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ϭϬͬϭϱͬϮϬϮϮͲ^ĂƚƵƌĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϭϬͬϭϴͬϮϬϮϮͲdƵĞƐĚĂǇ ϭϬͬϭϲͬϮϬϮϮͲ^ƵŶĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϭϬͬϭϳͬϮϬϮϮͲDŽŶĚĂǇ 5HJJ-DPHV%2*& )URP5XVVHOO*DOOHQ&5XVVHOO*DOOHQ#KLOFRUSFRP! 6HQW7XHVGD\2FWREHU$0 7R5HJJ-DPHV%2*&'2$$2*&&3UXGKRH%D\%URRNV3KRHEH/2*& &F$ODVND16$65:HOO6LWH0DQDJHUV 6XEMHFW)%23(WHVWUHSRUW $WWDFKPHQWV)%23(WHVWUHSRUWLQLWLDO[OV[ dŚĂŶŬǇŽƵ͘ Regards, Russell Gallen ASR DSM, Mobile: 907-529-7202 Office: 907-685-1266 russell.gallen@hilcorp.com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ll BOPE reports are due to the agency within 5 days of testing* SSu bm itt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:ASR 1 DATE: 10/10/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #1970580 Sundry #322-538 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:2383 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators PP #1 Rams 1 2 7/8" x 5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 2 1/16"P Time/Pressure Test Result HCR Valves 1 2 1/16"P System Pressure (psi)3000 P Kill Line Valves 2 2 1/16"FP Pressure After Closure (psi)1800 P Check Valve 0NA200 psi Attained (sec)18 P BOP Misc 0NAFull Pressure Attained (sec)57 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4 / 2200 PSI P No. Valves 16 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 26 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:1 Test Time:4.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 10/09/22 02:28 Waived By Test Start Date/Time:10/10/2022 1:30 (date) (time)Witness Test Finish Date/Time:10/10/2022 5:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Lou Laubenstein Hilcorp Tested with 2-7/8 test joint. F/P on Test #3 our manual Kill line valve #2 bled by. We gresed and functioned the valve. Valve tested good after that. Bottle Pre-charge 1000psi C. Pace / J. Werlinger Hilcorp Alaska LLC A. Haberthur/ R. Gallen MPU F-50 Test Pressure (psi): askans-asr-toolpushers@hilcorp.c ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022) 2022-1010_BOP_Hilcorp_ASR1_MPU_F-50 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 -5HJJ FP From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:BOP - Hilcorp ASR1 Date:Friday, November 18, 2022 2:55:45 PM Attachments:2022-1010_BOP_Hilcorp_ASR1_MPU_F-50.pdf MPU F-50 (PTD 1970580) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 7\SHRI5HTXHVW $EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 5HSDLU:HOO 2SHUDWLRQVVKXWGRZQ 6XVSHQG 3HUIRUDWH 2WKHU6WLPXODWH 3XOO7XELQJ &KDQJH$SSURYHG3URJUDP 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 5HHQWHU6XVS:HOO $OWHU&DVLQJ 2WKHU(63&KDQJHRXW 2SHUDWRU1DPH &XUUHQW:HOO&ODVV 3HUPLWWR'ULOO1XPEHU ([SORUDWRU\ 'HYHORSPHQW $GGUHVV6WUDWLJUDSKLF 6HUYLFH $3,1XPEHU ,ISHUIRUDWLQJ:HOO1DPHDQG1XPEHU :KDW5HJXODWLRQRU&RQVHUYDWLRQ2UGHUJRYHUQVZHOOVSDFLQJLQWKLVSRRO" :LOOSODQQHGSHUIRUDWLRQVUHTXLUHDVSDFLQJH[FHSWLRQ" <HV 1R 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ŽŶƚŝŶƵĞƚŽůŽĂĚǁĞůůĚƵƌŝŶŐWKK,ƚŽŵŝŶŝŵŝǌĞĐŚĂŶĐĞƐĨŽƌǁĞů ůƚŽƐǁĂƉďĞĨŽƌĞ ƉĞƌĨŽƌĂƚŝŶŐŝŶĨŽůůŽǁŝŶŐƐƚĞƉƐ͘ ď͘ ŽŶƚĂĐƚKĨŽƌĐĂůŝƉĞƌƌĞƐƵůƚƐŝĨŶŽƚƉƌĞǀŝŽƵƐůǇƉƌŽǀŝĚĞĚ͘ Đ͘ WƵůůŽƵƚĂůůǀŝƐƵĂůůǇďĂĚũŽŝŶƚƐĂŶĚŵĂƌŬĨŽƌĚŝƐƉŽƐĂů͘ Ě͘ >ŽŽŬĨŽƌŽǀĞƌͲƚŽƌƋƵĞĚĐŽŶŶĞĐƚŝŽŶƐĨƌŽŵƉƌĞǀŝŽƵƐƚƵďŝŶŐƌƵŶƐĂ ŶĚũƵŶŬƚŚĞŵ͘ Ğ͘ ůůĐůĂŵƉƐĂŶĚũĞǁĞůƌǇǁŝůůďĞĐůĞĂŶĞĚĂŶĚƉƵƚŝŶƚŽŝŶǀĞŶƚŽƌǇ ĨŽƌƌĞͲƵƐĞ͘ Ĩ͘ ůůĐĂďůĞŝƐƚŽďĞƐĂůǀĂŐĞĚĂŶĚƐĞŶƚƚŽĂŬĞƌĨŽƌŝŶƐƉĞĐƚŝŽŶĂŶĚƚĞƐƚŝŶŐĨŽƌƉŽƐƐŝďůĞ ƌĞͲƵƐĞ͘ &URVVFROODUFODPSV 3URWHFWROL]HU&ODPSV )ODW*XDUG&ODPSV 3XPS&ODPSV 3XPS %DQGV ϭϳ͘ ZhzĞůůŽǁ:ĂĐŬĞƚϳ͟ƐŚŽŽƚŝŶŐĨůĂŶŐĞǁŝƚŚϳ͛͛ƋƵŝĐŬƚĞƐƚƐƵď͘ 5LVNDVVHVVWRDVVXUHQRSUHVVXUHXQGHU&76%39/XEULFDWH RXWYDOYHLISRVVLEOHSUHVVXUHXQGHUYDOYH ^W^ǁĂƉ tĞůů͗DWh&ͲϱϬ ĂƚĞ͗ϬϵͬϬϵͬϮϬϮϮ Ă͘ ŶĐŚŽƌƚŽƚŚĞƚŽƉŽĨƚŚĞKWƐƚĂĐŬ ď͘ /ŶƐƚĂůůϲ͛͛ƚĞƐƚƉůƵŐŽƌŚĂŶŐĞƌǁŝƚŚdt͘ Đ͘ ZŝŐƵƉ>/EW Ě͘ WƌĞƐƐƵƌĞƚĞƐƚƚŽϯϬϬƉƐŝůŽǁĂŶĚϮ͕ϱϬϬƉƐŝŚŝŐŚ Ğ͘ ƌĞĂŬϳ͛͛ƋƵŝĐŬƚĞƐƚƐƵďĐŽŶŶĞĐƚŝŽŶ Ĩ͘ WƵůůϲ͛͛ƚĞƐƚƉůƵŐŽƌŚĂŶŐĞƌǁŝƚŚdt͘ ϭϴ͘ WhϯͲϯͬϴ͕͟ϲ^W&ŽƌϮͲϳͬϴ͕͟ϮͲϯͬϰ͕͟Ϯ͟'ƵŶƐ͘ ϭϵ͘ DhŐƵŶƐƚŽZ/,ǁŝƚŚ>/EĂŶĚŝŶƐƚĂůůƐŚŽŽƚŝŶŐĨůĂŶŐĞĨŽƌƉƌ ĞƐƐƵƌĞĐŽŶƚƌŽůǁŚŝůĞƐŚŽŽƚŝŶŐ͘ ϮϬ͘ sĞƌŝĨǇƚŚĞǁĞůůŝƐƐƚĂƚŝĐ͘>ŽĂĚǁĞůůƚŽƐƵƌĨĂĐĞƉƌŝŽƌƚŽƐŚŽŽƚŝŶŐ Ϯϭ͘ WĞƌĨƚŚĞďĞůŽǁŝŶƚĞƌǀĂůƐ͗ Ă͘ ŽŶƚĂĐƚ'ĞŽůŽŐŝƐƚʹ:ŽŚŶ^ĂůƐďƵƌǇʹϵϬϳͲϯϱϬͲϭϬϴϴ;ĐͿŽƌϵϬϳͲϳϳϳͲϴϰϴϭƚŽĐŽŶĨŝƌŵ ĐŽƌƌĞůĂƚŝŽŶĚĞƉƚŚ͘ ŝ͘ WĞƌĨŽƌĂƚŝŽŶ'ƵŶϭ͗цϭϱ͕Ϯϴϯ͛ʹцϭϱ͕Ϯϵϯ͛Θцϭϱ͕ϯϭϱ͛ʹцϭϱ͕ϯϰϬ͛;ϯϱ͛ŽĨĐŚĂƌŐĞƐͿʹ <ƵƉĂƌƵŬϭΘϭƐĂŶĚƐ ŝŝ͘ WĞƌĨŽƌĂƚŝŽŶ'ƵŶϮ͗цϭϱ͕Ϯϰϰ͛ʹцϭϱ͕ϮϱϮ͛Θцϭϱ͕Ϯϲϯ͛ʹцϭϱ͕Ϯϳϭ͛;ϭϲ͛ŽĨĐŚĂƌŐĞƐͿʹ <ƵƉĂƌƵŬϯΘϮƐĂŶĚƐ ϮϮ͘ &ůŽǁĐŚĞĐŬƚŚĞǁĞůů͘ŽŶĨŝƌŵƚŚĞǁĞůůŝƐĚĞĂĚ͕ƵůůŚĞĂĚƚŽŬŝůůƚŚĞǁĞůůĂƐŶĞĞĚĞĚ͘;EŽƚĞ͗tĞůůǁĂƐ ƉƌĞǀŝŽƵƐůǇĨƌĂĐ͛ĚĂŶĚůŽǁƉƌŽďĂďŝůŝƚǇĨŽƌƉƌĞƐƐƵƌĞĐŚĂŶŐĞͿ Ă͘ ŽŶƚŝŶŐĞŶĐǇͲ/ĨǁĞůůĐĂŶŶŽƚďĞŬŝůůǁŝƚŚ^ZƉƵŵƉƐ͘ZŝŐƵƉĂ ƵǆŝůŝĂƌǇĞƋƵŝƉŵĞŶƚƚŽĂůůŽǁ ǁĞůůƐŬŝůůĂƚϳнWD ď͘ ƵůůŚĞĂĚϭ͘ϱƚƵďŝŶŐǀŽůŽĨϴ͘ϴƉƉŐEĂů Đ͘ ƐƚĂďůŝƐŚĨŝůůƌĂƚĞĂŶĚŵĂŝŶƚĂŝŶŚŽůĞĨŝůů Ϯϯ͘ WKK,ĂŶĚZ>ĂŶĚƐŚŽŽƚŝŶŐĨůĂŶŐĞ͘ Ϯϰ͘ Dh^ƉŽŽůĞƌƚŽƌƵŶ^WĐĂďůĞ͘ Ϯϱ͘ WhŶĞǁ^WĂŶĚZ/,ŽŶϮͲϳͬϴ͟ϲ͘ϱη>ͲϴϬƚƵďŝŶŐ͘ŚĞĐŬĞůĞĐƚƌŝĐĂůĐŽŶŶĞĐƚŝŽŶƐĞǀĞƌǇϮ͕ϬϬϬ͛ Ă͘ ĂƐĞŽĨ^WĂƚцϭϱ͕ϭϯϱ͛D )0&´ ´. . >/EĂ ^W^ǁĂƉ tĞůů͗DWh&ͲϱϬ ĂƚĞ͗ϬϵͬϬϵͬϮϬϮϮ ď͘ ϭũŽŝŶƚƐŽĨϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Đ͘ ϮͲϳͬϴ͟yE;Ϯ͘ϮϬϱ͟EŽͲ'ŽͿEŝƉƉůĞ Ě͘ ϯũŽŝŶƚƐŽĨϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Ğ͘ >ŽǁĞƌϮͲϳͬϴ͟ǆϭ͟^ŝĚĞͲƉŽĐŬĞƚ'>DǁŝƚŚƵŵŵǇ'>s Ĩ͘ DƵůƚŝƉůĞũŽŝŶƚƐϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Ő͘ hƉƉĞƌϮͲϳͬϴ͟ǆϭ͟^ŝĚĞͲƉŽĐŬĞƚ'>DΛцϮϬϬ͛DǁŝƚŚϬ͘Ϯϱ͟Ks Ś͘ цϱũŽŝŶƚƐϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Ϯϲ͘ >ĂŶĚƚƵďŝŶŐŚĂŶŐĞƌĂŶĚůĂǇĚŽǁŶůĂŶĚŝŶŐũŽŝŶƚ͘EŽƚĞWh;WŝĐ ŬhƉͿĂŶĚ^K;^ůĂĐŬKĨĨͿǁĞŝŐŚƚƐŽŶ ƚĂůůǇ͘ Ϯϳ͘ ^ĞƚWs͘ WŽƐƚͲZŝŐWƌŽĐĞĚƵƌĞ;EŽŶͲ^ƵŶĚƌŝĞĚƐƚĞƉƐͿ͗ tĞůů^ƵƉƉŽƌƚ ϭ͘ ZŵƵĚďŽĂƚ͘DŽǀĞƚŽŶĞǆƚǁĞůůůŽĐĂƚŝŽŶ͘ Ϯ͘ ZhĐƌĂŶĞ͘EKW͘^Ğƚd^ƉůƵŐ͘ ϯ͘ EhƚƌĞĞĂŶĚƚƵďŝŶŐŚĞĂĚĂĚĂƉƚĞƌ͘ ϰ͘ dĞƐƚďŽƚŚƚƌĞĞĂŶĚƚƵďŝŶŐŚĂŶŐĞƌǀŽŝĚƚŽϱϬϬƉƐŝůŽǁͬϱ͕ϬϬϬƉƐŝŚŝŐŚ͘ ϱ͘ WƵůůd^ƉůƵŐΘWs͘ ϲ͘ ZĐƌĂŶĞ͘DŽǀĞϱϬϬďďůƌĞƚƵƌŶƐƚĂŶŬĂŶĚƌŝŐŵĂƚƐƚŽŶĞǆƚǁĞůůůŽĐĂƚŝŽŶ͘ ϳ͘ ZĞƉůĂĐĞŐĂƵŐĞ;ƐͿŝĨƌĞŵŽǀĞĚ͘ ϴ͘ dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ͘ZhǁĞůůŚŽƵƐĞĂŶĚĨůŽǁůŝŶĞƐ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ KW^ĐŚĞŵĂƚŝĐ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϵͬϵͬϮϬϮϮ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh&ͲϱϬ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϮͬϭϴͬϮϬϭϳ Wd͗ϭϵϳͲϬϱϴ dсϭϱ͕ϲϴϱ͛;DͿͬdсϳ͕ϱϱϭ͛;dsͿ ϮϬ´ 0DUNHU-W# ¶WR ¶ Z<͗'>сϰϭ͘ϳ͛ͬ'>ůĞǀ͘сϭϮ͘ϰ͛ ϳ͟ ϵͲϱͬϴ͟ $6DQGV Wdс ϭϱ͕ϱϳϴ͛;DͿͬWdсϳ͕ϰϱϱ͛;dsͿ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ ƌŝĨƚ/ dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϭ͘ϭͬ,ͲϰϬͬEͬ Eͬ ^ƵƌĨĂĐĞ ϭϭϮΖ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬƚƌĐ͘ ϴ͘ϲϳϵ ^ƵƌĨĂĐĞ ϵ͕Ϭϵϵ ϳΗ WƌŽĚƵĐƚŝŽŶ Ϯϲͬ>ͲϴϬͬƚĐDŽĚ ϲ͘ϭϱϭ ^ƵƌĨĂĐĞ ϭϱ͕ϲϲϯΖ dh/E'd/> ϮͲϳͬϴΗ dƵďŝŶŐ ϲ͘ϱͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϯϰϳ ^ƵƌĨĂĐĞ ϭϱ͕ϭϯϱ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ ϭϯϳ͛ '>Dηϭ͗ĂŵĐŽϮͲϳͬϴ͟<DD Ϯ ϭϰ͕ϴϳϬ͛ '>DηϮ͗ĂŵĐŽϮͲϳͬϴ͟ǁͬƵŵŵǇsĂůǀĞ<DD ϯ ϭϱ͕Ϭϭϯ͛ ϮͲϳͬϴ͟yEͲEŝƉƉůĞ;Ϯ͘ϮϬϱŶŽͲŐŽ/Ϳ ϰ ϭϱ͕Ϭϱϱ͘ϴ͛ ŝƐĐŚĂƌŐĞ,ĞĂĚ͗&W/^ϮϳͬϴΗhϴƌĚEϲϯϬϮϵ ϱ ϭϱ͕Ϭϱϲ͛ WƵŵƉ͗&>yZ,ϲ^y ϲ ϭϱ͕ϬϴϬ͛ WƵŵƉ͗ &>yZ,ϲ^y ϳ ϭϱ͕ϭϬϯ͛ 'ĂƐ^ĞƉĂƌĂƚŽƌ͗'Z^&ZEZ ϴ ϭϱ͕ϭϬϳ͛ hƉƉĞƌdĂŶĚĞŵ^ĞĂů͗'^ϯhd^ͬ^W&^ ϵ ϭϱ͕ϭϭϰ͛ >ŽǁĞƌdĂŶĚĞŵ^ĞĂů͗ '^ϯhd^ͬ^W&^ ϭϬ ϭϱ͕ϭϮϬ͛ DŽƚŽƌ͗yWͲϭϱϬ,W͕ϮϰϮϬsŽůƚ͕ϯϴĂŵƉ ϭϭ ϭϱ͕ϭϯϯ͛ WŚŽĞŶŝǆydͲϭϱϬdǇƉĞ͞K͟ǁͬϲ&ŝŶĞŶƚƌĂůŝǌĞƌʹƚŵΛϭϱ͕ϭϯϱ͛ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ <ƵƉ͘ϰ^ĂŶĚƐ ϭϱ͕ϮϱϮ͛ ϭϱ͕ϮϲϮ͛ ϳ͕ϭϲϱ͛ ϳ͕ϭϳϰ͛ ϭϬ͛ ϱͬϮϲͬϬϱ KƉĞŶ <ƵƉ͘Ϯ^ĂŶĚƐ ϭϱ͕ϮϳϮ͛ ϭϱ͕ϮϴϮ͛ ϳ͕ϭϴϮ͛ ϳ͕ϭϵϮ͛ ϭϬ͛ ϱͬϮϲͬϬϱ KƉĞŶ <ƵƉ͘ϭ^ĂŶĚƐ ϭϱ͕Ϯϵϰ͛ ϭϱ͕ϯϭϰ͛ ϳ͕Ϯϭϰ͛ ϳ͕ϮϯϮ͛ ϮϬ͛ ϱͬϴͬϵϳ KƉĞŶ KWE,K>ͬDEdd/> ϮϬΗ ŵƚǁͬϮϱϬƐǆŽĨƌĐƚŝĐƐĞƚ/ŝŶϮϰ͟,ŽůĞ ϵͲϱͬϴΗ ŵƚǁͬϭ͕ϭϱϬϬƐǆW&͕͟͞ϳϱϬƐǆůĂƐƐ͞'͟ŝŶϭϮͲϭͬϰ͟,ŽůĞ ϳ͟ ŵƚǁͬϮϯϱƐŬƐůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟,ŽůĞ t>>/E>/Ed/KEd/> <KWΛϲϬϬ͛ DĂǆ,ŽůĞŶŐůĞсϳϬƚŽϳϱĚĞŐ͘Ĩͬϯ͕ϲϬϬ͛ƚŽϭϯ͕ϬϮϭ͛ ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϮϴĚĞŐ͘ t>>^d/Dh>d/KEd/> ϳͬϮϴͬϵϳʹϭϱϵϬϬϬηϭϲͬϮϬĂƌďŽůŝƚĞďĞŚŝŶĚWŝƉĞ dZΘt>>, dƌĞĞ &DϮͲϵͬϭϲ͟ǆϱ tĞůůŚĞĂĚ ϭϭ͟ǆϳͲϭͬϭϲ͟ϱD^ƉŽŽůϳͲϭͬϭϲ͟ǆϮͲϵͬϭϲ͟,ĂŶŐĞƌ͘ϯ͟>, ĂĐŵĞdŽƉΘƚŵ͘ϮͲϵͬϭϲ͟ĐŝǁWs 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϳϱϲͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇEĂďŽƌƐϰͲ^Ͳϲͬϰͬϭϵϵϳ ŽŵƉůĞƚĞĚǁŝƚŚ^WďǇEĂďŽƌƐϰ^ʹϲͬϱͬϭϵϵϳ ^WŽŵƉůĞƚŝŽŶηϮǁͬEĂďŽƌƐϰͲ^ʹϳͬϯϬͬϭϵϵϳ ^WŽŵƉůĞƚŝŽŶηϯǁͬEĂďŽƌƐϰͲ^ʹϰͬϲͬϮϬϬϬ ^WŽŵƉůĞƚŝŽŶηϰǁͬEĂďŽƌƐϰͲ^ʹϳͬϯϬͬϮϬϬϰ WƵůůŽŵƉůĞƚŝŽŶĂŶĚĚĚWĞƌĨŽƌĂƚŝŽŶƐǁͬEĂďŽƌƐϰͲ^ʹϱͬϮϲͬϮϬϬϱ ^WŚĂŶŐĞͲŽƵƚĂŶĚ&KǁͬEĂďŽƌƐϯ^ʹϯͬϮϵͬϮϬϬϴ ^WŚĂŶŐĞͲŽƵƚǁEĂďŽƌƐϰͲ^ʹϳͬϮϭͬϮϬϭϬ ^WŚĂŶŐĞͲŽƵƚǁͬŽǇŽŶϭϲͲϭϭͬϮϴͬϮϬϭϯ ^WŚĂŶŐĞͲŽƵƚǁͬ^ZηϭʹϭϮͬϭϴͬϮϬϭϳ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϵͬϵͬϮϬϮϮ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh&ͲϱϬ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϮͬϭϴͬϮϬϭϳ Wd͗ϭϵϳͲϬϱϴ dсϭϱ͕ϲϴϱ͛;DͿͬdсϳ͕ϱϱϭ͛;dsͿ ϮϬ´ 0DUNHU-W# ¶WR ¶ Z<͗'>сϰϭ͘ϳ͛ͬ'>ůĞǀ͘сϭϮ͘ϰ͛ ϳ͟ ϵͲϱͬϴ͟ $6DQGV Wdс ϭϱ͕ϱϳϴ͛;DͿͬWdсϳ͕ϰϱϱ͛;dsͿ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ ƌŝĨƚ/ dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϭ͘ϭͬ,ͲϰϬͬEͬ Eͬ ^ƵƌĨĂĐĞ ϭϭϮΖ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬƚƌĐ͘ ϴ͘ϲϳϵ ^ƵƌĨĂĐĞ ϵ͕Ϭϵϵ ϳΗ WƌŽĚƵĐƚŝŽŶ Ϯϲͬ>ͲϴϬͬƚĐDŽĚ ϲ͘ϭϱϭ ^ƵƌĨĂĐĞ ϭϱ͕ϲϲϯΖ dh/E'd/> ϮͲϳͬϴΗ dƵďŝŶŐ ϲ͘ϱͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϯϰϳ ^ƵƌĨĂĐĞ цϭϱ͕ϭϯϱ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ цϭϯϳ͛ '>Dηϭ͗ Ϯ цϭϰ͕ϴϳϬ͛ '>DηϮ͗ ϯ цϭϱ͕Ϭϭϯ͛ ϮͲϳͬϴ͟yEͲEŝƉƉůĞ;Ϯ͘ϮϬϱŶŽͲŐŽ/Ϳ ϰ цϭϱ͕Ϭϱϱ͘ϴ͛ ŝƐĐŚĂƌŐĞ,ĞĂĚ͗ ϱ цϭϱ͕Ϭϱϲ͛ WƵŵƉ͗ ϲ цϭϱ͕ϬϴϬ͛ WƵŵƉ͗ ϳ цϭϱ͕ϭϬϯ͛ 'ĂƐ^ĞƉĂƌĂƚŽƌ͗ ϴ цϭϱ͕ϭϬϳ͛ hƉƉĞƌdĂŶĚĞŵ^ĞĂů͗ ϵ цϭϱ͕ϭϭϰ͛ >ŽǁĞƌdĂŶĚĞŵ^ĞĂů͗ ϭϬ цϭϱ͕ϭϮϬ͛ DŽƚŽƌ͗ ϭϭ цϭϱ͕ϭϯϯ͛ 'ĂƵŐĞǁͬϲ&ŝŶĞŶƚƌĂůŝǌĞƌʹƚŵΛцϭϱ͕ϭϯϱ͛ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ <ƵƉϯ^ĂŶĚƐ ϭϱ͕Ϯϰϰ͛ ϭϱ͕ϮϱϮ͛ ϳ͕ϭϱϴ͛ ϳ͕ϭϲϱ͛ ϴ͛ &ƵƚƵƌĞ &ƵƚƵƌĞ <ƵƉ͘ϰ^ĂŶĚƐ ϭϱ͕ϮϱϮ͛ ϭϱ͕ϮϲϮ͛ ϳ͕ϭϲϱ͛ ϳ͕ϭϳϰ͛ ϭϬ͛ ϱͬϮϲͬϬϱ KƉĞŶ <ƵƉ͘Ϯ^ĂŶĚƐ ϭϱ͕Ϯϲϯ͛ ϭϱ͕Ϯϳϭ͛ ϳ͕ϭϳϰ͛ ϳ͕ϭϳϰ͛ ϴ͛ &ƵƚƵƌĞ &ƵƚƵƌĞ <ƵƉ͘Ϯ^ĂŶĚƐ ϭϱ͕ϮϳϮ͛ ϭϱ͕ϮϴϮ͛ ϳ͕ϭϴϮ͛ ϳ͕ϭϵϮ͛ ϭϬ͛ ϱͬϮϲͬϬϱ KƉĞŶ <ƵƉ͘ϭ^ĂŶĚƐ ϭϱ͕Ϯϴϯ͛ ϭϱ͕Ϯϵϯ͛ ϳ͘ϭϵϮ͛ ϳ͕ϮϬϭ͛ ϭϬ͛ &ƵƚƵƌĞ &ƵƚƵƌĞ <ƵƉ͘ϭ^ĂŶĚƐ ϭϱ͕Ϯϵϰ͛ ϭϱ͕ϯϭϰ͛ ϳ͕Ϯϭϰ͛ ϳ͕ϮϯϮ͛ ϮϬ͛ ϱͬϴͬϵϳ KƉĞŶ <ƵƉ͘ϯ^ĂŶĚƐ ϭϱ͕ϯϭϱ͛ ϭϱ͕ϯϰϬ͛ ϳ͕ϮϮϭ͛ ϳ͕Ϯϰϯ͛ Ϯϱ͛ &ƵƚƵƌĞ &ƵƚƵƌĞ KWE,K>ͬDEdd/> ϮϬΗ ŵƚǁͬϮϱϬƐǆŽĨƌĐƚŝĐƐĞƚ/ŝŶϮϰ͟,ŽůĞ ϵͲϱͬϴΗ ŵƚǁͬϭ͕ϭϱϬϬƐǆW&͕͟͞ϳϱϬƐǆůĂƐƐ͞'͟ŝŶϭϮͲϭͬϰ͟,ŽůĞ ϳ͟ ŵƚǁͬϮϯϱƐŬƐůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟,ŽůĞ t>>/E>/Ed/KEd/> <KWΛϲϬϬ͛ DĂǆ,ŽůĞŶŐůĞсϳϬƚŽϳϱĚĞŐ͘Ĩͬϯ͕ϲϬϬ͛ƚŽϭϯ͕ϬϮϭ͛ ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϮϴĚĞŐ͘ t>>^d/Dh>d/KEd/> ϳͬϮϴͬϵϳʹϭϱϵϬϬϬηϭϲͬϮϬĂƌďŽůŝƚĞďĞŚŝŶĚWŝƉĞ dZΘt>>, dƌĞĞ &DϮͲϵͬϭϲ͟ǆϱ tĞůůŚĞĂĚ ϭϭ͟ǆϳͲϭͬϭϲ͟ϱD^ƉŽŽůϳͲϭͬϭϲ͟ǆϮͲϵͬϭϲ͟,ĂŶŐĞƌ͘ϯ͟>, ĂĐŵĞdŽƉΘƚŵ͘ϮͲϵͬϭϲ͟ĐŝǁWs 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϳϱϲͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇEĂďŽƌƐϰͲ^Ͳϲͬϰͬϭϵϵϳ ŽŵƉůĞƚĞĚǁŝƚŚ^WďǇEĂďŽƌƐϰ^ʹϲͬϱͬϭϵϵϳ ^WŽŵƉůĞƚŝŽŶηϮǁͬEĂďŽƌƐϰͲ^ʹϳͬϯϬͬϭϵϵϳ ^WŽŵƉůĞƚŝŽŶηϯǁͬEĂďŽƌƐϰͲ^ʹϰͬϲͬϮϬϬϬ ^WŽŵƉůĞƚŝŽŶηϰǁͬEĂďŽƌƐϰͲ^ʹϳͬϯϬͬϮϬϬϰ WƵůůŽŵƉůĞƚŝŽŶĂŶĚĚĚWĞƌĨŽƌĂƚŝŽŶƐǁͬEĂďŽƌƐϰͲ^ʹϱͬϮϲͬϮϬϬϱ ^WŚĂŶŐĞͲŽƵƚĂŶĚ&KǁͬEĂďŽƌƐϯ^ʹϯͬϮϵͬϮϬϬϴ ^WŚĂŶŐĞͲŽƵƚǁEĂďŽƌƐϰͲ^ʹϳͬϮϭͬϮϬϭϬ ^WŚĂŶŐĞͲŽƵƚǁͬŽǇŽŶϭϲͲϭϭͬϮϴͬϮϬϭϯ ^WŚĂŶŐĞͲŽƵƚǁͬ^ZηϭʹϭϮͬϭϴͬϮϬϭϳ hƉĚĂƚĞĚϴͬϭϭͬϮϬϮϬ DŝůŶĞWŽŝŶƚ ^ZZŝŐϭKW ϮϬϮϮ ϭϭ͟KW ϰ͘ϰϴΖ ϰ͘ϱϰΖ Ϯ͘ϬϬΖ /tͲh ϰ͘ϯϬΖ,ǇĚƌŝů'< ϭϭΗͲϱϬϬϬ sZŽƌWŝƉĞZĂŵƐ ůŝŶĚϭϭΖ͛ͲϱϬϬϬ ^͕ϭϭϱDyϳϭͬϭϲϱD;/ĨEĞĞĚĞĚͿ ϮϭͬϭϲϱD<ŝůů>ŝŶĞsĂůǀĞƐ ϮϭͬϭϲϱDŚŽŬĞ>ŝŶĞsĂůǀĞƐ ,ZDĂŶƵĂůDĂŶƵĂů,Z ^ƚƌŝƉƉŝŶŐ,ĞĂĚ ´[´9%5 r.',.,:„:„t,,,,,„EIVED STATE OF ALASKA A OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS lAN 1 9 2'' �i9i018'`` LJ 1.Operations Abandon Plug Perforations U Fracture Stimulate] Pull Tubing U �►Ywn U Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ :rforate New Pool ❑ Repair Well❑✓ Re-enter Susp Well❑ Other:ESP Change Out ❑., 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: CS ' 1� Name: HilcorpAlaskaLLC ICSH Development Q Exploratory ❑ 197-058 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-029-22756-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL025509/ADL0355018 MILNE PT UNIT F-50 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/KUPARUK RIVER OIL 11.Present Well Condition Summary: Total Depth measured 15,685 feet Plugs measured N/A feet true vertical 7,551 feet Junk measured N/A feet Effective Depth measured 15,578 feet Packer measured N/A feet true vertical 7,455 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 112' 112' N/A N/A Surface 9,068' 9-5/8" 9,099' 4,603' 5,750psi 3,090psi Production 15,635' 7" 15,663' 7,531' 7,240psi 5,410psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5/L-80/EUE 8rd 15,135' 7,061' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 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 80 0 Subsequent to operation: 103 20 237 260 221 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑� Exploratory Development El Service ❑ 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: 317-560 Authorized Name: Bo York Contact Name: Paul Chan Authorized Title: Operations Manager Contact Email: pchan@hilcorp.com Authorized Signature: dti_ a-+ '� J ��/�` Date 1/3/2018 Contact Phone: 777-8333 1— -t —/, RLDMS L"J.AN 2 4 2618 Form 10-404 Revised 4/2017 .®" L ([ Submit Original Only • • Milnll:e PointMPU UnitF-50 We SCHEMATIC Last Completed: 12/18/2017 !bleary Alaska,LLC PTD: 197-058 TREE&WELLHEAD RKB:AGL=41.7'/GL Elev.12.4' Tree FMC 2-9/16"x 5 L _ € _, 11"x 7-1/16"5M Spool 7-1/16"x 2-9/16"Hanger.3"LH ^• a Wellhead 20 0 t acme Top&Btm. 2-9/16"ciw BPV OPEN HOLE/CEMENT DETAIL 1 fw 20" Cmt w/250 sx of Arcticset I in 24"Hole 9-5/8" Cmt w/1,1500 sx PF"E",750 sx Class"G"in 12-1/4"Hole 7" Cmt w/235 sks Class"G"in 8-1/2"Hole CASING DETAIL ' Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 91.1/H-40/N/A N/A Surface 112' 9-5/8" Surface 40/L-80/Btrc. 8.679 Surface 9,099 7" Production 26/L-80/Btc Mod 6.151 Surface 15,663' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surface 15,135' 3/8" Capstring 3/8"SS N/A Surface 15,135' 'y WELL INCLINATION DETAIL j KOP @ 600' *. „ Max Hole Angle=70 to 75 deg.f/3,600'to 13,021' a4' Hole Angle through perforations=28 deg. 9-5/8"9 e. h �`+v JEWELRY DETAIL c) 1 1 No Depth Item �LSt 1 137' GLM#1:Camco 2-7/8"KBMM 2 14,870' GLM#2:Camco 2-7/8"w/Dummy Valve KBMM c,66- 3 15,013' 2-7/8"XN-Nipple(2.205 no-go ID) 4 15,055.8' Discharge Head: FPDIS 2 7/8"EUE 8rd N C63029 5 15,056' Pump:FLEXER H6SXD 6 15,080' Pump: FLEXER H6 SXD 7 15,103' Gas Separator:GRS FER N AR 2 8 15,107' Upper Tandem Seal:GSB3DBUT SB/SB PFSA 9 15,114' Lower Tandem Seal: GSB3DBUT SB/SB PFSA 3 10 15,120' Motor:XP-150HP,2420 Volt,38 amp 11 15,133' Phoenix XT-150 Type"0"w/6 Fin Centralizer-Btm @ 15,135' Marker STIMULATION DETAIL 15,088'to 4 15,129' 7/28/97-159000#16/20 Carbolite behind Pipe IA 5&6 PERFORATION DETAIL [II ''':7 Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status a1 tt8 &9 Kup.A4 Sands 15,252' 15,262' 7,165' 7,174' 10' 5/26/05 Open 1° ma k Kup.A2 Sands 15,272' 15,282' 7,182' 7,192' 10' 5/26/05 Open Kup.Al Sands 15,294' 15,314' 7,214' 7,232' 20' 5/8/97 Open lf 10 GENERAL WELL INFO to to t. API:50-029-22756-00-00 1 rt i Drilled and Cased by Nabors 4-ES -6/4/1997 11 51 Completed with ESP by Nabors 4ES-6/5/1997 ,: 5 ESP Completion#2 w/Nabors 4-ES-7/30/1997 s` ESP Completion#3 w/Nabors 4-ES-4/6/2000 1 ESP Completion#4 w/Nabors 4-ES-7/30/2004 %, 4.; Pull Completion and Add Perforations w/Nabors 4-ES-5/26/2005 ESP Change-out and FCO w/Nabors 3S-3/29/2008 ESP Change-out w Nabors 4-ES-7/21/2010 14 W NI MT ASands ESP Change-out w/Doyon 16- 11/28/2013 SS' ESP Change-out w/ASR#1-12/18/2017 7'j 61 TD=15,685'(MD)/TD=7,551'(TVD) PBTD=15,578'(MD)/PBTD=7,455'(TVD) Revised By:TDF 1/3/2018 • . Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-50 ASR#1 50-029-22756-00-00 197-058 12/11/17 12/18/17 Daily Operations: 12/6/2017-Wednesday No activity to report. 12/7/2017-Thursday No activity to report. 12/8/2017-Friday No activity to report. 12/9/2017-Saturday No activity to report. 12/10/2017-Sunday No activity to report. 12/11/2017- Monday Remove F-50 production tree,set BOPE into place on wellhead.SIMOPS: Dig out rig pits, doghouse,co rep trailer,tool pusher trailer on E-pad. 12/12/2017-Tuesday R/U floor, spot carrier on mud boat& level same, move &spot pits, prep& raise mast. Dig out& move office,tool push/accumulator change house &eq.to F pad, Rigging up circulation lines,Certek glycol heating system, accumulator hydraulic lines, pipe racks. Set stairs in position as well as tool sheds and cuttings tank. R/U HCR on kill side of mud cross. R/U cushion T's on mud cross and connect greylock fittings to choke and kill lines. Prep rig floor for testing BOPE. R/U 6" flow line from pits to flow spool. Wellhead rep on location to pull BPV. Check the IA for pressure prior to pulling BPV. 50 psi showing on the IA. Spot flowback tank into place and attempt to bleed pressure off to flowback tank. Pressure reduced, but continuing to flow gas. Contact Roads and Pads to order 290bbls of source water to perform well kill. Crews continue to R/U. Centrilift on location to deliver tools in prep for pulling ESP. Continue to bleed IA to flowback tank. Pressure eventually bled off completely. Well head hand screw into BPV w/t-bar and check for pressure. Spot fluid on top of BPV to verify no gas below BPV. No pressure seen below BPV. Pull BPV and set TWC. Leave IA open to flowback tank to vent any gas from IA. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-50 ASR#1 50-029-22756-00-00 197-058 12/11/17 12/18/17 Daily Operations ,I €� �ir 11i 12/13/2017 Wednesday M/U test joints, offload fluid to pits, Fill surface eq. shell test t/2,500, had leak on Kill line flange, repair leaks, re-test good gi Test BOPE as per Hilcorp &AOGCC regulations witness was waived by AOGCC inspector Matt Herrera,tested w/2-7/8" & 5 3-1/2"TJ Blow down lines & rig down test eq. Monitor well static, pull TWC, m/u landing jt Pull hanger free @ 62k,string movement @ 110k, leveling out @ 102k, l/d hanger& landing jt Pump tubing volume 90 bbls @ 4bpm,50 psi, bleed down annulus, monitoBlow-"e- r well static, down lines, pull 2-7/8" completion,feed cable over sheave &through containment hose. sort pipe as per caliper log &visual inspection, (note joint 20 bad) Continue to POOH wjESP c.Qrnpletion..on 2-7/8" EUE TBG f/^'1,800'md to 3,750'md. Fill hole utilizing double metal displacement. Perform kick while tripping drill and roll into a well evacuation drill due to inclement weather. Wait on weather. Forecast shows wind conditions decreasing after 2am. R/U to continue POOH w/ ESP completion. Verify well is still on a vacuum prior to opening BOPE and removing TIW. Line up to pump 20bbls of source water(8.33ppg)from pits. Unable to get prime on pump. Line frozen. Investigate where ice plug is located. Find ice plug in kill line elbow located in storage compartment below choke and kill manifold on pit trailer. Pump 20bbls of source water down the IA. Blow down all circulating lines when pumping complete. Continue to POOH w/ESP completion on 2-7/8" EUE pipe f/—3,750'md marking all bad joints for replacement. 12/14/2017-Thursday POOH sorting joints as per caliper tally&visual defects f/3,750't/surface,found 2 bad spots in cable where armor was severed, @ 10,620' & 12,390'+-,sorted out 264 bad joints, recovered 4 protector clamps, 2 flat pack, &237 collar clamps. L/d ESP assembly C/O handling Eq. p/u 7" scraper assy, RIH p/u 3-1/2"wk string t/7,734', up wt 65k, dn wt 32k. 12/15/2017-Friday RIH w/7" scraper,f/7,734't/10,136' reciprocate scraper f/9,950't/ 10,100', up wt 83k, dn wt 32k POOH, I/d 3-1/2"wk (D string L/D 7" scraper assy, p/u 7" 26#Retrievamatic test packer TIH w/7"test packer, p/u 3-1/2" wk string,t/10,037', up wt 86k, dn wt 32k Set packer @ 10,010',fill annulus 125 bbls, line up t/test Pressure up t/2,200, lost 200psi, bump pressure up, lost 100 psi, bleed pressure off t/0,wk air out pressure up t/2,100 held for 30 min good Bleed off, blow down lines, pull packer free let element relax POOH t/9,209' up wt 70k,dn wt 32k. 12/16/2017-Saturday POOH 1/d 3-1/2"wk string& 7" Retrievamatic test packer Clear floor& pipe rack, c/o handling eq. & prep t/P/U ESP assy. P/U &Service ESP Assembly: Centralizer, Phoenix, CL5 Motor, lower tandem seal, Upper tandem seal, Gas separator, Pump, Pump, Discharge Head =79.43'test cap line &cable. Note while lowering motor in hole it was tight on cap line, re- adjusted its location next to MLE clamp & re-ran good.Tally 2-7/8" L-80 6.5#EUE 8Rd tubing, p/u & RIH w/assy.t/2668', checking cable every 1000'Good 12/17/2017 Sunday Tlh f/2,668',t/8,270' w/ESP assy., p/u 2-7/8" 6.5#EUE 8rd tubing, checking cable every 1,000', cap line every 2,000', cannon clamp every jt on first 5,100' run in. Swap cable reels,splice @ 8,363'test good,while splicing fill tubing& pump through assembly, 1.5 BPM, 1,000psi Cont.Tlh t/11,889'w/ ESP assy., p/u 2-7/8" 6.5#EUE 8rd tubing, checking cable every 1,000', cap line every 2,000',cannon clamp every other jt f/5,100' up. • S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-50 ASR#1 50-029-22756-00-00 197-058 12/11/17 12/18/17 Daily operations: 12/18/2017- Monday Tlh f/11,889'w/ESP assy., p/u 2-7/8" 6.5#EUE 8rd tubing, checking cable every 1,000', cap line every 2,000', pump through assy @ 12,229', & 14,981' M/U landing jt & Hanger, m/u cap line& penetrator,test same good Land hanger placing tail @ 15,135' do wt 30k, run in L/D pins, set BPV Clean &clear floor, prep & I/d derrick, blow down & rig down lines, rig down pipe skate, clear" A" pad of snow in stack out area for rig&eq. Move carrier from well.Set up crane, pull floor, n/d BOPE, n/u tree.Test void t/5k good. final check on penetrator good Cont. r/d & move Eq.t/A-pad. 12/19/2017-Tuesday No activity to report. OF 7•y THE STATE AlaskaOil .,,i)",\ 1//7,,-4'4, and Gas N��'`►`�i�� fALr1 o ® SKA Conservation Commission ___ s tint 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF wa Main: 907.279.1433 AASY' Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager N�� ' Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool,MPU F-50 Permit to Drill Number: 197-058 Sundry Number: 317-560 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, staXr -- Hollis S. French l Chair DATED this 3o day of November, 2017. ReZL7,S L v7�� 1.117 1ett V J v ii • • 411, ECEIVED NOV 2 2 2017 STATE OF ALASKA OTS i 121��f/� ALASKA OIL AND GAS CONSERVATION COMMISSION PCV APPLICATION FOR SUNDRY APPROVALS AO 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well KI Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q , 197-058, 3.Address: 3800 Centerpoint Dr,Suite 1400 ❑ 6.API Number: Stratigraphic ❑ Service Anchorage Alaska 99503 50-029-22756-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D Will planned perforations require a spacing exception? Yes ❑ No ❑., /' MILNE PT UNIT F-50 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025509/ADL0355018 MILNE POINT/KUPARUK RIVER OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 15,685' • 7,551' , 15,578' , • 7,455' 486 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 112' 112' N/A N/A Surface 9,068' 9-5/8" 9,099' 4,603' 5,750psi 3,090psi Production 15,635' 7" 15,663' 7,531' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic ✓ See Schematic 2-7/8" 6.5/L-80/N/A 15,128' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A 12.Attachments: Proposal Summary Q Wellbore schematic E1 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: 12/8/2017 Commencing Operations: OIL Q ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. er Authorized Name: Bo York Contact Name: Paul Chan Authorized Title: Operations Manager Contact Email: pChanahiIcorp.Com Contact Phone: 777-8333 Authorized Signature:deAl----1Date: 11/21/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: // __ 3I7c6 1...(- Plug Integrity ❑ BOP Test MechanicalnIntegrity Test ❑ Location Clearance ❑ Other: A- Z 500 / 5v Uo1 • le, I XL C'u.sr5 l` ZeOpS Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No j' Subsequent Form Required: /0 r `i Oil ��'"ram L`� L'.J 1 APPROVED BY Approved by: tagCOMMISSIONER THE COMMISSION Date: t1 I ICI / lt.gcr. 11 1/7-2.77ORIGINA L � Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: MPU F-50 Ililcorp Alaska,LL Date: 11/20/2017 Well Name: MPU F-50 API Number: 50-029-22756-00 Current Status: Oil Well Pad: F-Pad Estimated Start Date: December 8th, 2017 Rig: ASR 1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 197-058 First Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) Second Call Engineer: Taylor Wellman (907)777-8449 (0) (907) 947-9533 (M) AFE Number: Job Type ESP Repairl $0 " Current Bottom Hole Pressure: 1,186 psi @ 7,021' TVD (ESP Gauge 10/02/2017/3.25 ppg EMW) Maximum Expected BHP: 1,186 psi @ 7,021' TVD (No new perfs being added) MPSP: 486 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU F-50 was drilled in April 1997,fracture stimulated in May, and completed in June 1997 as a Kuparuk River producer. ESP installation history: June 1997 (initial),July 1997,April 2000,July 2004, May 2005 (elective pull), March 2008,July 2010, and November 2013. Well has a suspected hole in tubing. Notes Regarding Wellbore Condition iiSr� A a I- • • The 7" production casing was tested on April 27, 1997. it,)': �S 7 C" • CO 390A: Hilcorp Alaska respectfully requests that a packer not be required on this ESP completion as the reservoir pressure is less than 8.55 ppg EMW. Objective: Pressure test 7" production casing and replace ESP. V Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.5 ppg sea water down tubing,taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. • • Well Prognosis Well: MPU F-50 Ilileorp Alaska,LI) Date: 11/20/2017 Brief RWO Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg sea water prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/2,500 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8" and 3-1/2" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure `i c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking A-4,X anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg sea water as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2010 ESP swap was 140K lbs. (includes 40K block weight) b. If needed,circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. 16. Recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 17. POOH and lay down the 2-7/8"tubing. Number all joints. Tubing will be re-used as noted. Lay down ESP. a. Lay down pitted joints as indicated by caliper run October 25, 2017: i. GLM #1 (lower pup pitted) ii. Joints 95- 120 iii. Joints 195—200, s • Well Prognosis Well: MPU F-50 Ililrorp Alarkn,Ili Date: 11/20/2017 iv. Joints 210—220, v. Joints 230—355, vi. Joints 370—375, vii. Joints 405—440, viii. Joints 455 -465 b. Replace bad joints of tubing as necessary and note on tally new tubing run. c. Note any sand or scale inside or on the outside of the ESP on the morning report. d. Look for over-torqued connections from previous tubing runs. 18. PU & RIH with 7" 26#scraper assembly to 10,100' MD on 3-1/2" workstring. Reciprocate scraper across packer setting depth of 10,000' MD. Circulate the well clean. 19. POOH. L/D scraper assembly and 3-1/2" workstring. 20. PU test packer and RIH on 3-1/2" workstring to^'10,000' MD. ✓ 21. Set test packer and pressure test 7" casing to 2000 psi for 30 charted minutes. 22. Unseat test packer and POOH. 23. PU new ESP and RIH on 2-7/8" tubing. Set base of ESP at± 15,126' MD. a. Upper GLM @ ± 140' MD w/SO b. Lower GLM @ ± 14,876' MD w/DGLV c. 2-7/8" XN (2.205" No-Go) @ ±15,019' MD d. Base of ESP centralizer @ ± 15,126' MD 24. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off)weights on tally. 25. Set BPV. Post-Rig Procedure: 26. RD mud boat. RD BOPE house. Move to next well location. 27. RU crane. ND BOPE. 28. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 29. RD crane. Move 500 bbl returns tank and rig mats to next well location. 30. Replace gauge(s) if removed. 31. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. Blank RWO MOC Form Milne Point Unit • • Well: MPU F-50 . IISCHEMATIC Last Completed: 11/28/2013 Ham,Alaska.LLC PTD: 197-058 TREE&WELLHEAD RKB:AGL=41.7'/GL Elev.=12A' Tree FMC 2-9/16"x 5 4 c 1 : ii 11"x 7-1/16"5M Spool 7-1/16"x 2-9/16"Hanger.3"LH 20 Wellhead acme Top&Btm. 2-9/16"CIW BPV g a, OPEN HOLE/CEMENT DETAIL 1 20" Cmt w/250 sx of Arcticset I in 24"Hole M 9-5/8" Cmt w/1,150 sx PF"E",750 sx Class"G"in 12-1/4"Hole 7" Cmt w/235 sks Class"G"in 8-1/2"Hole CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm €• * 20" Conductor 91.1/H-40/N/A N/A Surface 112' 9-5/8" Surface 40/L-80/Btrc. 8.679 Surface 9,099 7" Production 26/L-80/Btc Mod 6.151 Surface 15,663' TUBING DETAIL 4 2-7/8" Tubing 6.5/L-80/N/A 2.347 Surf 15,128' "' WELL INCLINATION DETAIL {t I KOP @ 600' 3 Max Hole Angle=70 to 75 deg.f/3,600'to 13,021' d Hole Angle through perforations=28 deg. 9-5/8" li JEWELRY DETAIL No Depth Item 1 139' Camco 2-7/8"x 1"Sidpocket KBMM GLM 2 2 14,876' Camco 2-7/8"x 1"Sidpocket KBMM GLM 3 15,019' 2-7/8"XN-Nipple(2.250 no-go ID) 1 4 15,061' GPDIS Discharge Head 3 5 15,062' Pump(2)SDX 141-P6 y' 6 15,094' Gas Separator GRSFTXAR 7 15,099' Centrilift Seal Section GSB3DB UT/L SB/SB PFSA 8 15,113' Motor,MSP-250 126HP,2450 Volt,31 amp pit 4 9 15,126' Phoenix XT-150 Type"0"w/6 Fin Centralizer-Btm @ 15,128' 5 WELL STIMULATION DETAIL 5/10/97-159100#16/20 Carbolite behind Pipe Marker Jt @ ;',� 1111 at 6 15,0s8'to ' PERFORATION DETAIL 15,129' 7 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.A4 Sands 15,252' 15,262' 7,165' 7,174' 10' 5/26/05 Open *;$ Kup.A2 Sands 15,272' 15,282' 7,182' 7,192' 10' 5/26/05 Open '' Kup.Al Sands 15,294' 15,314' 7,214' 7,232' 20' 5/8/97 Open v Mt VI ie GENERAL WELL INFO 9 " API:50-029-22756-00-00 Drilled and Cased by Nabors 22E -4/28/1997 1/44 M ESP Completion(Initial)by Nabors 4ES-6/5/1997 1 < ESP Completion#2 w/Nabors 4-ES-7/30/1997 ESP Completion#3 w/Nabors 4-ES-4/6/2000 ti Completion#4 w/Nabors 4-ES-7/30/2004 Pull Completion and Add Perforations w/Nabors 4-ES-5/26/2005 V i' ESP Change-out and FCO w/Nabors 3S-3/29/2008 la* ESP Change-out w Nabors 4-ES-7/21/2010 d ESP Change-out w/Doyon 16- 11/28/2013 t}As 7" 1 1D=15,685'(MD)/TD=7,551'(TVD) PBTD=15,578'(MD)/PBTD=7,455'(TVD) Revised By:TDF 10/21/2017 Milne Point Unit Well: MPU F-50 . fit PROPOSED Last Completed: 11/28/2013 Hiker')Alaska.LLC PTD: 197-058 TREE&WELLHEAD RKB:AGL=41.7'/GL Elev.=12A' Tree FMC 2-9/16"x 5 20J F Wellhead 11"x 7-1/16"5M Spool 7-1/16"x 2-9/16"Hanger.3"LH I acme Top&Btm. 2-9/16"ciw BPV OPEN HOLE/CEMENT DETAIL 1 20" Cmt w/250 sx of Arcticset I in 24"Hole t, 9-5/8" Cmt w/1,1500 sx PF"E",750 sx Class"G"in 12-1/4"Hole 7" Cmt w/235 sks Class"G"in 8-1/2"Hole ir CASING DETAIL v. Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 91.1/H-40/N/A N/A Surface 112' 9-5/8" Surface 40/L-80/Btrc. 8.679 Surface 9,099 r7" Production 26/L-80/Btc Mod 6.151 Surface 15,663' TUBING DETAIL a 2-7/8" Tubing 6.5/L-80/N/A 2.347 Surf ±15,128' WELL INCLINATION DETAIL 0 KOP @ 600' Max Hole Angle=70 to 75 deg.f/3,600'to 13,021' I4 Hole Angle through perforations=28 deg. ^^ 95/8" I tl I r JEWELRY DETAIL No Depth Item 1 ±139' Camco 2-7/8"x 1"Sidpocket KBMM GLM 2 2 ±14,876' Camco 2-7/8"x 1"Sidpocket KBMM GLM 3 ±15,019' 2-7/8"XN-Nipple(2.250 no-go ID) 4 ±15,061' GPDIS Discharge Head 3 5 ±15,062' Pump(2)SDX 141-P6 1 6 ±15,094' Gas Separator GRSFTXAR 7 ±15,099' Centrilift Seal Section GSB3DB UT/L SB/SB PFSA 8 ±15,113' Motor,MSP-250 126HP,2450 Volt,31 amp IA 4 9 ±15,126' Phoenix XT-150 Type"0"w/6 Fin Centralizer-Btm @ 15,128' 5 WELL STIMULATION DETAIL 7/28/97-159000#16/20 Carbolite behind Pipe CI , t',. 6 Marker Jt@ '' PERFORATION DETAIL 15,12 to...........1 Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status Kup.A4 Sands 15,252' 15,262' 7,165' 7,174' 10' 5/26/05 Open 1/24 1"8 Kup.A2 Sands 15,272' 15,282' 7,182' 7,192' 10' 5/26/05 Open z+ Kup.Al Sands 15,294' 15,314' 7,214' 7,232' 20' 5/8/97 Open >#s I4 GENERAL WELL INFO 9 1 API:50-029-22756-00-00 *44 i4 Drilled and Cased by Nabors 4-ES -6/4/1997 " ! Completed with ESP by Nabors 4ES-6/5/1997 ESP Completion#2 w/Nabors 4-ES-7/30/1997 r it ESP Completion#3 w/Nabors 4-ES-4/6/2000 1i rt ESP Completion#4 w/Nabors 4-ES-7/30/2004 Pull Completion and Add Perforations w/Nabors 4-ES-5/26/2005 el ESP Change-out and FCO w/Nabors 3S-3/29/2008 R #4 , ESP Change-out w Nabors 4-ES-7/21/2010 ESP Change-out w/Doyon 16- 11/28/2013 ii il l, 1 A Sands e iy 14 7"1 g TD=15,685'(MD)/TD=7,55t(TVD) PBTD=15,578'(MD)/PBTD=7,455'(TVD) Revised By:TDF 10/21/2017 • • . iti Milne Point ASR Rig 1 BOPE 11" BOPE Stripping Head 3.98' 1r f p Shaffer-II 11"- 5000 i l l liii till TV tLIJ Jf , - _ 4.54CI U II. :: •...= VBR or Pipe Rams ,C ine ArIIIIIIIlierowit 11' -5000 Ih:s_ ' Blind a iigrifiMlit 21/16 5M Kill Line Valves I 21/16 5M Choke Line Valves 2.00' I MI - - II - 11)i i s eee...yy t tAlliii if c i 1 r Manual Manual Manual HCR Updated 8/19/2015 • • Swab Valve-Cameron FLS-2 9/16" MPF-50 5K,manual gate valve,EE PSL2, PR2 11/20/2017 0.93 lit CURRENT °ismer.°•,xi Wing Valve,Cameron FLS 2 9/16" 2 9/16"5K tree with 1.38' ' 5K,reverse acting,actuated gate 2 7/8"FMC Tubing Hanger . G `'' valve,w/Baker actuator,EE PSL2 a (a$ PR2 u o. SSV Cameron FLS 2 9/16"5K, Elm1119, _ reverse acting,actuated gate IPa valve,w/Baker actuator,EE .42' lq s)tl _ 1 PSL2 PR2 _ 1.38 I 111 nve ,, Master Cameron FLS FLS 2 9/16" t 0 5K,manual gate valve,EE PSL2 PR2 1.38' ' Tbg Hd Adpter,FMC 7"5K x 2 1.52' 9/16"5K,rotating flanges top and bottom,w/lea 3/8"control line prep,w/ESP mandrel.No Heat trace run.Bottom prepped for 2 7/8"seal sleeve 11 IIIIIIa , a II 01 114..:Volli 01401-1-1 aMill I■ • • = 0 ) m > CO m * v0 > ix coo o v > M � aCL s ...