,4.44-.b~.44-~-'.-L4...i..~-...~...4..-~..-~ ...... ,~..-~-.-~..-~..-:-.4..4-4.-4 ..... i-++.4.--~ 4--+-4..4.-.-.4.-4.4-.4- ...... ~..++..-i ...... t'.4.-.-b4.-. ~--b.H..-H...4.-4---.b.~..-;..-H-b4.-~ .... ~ ~ 4..4.- -4.. ¢ 4 ~. ~ 4.4..4..~ ~. 44..-:;..-L.L.L.,~ - .~ :, ! .i ...LI.i.-L. ~..4-...':...~..-~ ..... 4..-4.-4---H.-4.--~--k.~ ........ k4.-L..,~ ....... L.4..-~....i ....... i...~...4..4... I--i..4.4....! ........ i.4....k..i...l.-~ ........ i.4 .... ..444..-L... 4..J..~ J -4 -J. ~ ~. .~ ~ t4_ . _." ~L.~ 4." .~ ~. .i ..... .L..L4.-L....i.-L4..4 ...... ~.4..4-4.-:....L.~..4.-.~.-...4.4....i..4 ........ i..4.4.4 ....... i....i ........ L.. ~...L.~..-i...~...-..-L..L4.4...i.-!...~....i.._i .... .... Fi;"i,-i-""i:""i"i;'4'----i;-'i-4"i:'-~'-'f-hi..'-? "i;'"i.;"4.."i;"?'"t;-?,.-;-i"]'4-'LJ''J''' ..-L-M.4 ....... ],-..M.4-. ~ ~ ~ ~ ~ ~ i ~ ~ ~ i' i i i i i i i i ~ i ~ i -b4-4..4-.- 44-4-4....-4--%4..4---"?"?'1'"?" "1"-"r?--r ....... ?.'...--? ........ !"-r"r'-r ...... r'~'--? ...... 1.'"-r--!"-r ...... ?""r'?'?'- .......... i,--4.,..4-,4..-- .,+,'--i,..¥+--..-i.,.4.....i,...4.,,-~ ...4.,.,4,....}.,`4 ....... ~---k,,,r..,b.- ,,4..-.,HH-!,,.~ ..-+-4..,-f..4. .... '"t".i,-t"?'-"'"r'4...-t"!'-"'t"'~"i'-h']'"t"?'j].] ~ _] ~ ]t].TI]Z]]i]Z].~...+-.';'..+...b ..++.+.~ ....... ~...+.+.-b-..4.+4.'..+....+.4".4..4.-..4.4..4.4 ....... H.4.4 ..... .i.4..4...4......4...4...-b.~...~...~...;..-~..4 .... ..4-4_4..~-...4-4...-~.4..i i i "-T?: :'":ii? .:_l,... ~:~il:::"~: '':: ..... ' ::-"~..: '~''''''.L<. .... ~...~...:.. ~...:...~'".4-*'.4"'t'4"H"'b ..+.+..,:.-i.--..-+-+-+-+-.--H..+~:: , ~ ...... :i"4"H~,, ....... ~-.~.4.4..-t.-.-i.--i...Li, ~ ,: ~ : : ~, ....... :bH'"~"-"'b'b"H"t'4"'i4"-i:,, ,: ~ , .... : .... ]! ..4.-4..+.4.-- .-4..+.-HH ...4.-4.--';'...,~...~ ..+.-.b.+.4... L-b.¥..i.-..b., ..4...-!..-b.+'.-.~.4,..HH~ .... · '-?r-1'--? ....... .*-.-r-:-~ ...... r"?'"?-~ ...... ?'"':'"'Y"? ..... ?_ 1. ] ? ? .~ 1. :'4"'L4"1-' ...i.4.4.-J ....... i...i.-L.-L.. : ......... : : : ~ · .+.+.+.-+: ....... H.-H ...... t..+--t..-t-.t-..t...?--r--~ .... t.-:-.].--t---t.--t.-1':---~ .... i".:'f'?'i"',"i"i"i"+'" .+-H....H.--H..-H.-...+..H...-i ...... H'"H'"!'-'-:'-'.*'-'H"- .-4--4.-4--4.----4-.4.-4.-4-----.4-..*..4.--i-'f'ff'"f'ff'-i'-"'.4~/~' ?~'i"ff"ff"~ -.4..-.b..4...~ ....... ~...-i...4...4 ....... .~---~.---.~.---k- -i ? ';.--';-.--.+: ' ' .%--%.-: :, ~ .: ~: :.: :::, t::,: .?,,~~:: ~...?:.+_~._~...,+_~....~_.~ ....... ,.-4.'.-i.-~ ....... H'H"'i'H"]'-i ........ H'H ....... H"'f'-! ....... i"'i'"'i'"i ....... H'"M'"I"'H"-H .... J4...L-L..,4...L~..-~ ...... ~...LL.L.N'.4..,L-i ...... L~...~.~'...L~..L~ ...... L~.44..-...444..4. ...... L~.44 ...... ~.4.-~,..L~...~...~....~..-~ ....... N...L~ ...... L-~.44 ....... N...i....i ........ !'--'i"--i""!"-t'"i'"bi"-i .... ,.-4-+4..4 ...... }-4."---i-'4 ...... H--'i'--b-L-i--4-'4"4'---'H-.H--~''-~: "~-'-H"4 ....... }'+'!'-4 ...... %'--!'--}-'4---,'-".'."-'4'-4-'4"-"'4"+'4"4 ...... i'-H"4 ....... H--bf-'"'4"'~"4 ......... ,..4. ........ : ........... m..-~ .... -4-4.--~-4.-i--!-~--i.--t:---r.4.-.;-f-ff ....... f--i"ff'-ff--'-i-t4:'--*; ...... f~---t ...... ?:'"1."-i:'-i;'-'-ff"i;-f"i ..... f-i"i:"-'t;-i'-'Ht-i"'i:"-'-i:'--r-i-?"'-ff-';."'f--t- ..i'--i-'+4-"'4--'A-!-4--"4'4'-i'-1.:'"-L4"-%-4"4'- "i"i"i-i"l"?'?-i"i ....... f-'.1..:"i"~ ........ t!'-?'?"_-t't't~ ..... ½-~.'"' "i"~Z"-?'tt-} ...... ti'-?'t!'-?'?-!-'?'-"'?-t?'""?'?'?'? ...... t-?"f'?""'4"'4"";-4`'-"-:"4"-:'"'~ ....... m...~..4.- "!; _f,,,...f;_.f fi '"h1'--i I ' "T-"r:, ?-"r ,?'i "!-'F- "T']-F!''-1--r'''-F] ," :"~"-~ '?- 1' 1'_.~ _: _ ?..~.1'._F -t -~--r-'?--'--r"1."'1.-I--'''I''''F?'T'' '"t-r'T ....... T"*,:"T"r' "T']" 9'7 ....... F]"T']'- ....... ~_,._,.., .... ~_~ .................................. .~. ........................... ~ ......... :;~L,_,.4...4..l.4..~ ...... ,....,.,4..,.....,--~-,-, ................ 4. ........... 4. ......... ~ ................. 4. ....................................... ...................... ? ......... *'?-.~ ....... ?"?~7-"~hhSzz:::r'~:~!?..?.::::::::::::::::::::::::::::::::;~::i~.[:.~.~;~ u'"ts~-~"~[-o' ~ Tr"? ............. .-&4-4.-¥- -4-4-4-4--.-4-..[.-4-4 ...... 4.-i.m-[-4..44-4-4..4..4..4.4... ~..4--.~..~ Lu.,--u?u-4-4-N..4..4..4--4.4.-4--4.--~..4..4-4..4..-,..4..4..4..;;..--.4.-.i..4.--¢..~ · -4-4.-~--4: , . : ..... ¢-4".4..4--: : : : ,-4-4..4-4--: : : : -4...4..4..4--: : : : ..4....i,..i.....i-~....i-.~-4..4,..: : : : : : : : ~~'-.~..ff'~: : : : : : : : ...½..4..4..4-, : ~ ~ [--4..4-4..4..-: : , , ..4..4..4..4..-: : : : ,"-L'4-4".4"': : : t ,..4..4..4..4..-~~] ] 11¢l'411411'~''~ ! ! : ~11.-'~..4.-4'---~"-'[ ! ! ! ,."~',..4.,.--~.-4,,'4[ ! i ~ I `4-4.--4,--i,- `4--`4--4- ,4, - -.4-`4-,4,,.A,-,. ,-,4--,¢,,-,~, ' ..... -4,- 4. 4, 4,-- 4, 4. --4- ,4, · --4, .4-,-i,-4--,2f.,-i--4--4,,-`4 ....... -4,,~-, ' '---4--4,-- ,,--4,-4,--4`,-,4, ....... t--`4--~,-,-,, ...... ,.~--~,,,--,,,,--,,,,. ,--,~,,-~,,-"-t,,~ ...... i-.-"~-,-~,-,; ...... ~..,-t,..~,,-~,,- .]_]_.i.Li_iLL].]..,LL-LL.-LL._i.~ZT._i...~_ i_Z...i...L. L~._I...LLL].J,_i._L.i..L..4..~L~i.._L]..LLi..LJ,._LL.;..Z4.L u.i..LL-L..LLLL.: -i..4-L4..~..J,-4.-L-.:,......-LJ,.4.-L..L.L-i..~4.-..4...~..]..4.-L.L]..]..] ..... -L..L.4..4,.~..4..4-J,.-i ...... L-LJL-L.~,,L..i..-~i~ 0D!..-L-i..-..4..-i...i....i ...... i,.-i..4..-i..-,.4...i--L,L:..-L-L.4..4,..'.,.L.i..£.4,- :Z..'::.L:i ::;.::;.::~:: ::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::: ::::::::::::::::::::::::: X!::;::; :::;!:::i:::;::.;:: :::::::i;::4:::: ::::.r:::i:::.r:::;::." ::~::.]..::;:::;::: ..;4..4.4~ ' 4- ~. 4-4 --4-4... ¢..4 ..f 4 4 -,..-- 4..-..4...4. ;-4-¢..4...~..4- 4 ..... .L.4..4-4._4..4-4-4..4 ....... 4...4..4-4- ..4..4..4.,4..-..4..4..' .4..q ... ;.: .' . ~ ...... 4...4..4..4._ __k.4...4...~.....4..4-4-4..-..4..4..4.-i,... ...4_.4...4_.,_+.~...4._,..-4 ...... 4,-*'"-.4'+.4'-'"i"`4"-"`4"`4"*'`4-*'.4"`4"'~"4 ....... ,...4`..-4..-,..-t..-4...~-.4`..-,..~..4-4..`4..-4..1..4`..-4...4..,-%...';-%-I..I i:1:~ ............ ~ ....... ~ ........ ,...~..`4...4. ...... ,....~ ........ ,......4...;...~.._,...~ ...?_,..?,_ _?:__,.?..~_.?.?~.1....?..?=I~:._..?.?..,_, ..... :---:-.,.-,.-.,--1'--??H.-71'-.:.-? ...... ?.-,..1'-., ...... :-'?-*--r--"-r.--r'-?"-r'4'-1' ,'--r"? .................. -r ...... r'"~"~"'? ...... r'1'"-r'-r ...... 'H~.--r:-r." ....... ....... ...... ....... ........ .+.i__f..._..i_ !...[. :+.++...--f:'--F+-H-k+.-.f.~+--- -+--H.-~-i.--.-H.-+-i;-'---H-'-F+i-i--f:--i'-+'' .-.-H.+-H.-++++, .--f.-+-4..--f..--t-h.-;,..'-~ ...... H'.+.+- "-i'-'i'--f""i"-H"--H'-i'"' "4'-'-f-H--- __H+...i_4...,.+_?_+..+... _++.++..r.+._?..+...i......+r~mi.~.,,_+.+.4 ....... +.++-+--r-?-++-4 ...... ';--++-+i'-+.+-+-4..-..++-i-.+.i.-i.'-;,'-ff--..~. --i'-+-'i"-f ...... ?.,.._i_ff ....... i"-i""i'"'f ...... !..4...ff..ff... ........ : : : :: i ' i':'~:": ,uu{ :: :: i :: i i ::' :: i i i :: :: { i : { i i i : i :: i i :, : ~ ~ l: ..' {, : i i" : : : : : : : : : : ! : : : : : : : : : : : ; : : : : : : : ...:..: : : :.:_.:, L : :,4-: ..... :.-:.: 4 ...... :.-:....L.: ..... [ 4. 4 4. '..`4.,, } .... 4.,3i, -, 4. ..... i-i-, 4. i.,,-i.,-r-- ..~_lr..~_:...,..?._1'_~ ...... r1'..1'..,...~L..r._:,.._:,.._r._.._..,..1'_.1._r....H.._r_l.,..1' .... ~1'-.."-1'"-r*.. ~ 1.-..'"b,"~': -:.. ', 1"1'": : ~ ~ 1' .... ~ ~'~ ::e .: : [ 4-4-*..4--.-4-4.,4-4..--4-4..4.-kl..4.-k%.4...-4-.H4.--4..4.-k4-4"-.H,.-4.-~:--%-4"-+.4,4..4.-+.-,..4..4-4...-H 1-4.'-.?:,4..4..-.~..4..-+-+1+.-,.-4..--~--4.:.4. ....... +-+.+--?,.~ .l~ · :: t - -~ . · ..~ ....... ~'' '~ ~'--~' '" '~' ~' '"i"~--f--}--I"H"-[-~ ....... ff--i--} ....... f"}-'~'-} ...... }"'?'i"-}'-~'"i'l"["-}'"'i-'''??;''+t+ti''l~..-q---i.+t-.-t-i.+i ...... i.-t--.i---i ........ h[l'"i'"t ........ hi'"'i'"t'"i""i'"t"~""i"""t"t"i""i ....... 3 u.. L_L L :.. L: .... :_.].._[.._[ ...... L~[:..J..~L.~..JJ'...LZL~.4.4...~-~...-L.L~L.LJ~..~Lj,~L~L...4..4..-L.i--..~L4.4..4... : : :: ...~..~ ....... ~..-i...i..-~,..~..-L..~_.~..?...~..4--L~,,,,.-~..~..-~.-i..'..~..~-i-4,:..-~ ..... ;>4--44..'-.;:. 4..4.4 ~ ...................................... ;.--?.-.?,-..:.-- '' ~'''''' ''" i''" "" ::".;ii:: ::i:: ::: ::"(::i '!:: ::.~::::..4444,....4..4--!.4 ..... ~..--i.-i.-..~--..-,....,.--:.-~.,-TFT 'TT"T:'-]-t'T'YTT" '-'T:'-Y]-] ...... T'TT"7-~ '-~l'l"~lrTl~ 0TTT'7"' ""]"TT:'"T' ,'t-T"7'TT' 'TT"]-]-'."'TT'T']''' !i iii!ii:: ;i;i .H-H-H-i-4.4.-..,-H-4-4 ...... i..4-.4..4-~444-...'-i4-..i4-4...4444 ...... i-H4.-?-i'-.H.+44--.i ...... HH.-t..4....H-.i ...... .b.H...H,..i.-.f.-f-i..-,..i...i.-i...i ....... -'f-+.'-'f-4.~-t--i'--f.'-4.-+.-.-4.-+--½-4.-- -+.4.--4.,--i':.'-~ -4..--f--H-'i:'-~-.+-.-H+.4.-..--f-4'~.'"+- -+-:,.-+-4.--r- .-.4.-?-'?-t-';-4.-+-'-? ..... .,..% -.;...-r ..~'.-r.---.,'-..r .-~' ....... .t...?-.?--.,...--r.-r..?--r..'t ....... r...:---r-'?.- '--f'--?f.---r-- - .j.,4-4-4..4..4- 4.-4-4 - -4-4. 4.-4...- .4- 4-4-4-4 -4.-;.--;--4--~-4-4.-i-4- ,.4..4-4-4-.- ..4..4-4..4 ...... 4..-4-4.-4-4-4".4".4..4 ...... 4...-i....L-~.-4...;...-!...,f....~ ........ b-.i...~.-i..4..-b-.'b'-b"~ ....... ~ ........ ~""i ...... -H-b4.-!..- -i ...... ....... ....... i ....... !'"%'- · .+.-H-+..!-.4-¥.4:.-~ ...... H--+--~ ....... ';-.+.+.-.? ...... r..74-4- -4..4- i...4 ..... 4.4--N---4-.4.-4.4.--b4..4.-.H! ........ H+-+-+' ..+--H..+-.,H.-i-+..-i ........ !,.-h..i.-..i ........ i...f...i--..i ...... H.-HPl ....... t't'"?' -e4.-.4.-+.-k-e-';-+-? ....... +-4.-4.--4. ....... ~.-4.--?.+.-~-.4.--t--::-4. .... +.4..-.~:.-+ ........ f.+.+.4. ...... .~-+--i--?'--?-+-74. ....... h4.-';--'i ...... f--i--i'-i ........ r'4-"i'--! ........ r"r'"?'"r ............ r'".~""r ........ r'-r'"F"r ....... .... k~---!4.: q.-..k.!-~ ....... i-H.-+...,-++H.. "~r~'H"i--'~''-HH ....... H-'H ....... H--f--H--.?-t--?f-!--'i"-f'--!---H"'-!'-"i'-'f'"i ........ i"i"-'i'"'!""!"-'i'"t::!ff ...... f.'?.---~-'i ....... f"i"-'i""! .... _.M_.L.L...J-.L4..4 ...... LL4..X ......4 ~..4-4..4-.~..i4..-L4 .....1 LL4...L-.4..4..4..4 ...... N-i..4 ....... L4..44 ...... ;.4...;_x... 4_.4..x....[.4.4....~"4'4"';'4 ........ i.4...L.i......~....i....:.4 .......1 b.~.4..-4--4..4.4..4 ....... b.H-i ....... ...... ....... ...... ........... ........ ........ · --t-~--?,--f-----?--t'---:-? ....... ';--'f..'"?"-.~ .... ?"'?"I' } i '1. 1. 'f. 1' .... I' '1' : 1' "?."'?'f.:"'1'., ..... .."1'"'T'~ ....... ?"T'1'"'1' ..... ?'-:'"'1."1'."' ;'"'["'I'""}"'? ....... .,'"".,'""["'1' ........ F"F"F'lf''' :'"!'l"1.'"'F"[ ...... ?'"'F":'""~ ......... F..1...1...,....} .... --.b4..+-t-..+4.'-H--++-t:--t----?:-.4:--+-4.-1-t~4.~4.~.t.~.~-t~++.4.~-~f-1.l.++:[.~t~.t:-f~+~l...t...';~4...+~"+.4.-4...?.~4.-:..4..+"]...t.-h.t-t ........ ?.-t'..t'"-~ ....... t.-.t-"t'"1' ....... ?-.?.-t.......1.'""i"-i"'..'l'' .... ;..4....,,'..,.'...,..+.?...';-4,...,-+.+.+4. ...... ';..+._,~..+....+..';_+.4. ...... ~..+.+..4, .... ,.,..+.+.4...j...';..+.4...4. ....... ';..4...4,..4. .... ?.-?-.+.ff.-. r.4..-4..-4.--4. ......._~ %.!..+.-'; ............ :.-...,,.-.?.,,,,-,-r-.?.,-,,....: ........ :,,,?.,.-r.-.,,.--r"?"'?"'?"":"- ..4-4..4..4-. ,-4..~M-4-- -4-4-4-4-., -4-i..4...4-. -4-.i-.i-4 ...... 4,-4..4..4--,-4-4..4..4....f-4-4-.4..4-. ,,.4-4-4....4.-.. -4..4..4-.4...- !..4.4..4..4". ,.4..,i-4-.i ....... -i,..-b.-b--b,-;.--.b-H.?.-,i ....... b..i,--H.b-H-..~,.,-b+.- .-H-1.':-+-.-4.--..'-4-4----..'"-H-H-H-.H-.-H-H ...... -..'"----..'".--.'."..4 -+H'H'-'H-H-'"'++H'-H'-i;'-'i ....... H"H'-r'"H-'!'"'i ...... H""H ....... H'-'i"i ..... H""H"';'"i"i"ff"'i"- .................................~; ~ ?*"?~,,,, ..... :"~"~"'",,,, ....... !I'F;D'B~"T'T"? .............................................. ~~ ?"*..--r'*.. ........ ..... ?"*.."'?-'1' ....... F'TT"FI'T']-T'"r ........ r'T'T'"! ........ i'"?'"T'"i ........ !'"T'T'"F';'"'!"T"!""!"' 12000 91. PROJECTION ON VERTICAL PLANE 91. - 271. SCALED IN VERTICAL DEPTHS HORIZ SCALE = 1/2000 IN/FT AOGCC GEOLO(]ICAL MATERIALS INVENTORY LIST .. PERMIT · ~' o - COMPLETION DATE WELL NAME /',,37 (.Z' / -.~ ~ ! ?o CO. CONTACT&NO. form received received date comments 407~ (/~s~ no .~-./y/~o completlon rep°"' 403 yes no sundry application 404 yes no report of sundry application Open required received Cased required received Pr°ductionrequired receive~' hole log ' hole loa~ Io~ MUD ,,~o (]CT TEMP ,..j .3- ~'~ DII_/sFL CNL PROD ~j~ ,//: ,, DLL CBT J PRESS ,, ~ BHC/SL CE'I' ,.~ //' SPINNER BHc~AC EPT OTHER DATA ESS PERF Survey nEC ~'J ~ 'SSS PACKER ........ Digital' ~'~_ I:DC- Well ' ' '' CNL Tests FDC RWD required received SAMPLES required received MWD LDT!CNL' dry ditch ,~"'o ML core CYBER core LOOK , Analysis EMS ./ ~'~ T~p ~ ~ I~ ~ {~ ; .2 ~" BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 19, 1990 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle' Enclosed please find one sepia and one blueline print for the well logs run in the following Endicott wells' v.WELL 1-01/J-19 % ~; ''*' *DUAL BURST TDT LOG (TDT-P) 11640' - 12264' Run No. 2 SCHLUMBERGER /*PRODUCTION PROFILE 11900' - 12200 CAMCO Run No. 1 WELL 1-09/J-18 '~P~-' ~' /' , *DUAL BURST TDT LOG (TDT-P) 11180' - 1217--~ Run No. 2 SCHLUMBERGER WELL 1-21/K-25 *SPECTRAL DENSITM DUAL SPACED NEUTRON LOG 13483' - 14091' Run No. 1 HALLIBURTON *FORMATION TEST LOG NA HALLIBURTON Run No. 1 MAR Anch0f~9e *DUAL LATEROLOG MICROSHERICALLY FOCUSED L 13482' - 14090' Run No. 1 HALLIBURTON *CEMENT EVALUATION LOG (CET) 12500' - 13985' Run No. 1 SCHLUMBERGER *CEMENT BOND LOG (CBT) 12500' - 13965' Run No. 1 SCHLUMBERGER *TCP GUN POSITIONING LOG 13454' - 13750' Run No. 1 SCHLUMBERGER WELL 1-45/Q,26 *CEMENT BOND LOG (CBT) 12792' - 14181' Run No. 1 SCHLUMBERGER *CEMENT EVALUATION LOG (CET) 12792' - 14181' Run No. 1 SCHLUMBERGER *GRCCL- PACKER RECORD 12850' - 14172' Run No. 1 SCHLUMBERGER WELL 1-67/T-20 *GAMMA RAY TEMP LOG 11500' - 12041' CAMCO Run No. 1. WELL 2-52/$-14 *TEMPERATURE SURVEY 11600' - 12670' Run No. 1 CAMCO WELL 3-01/N-29 *DUAL BURST TDT LOG (TDT-P) 11845' - 12947' Run No. 3 SCHLUMBERGER January 5, i990 Telecopy: (907)276-7542 M. E. Miller Endicott Lead Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 h Alaska 99519-6612 ~nc orage, lie ~ Duck Island Unit/Endicott 1-21/K-Z5 MPI BP Exploration (Alaska) Inc. Permit No. 90-2 Sur. Loc. 20i2'SNL, 2081'WEL, Sec. 36, T12N, R16E, UM Br~ole Loc. 1958'SNL, 3829'WEL, Sec. 32, T12N, R17E, UM Dear Mr. Miller Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pe~itting deteminanions are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equtp~ng so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may' witness testing before drilling below the shoe of the conductor pipe. Verf truly yours, J" i / ./ i'~ ~ ' / [ ., j: x::.:i(/ A~a~ka Oil and Ga~ Conservation Co~tssion BY O~ER OF THE COI@ilSSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 December 29, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn' Mr. C. V. Chatterton 1-2//K-25 MPI (Endicott) Enclosed, in triplicate, is form 10-401, our Application for Permit to Drill the above-named well. Also included are the attachments listed on the application form, and a check in the amount of $100 to cover the permit filing fee. Yours very truly, M. E. Miller Exploration Lead Engineer MEM/KTH CC Richard Loveland Well File , , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.OO5 la. Type of work Drill [] Redrill I-Illb. Type of well. Exploratory l-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenF-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration BKB=56 feet Endicott Field/Endicott Pool 3. Address 6. Property Designation P. 0. Box 196612, Anchora.ge, A/aska 99519-6612 ADL 312828 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025) 2012' SNL, 2081' WEL, SEC. 36, T12N, R16E Duck Island Unit/Endicott At top of productive interval 8. Well number Number 1950' SNL, 4150' WEL, SEC. 32, T12N, R17E 1-21/K-25 MPI 2S100302630-277 At total depth 9. Approximate spud date Amount 1958' SNL, 3829' WEL, SEC. 32, T12N, R17E January 11, 1990 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(uoandTVD) It/ line prop L 47502 @ 3320 feet 1-25/N-22 @ 3113' TVD/13foet 2560 14216' MD/10306' TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 ^^c 25.035 (e)(2)) Kickott depth ;~,¢'0~' feet Maximum hole angle~/./, o Maximum surface 3900 pslg At total depth (TVD)9855Y4840 psl¢ 18. Casing program 1~.. ~. )~,fL/ia'~../',~.,~¢', Setting Depth s~ze ~pec~mauons Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" Struct. Drive Pipe 75 Surface 131 131 Drive 17-1/2" 13-3/8" 68# 1Y~-80¢ f#£ Butt 2444 Surface 2500 2500 2700 cuft Permafrost 12-1/4" 9-5/8" 47# NT80S NSCC 11250 Surface 11306 8500 12-1/4" 9-5/8" 47# NT95H NSCC 2120 11306 8500 13426 9816 575 cu fl Permafrost 8-1/2" 7" 29# SM11O Butt 1041 13175 9660 14216 10306 400 cu fl Permafrost 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured - true vertical _~0. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth pict [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed'"~ ~ Title EndicottLoadEnginoor Commission Use Only Permit_..Number IAPI number ~. IAppro,,v~.l ,d,,at,.e,,,,, Ieee cover letter ~'0''''2'' 150' O2--P'' ~-~-----"~:~"~ I uJ./u..3/~U Ifor other requirements Conditions of approval Samples requ. ired [] Yes /'l~'.No Mud Icg required I-IYes/'~ No Hydrogen sulfide measures [] Yes ~_ No Directional survey requ~re~ 'l~rYes [] -No Required working~¢'~, ur~-~r/~"~~,,3M/,l~3U; zl~5U; ~1 OM; []15M; Other: / //'"~/./Z~~------ by order of Approved by (' /..- ~'.( (_~~~ Commissioner the commission_ .Da.t.e. ...... Form 10-401 ~-1. licate PRQPQSED DRILLING AND CQMPLETIQN PRQGRAM WELL 1-21/K-25 (MPI) Objective Well 1-21/K-25 will be drilled as an oil production well. Zone 1 is the primary objective. The completion will be run at the time of drilling and will consist of a simple type assembly. Operation Execute a rig move to slot 1-21 and rig-up. Vertically drill 17-1/2" hole to 2500 ft. Run and cement 13-3/8" 68#/ft., NT-80CYHE Buttress casing to surface. Pressure test casing. Install BOPE. Maximum BHP is 4840 psi at 9855 ft. TVDss. Maximum possible surface pressure is 3900 psi based on a full gas column. Drill out casing and 5 ft. of new hole and conduct a formation leak-off test. Vertically drill 12-1/4" hole to 2550 ft., then directionally drill to the intermediate casing point above the Kekiktuk formation. Run and cement 9-5/8" 47#/ft., NT80S and NT95HS, NSCC casing. No abnormal pressures are expected in the 12-1/4" hole section. Pressure test casing. Drill out casing shoe. Drill 8-1/2" hole to TD. Run open hole logs. Run and cement 7" 29#/ft, NT95HS buttress (TKC) liner to TD with approximately 250 ft. of lap in the 9- 5/8" casing. Clean out to float collar. Test casing and lap to 3000 psi. Change over to NaC1 packer fluid. Run CET/CBT/GR/CCL in 7" liner and gyroscopic survey from PBTD to surface. Perforate well underbalanced utilizing drill pipe conveyed guns. Flow well for simple clean-up. Kill well and complete with a simple completion. A sub surface safety valve will be installed below base of permafrost. Nipple down BOPE. Install tree on wellhead and release rig. Fluids incidental to the drilling of a well will be pumped down the 13-3/8" by 9- 5/8" annulus of the well. The 13-3/8" x 9-5/8" annulus will be freeze protected with a non-freezing fluid down to 3000 feet once the rig is released. KRL 11/29/89 