- E -• E rn c°> d N a) aa) Y or := a) xav 3 Q C. >, L" am -0a) - c L di Q 7- = a) L CO o co 0 0 c a) (0 C U (0 a) _c L U .- C1) o To 0 _0 o V -0 a > a� OL � o C C a Qa) (0 a - as U CUo 112 = a) O L L O 3 E ' d a) O ) U - • Ea %.... o a 3 3 To a,li, n „... N L c o >O• w a) a 0 Q. o Q m CO 2 co w CC Q d (B L N N r cr) Q ,Q d O O O CC3ts) r. Q cre co > (=0 O a)a ) a) d 0" ) z = CO a 0 0 CD ii j a 0 QCT) �'' p 0 (0 N x _ EV > (0 = m t% 0 o U) 3 ) Q < y < XHVZE Pages NOT Scanned in this Well History File 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. //~ ~- ~-"~'/ File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: n GraYScale, halftones, pictures, graphs, charts - Pages: [] Poor Quality Odginal- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type *OVERSIZED .Logs of vadous kinds Other Complete COMMENT~: Scanned by: E~er~j ! , TO RE-SCAN Notes: Re-Scanned by: ~ve~ M~dred Daretha Natl3an Lowell Date: /s/ STATE OF ALASKA RECEIVED AL ,(A OIL AND GAS CONSERVATION CO, .SSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS DEC 19 2013 1. Operations Performed: _AOGCC ❑Abandon ❑Repair Well ❑Plug Perforations ❑Perforate ❑Re-Enter Suspended Well ❑Alter Casing ®Pull Tubing' ❑Stimulate-Frac ❑Waiver ®Other • ❑Change Approved Program ❑Operation Shutdown ❑Stimulate-Other ❑Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑Exploratory ❑Stratigraphic 197-058 ' 3. Address: ®Development ❑Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-22756-00-00 ' 7. Property Designation(Lease Number): 8. Well Name and Number: ADL 025509&ADL 355018 MPF-50 • 9. Logs(list logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Milne Point Unit/Kuparuk River Oil • 11. Present well condition summary: Total depth: measured 15685' feet Plugs:(measured) None feet true vertical 7551' feet Junk:(measured) None feet Effective depth: measured 15578' feet Packer: (measured) None feet true vertical 7455' feet Packer: (true vertical) None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 32'- 110' 32'- 110' 1490 470 Surface 9068' 9-5/8" 31'-9099' 31'-4603' 5750 3090 Intermediate Production 15635' 7" 28'- 15663' 28'-7531' 7240 5410 Liner Perforation Depth: Measured Depth: 15252'- 15314' $ED / 1 t�) True Vertical Depth: 7165'-7220' feet G Tubing(size,grade,measured and true vertical depth): 2-7/8" 6.5#, L-80 15128' 7055' Packers and SSSV(type,measured and true vertical depth): None None 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment description including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 282 81 146 340 256 Subsequent to operation: 267 47 157 280 220 14.Attachments: ❑Copies of Logs and Surveys run 15.Well Class after work: ❑Exploratory ❑Stratigraphic ®Development ❑Service ®Daily Report of Well Operations 16. Well Status after work: IS Oil. ❑Gas ❑WDSPL ®Well Schematic Diagram ❑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: Contact: Jimmy Smith,564-5616 Email: James.Smith7 @bp.com N/A Printed N m Joe Lastu Title: Drilling Technologist Signature: K ` Phone: 564-4091 Date: Wig 113 Form 10-404 Re 's d 0/2012 vvri Submit Original Only / //g///1 )4, F;B S DEC 2 0 20 North America-ALASKA-BP Page 1 of 7 Operation Summary Report Common Well Name:MPF-50 AFE No Event Type:WORKOVER(WO) Start Date:11/23/2013 End Date:11/28/2013 X4-00YF4-E.(1,850,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/12/1997 12:00:00AM Rig Release: 11/28/2013 Rig Contractor:DOYON DRILLING INC. UWI:500292275600 Active datum:Kelly Bushing/Rotary Table @31.40usft(above Mean Sea Level) Date i (hr) usft Phase I Description of Operations From-To (; Task Code NPT NPT Depth I, -- 11/23/2013 !03:00 04:00 1.00 • MOB P PRE RIG RELEASED FROM WELL MPF-93 AT 03:00 11/23/2013. B/D AND R/D CIRCULATION LINES AND SECURE TREE. CONTINUE SECURE CELLAR AREA. 04:00 - 05:00 1.00 MOB P PRE PJSM,PULL RIG OFF WELL -WSL/TOOLPUSHER PRESENT -PULL OFF MPF-78. -STAGE ON EDGE OF PAD. 05:00 - 06:00 1.00 MOB P PRE LIFT BOP OFF OF STUMP. -REMOVE 13-5/8"X 11"5M SPOOL FROM BOP STACK. -N/U 13-5/8"X 13-5/8"5M SPACER SPOOL ON TO BOP STACK. -REMOVE MATS FROM MPF-78. 06:00 - 08:30 2.50 MOB P PRE PJSM,INSTALL NEW BOP PEDESAL. -WELDER REMOVED OLD PEDESAL AND INSTALL NEW. -LAY MAT ON WELL,MPF-50 AND STAGE EQUIPMENT BEHIND CELLAR WHILE WELDING PEDESAL IN PLACE. 08:30 - 10:30 2.00 MOB P PRE PJSM,SPOT RIG ON MPF-50. -WSL/TOOLPUSHER PRESENT. -SPOT OVER MPF-50 AND SHIM RIG. -SPOT CUTTING BOX,FUEL TRAILER AND CHANGE TRAILER. 10:30 - 11:00 0.50 RIGU P PRE PJSM,RIG UP. -R/U LINES. -BERM CELLAR. ACCECPT RIG AT 11:00 HRS 11/23/2013 11:00 - 14:30 3.50 MOB P PRE PJSM,R/U KILL MANIFOLD. -R/U AND TEST LINES AND KILL MANIFOLD -TEST LINES TO 250 PSI LOW,3500 PSI HIGH WITH DIESEL. -TAKE ON 8.5 PPG 120 DEGREE SEAWATER. 14:30 - 15:00 0.50 RIGU P PRE FIRE RIG EVACUATION DRILL AND AAR. 15:00 - 17:00 2.00 WHSUR P DECOMP P/U LUBRICATOR AND TEST TO 250 PSI LOW, 3500 PSI HIGH -PULL BPV. -L/D LUBRICATOR TBG PRESSURE=150 PSI,IA PRESSURE= 400 PSI. 17:00 - 17:30 0.50 WHSUR P DECOMP PJSM,WELL KILL. -REVIEW DDI WELL KILL S.O.P. -DISCUSS CIRCULATION KILL PLAN WITH MUD ENGINEER AND PIT CREW. -DISCUSSED INDIVIDUAL ROLLS AND RESPONSIBILITIES. -WSL AND TOOL PUSHER INSPECT R/U OF KILL MANIFOLD AND HARD LINE. Printed 12/9/2013 11:43:50AM North America-ALASKA-BP Page 2 of 7 Operation Summary Report Common Well Name:MPF-50 AFE No Event Type:WORKOVER(WO) Start Date:11/23/2013 End Date:11/28/2013 X4-00YF4-E:(1,850,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/12/1997 12:00:00AM Rig Release:11/28/2013 Rig Contractor:DOYON DRILLING INC. UWI:500292275600 Active datum:Kelly Bushing/Rotary Table @31.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:30 - 21:00 3.50 WHSUR P DECOMP PERFORM BULLHEAD WELL KILL. -SITP=150 PSI,SICP=400 PSI,OA=120 PSI. KWF=8.5 PPG SEAWATER HEATED TO 120 F. BLEED FROM THE IA TO FLOW BACK TANK -IA BLEED FROM 400 PSI TO 100 PSI IN 30 MINUTES. -TUBING BLEED FROM 150 PSI TO 0 PSI IN 30 MINUTES. -OA DROP FROM 120 PSI TO 55 PSI IN 30 MINUTES. NO FLUID RETURNS SEEN AT FLOW BACK TANK. -BULLHEAD 10 BBLS DOWN TUBING AT 3 BPM,90 PSI. -OPEN IA AND SIMULTANEOUSLY BULLHEAD DOWN TUBING AND IA AT 7 BPM. -CATCH FLUID AT 3500 STROKES. ICP=7 BPM,1300 PSI. -FCP=1 BPM,500 PSI. -KEEP OA BELOW 1000 PSI WHILE PUMPING. -TOTAL STROKES PUMPED 13593. ,21:00 - 22:00 1.00 WHSUR P DECOMP !MONITOR WELL. -TUBING PRESSURE=0 PSI -ANNULAR PRESSURE=0 PSI. -VERIFIED WELL ON VAC. 22:00 - 00:00 2.00 WHSUR P DECOMP PJSM WITH WELL SUPPORT AND RIG CREW TO SET TWC. -M/U LUBRICATOR&TEST. -250 PSI LOWAND 3500 PSI FOR 5 CHARTED MINUTES. -SET TWC. -L/D LUBRICATOR. PERFORM ROLLING TEST BELOW TWC. -ATTEMPT TO TEST BOTTOM OF TWC,PUMP 7 BPM,0 PSI FOR 5 CHARTED MINUTES. -TEST TWC FROM ABOVE,250 PSI LOW& 3500 PSI HIGH FOR 5 CHARTED MINUTES. 24 HRS LOSSES=1195 BBLS 8.5 PPG BRINE. 11/24/2013 00:00 - 02:00 2.00 WHSUR P DECOMP SPCC CHECKS AND PRE-TOUR MEETING PRESSURE TEST TWC FROM ABOVE 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES. -VERIFIED NO FLOW PAST TWC. 02:00 - 05:00 3.00 WHSUR P DECOMP PJSM,N/D TREE. -N/D TREE AND ADAPTER FLANGE. -FMC INSPECT HANGER AND THREADS 8.5 TURNS. 05:00 - 09:00 4.00 BOPSUR P DECOMP PJSM,NIPPLE UP BOP -N/U 13-5/8"5M 4 PERVENTOR BOPE AND KILL LINE. -INSTALL ADJUSTED FLOW LINE RISER. -HOOK UP KOOMEY HOSES AND NEW CHOKE HOSE CLAMP ASSEMBLY. Printed 12/9/2013 11:43:50AM • • North America-ALASKA-BP Page 3 of 7 Operation Summary Report Common Well Name:MPF-50 AFE No Event Type:WORKOVER(WO) Start Date:11/23/2013 End Date:11/28/2013 X4-00YF4-E:(1,850,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/12/1997 12:00:00AM Rig Release:11/28/2013 Rig Contractor:DOYON DRILLING INC. UWI:500292275600 Active datum:Kelly Bushing/Rotary Table @31.