ENDICOTT PROPOSED DIAGRAM WELL 1-21/K-25 (MP, I) NON-FREEZING FLUID ~ MD (8K8) 30" DRIVE PI PE 131 FT 131 FT BASE PERMAFROST SSSV 1466 FT 1466 FT 1550 FT 1550 FT , 13-3/8" 68~/FT NT-8OCYHE BTC 2500 FT KOP(DIR:N89.6' E; ANGLE:51.6DEG) 2500 FT 2550 FT BOTTOM OF FREEZE PROTECTION (ESTIMATED) 3000 FT 1/2", 9.2=/FT L-80 TDS TUBING W/ 3-1/2" TAILPIPE 9-5/8" 47~/FT NT80S NSCC TOP OF 9-5/8"CEMENT 8500 FT 11306 FT (ESTIMATED) 11626 FT 3-1/2" SLIDING SLEEVE 9-5/8" PACKER 7" LINER TOP 9629 FT 13125 FT 9660 FT 13175 FT 9-5/8"47~/FT NT95HS NSCC 9816 FT 13426 FT PLUG BACK TD 7" 29~/FT NT-95HS BUTT (TKC) LINER 14136 FT 10306 FT 14216 FT KRL/1 1-28-89 BOP STACK CONFIGURATION 13 5/8", 5000 PSI WP TRIPLE RAM ST ACK DRILLING RISER ANNULAR PREVENTER 2" KILL LINE MANUAL HYDRAULIC GATE GATE PI PE RAMS ! I BLIND RAMS I ,, DRILLING SPOOL I 4" CHOKE LINE HYDRAULIC MANUAL GATE GATE PIPE RAMS ! ! I I ENDICOTT DEVELOPMENT WELL 1-21 / K-25 (MPI) TRUE NORTH GRID N 89° 36' E DEPARTURE TO BHL: 8397 FT 14216 FT MD 10306FT TVD BKB SLOT 1-21 SURFACE LOCATION X = 259,123 FT ;Y = 5,982,400 FT 2012 FT SNL; 2081 FT WEL SEC 36, T12N, R16E DEPARTURE TO TARGET: 8081 FT 13814 FT MD 10056 FT TVD BKB NOTE: THE NEAREST WELL TO 1-21/K-25 IS 1-25/N-22 LOCATED 13.5 FT SOUTHWEST AT SLOT 1-25. KRL/12-26-89 $6 YES' 36 CERTIFICATE OF SURVEYOR I Nearby certify that I m properly registered and licensed to practice land lurve,ying in the State of Alaska end that this plat represents on propoled leeation for the Well numbers shown above. All surveying wes done by me or under my supervision, and that ell dimensions end details are correct. DRW. 115-85 SHEET ~. of I0 REV. O i 0 Indicates well .~ Indicates Celcblated Section Corner Position Indicates PerlNedicaler Offset Distance Indicates Por~eediculer Offset Oiete~ce t~er~endicu~or&st~Bc~ v~rils tgr ~och loll ) PLAT OF ~PI PROPOSED WELL LOCATIONS LOCATED IN SEC. ll~ T.I~N.~R. I~E. UMIAT ~. PREPARE 0 FOR SOHIO ALASKA PETROLEUM CO. PREPARED BY F.R. BELL ~i ASSOC.' - PRUDHOE BAY OFFICE PRUDflOE BAY, ALASKA DATE: NOV. I$, 1118 ICALE, I"" bRAwN iY Ri.T. CHECKED BY' D.E. I~ L I I II IIII I I II I I I · I I .... I II II .... IIELL ~11' IONE I UTI. JNE 6 LtTITUIE LI~ ;1111: IIIT~), llll~ I Y-'8912412~17 N-7105324.5! 70~21"10.0670 X- 259i10.71 E- 464137.3& 2 Y- 59112579.813 N- 7805:355.52 70o21'10.9814· 147°$7'24.&257' 1135."45 2161.94 X' 259041.49 E,, 464094.45 :3 ¥.. 5982474.18 NB ?80§322.98 70~21~09'9E~46~' 147~§7'20.6258' 1956.77 ~ 20:32.11 X- 2~9175 01 ~ E- 4641:35 65 4 Y- 598~-571,69 'N- 7805350,99 70o21.10,B~*" ' 1'~--~.5~.24,7856, IB43,B0:2174,41 I X- 257055,76 E- 464092,74 5 Y- 5982465.99 N- 7805319,46 70~- 21' 09, 9023" 147c 57 ~ 20, 7857· X' 259169,27 E' 464133.95 6 Y' 5982565.50 N' 7805348.47 70~21'~0.8168' ~47°57'24.9454' ~052.17~ 2179.88 X' 259030.02 E- 464091.04 7 Y- 59ii2457.80 N- 7805316.94 70o21'09.8200. 147~57'20.9455' 1953.52 204:3.06 X' 259165.54 E' 464152.24 B Y- 59025~55.30 N" 71105345.94 70°21'10.7344 X- 259024.29 Em 464089.33 9 Y- 5902449.6! N" 7805:314.41 70°21'09.7376' ~'47°57'21~'i05'4' 1961.B9 2040.53 X- 259157,B0 E' 464130.53 lO Y" 5982547'll N' 7005343.42 70°21'10.6521" 147°~7'25.2651" 1160.91 2190.13 X" 259018.55 E" 464.087.62 Ii Y' 5902441.42 N' 7805311.B9 70~21'09.6553" 147°57'21.2655" 1970.26 2054.00 X" 259152.07 E" 464128.B$ 12 Y" 5902538.92 N' 7805340.90 70~21'10.5697" 147°57'25.4250" 1177.21 2196.30 X' 259012.82 E" 464085.92 13 Y" 5982435.25 N' 7805309.36 70021'09.5730" 147°~57'21.4251" 1978.63 2059.47 X" 2~59146.33 E" 464127.i2 14 Y' 5982530.73 N' 7805338.37 70°21'10.4874" 147°57'25.5B49" tB85.66 2201.77 X- 259007,08 E:' 15 Y" 5982425.03 N" 7805:306.114 70~21'09.4906" 147~57'21.51150" 1987.00 2064.94 X" 259140.60 E" 464125.42 16 Y" 5982522.54 N' 7805335.85 70°21'10.4051" 147057'25.7447, 1194.03 2207.24 X" 25900~.:35 E" 464002.50 17 Y" 590:~416.B4 N" 7805304.3i 70°21'09.4003" 147°57'21.7449" 1995.3B 2070.41 X' 259134.16 E" 464123.71 1! Y- 5982514.35 N- 7B05333.32 70021'10.3227" 147°57'25.9046' 1902,'40 2212,71 X- 25899:5.6! E- 464080.80 19 Y- 5982408.65 N- 7805501.79 70¢21'09.3260" 147o57'21.9047" 2003.75 2075.19 X- 259~29.13 E- 464122.00 20 Y- 5982506.~6 N. 7805330.B0 70¢21'~0.2404" 147c57'26.0644" 1910.77 221B.~8 X- 258909.B7 E- 464079.09 21 Y"' 5982400.46 N. 780~5299.27 70021'09.2436· 147~57'22';0646" 2012.12 2081.36 X- 25912:3.39 E- 464120.30 MPI PROPOSED WELL LOCATION LIST -" --O1',4~:4~ ._ LOCATED IN SEC. ~I',T. IZN.,R.ISE. UMIAT M. ' SOHIO ALASKA PETROLEUM CO. l'a';,'l. H0.691~'4 '~ ~ DRW. NO. 116-8,5 PREPARED IY DATE'NOV. 13~ 1~0~ ' ·('a--~".-'"~-,~ ~' F.R. BELL & ASSO¢ '~.?~/:E$SlOt41k~..,~,~,,,m, SHE ET $ of IO ' SCALE: N/A '-~,~%,~,,qb, b,--- PRUOHOE BAYOFFICE ORAWN BY: RG.T REV. O PRUOHOE BAY~ALASKA CHECKEO BY'. I.E. i iii I ~_ _ 11 . II I I I III · NLL ~ 1~ I IT i 6 L&TITi LI Tu~ llll~ iilT~ 22 Y- 19124~7,97 #-'"710~$21.27 ~2i;'IO. IXI' 14~17'26.2~43' il ~Sltl4. i4 E~ 4&4077.31 23 Y- 59B23~2.27 N- 7B0~29&.74 70°21'09.'1&13· 147°S7'22.2244' 2020.49~ 20l&.13 X- 259117.&5 E- 4&4Jig. S9 24 .y, 'S982489.77 N,"780~32~.7~ '70~21'~0.07~7· ~47~7'26.38~2· "X- 258978.40 ~ E= 464075,68 25 Y- 598~4,08 N- 7805294~2~'~0~21~'09~0~9'0~ .... i4~~57''2~,~B43" ~ 2028,86 -20~2.~0 Y= 59B~-~81.58 : N= 7805323.23 '70~21'09.9934' 147~7'26,5440" 1935.90 ~ 2234.60 ,X= 258972.67 ' E= 46407~.97 . _ ............................................... 27 ~Y= 59G2375.B9 N= 7B05291.69 ~70~21'0B.9966" 147c57'22.5~42" 2037.24 : 2097.77 l- 259106,1, E- ~i~115, lg 2B Y= 5982473,39 N= 7B05320.70 70~21'09.~111· 147c57'2&,7039" 1~4~.27 2240,07 1- 258966,93 E= 4~4072.27 29 Y= 59B2367,70 N= 7805289,17 70c21'0B.91~3· 147c57'22,7040" 2045.~1 ~103.24 ....... X- 259100,45 E- ~4113.47 .... 30 Y- 59B2~65,20 N- 71053Ii, lB 70~21'09,12g7" 147~57'21,1137" It52,1~ 2245.54 l- 25~9~1.20 E- 31 Y- 59g23'59,50 N, 71052g~,15 70~21'0g,1320" 147c~7'22,113t" 2053,~ 2'i01,72 l- 259094,71 E- 46~111.7~ X" 258955.46 E- 464068 33 "Y- 5982351,31 N= 780528~ 12 70021'08 7496" 147057'23.0237" 2062.35 2114.19 X= 259068,98 E= 464110 06 3'4 Y= 5982448.B2 N= 7805313 13 170~21'09 &641' 147~' 57 ' 27.1834' 19&9.38 2256.49 X' 258949.73 E= 464067.15 I " 35 Y- 5982~i8.55 N' 7805274.02 70o2~'0B.4203· S47G57'23.&&32' 2095.14 2A36.07 X- 259066.03 E- 464103.23 36 Y- 598~416.05 N, 7605303.03 70o2l;09.3347' ~47c~7~27.B229' 2002.17 '"~2~B.37 X- 256926.78 E- 464060.32 37 Y- ~9823~0.36 * N- 7805271.50 70°21;08.3379' 147~57'23.B230' 2104.2J 214~.55 X- 259060.30 E- 464~0~.53 3B Y- 5962407.06 N- 7g05300.51 70o2~'09.2524· 147~5~'27.~B27· 201t'~24 2263.64 X- 2~892&.05 E- 464059.61 39 Y-5'962302.17 N-7g05266.~6 70o2l'0B.2556· i47~57'23.tl2~' 2112.51 2147.02 X- 259054.56 E- 464099.62 40 Y- 5962399.47 N' 7605297.98 70~2~'09.~700' ~47~57'26.1426' 2019.&2 2269.31 X- 2589~5.3~ E- 464056.9~ 41 ' Y- 5982293.9~' N-"7605266.45 70o2~'08.~733· 147~57'24.1427' 2120.~5 2~52~49 X- 25904B.B3 E- 464098.~ 42 Y-590239l 4B N-7B05295 46 70o21"09.0877' 347~'~7'28.3024' 2027.99 2294.7~' II II I _--~~--~r ~ MPI PR~SED WELL L~ATION LIST ~_~ O~ 4~ ~1 LOCATED ~, SEC. ~6, ~.~Z,., ~.~S [. U~l*~ ~. so,,o · ,E aOLEUM CO. ,~:~%~~~/~,~___~__ ~~ -- ORW. NO. IIS-BS PREPARED BY OATE'NOV.I~, s ~ ~~ ER. BELL · ASSOC ~k~ss~K ~ SHEET 4 of IO ' SCALE: N/A '~~~ ' ' PR UDHOE BAY O~1 CE DRAWN BY: R.G.~ -',. ncr. O PRUDHOE BAY, ~ASKA :............. i ..... [ J I i Ill III I I I I -- I _ II II II I ~' I I [] I II~ .------ ~' I I I I1~ WELL lip Z0ll I UTk .ONE 6 LI~TITUIE LO~..rUN IIIT~ IIIT~ 43 Y- ~91Z2B~,71 N- 710S~&3.93'[70~'0i.0909' i4~i~24,3~&' ~ i1~,ii~ ii1'7',~6 X- '2S9043.09 E- 464096.4~ 44 Y- 59B2383.29 N-'~B05292.93 70~21'09.00~4" ~47~57'2B.4623' 2036.36 2300.26 X- 2~8903,B4 E- 4640~3,~0 . .... ~ ...... ~-Y=-5~82~';~'~--~,--~'G052~ 1., 40-- ...... ~...~ .... ~.59037.36 E= 4640~4.70 46 Y'X- 5982375'[01N'258898.tt E- 7805290.4146405t.79 47 Y- 5982269.40 N- 7805258,B8< 70c2t'07.9263"= ~47c57'24.6223" , 2t46.07 2t6B,gt X- 2Sg03t.62 E- 464092.99 48 Y- S98236~.9~ N- ~805287.B9 {70°2t'08.8'~'07" 't47oS~':2B,Ta20" 2053. t0~ 23tt.20 X- 258892,37 E- 464050.08 4~ Y- 598226t.2t N- 7805'~5~.35 70o2t'07.8439· t47°57'24,7122" 2t54.44 2t74.38 X' 259025.B9 E- 464091.29 ~0 Y- ~9B23~e.71 W- 780528~,36 70o21'08,7584· S47°ST'2B'.'~41B" X- 2~8BB6,63 E- 46404B,3B }{ Y- ~9d~2S3.02 N- 78o52~3.83 70~2l'07.76~6"'' 147°~7'24.942O" Xm 2~9020,1~ E' 464089.SB 52 Y. sv823 0."'S2 780d' e2'.,4 70=2 '0B.6760" 147o57'29,1017· 2069.l~ 2322.14 X" 2~8880,90 E- 464046.67 . ,, ~3 ym ~982244.B3 H' 780~25{.3t 70~2~'07.6793" ~47~7"2~.10~9" 2{7~.~9 Xm 2~90t4,4~ E- 464087.88 ~4 Y' ~982342.33' N' 780~2B0.3l 70~2S'08.~937' ~47~7'29.2&1~' 2078.22I 2327.&2 X' 2~BG7~.I6,.E- 464044.96 ~ Y- ~982236.64 N= 780~248.78 70c2~'07.~69· 147o~7"25.26~7' 2~79.56~ 2~90.80 X- 25900B.6B E- 464086.~7 ~6 Y- ~982334.~4 N- 780~277.79 70~21~0g'~1~3· ~47o57~29.42~4~' 20g6.59, 2333.0~ X- 2~8B69.43 E- 464043.26 57 Y- 59B2228.44 N- 7B0~246.26 70°2['07.5~46&'' 147°~7"2S;42~&" : 2~B7.9~ ~ 2196~27 X- 2~9002.94 E- 464084.46 ~8 Y- ~98232~.9~ N- 780~27~.27 70o2~'0B.~90" 147~7'29.S1~2" 2094.9& 2338.56 X- 2~8863.&9 E- 46404t.~ 59 Y' G982220.2~ H- 780~243.73 70G2~'07.4323" li7o~7'25','51[4" 2tg&.30 220~.74 X- 2SB997.2~ E- 4640B2.7& &0 Y- SgB23~7.T& H- 7B05272.74 70o2t'0B.3467" ~47°57'29.74~" 2~'03.33 2344.03 X- 2~88~7.96 E- 464039.8~ &2 Y- S9822~2.06 -N, 780~24~.2~ 70c2~'07.3499" ~4'7~57'25'.74~3· 2204.&7 ~207.2~ X- 2~899~.47 E- 46408t.0S 62 Y- ~82309.~7. N- 780~270.22 70c2t'08.2&43· ~47~57'29.9009" ~.7~ X- 2~88~2,22 E- 464038.~4 .... &3 Y- S982203.B7 N- 7g0~238.&9 70o2~'07.2676· ~47~7'25;t011. ' 2213.0~ 22~2,&9 X- 25BgBS.74 E- 464079,34 ~ , , I il i -, MPI PRO SED WELL L TION LIST SOHI'O ALASKA PETROLEUM CO. ] ~ ' ' / DRW. NO. IlS- 85 PREPARED BY DATE:NOV.13,1115 8CALl' N/A D~AWN BY : RG.T ~Ev. o P~UDHOE ~Y, ALAS~ CH[CK[O,Y: ~.E. .... II ' _~ I ~_ 111 I I .1! Iii _ I I I I I_ III I II L I I _~L~.~'~ I -- I~LL -lip ZOllE 3 I1: ONE 6 LITITUll LO..TUll lilt "&4 L':Y-'Se'i2$0I'.'$1 II-710SliT.i* 7F21";01,1120' 147~B7'10.0101' l- 251141,41 E- 4&4036.43 &S Y- 5962195,46 N- ~g05236,16 70~21'07.1652' 147o5~'26.0410· 222~.43 X- 256960.00 E- 444077.&4 66 ~Y- 5962293,'16''N- 7605265.17' 70:21'06,0997" ' 147:57'30.2206' ~ 2126.45 ~ 2360.45 X= 2~6640.7~ E' 4640~4.7~ X= 256974.26~ E= 464075.93 . . 66 Y- 5~62264,99 ~ ~- 7605262.64 x- 25ae~5.0~, [- 4640~T.02 &9 :Y.'59~2179 ~ N- 7BO52T~ ~1 70~2J,07.0206· 147~57'2&.3B07' 22~6~t7 2229.10 X" 2~'96":~S3 E" 464074:23 70 Y" 598227&,'10~ N' 7BOS2&0,12 7~2~'07.9350" ~ 147~7'30.5403" 2t4~,19 2371.39 X" 2~B829,28 E- 46403t,31 ~ ~ .... I I MPI P~O~SED WE~ L~ATION LIST -- OF ~.~! LOCATED INSEC 36 T. I2N.,R. ISE. UMIATN. ~'~''~~~~~~~~.t~1~4 ~~ .... SOHIO ALASKA PETROLEUM CO. -~A~ ,~ ORW. NO. 116-15 PREPAR[O BY ~i~.-,,. --- F.R BELL 6 ASSOC ~ ~ ~~ SHEET 6 of I0 ' ' SC~E: ~~ssl~~ ~ pR U DHOE BAY OF FICE ., ~~~ DRAWN BY: R.G.T. R~. O PRUDHOE BAY~ALA~KA CHECKED BY: B.E. i ~-r r~h~"~- FFF ' i}i FFFFFFFFFF 888888888888888888888888 Digital Equipment COrporation - VAX/VMS Version VO. 1 88888888888888888888888B RFFFFRFF FF :) · - · :. :..~:' '*.,:.,~?,?..~ :~?.!.~ :,.~.;.,:.. - . .... .- ,;., -. :.' :: :~::~;.:.,?r .:,-.:., ...... .:.. . ..... ... 11~ ------Closest Approach Anmlusis. --- Dmte- 26-DEC-89 Time: 16:00:37 ...~.::::~.~.~,~.~,., + . '~..:.~ ;:?. '::' ' ;.:: ./,: ~¢ ::."..' :,:; ; ~.~:::;: :..:;; ;~'?;J::,?J?: Location = W-E S-N TVD (SBS) 259123. O0 5982400. O0 -56. O0 10250. O0 ~--'-' ....... :.': (.:. J~::: ~' ':'.'.~i:!:: :~' :: :~:. ::: !.::::~!':.'.¥'.C' ' ,,~ Bushing (BM, B) Closest Approach /NEARBYN':: TVD DEPART AO00-O000051 MI-1 A000-0000083 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH wiN~OW Vertical Intersection RBPOSED~'~:!?:'""':,~'.:'¥'-'!: '? ...... ............ ::;?:'":", VERTICAL DEPAR~i':'.. .':,..: TVD .'DEPART:'.:.. :.. ::DISTANCE · ,,,..~;,...j:. ::,: ~::: ,. :.~:.., ,: .::: .... =..~, .....:. 'F, .. ::: ~: Aooo-oooooe~' MI-36 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH wIN'~'OW''::,?*'`':~':'::~:'::~': A000-0000119 MI-89 A029-~084000 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW MISDiO . 4595.2 1183.0 4742.6 A0~9-~156800 MI-P18:i ' 'i 1~00.8 0;0 1200.0 1663. 5 ,586. ~ :': i ,5054. 3 1762.8 6~37.7 2537.9 11~0.9 391 , A02~-2158500 -) !"i MI-MI? ~550. 0 O. 0 2549. 5 i4z A029-~ 160500 7.2 186.3 12.4 61;'5 ........ 5914.4 2849.1 10262.~ 280~.5 i~s! MI-~21 200.9 0.0 200.0 O. 4 159. 7. 5 166.7 ';~ A029-2163~00 ~i~Ti MI-OI8 2550.0 0.0 2550.1 i,~' A02~-2166200 !~:! MI-P14 ~550.0 0.0 2550.4 :.i A0~-~I66~00 '~fi MI-~25 500.9 0.0 500.0 5. ~' 175. 4 2.3 38.9 ~: A029-~167200 ;!~Y MI-025 1.0 0.0 0.0 O. 0 ~9.9 * A0~9-=i69300 ~! MI-P~O 200.5 0.0 200.0 :~i A029-2189800 0.2 30.0 2698.6 5.4 2696.5 124.5 135.1 A029-2171300 Mi-023 A029-2172200 O.B 0.0 0.0 0.0 130. 7 . --~ti ---N~=~2 3111. 3 AO~9-~174300 Mi-~I8 I. 0 AO~ET-2174800 MI-P~4 O. 5 ~.~-~ 1771 O0 MI 'K 16 ~ ~550.0 80. 6 ....... i3-'5 ...... 0.0 0.0 0.0 61.0 0.0 0.0 0.0 I07.9 A0~9-2178800 ____~;f -i_~RP_5, 1.0 0.0 ,, AO~9-~ 180100 MI-~I9 1779. 4 O. 0 1800. 0 7. ~ !O~O0 MI-NI4 : :1500.9:0':0 . I000,0 0.3 9:25. 0 I70. 8 {7 ~ B4$DUA I ~4: [ DR~N0-~ I ] M 1½-~0 cLOsAP;: SHORT~L I S; ~0~c2-~ 18~700 a6-DEC-i989 16i01 MI-PI7 8~4.9 0.0 894.0 ~__Q__~9-~184100 117. 8 'he meii wh ich :comes':'C"iosest ~0 ~he'::'~ ~o o'Sed we! <.:_...~.. .,~ A027--217~00 M I -N~ ) losest appeoach ;distance = ,. .... ..::::.:~: .. ICK OFF For ~his run = ~550.0 Feet }69 Interval Mud Weight ENDICOTT MUD PROGRAM MAIN PRODUCTION ISLAND WELL 1-21/K-25 Viscosity Fluid Loss (sec/qt) (ml/30min) 0-2500 8.8-9.8 100-200 20-15 9.0-9.5 2,500- 13,426 13,426- 14,216 Set 13-3/8" casing 9.2-10.2 40-45 15-16 9.0-10.5 9.6-10.2 Set 9-5/8" casing 40-45 6-8 9.0-11.0 Hang 7" Liner Mud Type/ Components Generic Mud #5 Seawater Fresh water Gel Soda Ash Generic Mud #7 Seawater Fresh water Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite Newdrill Generic Mud #7 Seawater Fresh water Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite Newdrill :3T... ASKIt J! JL ; VIEW- J..E VEL__~.. II II IIII II I IF IN DOUBT..- ASKI! I I I__ 12 ~0 e -o' POW£~ · __..-o -t- i&-o' IZ'-O" t I / I II:~ ' ? o! O' ! I .0..9-'0 ' -7 ;o' : , -%, DOYON DRILLING, INC. RIG NO. 15 MUD AND SOLIDS CONTROL EQUIPMENT Equipment Manufacturer Model Nominal Capacity Shaker Desander Mu del can er s Centrifu9e Brandt Dual Double nemco 2-12" cones Tri Flow Pioneer Degasser Dr i I co Agitators Brandt Ho@pers Geosource 1000 9Pm 700 9Pm (each) Double 400 9pm 8 each - 4" (each) cones Hark II, 150 gpm Decantin9 Vacuum 1000 9pm 8 each - 25 h.p. Dual Sidewinders 1000 9Pm The trip tank and mud tank sections have one vertical pit level float in~licator which are connected to the drillin9 recorder system that contains visual and audio warnin9 devices located in the driller's console. L J t J 13-5/8" APl-S000, 13-S/8" APl-BO00, © f@ CONTROL LINE WELLHEAD ASSEMBLY,ENDICOTT 5KSI 13-3/8"x 9-5/8"x SOHIO ALASKA PETROLEUM COMPANY FIC, URE (3) 13-3/8" CONTROL LINE 4-1/2:' It. 3. 9-5/8" CASING AND WELLltEAD EqfflPHENT 3.1 TESTING B.O.P. STACK I. After B.O.P.'s are nippled up to split speedhend, make up 13" x 4-1/2 Internal ~'lusb B.O.I'. test plug, Accessories Item ?, Part No. 538116. 2. Lower plug into head (it will land on lower step). Tighten t~ lockscrews 90° apart. 3. After B.O.P. test, back out tockscrews and retrieve test pltJl~. CAUTION: It Is very fmportant not to have the lockscrews protruding into the bore of the head while either running or pulling the B.O.P. test plug. Always check them tf In doubt. (29) SPL 1 T SPEEOHEAO TEST PLUG 13-3/8" O.D. CASING II II II II II II ( ACCESSORX. ES [TEN 6 210 BOP TEST PLUG FOg UPPCR BOWL 1538117) I~.98 :1 '1 \ ! /~-/,-~/?.1¢ FEMALE THO · I I! II l! ¥ ACCESSORIES ITEH Z 710 i - fi.,. TM - -r._ _' ? ,'- L J5 .~OF~ LID/CER 80WL :'c, II. 4. 4-1/2 TUBING AND WELLHEAD E~UIPHENT 4.1 TESTING B.O.Po's 1. After 9-5/8" has been sec and tested, run In B.O.P. rest pluf:, Accessory Item 6, Parc Number 538117, which lands In upper bowl of the split speedhead. Run In 4 lockscrews liffhtly, 90° apart to keep plug from moving. 2. After test, retract lockscrews and pull 3. Run In short bowl protector, Accessory Item 8, Part Number 538114, ustnff the same running tool, Accessory Item 5, Part Number 538115, that was used for the long protector. 4. After bowl protector ts tn place, run In 4 lockscrews lightly to hold protector in place. CAUTION: Upper lockscrews must be retracted when the bowl protector or B.O.P. test plug is either run or pulled. --TEST PLUG --PACKING PORT TEST .PORT LOCKSCREW CASING HANGER SPLIT SPEEDHEAD I 3 - 3/8 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee ~C /~/qd 1. Is / 2~ 3. 4. 5. 6. 7. eo (8) (3) Admin~pc ~ ~5 9. (9 thru ~1~ ~- 10. ~~' l-q- ~ 11. (10 ~ 13) 12. 13. (4) Casg ~~. /-3-¢O (14 thru 22) (5) BOPE ~,~ (23 thru 28) 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Company Lease & Well No. /~/_ ~/ZZZ~) ~.~. g/. ~ Zo/~_///'~-//~-.2,~' ~f. RMMARKS / -- the permit fee attached .......................................... YES NO Is well to be located in a defined pool ............................. Is wet] located proper distance from property line .................. Is we,lL located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ................ Is operator the only affected party ................................. Can permit be approved before fifteen-day wait ...................... Does operator have.a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate .................................... Does the well have a unique name and number ......................... Is conductor string provided ............................... ' ......... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate ~ Are necessary diagrams and descriptions of diverter and BOPE attaChed. ~oes BOPE have sufficient pressure rating - Test to ~oz~.?~mpsig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. O ~Z (6) OTHER '(29 thr~ (6) Add: ,4~.~.z~Z~o,T-f~ Geolo ~y: Eng~eerin~: :,. rev: 01/30/89 6.011 For 29. 30. 31. 32. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of Seabed conditions presented Additional requirements ............................................. Additional Remarks: ~-~ ,'W~v~ ~m ~/'~,'~ I~~ ~- ~'~ Well HiStory File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically organize this category of information. oo9, * ALASKA COMPUTING CENTER * * . *WESTERN ATLAS LOG PROCESSED* * ........... BY ............ * * ....... SCHLUMBERGER ....... * * ............................ , ****************************** COMPANY NAME : BP EXPLORATION (ALASKA), INC. WELL NAME : 1-21/K-25 FIELD NAME : ENDICOTT (MPI) BOROUGH : NORTH SLOPE STATE · ALASKA API NUMBER : 500292200500 REFERENCE NO : 98298 MICROFILMED LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE · 98/06/25 ORIGIN : FLIC REEL NAME · 98298 CONTINUATION # : PREVIOUS REEL : CO;4~ENT : BP EXPLORATION, 1-21/K-25, ENDICOTT, API# 50-029-22005-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE · 98/06/25 ORIGIN : FLIC TAPE NAME : 98298 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : BP EXPLORATION, 1-21/K-25, ENDICOTT, API# 50-029-22005-00 TAPE HEADER ENDICOTT (MPI) CASED HOLE WIRELINE LOGS WELL NAME: 1-21/K-25 API NUMBER: 500292200500 OPERATOR: BP EXPLORATION (ALASKA) , INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 25-JUN- 98 JOB NUMBER: 98298 LOGGING ENGINEER: E MURPHY OPERATOR WITNESS: D BARBA SURFACE LOCATION SECTION: 36 TOWNSHIP: 12N RANGE: 16E FNL: 1958 FSL : FEL : FWL : 3835 ELEVATION (FT FROM MSL O) KELLY BUSHING: 55.10 DERRICK FLOOR: 54.10 GROUND LEVEL: 14.50 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 13 . 