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:00 - 09:30 0.50 BOPSUR P DECOMP PJSM,BOP AND RELATED EQUIPMENT -R/U TEST EQUIPMENT • -FUNCTION TEST BOPE -PERFORM BODY TEST. 09:30 - 18:30 9.00 BOPSUR P DECOMP TEST FOUR PREVENTER 13 5/8"BOP AND RELATED EQUIPMENT -TEST BOP ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES -TEST ANNULAR WITH 2 7/8"TEST JOINT TO 250 PSI LOW,3500 PSI HIGH,5 MINUTES EACH,CHARTED -TEST 2 7/8"X 5"VARIABLE RAMS WITH 2 7/8" AND 4"TEST JOINT,250 PSI,3500 PSI,5 MIN, CHARTED -TEST BLIND RAMS,FLOOR VALVES,AND CHOKE MANIFOLD TO 250 PSI,3500 PSI,5 I MIN,CHARTED -TEST WITH FRESH WATER. • -PERFORM ACCUMULATOR DRAW DOWN TEST -NO FAILURES. R/D BOP TEST EQUIPMENT JEFF JONES OF AOGCC WITNESS BOP TEST • • 18:30 20:30 2.00 WHSUR P DECOMP PJSM,P/U DSM LUBRICATOR -DRAIN BOP AND M/U OFF SET LUBRICATOR TO HANGER M/U DSM LUBRICATOR -TEST 250/3500 PSI,5 MIN CHARTED -PULL TWC,R/D DSM LUBRICATOR 20:30 - 21:30 1.00 PULL P DECOMP MU LANDING JOINT WTH FOSV TO TBG HANGER. BOLDS PER FMC REP -PULL TBG HANGER OFF SEAT @ 140K INCLUDES 40K TOP DRIVE WT. -PU=140K,SO=70K -CENTRILIFT REP CONDUCT CONDUCTIVITY TEST ON ESP -PULL HANGER AND REMOVE 1 CLAMP ON FIRST FULL JOINT -CUT ESP CABLE AT FIRST CLAMP AT BOTTOM OF FIRST FULL JT -POSITION SLICK JOINT ACROSS BOP '21:30 - 22:30 I 1.00 PULL P DECOMP 'BULLHEAD TUBING VOLUME -BULLHEAD 90 BBLS, 8.5#SEAWATER DOWN TUBING -SPR=2 BPM @ 70 PSI,PUMP 3 BPM @ 70 PSI -MONITOR WELL,WELL IS ON A VACUUM • 22:30 - 00:00 1.50 PULL P DECOMP M/U TIWAND HOSE IN STUMP ON TOP OF 2-7/8"TUBING. -L/D TBG HANGER. -WEEKLY SAFETY MEETING WITH'D'CREW i-DOYON HSE REP IN ATTENDANCE CONTINUOUS HOLE FILL AT 30 BPH 24 HRS LOSSES=663 BBLS 8.5 PPG BRINE. Printed 12/9/2013 11:43:50AM • North America-ALASKA-BP Page 4 of 7 Operation Summary Report Common Well Name:MPF-50 AFE No Event Type:WORKOVER(WO) Start Date:11/23/2013 End Date:11/28/2013 X4-00YF4-E:(1,850,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/12/1997 12:00:00AM Rig Release:11/28/2013 Rig Contractor:DOYON DRILLING INC. UWI:500292275600 Active datum:Kelly Bushing/Rotary Table©31.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/25/2013 00:00 - 02:00 2.00 DHB P DECOMP SPCC CHECKS AND PRE-TOUR MEETING. -CHECK CROWN-O-MATIC PJSM,R/U AND RUN HES 7"RTTS -P/U 3 JTS 4"DP&SET 1 STAND BELOW WELL HEAD. -TEST TO 250 PSI LOW,2000 PSI HIGH FOR 5 CHARTED MINUTES. 02:00 - 02:30 0.50 WHSUR P DECOMP CHANGE OUT BLIND FLANGE ON IA. -REPLACE WITH INTEGRAL FLANGE AND VALVE. 02:30 - 03:30 1.00 DHB P DECOMP RELEASE RTTS AND MONITOR WELL. -WELL IS ON A VAC. -POOH UD 3 JTS 4"DP AND RTTS. 03:30 - 11:00 7.50 PULL P DECOMP PJSM,PULL ESP COMPLETION ASSEMBLY -CENTRALIFT ATTACH 3 LEG SPLICE AND SECONDARY RESTRAINT. -PULL ESP CABLE OVER SHEAVE USING WINCH IN SPOOLER. -POOH W/6.5#,2-7/8 EUE 8RD TUBING, STANDING BACK -POOH FROM 14,952'TO 7,910'MD. -PUW=135K,SOW=55K -MAINTAIN CONTINUOUS HOLE FILL AT 30 BPH W/NO RETURNS. 11:00 - 12:00 1.00 PULL P DECOMP CHANGE OUT FULL REEL IN SPOLLING UNIT. 12:00 - 12:30 0.50 PULL P DECOMP RIG SERVICE -CHECK CROWN-O-MATIC 12:30 - 17:00 4.50 PULL P DECOMP CONTINUE PULL ESP COMPLETION. -STAND IN DERRICK -FROM 7,910'TO 3835'. -MAINTAIN CONTINUOUS HOLE FILL AT 30 BPH W/NO RETURNS. 17:00 - 18:00 1.00 PULL P DECOMP 1 SAFETY MEETING TO DISCUSS DEFEATED SAFETY DEVICES. DDI SAFETY,DDI SUPERINTENDENT,BP SUPERINTENDENT AND BP WSLS IN ATTENDANCE. 18:00 - 22:00 4.00 PULL I P DECOMP CONTINUE PULL ESP COMPLETION. -STAND IN DERRICK -FROM 3835'TO 198'. -MAINTAIN CONTINUOUS HOLE FILL AT 30 BPH W/NO RETURNS. 22:00 - 00:00 2.00 PULL P DECOMP PJSM,L/D PUMP AND MOTOR ASSEMBLY. -ALL PROTECTORS,FLAT GUARDS AND CLAMPS RECOVERED. -PROTECTORS=5,FLAT GUARDS=3, CLAMPS=245. CONTINUOUS HOLE FILL AT 30 BPH 24 HRS LOSSES=727 BBLS 8.5 PPG BRINE. 11/26/2013 00:00 - 00:30 0.50 PULL P DECOMP SPCC CHECKS AND PRE-TOUR MEETING. -CHECK CROWN-O-MATIC. -UD PUMP AND MOTOR ASSEMBLY. -ESP PUMP AND DISCHARGE LOCKED-UP. -ESP MOTOR WAS GROUNDED OUT. Printed 12/9/2013 11:43:50AM • • North America-ALASKA-BP Page 5 of 7 Operation Summary Report Common Well Name:MPF-50 AFE No Event Type:WORKOVER(WO) Start Date:11/23/2013 End Date:11/28/2013 X4-00YF4-E:(1,850,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/12/1997 12:00:00AM Rig Release:11/28/2013 Rig Contractor:DOYON DRILLING INC. I UWI:500292275600 Active datum:Kelly Bushing/Rotary Table©31.40usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ (usft) 00:30 - 01:30 1.00 RUNCOM P RUNCMP CLEAN AND SERVICE RIG. 01:30 - 02:00 0.50 RUNCOM P RUNCMP R/D ESP TRUNK. 02:00 - 04:00 2.00 RUNCOM P RUNCMP PJSM,STRING KEVLAR ROPE TO SPOOLING UINT. CENTRILIFT INSTALL CONNECTOR TO ESP CABLE. -STRING ESP CABLE TO RIG FLOOR. 04:00 - 10:30 6.50 RUNCOM P RUNCMP CENTRILIFT REP PERFORM MOTOR LEAD EXTENSION POT HEAD SPLICE. 10:30 - 15:30 5.00 RUNCOM P RUNCMP PJSM,P/U AND SERVICE ESP MOTOR/PUMP ASSEMBLY. -30 BPH CONTINUOUS HOLE FILL W/8.5# SEAWATER W/NO RETURNS. 15:30 - 16:30 1.00 RUNCOM P RUNCMP PLUG IN MOTOR LEAD EXTENSION AND INSTALL 5 PROTECTORS AND 2 FLATGUARDS. 16:30 - 00:00 7.50 RUNCOM P RUNCMP RUN IN HOLE WITH 2-7/8"6.5#,EUE 8RD TUBING ESP COMPLETION TO 7057'. -INSTALL CLAMPS ON EVERY OTHER JOINT. -TEST CONDUCTIVITY EVERY 2000'. -PUMP 5 BBL THROUGH PUMP AND MOTOR EVERY 2000'AT 2 BPM,40 PSI. CONTINUOUS HOLE FILL AT 30 BPH. 24 HRS LOSSES=737 BBLS 8.5 PPG SEAWATER. 11/27/2013 00:00 - 01:00 1.00 RUNCOM P RUNCMP SPCC CHECKS AND PRE-TOUR MEETING. -CHECK CROWN-O-MATIC. RUN IN HOLE WITH 2-7/8"6.5#,EUE 8RD TUBING ESP COMPLETION. -INSTALL CLAMPS ON EVERY OTHER JOINT. I -TEST CONDUCTIVITY EVERY 2000'. -PUMP 5 BBL THROUGH PUMP AND MOTOR EVERY 2000'AT 2 BPM. ;-MAINTAIN CONTINUOUS HOLE FILL WITH 8.5 PPG SEAWATER AT 30 BPH. 01:00 - 05:30 4.50 RUNCOM P RUNCMP PERFORM ESP CABLE SPLICE AT 7884'MD. -CENTRILIFT REP TEST CONDUCTIVITY. 05:30 - 12:00 6.50 RUNCOM P RUNCMP RUN IN HOLE WITH 2-7/8"6.5#,EUE 8RD TUBING ESP COMPLETION. -INSTALL CLAMPS ON EVERY OTHER JOINT. -TEST CONDUCTIVITY EVERY 2000'. -PUMP 5 BBL THROUGH PUMP AND MOTOR EVERY 2000'AT 2 BPM. 12:00 - 12:30 0.50 RUNCOM P RUNCMP CREW SERVICE RIG AND INSPECT FLOOR EQUIPMENT. -CHECK CROWN-O-MATIC. 12:30 - 13:00 0.50 RUNCOM P RUNCMP RUN IN HOLE WITH 2-7/8"6.5#,EUE 8RD TUBING ESP COMPLETION. -INSTALL CLAMPS ON EVERY OTHER JOINT. -TEST CONDUCTIVITY EVERY 2000'. -PUMP 5 BBL THROUGH PUMP AND MOTOR EVERY 2000'AT 2 BPM. Printed 12/9/2013 11:43:50AM North America-ALASKA-BP Page 6 of 7 Operation Summary Report Common Well Name:MPF-50 AFE No Event Type:WORKOVER(WO) I Start Date:11/23/2013 End Date: 11/28/2013 X4-00YF4-E:(1;850,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/12/1997 12:00:00AM Rig Release:11/28/2013 Rig Contractor:DOYON DRILLING INC. UWI:500292275600 Active datum:Kelly Bushing/Rotary Table @31.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 13:00 - 15:30 2.50 RUNCOM P RUNCMP M/U HANGER AND LANDING JOINT. -FMC REP.INSTALL TWC PRIOR TO LANDING HANGER. -P/U LANDING JOINT AND M/U IN HANGER. -INSTALL PENETRATOR AND ATTACH FIELD CONNECTOR PLUG INTO PENETRATOR AND TEST. 15:30 - 16:30 1.00 RUNCOM P ! RUNCMP LAND TUBING HANGER. -PUW=137K,SOW=72K,INCLUDES 40K BLOCK WT. -FMC REP.RILDS. -RAN 5 PROTECTORS,2 FLAT GUARDS AND 226 CANNON CLAMPS. -L/D LANDING JOINT. 16:30 - 18:00 1.50 RUNCOM P RUNCMP TEST TWC. -ATTEMPT TO TEST F/BELOW. -PUMP 7 BPM,50 PSI F/5 CHARTED !MINUTES. -TEST F/TOP 250 PSI LOW,3500 PSI HIGH F/ 5 CHARTED MINUTES EACH. 18:00 - 20:00 2.00 RUNCOM P RUNCMP N/D BOPE. DRAIN OUT STACK AND BLOW DOWN LINES. 20:00 - 20:30 0.50 RUNCOM P RUNCMP CENTRILIFT REP TO MAKE FINAL CONDUCTIVITY TEST. 20:30 - 00:00 3.50 RUNCOM P RUNCMP N/U TUBING HEAD ADAPTER AND FMC 2-9/16" 5M TREE. -FMC TEST TUBING HEAD ADAPTER TO 5000 PSI FOR 30 MINUTES. -TEST TREE TO 250 PSI LOW,5000 PSI HIGH F/5 CHARTED MINUTES. 24 HRS LOSSES=737 BBLS 8.5 PPG SEAWATER. 11/28/2013 00:00 - 01:00 1.00 RUNCOM P ' RUNCMP 1SPCC CHECKS AND PRE-TOUR MEETING. CHECK CROWN-O-MATIC. PJSM,R/U WELL SUPPORT LUBRICATOR TO PULL TWC. -PRESSURE TEST LUBRICATOR T/250 PSI LOW,3500 PSI HIGH F/5 CHARTED MINUTES EACH. -PULL TWC. 01:00 - 02:00 1.00 RUNCOM P RUNCMP PJSM,R/U WELL SUPPORT LUBRICATOR TO SET BPV. 1-PRESSURE TEST LUBRICATOR T/250 PSI 1 LOW,3500 PSI HIGH F/5 CHARTED MINUTES EACH. -SET BPV. -R/D LUBRICATOR AND LID. 02:00 - 02:30 0.50 RUNCOM P RUNCMP R/U AND ATTEMPT ROLLING PRESSURE TEST ON BPV. -ATTEMPT PRESSURE TEST F/BELOW AT 3 BPM W/0 PSI. 02:30 - 03:30 1.00 RUNCOM P RUNCMP BLOW DOWN AND RIG DOWN LINES IN CELLAR. Printed 12/9/2013 11:43 50AM • North America-ALASKA-BP Page 7 of 7 Operation Summary Report Common Well Name:MPF-50 AFE No Event Type:WORKOVER(WO) Start Date:11/23/2013 End Date:11/28/2013 X4-00YF4-E:(1,850,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/12/1997 12:00:00AM Rig Release:11/28/2013 Rig Contractor:DOYON DRILLING INC. UWI:500292275600 Active datum:Kelly Bushing/Rotary Table @31.