375 2509.0 9. 625 13488.0 7. 000 14000.0 3. 500 13254.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH 88888.0 13838.5 13836.5 13833.0 13829.5 13826.0 13821.0 13819.5 13817.5 13816.5 13810.0 13804.0 13796.0 13794.5 13790.5 13783.5 13774.5 13770.0 13768.5 13766.0 13751.5 13746.0 13740.5 13736.5 13728.5 13727.5 13721.5 13717.0 13709.5 13708.0 13703.0 13701.0 13699.0 13698.5 13695.5 13692.5 13692.0 13690.0 13688.0 13683.5 13683.0 13681.0 13679.5 13677.0 13676.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88888.0 88888.0 13838.5 13836.5 13833.0 13828.5 13826.5 13820.5 13819.5 13815.5 13816.5 13810.0 13809.5 13803.0 13796.5 13794.0 13791.0 13786.5 13776.0 13769.5 13769.5 13766.5 13766.5 13753.5 13747.5 13741.5 13736.5 13729.5 13729.5 13723.0 13717.5 13711.0 13709.0 13704.5 13704.5 13701.0 13699.5 13699.5 13696.0 13692.5 13692.5 13691.0 13691.0 13688.0 13687.0 13684.5 13684.5 13681.0 13681.0 13680.0 13676.5 13676.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 13675.5 13672 5 13668 0 13665 0 13664 5 13659 5 13658 5 13654 0 13646 0 13645 0 13643.5 13639.5 13637.5 13632.0 13 629.5 13629.0 13626.0 13621.5 13616.5 13615.5 13610.5 13600.0 13595.5 13594.5 13589.5 13584.0 13581.5 13572.5 13570.5 13565.5 13563.0 13557.0 13554.0 13550.5 13548.5 13540.0 13538.5 13535.5 13533.5 13531.5 13530.0 13529.5 13527.5 13524.5 13524.0 13519.5 13516.0 13515.0 13513.5 13513.0 13510.5 13510.0 13507.5 13505.0 13503.0 13501.5 13673.0 13665.5 13660.0 13654.0 13647.5 13645.5 13641.0 13633.5 13630.5 13627.5 13623.0 13617.5 13611.5 13596.0 13592.0 13586.0 13564.5 13557.0 13554.5 13549.0 13539.5 13534.0 13532.5 13531.5 13525.5 13520.5 13516.0 13514.0 13511.5 13508.0 13505.5 13503.0 13675.0 13668.5 13665.5 13660.0 13645.0 13636.5 13630.5 13627.5 13623.0 13617.5 13611.0 13602.5 13596.0 13590.0 13583.0 13573.0 13571.0 13564.5 13552.0 13549.0 13539.5 13536.5 13534.5 13531.0 13529.0 13525.5 13520.0 13516.0 13514.0 13511.0 13505.5 13503.5 25-JUN-1998 13:40 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 13499 0 13496 0 13493 5 13490 0 13489 5 13487 0 13486.5 13484.5 13482.0 100.0 $ REMARKS: 13500.5 13494.5 13491.0 13488.0 13485.0 13483.0 101.0 13500.5 13496.0 13494.5 13490.0 13488.0 13485.0 100.5 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE TDTP DATA AQUIRED ON BP'S 1-21/K-25 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #1 AND THE BASE GAM~A RAY, ALSO PASS #1 SIGMA AND THE BASE GAI~IA RAY, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. THIS IS A WESTERN ATLAS LOG PROCESSED BY SCHLUMBERGER. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 98/06/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 13833.0 13421.0 TDTP 13843.0 13420.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 PAGE: REMARKS: THIS FILE CONTAINS CASED HOLE TDTP PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELt~ CODE (HEX) DEPT FT 189714 O0 000 O0 0 1 1 1 4 68 0000000000 SGMA PDK CU 189714 O0 000 O0 0 1 1 1 4 68 0000000000 RATO PDK 189714 O0 000 O0 0 1 1 1 4 68 0000000000 MSD PDK CU 189714 O0 000 O0 0 1 1 1 4 68 0000000000 BKS PDK CPS 189714 O0 000 O0 0 1 1 1 4 68 0000000000 BKL PDK CPS 189714 O0 000 O0 0 1 1 1 4 68 0000000000 SS PDK CPS 189714 O0 000 O0 0 1 1 1 4 68 0000000000 LS PDK CPS 189714 O0 000 O0 0 1 1 1 4 68 0000000000 RICS PDK DIM 189714 O0 000 O0 0 1 1 1 4 68 0000000000 RIN PDK DIM 189714 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH PDK GAPI 189714 O0 000 O0 0 1 1 1 4 68 0000000000 TENS PDK LB 189714 O0 000 O0 0 1 1 1 4 68 0000000000 CCL PDK V 189714 O0 000 O0 0 1 I 1 4 68 0000000000 RBOR PDK 189714 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 PAGE: ** DATA ** DEPT. 13843.000 SGMA.PDK 25.346 RATO.PDK 19.297 BKS.PDK 360.033 BKL.PDK 118.105 SS.PDK 30804.422 RICS.PDK 15.338 RIN. PDK 11.287 GRCH. PDK -999.250 CCL.PDK 0.000 RBOR.PDK 1.629 DEPT. 13420.500 SGMA.PDK 46.811 RATO.PDK 36.060 BKS.PDK 243.213 BKL.PDK 147.324 SS.PDK 16279.383 RICS.PDK 20.847 RIN. PDK 13.151 GRCH. PDK -999.250 CCL.PDK 0.000 RBOR.PDK 1.809 MSD.PDK LS.PDK TENS.PDK MSD. PDK LS. PDK TENS. PDK 0.337 1567.364 244.500 O. 469 460.517 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 98/06/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 13814.7 13433.7 TDTP 13812.7 13431 . 2 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 PAGE: LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888 0 13810 5 13809 0 13807 0 13803 5 13800 0 13796 0 13795 0 13793 0 13790 5 13783 5 13775 0 13769.5 13766.0 13760.0 13757.5 13756.5 13752.0 13748.0 13747.0 13745.0 13739.5 13735.0 13734.5 13731.5 13730.0 13728.0 13726.5 13725.0 13724.0 13719.0 13716.5 13711.5 13710.0 13709.5 13708.0 13703.5 13700.0 13699.0 13698.5 13695.5 13695.0 13692.5 13690.5 13690.0 13688.5 13687.5 13684.0 13683.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88889.0 88887.0 13810.0 13800.5 13796.5 13795.0 13786.5 13776.0 13767.0 13758.0 13747.5 13736.0 13732.5 13729.5 13726.0 13717.5 13712.5 13711.0 13704.0 13699.5 13696.0 13693.0 13691.0 13688.5 13684.5 13809.5 13806.5 13803.5 13793.5 13791.0 13769.0 13766.5 13761.0 13760.0 13752.5 13748.5 13745.0 13741.0 13735.0 13732.0 13727.5 13725.5 13720.5 13711.0 13709.0 13700.5 13699.5 13696.0 13692.5 13691.0 13687.5 13684.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 PAGE: 13681.5 13679 5 13672 0 13669 5 13669 0 13668 0 13658 5 13656 5 13655 0 13653.5 13644.0 13643.5 13640.0 13639.5 13635.5 13631.5 13629.5 13626.5 13622.5 13621.0 13620.0 13617.5 13615.5 13610.0 13609.0 13607.0 13605.0 13601.0 13594.0 13593.0 13592.0 13589.0 13581.5 13580.0 13578.5 13575.0 13570.0 13564.5 13563.0 13556.5 13555.0 13548.5 13547.5 13542.0 13539.5 13537.5 13536.0 13533.0 13531.5 13530.5 13529.5 13525.0 13524.5 13520.5 13518.5 13679.5 13672.0 13669.0 13666.5 13654.5 13645.0 1364.1 . 0 13634.0 13627.5 13623.0 13617.5 13611.5 13602.5 13596.0 13585.5 13583.0 13565.0 13555.0 13549.0 13542.5 13538.5 13532.5 13531.5 13526.0 13520.5 13681.5 13669.0 13660.5 13656.5 13653.5 13645.0 13641.5 13636.5 13630.5 13627.5 13623.5 13621.0 13618.0 13611.0 13607.5 13602.5 13595.0 13592.5 13590.0 13580.0 13576.0 13571.0 13564.0 13557.0 13549.0 13540.0 13536.5 13534.5 13531.5 13525.5 13520.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-i998 13:40 PAGE: 13515.5 13515.5 13515.0 13516.5 13510.0 13511.0 13510.5 13507.5 13508.0 13503.5 13504.0 13503.0 13504.0 13499.5 13500.5 13495.5 13497.0 13496.0 13493°5 13494.0 13493.0 13494.5 13489.0 13490.5 13488.5 13490.5 13486.0 13487.5 13484.5 13485.0 13482.5 13483.0 13481.0 13482.5 13476.5 13477.5 13475.5 13475.5 13475.5 13472.5 13472.5 13472.0 13473.0 13469.5 13471.0 13469.0 13470.5 13467.5 13467.0 13462.5 13465.5 13459.0 13462.0 13458.0 13458.5 13456.0 13457.0 13452.0 13452.5 13450.5 13450.5 13445.5 13444.5 13443.0 13444.0 13439.5 13442.0 13436.5 13438.0 100.0 101.5 99.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1, ALSO SIGMA PASS #2 AND SIGMA PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 PAGE: 10 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 189714 O0 000 O0 0 2 1 1 4 68 0000000000 SGMA PDK CU 189714 O0 000 O0 0 2 1 1 4 68 0000000000 RATO PDK 189714 O0 000 O0 0 2 1 1 4 68 0000000000 MSD PDK CU 189714 O0 000 O0 0 2 1 1 4 68 0000000000 BKS PDK CPS 189714 O0 000 O0 0 2 1 1 4 68 0000000000 BKL PDK CPS 189714 O0 000 O0 0 2 1 1 4 68 0000000000 SS PDK CPS 189714 O0 000 O0 0 2 1 1 4 68 0000000000 LS PDK CPS 189714 O0 000 O0 0 2 1 1 4 68 0000000000 RICS PDK DIM 189714 O0 000 O0 0 2 1 1 4 68 0000000000 RIN PDK DIM 189714 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH PDK GAPI 189714 O0 000 O0 0 2 1 1 4 68 0000000000 TENS PDK LB 189714 O0 000 O0 0 2 1 1 4 68 0000000000 CCL PDK V 189714 O0 000 O0 0 2 1 1 4 68 0000000000 RBOR PDK 189714 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 13814.750 SGMA.PDK -999.250 RATO.PDK -999.250 MSD. PDK BKS.PDK -999.250 BKL.PDK -999.250 SS. PDK -999.250 LS.PDK RICS.PDK -999.250 RIN. PDK -999.250 GRCH. PDK 55.977 TENS. PDK CCL.PDK -999.250 RBOR.PDK -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 PAGE: 11 DEPT. 13431.250 SGMA.PDK 46.816 R~TO.PDK 33.375 BKS.PDK 289.246 BKL.PDK 129.544 SS.PDK 21401.992 RICS.PDK 20.338 RIN. PDK 13.414 GRCH. PDK -999.250 CCL.PDK 0.000 RBOR.PDK 1.815 MSD. PDK LS. PDK TENS. PDK 0.385 631. 964 -999. 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION · 001 CO1 DATE · 98/06/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE · 98/06/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SUMPIARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 13814.2 13439.0 TDTP 13824.2 13437.2 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS AU3MBER: 1 BASELINE DEPTH .............. 88888.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88888.5 88888.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 PAGE: 12 13819.5 13817.0 13811 0 13809 5 13808 5 13801 0 13799 0 13798 0 13797 0 13794 5 13793 0 13790 5 13788 0 13787 0 13780 5 13778.0 13773.5 13769.5 13769.0 13766.0 13765.0 13758.0 13757.0 13745.5 13739.5 13733.0 13717.0 13711.0 13709.0 13703.5 13700.5 13699.5 13698.5 13696.0 13695.0 13691.5 13689.0 13687.0 13683.0 13680.0 13676.5 13676.0 13673.0 13667.5 13663.5 13660.5 13659.5 13653.5 13647.5 13628.5 13626.0 13622.5 13616.0 13615.5 13610.0 13810.0 13800.5 13796.5 13795.0 13790.0 13784.0 13776.0 13769.5 13767.0 13759.0 13737.0 13717.5 13712.5 13704.5 13701.5 13696.5 13693.0 13688.5 13676.5 13669.0 13665.5 13664.0 13654.5 13649.0 13627.5 13623.0 13617.5 13820.0 13815.5 13809.5 13806.0 13800.0 13795.5 13794.0 13791.0 13788.0 13779.0 13769.5 13766.5 13758.0 13745.0 13741.0 13734.0 13711.0 13705.0 13701.0 13699.5 13696.0 13692.5 13691.0 13687.0 13684.5 13680.0 13676.5 13673.0 13660.5 13630.5 13627.5 13617.5 13611.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 PAGE: 13 13600.5 13594.0 13592.5 13589.5 13586.5 13578.5 13575.5 13573.0 13563.0 13552.0 13546.5 13541.5 13538.5 13537.0 13533.5 13531 0 13530 0 13527 0 13525 0 13524 0 13520 0 13516 5 13515 0 13513.5 13512.5 13509.5 13504.5 13498.5 13496.0 13494.0 13491.5 13487.0 13486.0 13485.0 13482.5 13477.0 13474.5 13471.5 13469.5 13469.0 13466.0 13465.0 13459.0 13457.0 13454.0 13453.0 13449.5 13446.0 13440.5 100.0 $ REMARKS: 13603.0 13596.0 13578.0 13564.5 13545.0 13540.0 13534.0 13532.5 13530.0 13525.5 13520.5 13516.5 13514.0 13511.0 13505.5 13492.5 13487.5 13475.5 13470.5 13465.5 13462.0 13458.5 13457.0 13453.0 13443.5 103.0 13592.0 13590.5 13587.5 13580.0 13573.5 13552.5 13548.5 13539.5 13531.5 13525.5 13520.0 13515.5 13514.0 13511.0 13500.0 13496.5 13495.0 13488.0 13485.0 13483.5 13478.0 13473.0 13471.0 13466.5 13455.0 13447.0 101.0 THIS FILE CONTAINS CASED HOLE TDTP PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #3 AND GRCH PASS #1, ALSO SIGMA PASS #3 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 PAGE: 14 AND SIGMA PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. LIS FORMAT DATA * * DATA FORMAT SPECIFICATION RECORD * * ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 189714 O0 000 O0 0 3 1 1 4 68 0000000000 SGMA PDK CU 189714 O0 000 O0 0 3 1 1 4 68 0000000000 RATO PDK 189714 O0 000 O0 0 3 1 1 4 68 0000000000 MSD PDK CU 189714 O0 000 O0 0 3 1 1 4 68 0000000000 BKS PDK CPS 189714 O0 000 O0 0 3 1 1 4 68 0000000000 BKL PDK CPS 189714 O0 000 O0 0 3 1 1 4 68 0000000000 SS PDK CPS 189714 O0 000 O0 0 3 1 1 4 68 0000000000 LS PDK CPS 189714 O0 000 O0 0 3 1 1 4 68 0000000000 RICS PDK DIM 189714 O0 000 O0 0 3 1 1 4 68 0000000000 RIN PDK DIM 189714 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH PDK GAPI 189714 O0 000 O0 0 3 1 1 4 68 0000000000 TENS PDK LB 189714 O0 000 O0 0 3 1 1 4 68 0000000000 CCL PDK V 189714 O0 000 O0 0 3 1 1 4 68 0000000000 RBOR PDK 189714 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 PAGE: 15 ** DATA ** DEPT. 13824.250 SGMA.PDK 28.760 RATO.PDK 24.744 BKS.PDK 329.090 BKL.PDK 132.329 SS.PDK 31554.332 RICS.PDK 14.744 RIN. PDK 11.157 GRCH. PDK -999.250 CCL.PDK -999.250 RBOR.PDK 1.525 DEPT. 13437.250 SGMA.PDK 46.765 RATO.PDK 34.553 BKS.PDK 309.224 BKL.PDK 149.870 SS.PDK 16123.041 RICS.PDK 21.455 RIN. PDK 13.219 GRCH. PDK -999.250 CCL.PDK 560.000 RBOR.PDK 1.807 MSD. PDK LS.PDK TENS.PDK MSD.PDK LS.PDK TENS.PDK 0.250 1268. 413 .308..] 92 0. 425 473.51 (~ - 999.2.50 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION : O01CO1 DATE : 98/06/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 98/06/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, TDTP $ REMARKS: THIS FILE COIFTAINS THE ARITH~ETIC AVERAGE OF PASSES 1,2, &3. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 PAGE: 16 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB IvTJMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUmB SgMP ELEM CODE (HEX) DEPT FT 189714 O0 000 O0 0 4 1 1 4 68 0000000000 SGMA PNAV CU 189714 O0 000 O0 0 4 1 1 4 68 0000000000 RATO PNAV 189714 O0 000 O0 0 4 1 1 4 68 0000000000 MSD PNAV CU 189714 O0 000 O0 0 4 1 1 4 68 0000000000 BKS PDK CPS 189714 O0 000 O0 0 4 1 1 4 68 0000000000 BKL PDK CPS 189714 O0 000 O0 0 4 1 1 4 68 0000000000 SS PNAV CPS 189714 O0 000 O0 0 4 1 1 4 68 0000000000 LS PNAV CPS 189714 O0 000 O0 0 4 1 1 4 68 0000000000 RICS PNAV DIM 189714 O0 000 O0 0 4 1 1 4 68 0000000000 RIN PNAV DIM 189714 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH PDK GAPI 189714 O0 000 O0 0 4 1 1 4 68 0000000000 RBOR PNAV 189714 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 PAGE: 17 DEPT. 13843.000 SGMA.PNAV -999.250 RATO. PNAV -999.250 MSD. PNAV BKS.PDK 360.033 BKL.PDK 118.105 SS.PNAV -999.250 LS.PNAV RICS.PNAV -999.250 RIN. PNAV -999.250 GRCH. PDK -999.250 RBOR.PNAV DEPT. 13420.500 SGMA.PNAV -999.250 RATO.PNAV -999.250 MSD.PNAV BKS.PDK 243.213 BKL.PDK 147.324 SS.PNAV -999.250 LS.PNAV RICS.PNAV -999.250 RIN. PNAV -999.250 GRCH. PDK -999.250 RBOR.PNAV -999.250 -999.250 -999.250 -999.2{30 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION · O01CO1 DATE : 98/06/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NU~IBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SURkr~ARY VENDOR TOOL CODE START DEPTH PDK-IO0 13886~0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : STOP DEPTH .......... 13395.0 18-MAR-98 REL 3.0 1630 18-MAR-98 14000.0 13853.0 13420.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 PAGE: 18 BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY PDK- 1 O0 THERMAL DECAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G) : SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 13843.0 900.0 TOOL NUMBER GR 2725XA PDK-iO0 2725XA 14000.0 PRODUCED/BRINE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 5 FAR COUNT RATE HIGH SCALE (CPS): 15 NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: N/A MEANS NOT APPLICABLE OR NOT AVAILABLE AT TIME OF LOG. LOG SCALED AND PRESENTED AS PER CUSTOMER REQUEST. THIS FILE CONTAINS THE RAW DATA FOR PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 PAGE: 19 ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 255 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 189714 O0 000 O0 0 5 1 1 4 68 0000000000 BKL PS1 CPS 189714 O0 000 O0 0 5 1 1 4 68 0000000000 BKS PS1 CPS 189714 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PSi V 189714 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 189714 O0 000 O0 0 5 1 1 4 68 0000000000 ISS PS1 189714 O0 000 O0 0 5 1 1 4 68 0000000000 LS PS1 CPS 189714 O0 000 O0 0 5 1 1 4 68 0000000000 MSD PS1 CU 189714 O0 000 O0 0 5 1 1 4 68 0000000000 R~TO PS1 189714 O0 000 O0 0 5 1 1 4 68 0000000000 RBOR PS1 189714 O0 000 O0 0 5 1 1 4 68 0000000000 RICS PS1 CPS 189714 O0 000 O0 0 5 1 1 4 68 0000000000 RIN PSI CPS 189714 O0 000 O0 0 5 1 1 4 68 0000000000 SGMA PS1 CU 189714 O0 000 O0 0 5 1 1 4 68 0000000000 SPD PS1 F/HR 189714 O0 000 O0 0 5 1 1 4 68 0000000000 SS PS1 CPS 189714 O0 000 O0 0 5 1 1 4 68 0000000000 TEN PS1 LB 189714 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 13395.000 BKL.PS1 -999.250 BKS.PS1 -999.250 CCL.PS1 GR.PS1 -999.250 ISS. PS1 -999.250 LS.PS1 -999.250 MSD.PS1 RATO.PS1 -999.250 RBOR.PS1 -999.250 RICS.PS1 -999.250 RIN. PS1 SGMA.PS1 -999.250 SPD.PS1 -999.250 SS.PSI -999.250 TEN. PSi 0.000 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 PAGE: 2O DEPT. 13886.000 BKL.PS1 -999.250 BKS.PS1 -999.250 CCL.PS1 GR.PS1 -999.250 ISS.PS1 -999.250 LS.PS1 -999.250 MSD.PS1 RATO.PS1 -999.250 RBOR.PS1 -999.250 RICS.PS1 -999.250 RIN. PS1 SGMA.PS1 -999.250 SPD.PS1 -999.250 SS.PSi -999.250 TEN. PS1 -999.250 -999.250 -999.250 999.2~0 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION · O01CO1 DATE · 98/06/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 98/06/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH PDK-iO0 13851.75 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : STOP DEPTH 13407.75 18-MAR-98 REL 3.0 1630 18-MAR-98 14000.0 13853.0 13420.0 13843.0 900.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 PAGE: 21 DEPTH CONTROL USED (YES/NO) : TOOL STRING (TOP TO BOTTOM) VE~FDOR TOOL CODE TOOL TYPE GR GAdVk4A RAY PDK- 1 O0 THERMAL DECAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : TOOL NUMBER GR 2725XA PDK-iO0 2725XA 14000.0 PRODUCED/BRINE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 5 FAR COUNT RATE HIGH SCALE (CPS): 15 NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: N/A MEANS NOT APPLICABLE OR NOT AVAILABLE AT TIME OF LOG. LOG SCALED AND PRESENTED AS PER CUSTOMER REQUEST. THIS FILE CONTAINS THE RAW DATA FOR PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 PAGE: 22 ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 255 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 189714 O0 000 O0 0 6 1 1 4 68 0000000000 BKL PS2 CPS 189714 O0 000 O0 0 6 1 1 4 68 0000000000 BKS PS2 CPS 189714 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 189714 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 189714 O0 000 O0 0 6 1 1 4 68 0000000000 ISS PS2 189714 O0 000 O0 0 6 1 1 4 68 0000000000 LS PS2 CPS 189714 O0 000 O0 0 6 1 1 4 68 0000000000 MSD PS2 CU 189714 O0 000 O0 0 6 1 1 4 68 0000000000 RATO PS2 189714 O0 000 O0 0 6 1 1 4 68 0000000000 RBOR PS2 189714 O0 000 O0 0 6 1 1 4 68 0000000000 RICS PS2 CPS 189714 O0 000 O0 0 6 1 1 4 68 0000000000 RIN PS2 CPS 189714 O0 000 O0 0 6 1 1 4 68 0000000000 SGMA PS2 CU 189714 O0 000 O0 0 6 1 1 4 68 0000000000 SPD PS2 F/HR 189714 O0 000 O0 0 6 1 1 4 68 0000000000 SS PS2 CPS 189714 O0 000 O0 0 6 1 1 4 68 0000000000 TEN PS2 LB 189714 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 13407.750 BKL.PS2 -999.250 BKS.PS2 -999.250 CCL.PS2 GR.PS2 -999.250 ISS.PS2 -999.250 LS.PS2 -999.250 MSD.PS2 RATO. PS2 -999.250 RBOR.PS2 -999.250 RICS. PS2 -999.250 RIN. PS2 SGMA.PS2 -999.250 SPD.PS2 -999.250 SS. PS2 -999.250 TEN. PS2 0.000 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 PAGE: 23 DEPT. 13851.750 BKL.PS2 -999.250 BKS. PS2 -999.250 CCL.PS2 GR.PS2 -999.250 ISS.PS2 -999.250 LS.PS2 -999.250 MSD.PS2 RATO.PS2 -999.250 RBOR.PS2 -999.250 RICS.PS2 -999.250 RIN. PS2 SGMA.PS2 -999.250 SPD.PS2 -999.250 SS.PS2 -999.250 TEN. PS2 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION : O01CO1 DATE : 98/06/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT ~007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE S~Y VENDOR TOOL CODE START DEPTH PDK-iO0 13851.25 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 13412.25 18-MAR-98 REL 3.0 1630 18-MAR-98 14000.0 13853.0 13420.0 13843.0 900.