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 03:30 - 06:00 2.50 RUNCOM P RUNCMP PJSM,PUMP FREEZE PROTECT. -R/U AND TEST FREEZE PROTECT T/250 PSI LOW,3500 PSI HIGH. -PUMP 75 BBLS DIESEL DOWN IA AT 0 PSI. -PUMP 15 BBLS DIESEL DOWN TUBING AT 0 PSI. RELEAESE DOYON 16 FROM MPF-50 TO MPL-09 AT 06:00 ON 11/28/2013. 06:00 - RUNCOM P RUNCMP Printed 12/9/2013 11:43:50AM I Tree:FMC 2 9/16"x 5M C Orig. 1 .lev. =41.7 ' (N 22E) Wellhead:11"x 7 1/16"5M spool M P F�JO Orig. GL Elev. = 12.4' 7-1/16"x 2-9/16" hng.3" LH acme / ' ;' RT To Tbg. Spool = 28.50' (N 22E) Top&btm. 2-9/16"ciw BPV • 20" 91.1 ppf, H-40 112' c g I Camco 2 7/8" x 1" 139' sidepocket KBMM GLM KOP @ 600' c Max. hole angle =70 to 75 deg. f/ r 3,600' to 13,021' c (_' Hole angle thru' perfs =28 deg. I• • I 9 5/8", 40#/ft, L-80 Btrc. 9,099' •, €, % ` • 7"26 ppf, L-80, BTC-Mod production / ; Camco 2 7/8"x 1" casing % sidepocket KBMM GLM 14,876' (drift ID = 6.151", cap. = 0.0383 bpf ) / g3 d•• 1'ime, 1 2-7/8" XN Nipple (2.250" I.D.) 15,019' O GPDIS Discharge Head 15,061' % ' 0 t i Pump SDX 141-P6 15,062' 0-®. Gas Separator 15,094 . : GRSFTXAR Marker Jts 15,088' - 15,129' X 1 Centrilift Seal Section t GSB3DB UT/LT SB/SB PFSA 15,099 Motor- MSP-250 Perforation Summary 126 HP, 2450 volt, 31 amp 15,113' Ref log: GR/CCL 05/06/97 ail Too 2 intervals below added 5/26/05 RWO Phoenix XT-150 Type"0" 15,126' w/6 fin Centralizer Size SPF Interval (TVD) — 3 3/8" 6 15252-15262' 7165-7174' 3 3/8" 6 15272-15282' 7182-7192' 3 3/8" 6 15294-15314' 7214-7232' — Mid-perf=7199' tvd 15283' and (Tagged 7/29/97 15,575' ) •A. *. ..•■•■•■•6 . 7"float collar(PBTD) 15,578' 7"float shoe 15,663' DATE REV.BY COMMENTS MILNE POINT UNIT 06-09-97 MDO ESP completion 4ES 07/30/97 MDO 2nd. ESP Completion 4ES WELL MPF-50 4/6/00 GMH 3rd ESP Completion Nabors 4ES 07/30/04 JRC 4th ESP Completion Nabors 4ES 5/26/05 LH Elective pull and add pert Nabors 4ES API NO: 50-029-22756-00 3/29/08 LH ESP CO and FCO Nabors 3S _ 7/21/10 REH ESP c/o Nabors 4ES 7/21/10 B.Bixby ESP 0/0 Doyon 16 BP EXPLORATION (AK) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 5 � Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ` 5 333 West 7 Avenue 1� Anchorage, Alaska 99501 �I 1 Subject: Corrosion Inhibitor Treatments of MPF -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator II 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPF -Pad 10/29/2011 Corrosion I Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls ft Pal MPF -01 1950450 50029225520000 10.2 N/A 10.2 N/A 122.4 8/7/2011 MPF-02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF-05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 1.2 N/A 15.3 8/212011 MPF-09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 8/2/2011 MPF -13 1950270 50029225490000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 816/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 8/2/2011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/1/2011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/9/2011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF -33 2010620 50029226890000 23 Need top job MPF-34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF -37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 • MPF -41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF-42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF-45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A N/A MPF-49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 """4 " MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF-61 1951170 50029225820000 62 Need top job MPF -62 1951610 50029226090000 2.0 NN 2.0 N/A 13.6 9/1/2011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/31/2011 MPF-69 1951250 50029225860000 0.8 N/A 0.8 N/A 8.5 8/42011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/312011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 WA 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/312011 MPF -77 1951360 50029225940000 0.2 N/A 0.2 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 N/A 5.1 7/312011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 N/A 6.8 8/3/2011 MPF -80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 813/2011 MPF-81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/32011 MPF-82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/32011 MPF-83 2000930 50029229630000 1.2 N/A 1.2 N/A 13.6 8/3/2011 MPF -84B 2001760 50029229310200 1.2 N/A 1.2 N/A 102 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF-86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/12/2011 MPF -87A 2032130 50029231840100 1.3 NIA 1.3 N/A 11.9 8/13/2011 MPF -88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 813/2011 MPF -89 2050900 50029232680000 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/132011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/13/2011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 N/A 7.7 9/12011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/132011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/1/2011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/11/2011 STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5® Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 197-058 3. Address: ^ Service ^ Stratigraphic .API Number. P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22756-00-00 7. Property Designation: ~ 8. Well Name and Number: ~ ADL 025509 &ADL 355018 'MPF-50 9. Field /Pool(s): ~ Milne Point Unit / Kuparuk River Sands 10. Present well condition summary Total depth: measured 15685 feet true vertical 7551 feet Plugs (measured) None Effective depth: measured 15578 feet Junk (measured) None true vertical 7455 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 110' 110' 1490 470 Surface 9068' 9-5/8" 9099' 4603' 5750 3090 Intermediate Production 15635' 7" 15663' 7531' 7240 5410 Liner A,. ~\it ~t.. ~ S1 '~~~}il} Perforation Depth: Measured Depth: 15252' - 15314' True Vertical Depth: 7165' - 7220' Tubing (size, grade, measured and true vertical depth): 2-718" 6.5#, L-80 15152' 7076' Packers and SSSV (type, measured and true vertical depth): None None 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: ~ ~ ~ t gro q^ gY'[~ M J xFSe~+~ 4j?,y!'#bROdSIQ~I " ~ ~ ~~A a ~ . . f ,a; 12. Representative Daily Average Production or Injection Dafa' Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 336 33 227 280 297 13. Attachments: ^ Copies of Logs and Surveys run 14. Well Class after work: ' ^ Exploratory ®Development ^ Service ® Dail Re ort of Well O erations y p p ® Well Schematic Diagram 15. Well Status after work: ®Oil ^ Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N!A if C.O. Exempt: Contact Mehrdad Nadem, 564-5941 N/A Printed Name Sondra Stewman Title Drilling Technologist / Prepared ey Name/Number. ~' ' ignature Phone 564-4750 D at ~.