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 PAGE: 24 DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY PDK- 1 O0 THERMAL DECAY $ TOOL NUMBER GR 2725XA PDK-iO0 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 14000.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED/BRINE NEUTRON TOOL TOOL TYPE (EPITHER~VlAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): 15 NEAR COUNT RATE LOW SCALE (CPS) NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: N/A MEANS NOT APPLICABLE OR NOT AVAILABLE AT TIME OF LOG. LOG SCALED AND PRESENTED AS PER CUSTOMER REQUEST. THIS FILE CONTAINS THE RAW DATA FOR PASS #3. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 PAGE: 25 ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 255 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** N.~VJE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 189714 O0 000 O0 0 7 1 1 4 68 0000000000 BKL PS1 CPS 189714 O0 000 O0 0 7 1 1 4 68 0000000000 BKS PS1 CPS 189714 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PSi V 189714 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS1 GAPI 189714 O0 000 O0 0 7 1 1 4 68 0000000000 ISS PS1 189714 O0 000 O0 0 7 1 1 4 68 0000000000 LS PS1 CPS 189714 O0 000 O0 0 7 1 1 4 68 0000000000 MSD PSi CU 189714 O0 000 O0 0 7 1 1 4 68 0000000000 RATO PSI 189714 O0 000 O0 0 7 1 1 4 68 0000000000 RBOR PS1 189714 O0 000 O0 0 7 1 1 4 68 0000000000 RICS PS1 CPS 189714 O0 000 O0 0 7 1 1 4 68 0000000000 RIN PS1 CPS 189714 O0 000 O0 0 7 1 1 4 68 0000000000 SGMA PSI CU 189714 O0 000 O0 0 7 1 1 4 68 0000000000 SPD PS1 F/HR 189714 O0 000 O0 0 7 1 1 4 68 0000000000 SS PS1 CPS 189714 O0 000 O0 0 7 1 1 4 68 0000000000 TEN PS1 LB 189714 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 13412.250 BKL.PS1 -999.250 BKS.PS1 -999.25b CCL.PS1 GR.PS1 -999.250 ISS.PS1 -999.250 LS. PS1 -999.250 MSD.PS1 RATO. PS1 -999.250 RBOR.PS1 -999.250 RICS. PS1 -999.250 RIN. PS1 SGMA.PS1 -999.250 SPD.PS1 -999.250 SS.PSi -999.250 TEN. PSi 0.000 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUN-1998 13:40 PAGE: 26 DEPT. 13851.250 BKL.PS1 -999.250 BKS.PS1 -999.250 CCL.PS1 GR.PS1 -999.250 ISS.PS1 -999.250 LS.PS1 -999.250 MSD.PS1 RATO.PS1 -999.250 RBORoPS1 -999.250 RICS.PS1 -999.250 RIN. PS1 SGMA.PS1 -999.250 SPD.PS1 -999.250 SS.PSi -999.250 TEN. PS1 -999.250 -999.250 -999.250 .999.2~0 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE · FLIC VERSION · O01CO! DATE : 98/06/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/06/25 ORIGIN : FLIC TAPE NAME : 98298 CONTINUATION # : 1 PREVIOUS TAPE : COIff~ENT : BP EXPLORATION, 1-21/K-25, ENDICOTT, API# 50-029-22005-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/06/25 ORIGIN : FLIC REEL NAME : 98298 CONTINUATION # : PREVIOUS REEL : COGENT · BP EXPLORATION, 1-21/K-25, ENDICOTT, API# 50-029-22005-00 rape Subfil~ 2 i~ type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1-21 ! K-25 500292200500 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 06-DEC-93 6096.00 K. BRUNNER G. HOBBS 36 12N 16E 1958 3835 55.10 54.10 14.50 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 13.625 2509.0 68.00 9.625 13488.0 47.00 7.000 14085.0 29.00 3.500 13254.0 9.20 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH 13506.5 13509.0 13509.5 13525.0 13535.0 13540.5 13620.0 13621.5 13622.5 13624.5 13631.0 13632.0 13669.5 31-JAN-90 UNKNOWN DLL GR 2 LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: GRCH 13506.0 13508.5 13509.5 13525.0 13534.5 13540.0 13620.0 13621.5 13622.0 13624.0 13630.0 13631.0 13670.0 13687.5 13695.0 13701.5 13710.0 13713.0 13763.5 13779.0 13783.0 13784.0 13785.0 13801.0 13801.5 13805.0 13819.5 13826.0 13827.0 13831.0 13832.0 13834.0 13834.5 13842.0 13842.5 13891.0 13895.5 13907.5 13911.5 13912.0 13919.0 13926.0 13928.5 13929.0 $ REMARKS: 13688.0 13695.0 13701.5 13709.5 13712.5 13764.0 13779.5 13784.5 13785.5 13786.0 13802.0 13803.0 13806.5 13820.5 13827.0 13827.5 13831.5 13832.0 13834.0 13835.0 13843.0 13843.5 13893.5 13898.0 13909.0 13913.0 13914.0 13921.0 13929.0 13931.5 13932.0 PDK-100/GR Log. LOG TIED INTO CBT RUN 05-FEB-1990. LOGGING PROGRAM ORGANIZATION: 1. LOGGED 3 FLOWING PASSES. A DIFFUSION CORRECTED SGMA CURVE IS INCLUDED FOR EACH PASS. THE CURVE IS NAMED SGNT AND WAS CORRECTED WITH THE FOLLOWING PARAMETERS: BOREHOLE SIZE = 8" CASING SIZE = 7" SALINITY = 0 PPM OPEN HOLE GAMMA RAY FOR DEPTH MATCHING DOWNLOADED FROM BP EXPLORATION UPS/CSS ON 04-DEC-93. SHIFT PROCEDURE AS FOLLOWS: 1. FIRST PASS GAMMA RAY DEPTH MATCHED TO PREVIOUS OPEN HOLE GAMMA RAY. 2. FIRST PASS SGMA DEPTH MATCHED TO "SHIFTED" FIRST GAMMA RAY. 3. ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4. ALL SUBSEQUENT SGMA (PDK) PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS SGMA. PRODUCTION RATES WHILE LOGGING: OIL = 1.18 MBPOD WC = 1.1% GFR = 1272 FWHP = 350 PSI @ 89 DEGF CHOKE = 80 BEANS GAS LIFT PRESSURE = 1383 PSI / ? ?MATCH1A. OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 13436.0 13448.0 BASELINE DEPTH SGMA 13430.0 13430.0 13470.5 13470.5 13473.5 13473.0 13483.0 13483.0 13506.5 13506.0 13514.0 13514.0 13520.0 13520.0 13525.0 13525.0 13535.0 13534.5 13540.5 13540.0 13624.5 13624.0 13627.5 13627.0 13669.5 13670.0 13679.0 13680.0 13684.5 13684.0 13687.5 13688.0 13690.5 13690.0 13695.5 13696.0 13701.5 13701.5 13710.0 13709.5 13713.0 13712.5 13763.5 13764.0 13769.5 13770.5 13779.0 13779.5 13794.5 13795.5 13801.0 13802.0 13801.5 13803.0 13806.5 13808.5 13819.5 13821.5 13835.0 13835.5 13837.5 13839.0 13842.0 13843.0 13842.5 13843.5 13849.0 13850.5 13860.5 13861.5 13862.5 13864.0 13870.0 13871.5 13879.5 13881.5 13885.5 13887.5 STOP DEPTH 13938.0 13950.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH in separate files. 13888.0 13891.0 13895.5 13907.5 13911.5 13912.0 13916.5 13919.0 13932.0 13936.0 13939.0 13943.5 13947.0 13955.0 $ REMARKS: 13890.0 13893.5 13898.0 13909.0 13913.0 13914.0 13918.5 13921.0 13934.0 13939.0 13941.5 13946.0 13948.5 13955.0 FLOWING PASS 1. ALL PDK CURVES WERE SHIFTED WITH SGMA. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. / ? ?MATCH1B . OUT $ CN : BP EXPLORATION WN : 1-21 / K-25 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod GRCH PDK 68 1 GAPI 4 BIF PDK 68 1 4 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 4 CSLS PDK 68 1 CU 4 LS PDK 68 1 CPS 4 MSD PDK 68 1 CU 4 RATO PDK 68 1 4 RBOR PDK 68 1 4 RICS PDK 68 1 4 RIN PDK 68 1 4 SGMA PDK 68 1 CU 4 SGMB PDK 68 1 CU 4 SS PDK 68 1 CPS 4 SGNT PDK 68 1 CU 4 PHI PDK 68 1 PU-S 4 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 64 * DATA RECORD (TYPE# 0) Total Data Records: 76 958 BYTES * Tape File Start Depth = 13955.000000 Tape File End Depth = 13430.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 17868 datums Tape Subfile: 2 297 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 13436.0 13448.0 BASELINE DEPTH GRCH 13438.5 13438.5 13439.5 13439.5 13442.0 13445.0 13446.5 13447.5 13449.0 13451.5 13455.5 13459.0 13458.0 13461.5 13459.0 13462.0 13460.0 13462.5 13460.5 13461.0 13463.5 13464.0 13465.0 13468.0 13468.5 13469.0 13479.0 13479.5 13480.5 13481.0 13481.5 13482.5 13482.5 13484.0 13484.5 13490.0 13491.5 13506.5 13507.5 13508,5 13509.5 13509.5 13510.0 13521.0 13521.5 13521.5 13522.5 13524.5 13525.5 13526.5 13537.0 13538.0 13539.5 13540.0 STOP DEPTH 13938.0 13950.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 13442.0 13451.5 13462.0 13465.5 13466.0 13469.0 13469.5 13481.0 13482.0 13482.5 13483.0 13484.5 13485.5 13491.0 13492.0 13507.0 13508.5 13525.5 13526.0 13537.5 13538.0 13539.5 13540.5 13541.0 13551.0 13553.5 13554.5 13563.0 13564.0 13564.5 13566.5 13567.0 13575.5 13576.5 13578.0 13605.5 13606.0 13612.5 13614.5 13620.0 13620.5 13622.0 13623.0 13627.0 13630.5 13631.5 13632.0 13632.5 13633.0 13660.0 13664.5 13666.0 13671.5 13672.0 13672.5 13673.5 13674.0 13677.0 13677.5 13678.0 13680.5 13684.5 13686.5 13698.0 13698.5 13699.5 13700.0 13701.5 13740.0 13741.0 13749.0 13750.0 13761.0 13761.5 13762.5 13763.0 13764.0 13770.0 13771.0 13774.0 13775.0 13777.0 13777.5 13622.0 13627.0 13631.0 13632.0 13633.0 13633.5 13674.0 13675.0 13681.5 13687.0 13698.5 13699.5 13702.5 13764.0 13764.5 13765.0 13771.0 13771.5 13541.5 13551.0 13553.5 13554.0 13563.0 13564.0 13565.0 13567.0 13568.0 13576.5 13577.0 13578.5 13605.5 13606.5 13613.0 13614.5 13620.0 13621.0 13622.5 13623.0 13632.5 13633.5 13661.0 13665.5 13667.5 13673.0 13674.0 13674.5 13675.0 13678.5 13679.5 13680.0 13685.0 13700.0 13701.0 13741.0 13741.5 13749.5 13750.0 13763.0 13763.5 13764.0 13775.5 13776.0 13776.5 13777.5 13778.5 13781.0 13782.5 13783.5 13784.0 13785.5 13786.0 13792.5 13793.0 13793.5 13798.0 13800.5 13822.5 13826.5 13828.5 13829.5 13830.0 13830.5 13831.0 13831.5 13832.0 13833.0 13833.5 13839.0 13840.0 13841.0 13841.5 13846.0 13849.0 13868.0 13869.5 13874.5 13875.0 13883.0 13888.0 13889.0 13894.5 13895.0 13900.5 13901.5 13902.5 13906.0 13907.0 13908.0 13912.0 13912.5 13913.5 13914.5 13915.0 13915.5 13926.5 13927.0 13931.0 13931.5 13938.0 13943.0 13945.0 13945.5 $ 13779.0 13785.0 13824.0 13829.5 13830.0 13830.5 13831.0 13831.5 13832.5 13833.5 13834.5 13842.0 13843.0 13869.5 13871.5 13891.5 13897.5 13908.0 13909.0 13909.5 13913.5 13914.5 13915.5 13916.0 13916.5 13917.5 13928.5 13929.0 13778.5 13781.5 13783.0 13785.0 13786.5 13787.5 13794.0 13794.5 13795.0 13799.5 13802.5 13828.5 13831.0 13831.5 13832.0 13833.0 13834.5 13841.0 13842.0 13842.5 13847.0 13851.0 13876.0 13877.0 13885.0 13890.5 13897.0 13898.0 13903.5 13904.0 13904.5 13933.0 13934.0 13940.5 13944.5 13946.5 13947.0 REMARKS FLOWING PASS 2. ALL PDK CURVES WERE SHIFTED WITH SGMA. / ? ?MATCH2A. OUT / ? ?MATCH2B. OUT $ CN : BP EXPLORATION WN : 1-21 / K-25 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units 1 GRCH PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 MSD PDK 68 1 CU 8 RATO PDK 68 1 9 RBOR PDK 68 1 10 RICS PDK 68 1 11 RIN PDK 68 1 12 SGMA PDK 68 1 CU 13 SGMB PDK 68 1 CU 14 SS PDK 68 1 CPS 15 SGNT PDK 68 1 CU 16 PHI PDK 68 1 PU-S API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 64 * DATA RECORD (TYPE# O) Total Data Records: 76 958 BYTES * Tape File Start Depth = 13955.000000 Tape File End Depth = 13430.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 17868 datums Tape Subfile: 3 Minimum record length: Maximum record length: 265 records... 62 bytes 958 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 13436.0 13448.0 BASELINE DEPTH 13438.5 13439.5 13442.0 13443.0 13448.0 13451.5 13457.5 13458.0 13460.5 13462.5 13464.0 13465.0 13474.0 13475.0 13505.5 13509.5 13510.0 13510.5 13520.5 13521.0 13522.5 13523.5 13525.5 13526.0 13526.5 13551.5 13552.5 13563.5 13564.0 13578.0 13583.5 13591.0 13596.0 13599.5 13604.0 13622.0 13622.5 GRCH 13437.5 13438.5 13444.0 13449.0 13475.0 13505.5 13509.0 13510.0 13520.5 13521.5 13523.0 13523.5 13526.0 13620.5 13621.0 STOP DEPTH 13938.0 13950.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH -- SGMA 13441.0 13450.5 13458.5 13459.5 13462.0 13463.5 13465.0 13465.5 13474.5 13475.0 13510.0 13511.0 13526.0 13526.5 13551.5 13552.0 13563.0 13564.0 13578.0 13583.0 13590.5 13596.0 13599.5 13603.5 13623.0 13624.5 13651.0 13651.5 13654.5 13660.5 13669.5 13670.0 13670.5 13673.0 13674.5 13675.0 13678.5 13679.5 13681.0 13684.0 13684.5 13685.5 13686.0 13688.0 13688.5 13701.0 13701.5 13702.0 13702.5 13710.0 13711.0 13711.5 13729.5 13730.0 13739.0 13745.5 13761.5 13762.0 13763.0 13763.5 13764.0 13764.5 13765.5 13767.0 13767.5 13768.0 13776.5 13778.5 13783.5 13784.0 13785.0 13796.5 13797.0 13801.0 13801.5 13805.0 13810.5 13813.5 13826.0 13828.0 13829.0 13829.5 13830.0 13831.0 13622.0 13623.5 13670.5 13671.0 13673.0 13674.5 13675.5 13680.0 13682.0 13684.0 13686.0 13701.5 13702.0 13710.0 13763.0 13778.5 13784.5 13805.5 13811.5 13827.0 13828.5 13829.5 13830.0 13830.5 13650.5 13651.5 13654.5 13661.0 13670.0 13671.0 13679.5 13684.5 13685.0 13687.5 13688.5 13701.0 13702.0 13702.5 13709.0 13710.5 13729.5 13730.0 13738.5 13745.0 13762.5 13763.0 13763.5 13764.0 13765.0 13765.5 13766.0 13767.5 13768.0 13768.5 13777.0 13784.5 13785.0 13785.5 13797.0 13798.0 13802.0 13803.0 13815.0 13830.0 13831.5 13832.0 13832.5 13833.0 13838.5 13841.0 13854.5 13855.0 13856.0 13857.0 13858.0 13861.0 13863.5 13864.5 13867.5 13871.0 13873.5 13881.0 13895.0 13895.5 13898.5 13900.5 13901.5 13902.5 13903.5 13906.0 13906.5 13907.0 13908.5 13909.5 13910.0 13910.5 13917.5 13918.0 13918.5 13919.5 13922.0 13922.5 13924.0 13924.5 13925.5 13926.0 13927.0 13927.5 13928.0 13935.5 13936.0 13938.0 13941.5 13943.0 13945.0 13945.5 $ REMARKS: 13831.0 13832.0 13832.5 13833.5 13841.5 13855.5 13858.0 13858.5 13865.5 13868.5 13882.5 13897.0 13906.5 13907.0 13908.0 13909.5 13910.0 13910.5 13911.5 13920.5 13925.5 13927.5 13928.0 13936.5 13937.0 13833.0 13839.5 13856.0 13856.5 13861.5 13864.5 13872.0 13875.0 13896.5 13901.5 13903.5 13904.0 13904.5 13905.0 13907.0 13910.5 13911.5 13918.5 13919.5 13920.0 13920.5 13923.0 13924.0 13926.0 13926.5 13928.5 13929.5 13939.5 13942.5 13943.5 13945.5 13946.0 FLOWING PASS 3. ALL PDK CURVES WERE SHIFTED WITH SGMA. / ? ?MATCH3A. OUT /??MATCH3B. OUT CN : BP EXPLORATION WN : 1-21 / K-25 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPES 64 ) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 MSD PDK 68 1 CU 4 8 RATO PDK 68 1 4 9 RBOR PDK 68 1 4 10 RICS PDK 68 1 4 11 RIN PDK 68 1 4 12 SGMA PDK 68 1 CU 4 13 SGMB PDK 68 1 CU 4 14 SS PDK 68 1 CPS 4 15 SGNT PDK 68 1 CU 4 16 PHI PDK 68 1 PU-S 4 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 64 * DATA RECORD (TYPES 0) 958 BYTES * Total Data Records: 76 Tape File Start Depth = 13955.000000 Tape File End Depth = 13430.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 35736 datums Tape Subfile: 4 259 records... Minimum record length: Maximum record length: 62 bytes 958 bytes £ape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 13435.0 PDK 13447.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR PDK PDK-100 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): STOP DEPTH 13956.0 13968.0 27-NOV-93 FSYS REV. J001 VER. 1.1 1143 27-NOV-93 14000.0 13959.0 13450.0 13950.0 900.0 YES TOOL NUMBER 2725XA 0.000 14085.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY'. HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 1600 FAR COUNT RATE HIGH SCALE (CPS) : 7600 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): 0.0 REMARKS: FLOWING PASS 1. THE NEAR COUNT RATE HIGH SCALE VALUE IS 120,000. $ CN : BP EXPLORATION WN : 1-21 / K-25 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 24 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 $ G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 GElS PDK 68 1 CPS 4 11 ISS PDK 68 1 CPS 4 12 LS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 RATO PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 1 4 19 SGMA PDK 68 1 CU 4 20 SGMB PDK 68 1 CU 4 21 SPD PDK 68 1 F/MN 4 22 SS PDK 68 1 CPS 4 23 SGNT PDK 68 1 CU 4 24 PHI PDK 68 1 PU-S 4 4 06 511 09 4 00 201 24 4 39 705 61 4 74 169 61 4 92 630 79 4 00 201 24 4 00 201 24 4 35 975 96 4 36 631 32 4 74 169 61 4 00 201 24 4 71 162 89 4 32 125 68 4 00 201 24 4 23 260 40 4 23 260 40 4 23 260 40 4 23 260 40 4 96 761 61 4 00 201 24 4 52 386 28 4 05 626 89 4 00 201 24 4 00 201 24 0 1 6 6 6 1 1 1 1 6 1 6 0 1 0 0 0 0 6 1 5 6 1 1 96 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 214 Tape File Start Depth = 13968.000000 Tape File End Depth = 13435.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code-. 68 71194 datums Tape Subfile: 5 Minimum record length: Maximum record length: 290 records... 62 bytes 1006 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 13435.0 PDK 13447.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR PDK PDK-100 $ STOP DEPTH 13957.0 13969.0 27 -NOV-93 FSYS REV. J001 VER. 1.1 1221 27-NOV-93 14000.0 13959.0 13450.0 13950.0 900.0 YES TOOL NUMBER 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 14085.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 1600 FAR COUNT RATE HIGH SCALE (CPS): 7600 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): 0.0 REMARKS: FLOWING PASS 2. THE NEAR COUNT RATE HIGH SCALE VALUE IS 120,000. $ CN : BP EXPLORATION WN : 1-21 / K-25 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 24 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 GElS PDK 68 1 CPS 4 11 ISS PDK 68 1 CPS 4 12 LS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 RATO PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 1 4 19 SGMAPDK 68 1 CU 4 20 SGMB PDK 68 1 CU 4 21 SPD PDK 68 1 F/MN 4 22 SS PDK 68 1 CPS 4 23 SGNT PDK 68 1 CU 4 24 PHI PDK 68 1 PU-S 4 4 06 511 09 4 00 201 24 4 39 705 61 4 74 169 61 4 92 630 79 4 00 201 24 4 00 201 24 4 35 975 96 4 36 631 32 4 74 169 61 4 00 201 24 4 71 162 89 4 32 125 68 4 00 201 24 4 23 260 40 4 23 260 40 4 23 260 40 4 23 260 40 4 96 761 61 4 00 201 24 4 52 386 28 4 05 626 89 4 00 201 24 4 00 201 24 0 1 6 6 6 1 1 1 1 6 1 6 0 1 0 0 0 0 6 1 5 6 1 1 96 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 214 Tape File Start Depth = 13969.000000 Tape File End Depth = 13435.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 89162 datums Tape Subfile: 6 290 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 13434.0 PDK 13446.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 13958.0 13969.0 27-NOV-93 FSYS REV. J001 VER. 1.1 1303 27-NOV-93 14000.0 13959.0 13450.0 13950.0 900.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR PDK PDK- 100 $ TOOL NUMBER 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER' S CASING DEPTH (FT): 0.000 14085.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 1600 FAR COUNT RATE HIGH SCALE (CPS): 7600 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): 0.0 REMARKS: FLOWING PASS 3. THE NEAR COUNT RATE HIGH SCALE VALUE IS 120,000. $ CN : BP EXPLORATION WN : 1-21 / K-25 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 24 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 GElS PDK 68 1 CPS 4 11 ISS PDK 68 1 CPS 4 12 LS PDK 68 1 CPS 4 13 MON PDK 68 ! CPS 4 14 MSD PDK 68 1 CU 4 15 RATO PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 1 4 19 SGMA PDK 68 1 CU 4 20 SGMB PDK 68 ! CU 4 21 SPD PDK 68 1 F/MN 4 22 SS PDK 68 ! CPS 4 23 SGNT PDK 68 1 CU 4 24 PHI PDK 68 1 PU-S 4 4 06 511 09 4 00 201 24 4 39 705 61 4 74 169 61 4 92 630 79 4 00 201 24 4 00 201 24 4 35 975 96 4 36 631 32 4 74 169 61 4 00 201 24 4 71 162 89 4 32 125 68 4 00 201 24 4 23 260 40 4 23 260 40 4 23 260 40 4 23 260 40 4 96 761 61 4 00 201 24 4 52 386 28 4 05 626 89 4 00 201 24 4 00 201 24 96 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 215 Tape File Start Depth ~ 13969.000000 Tape File End Depth = 13434.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 124720 datums Tape Subfile: 7 291 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 8 is type: LIS 93/12/ 6 01 **** REEL TRAILER **** 93/12/ 6 01 Tape Subfile: 8 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 6 DEC 93 4:25p Elapsed execution time = 23.56 seconds. SYSTEM RETURN CODE = 0