(- ~~ Sondra Stewman, 564-4750 Form 10-404 Revised 07/2009 ~ ~ Submit Original Only RBDM~ ~~ ~~~ ~t~ ~~> Tree:FMC 2 9/16" x 5M M P F-5~ Orig. KB = 41.7 ' (N 22E) Wellhead:11" x 7 1/16" 5M spool Orig. GL Elev. = 12.4' 7-1/16"x 2-9/16" hng. 3" LH acme ~ RT To Tbg. Spool = 28.50' (N 22E) Top & btm. 2-9/16" ciw BPV 20" 91.1 ppf, H-40 112' KOP @ 600' Max. hole angle = 70 to 75 deg. f/ 3,600' to 13,021' Hole angle thru' perfs = 28 deg. 9 5/8", 40#/ft, L-80 Btrc. 9,099' I Camco 2 7/8" x 1" 136' sidepocket KBMM GLM 7" 26 ppf, L-80, BTC-Mod production casing ( drift ID = 6.151", cap. = 0.0383 bpf ; Marker Jts 15,088' - 15,129' Pertoration Summary Ref loa: GR/CCL 05/06/97 Ton 2 intervals below added 5/26/05 RWO Size SPF Interval (TVD) 3 3/8" 6 15252 -15262 7165 -7174' 3 3/8" 6 15272 -15282 7182 -7192' 3 3/8" 6 15294 -15314 7214 -7232' Mid-pert = 7199' tvd 15283' and DATE IREV. BY I COMMENTS 5/26/05 LH Elective pull and add pert Nabors 4ES 3/29/08 LH ESP CO and FCO Nabors 3S 7/21/10 REH ESP c/o Nabors 4ES Camco 2 7/8" x 1" 14 937" sidepocket KBMM GLM ' 2-7/8" XN Nipple (2.205" I.D.) 15,079' GPDIS Discharge Head 15,092' Pump 161 P11 SDX, 15,093' Gas Separator 15 115' GRSFTXARH6 , Centrilift Seal Section 120' 15 GS63D6 UT/LT SB/SB PFSA/PFSA CL6 , Centrilift KMH Motor 134' 15 152 HP, 2325 volt, 40 amp , PumpMate XTO sensor 15,148' w/6 fin Centralizer ( Tagged 7/29/97 15,575' ) 7" float collar (PBTD) 15,578' 7" float shoe 15,663' MILNE POINT UNIT WELL MPF-50 API NO: 50-029-22756-00 BP EXPLORATION • • North America -ALASKA - BP P<,ye i of ~ Operation Summary Report Common Well Name: MPF-50 DIMS AFE No Event Type: MOBILIZATION (MOB) Start Date: 7/15/2010 End Date: 7/16/2010 X4-0009E-E (50,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 51:50 4/4/2000 12:00 @31.4ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations __ (hr) (ft) 7/15/2010 06:00 - 08:00 2.00 RIGD P PRE PJSM. RIG DOWN RIG COMPONENTS, PREP TO _ SCOPE DOWN DERRICK. 08:00 - 10:00 2.00 RIGD P PRE PJSM. SCOPE DOWN AND LAY OVER DERRICK. 10:00 - 11:00 1.00 RIGD P PRE CONTINUE TO RIG DOWN RIG COMPONENTS. 11:00 - 15:00 4.00 RIGD P PRE MOVE SUB, PIPE SHED AND MUD PITS OFF OF ____~ ~ MPI-13. 15:0 0120 0 6.00 RIGD P _ PRE'' PJSM. MOVE OFF I PAD AND MOVE RIG __ _ COMPONENTS TO MPF PAD. 21:00 - 00:00 ___ 3.00 ___ RIGD P i PRE _ PJSM. SPOT CAMP, SHOP, LAY MAT BOARDS AND SPOT SUB OVER MPF-50. -DS OPERATOR NOTIFIED OF SUB SPOTTING OVER WELL. -WSL WITNESSED SUB SPOTTING OVER WELL. 7/16/2010 00:00 - 02:00 2.00 RIGD P PRE PJSM. RAISE DERRICK AND SCOPE UP. FINISH RIGGING UP. RIG ACCEPTED @ 02:00, ~ _ `, 07/16/2010. Printed 8/10!2010 11:19:46AM • North America -ALASKA - BP Page 1 or 3 Operation Summary Report Common Well Name: MPF-50 DIMS AFE No Event Type: WORKOVER (WO) i Start Date: 7/15/2010 End Date: 7/21/2010 X4-0009E-E (400,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES ~ Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 51:50 4/4/2000 12:00 @31.4ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ 7/16/2010 02:00 - 05:30 3.50 WHSUR P DECOMP PJSM. TAKE ON 8.4, 110 DEG SEAWATER TO PITS. -RIG UP LINES TO TIGER TANK AND TREE. -RIG UP LUBRICATOR, TEST TO 500 PSI, OK. -PULL BPV. L/D LUBRICATOR. ' -TBG = 270 PSI OA = 200 PSI 05:30 - 06:00 _ 0.50 KILLW P __ DECOMP PRE KILL SAFETY MEETING WITH ALL PARTIES INVOLVED. 06:00 - 06:30 0.50 KILLW P DECOMP ` RFG SERVICE AND PERFORM PRE-TOUR CHECK -WEEKLY CREW CHANGE 06:30 - 12:00 5.50 KILLW P bECOMP TESTED SURFACE LINE TO 3.500 PSI ONE`2" STEEL SWING FAILED TO TEST (WEEP HOLE) ' -TESTED DOWN STREAM LINES TO THE TIGER i TANK T© 500 PSL -WHP: TBG= 270 PSI, IA = 180 PSI, OA = 200 PSI. ~ BLEED OFF TBG AND IA: TBG = 250, IA = 0 PSI, OA =180 PSI -PUMP 130 BBLS 120 DEG F. 8.45 PPG, 2% KCL DOWN THE TBG AT (1 BPM / 220 PSI) -3 BPM / 30 PSI) (4 BPM / 60 PSI) CAUGHT FLUID - 74 BBLS AWAY, THEN -PUMP PRESSURE INCREASED TO 150-170 PSI. -STOP CLOSE CHOKE AND BULL HEAD 675 BBLS 120 ~~,$45 PG. 2% KCL.,_ -DOWN THE 2-3/8" X 7" ANNULUS, AT 4 BPM i /-550 - 1080 PSI -FINISHED WITH 3.5 BPM / 1080 PSI -BLEED OFF -TBG AND IA ON A VACUUM. 12:00 - 13:00 1.00 _ KILLW P DECOMP FMC WELL HEAD TECH INSTALL TWC I -TESTED FROM ABOVE TO 3,500 PSI F/ 5 ~ CHARTED MINUTES. __ __ 13:00 - 16:00 3.00 WHSUR P DECOMP PJSM. N/D TREE. 16:00 - 22:00 ~ 6.00 BOPSUR P DECOMP PJSM. N/U 13 5/8" X 5M BOPE. ~ -REPLACE STUDS ON ADAPTER THAT ARE A i LITTLE TOO SHORT. i -PUMPING 20 BBLS EVERY HOUR INTO I/A, WELL _ STABLE. 22:00 - 00:00 2.00 BOPSUR P DECOMP PJSM. RIG UP TEST EQUIPMENT TO TEST BOP_E..._ -TEST BOPE AS PER AOGCC REQUIREMENTS, 250 PSI LOW, 3500 PSI HIGH. -AOGCC REP BOB NOBLE WAIVED WITNESSING THE TEST. I -CHOKE HOSE FLANGE LEAKED, TIGHTENED ~ SAME. REPLACED SENSOR ON TEST SPOOL. - _ -t --- Printed 8/10/2010 11:20;31AM North America -ALASKA - BP Page 2 of a Operation Summary Report Common Well Name: MPF-50 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/15/2010 End Date: 7/21/2010 X4-0009E-E (400,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. ~ UWI: Active Datum: 51:50 4/4/2000 12:00 @31.4ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/17/2010 00:00 - 06:00 6.00 BOPSUR P DECOMP CONTINUE CONDUCTING INITIAL PRESSURE TEST OF 13 5/8" X 5M BOPE. HCR, (KILL SIDE), i ~ LEAKING. -TESTING ALL CHOKE VALVES AND MUD i CROSS VALVES AGAINST BLIND SHEAR RAMS ___ __ 250 / 3500 PSI. 06:00 - 06:30 0.50 BOPSUR P DECOMP .. PJSM-RIG SERVICE AND PERFORM PRE-TOUR _____ ___ __ .CHECKS. 06:30 - 08:30 2.00 BOPSUR N RREP DECOMP MAKE REPAIRS TO HCR Klll VALVE. Printed 8/10/2010 11:20:31AM r• • North America -ALASKA - BP Page 3 of 8 Operation Summary Report Common Well Name: MPF-50 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/15/2010 End Date: 7/21/2010 X4-0009E-E (400,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 51:50 4/4/2000 12:00 @31.4ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) ___ 08:30 - 18:00 ___ 9.50 ___ BOPSUR N SEAL DECOMP _RESUME BOPE TEST. -TOOK 45 MINUTES TO COMPLETE ONE TEST -BELIEVE TWC NOT HOLDING i -PU/MU 2-7/8" TEST JT TO CONFIRM FAILED TWC -200 PSI DROP IN (2) MINUTES -FEED WELL AT 20+ BPH DURING TESTING. =MU DUTCH SYSTEM. -11:30 HRS CALLED ADW RWO ENGINEER AND SUPERINTENDENT DISCUSSED PLAN FORWARD. -TESTED (HANGER-ESP PENETRATION AND TWC) AGAINST THE BLIND/SHEAR RAMS TO 500 PSI WITH A ROLLING TEST FOR 5 CHARTED MINUTES. i -PU/MU'AND TEST LUBRICATOR AGAINST THE BLINDS/SHEAR RAMS TO 500 PSI. GOOD TEST. i -14:15 HRS ~ -MPU WELL SUPPORT TECH PULLED TWC OFF SEAT, WITH 42 PSI ON TBG, SHUT IN IA (ON A VACUUM). -WHEN THE TWC WAS PULLED THE BLEED OFF ~ VALVE WAS PARTLY OPEN TO RELEASE ANY TRAPPED PRESSURE UNDER THE TWC IN TO THE FLOW-LINE. SETTING OFF THE METHANE GAS ALARM IN THE PITS. j THE CREW FOLLOW PROCEDURE AND EVACUATED TO THE i SHOP. DRILLER-TOOLPUSHER-WSL MADE RISK I I ASSESSMENT. i I -14:30 HRS CALLED ADW RWO ENGINEER AND SUPERINTENDENT DISCUSSED PLAN FORWARD. -ORDERED MORE SEAWATER. MADE ~ NOTIFICATIONS OF GAS VENTING TO MPU. i ( -15:30 HRS -PJSM WITH CREW -BLEED OFF TBG 42 PSI TO'0" PSI TO THE GAS BUSTER, INCREASED TO 17 PSI. BLEED TO'0', NO INCREASE. -CIRCULATED 3-4 BPM ACROSS WELL THROUGH THE CHOKE TO THE GAS BUSTER ~ -PUMPED 93 BBLS SEAWATER AT 4 BPM / 90 PSI THEN 43 BBLS 3-4 BPM / 130 PSI. FCP= 3.5 BPM / ~ 380 PSI -TBG ON A VACUUM, IA 16 PSI 16:30 HRS CALLED ADW RWO ENGINEER AND SUPERINTENDENT DISCUSSED PLAN FORWARD. -BLEED IA TO'0' AND CONTINUE TO FEED IA ~ WITH 2O-30 BPH SEAWATER, TBG AND IA ON A VACUUM. Printed 8/10/2010 11:20:31AM ~ 1 North America -ALASKA - BP Page a of 8 Operation Summary Report __ Common Well Name: MPF-50 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/15/2010 End Date: 7/21/2010 X4-0009E-E (400,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 51:50 4/4/2000 12:00 @31.4ft (above Mean Sea Level) Date From - To Hrs Task ~ Code NPT NPT Depth Phase Description of Operations _______________ _ (hr) ' (n) 118:00 - 20:00 2.00 BOPSUR N _ SEAL __ DECOMP pJSM. CALLED OUT FOR FMC HAND TO INSTALL ~ TWC. PUMPED (1) TUBING VOLUME. -4BPM / 90 PSI, HIT FLUID W/ 44 BBLS AWAY @ 6700', CONTINUED PUMPING @ 3 1/2 BPM / 400PSI. -PUMPED 88 BBLS & SHUT DOWN, TUBING IS ON ' A VACUUM. ____ ___ 20:00 - 21:30 1.50 BOPSUR N SEAL DECOMP PJSM. SET TWO WAY CHECK VALVE. TEST SAME @ 3500 PSI, PUMP BACK UP SEVERAL TIMES. -TESTSGETTING PROGRESSIVELY BETTER, BUT _ ' __ 21:30 00:00 2.50 BOPSUR N ~ SEAL DECOMP UNABLE TO ATTAIN A GOOD TEST. CONSULT WITH TOWN ENGINEER REGARDING NEW PLAN FORWARD. -DISCUSS PULLING TUBING HANGER & RUNNING STORM PACKER. I -ENGINEER GENERATING E-MOC AND ' SUBMITTING SAME TO UPPER MANAGEMENT. I i -CALL MADE TO GET HALLIBURTON STORM I I PACKER HEADED THIS WAY. -.PICKUP 2 7/8" TEST JT & TEST PIPE RAMS & ANNULAR @ 500 PSI, OK. 7/18/2010 --- 00:00 - 02:00 2.00 BOPSUR N SEAL - DECOMP PJSM. DISCUSS MODIFIED PLAN FORWARD APPROVED BY ENGINEER. -NOTIFY STATE AOGCC REP LOU GRIMALDI & GET APPROVAL TO PULL TBG HANGER & SEL I STORM PACKER TO TEST BOPE. -PICK UP LUBRICATOR, TEST TO 500 PSI 8 PULL TWO WAY CHECK VALVE. 02:00 - 04:30 2.50 BOPSUR N SEAL __ DECOMP PJSM. M/U LANDING JT. BOLDS. PULL HANGER TO FLOOR, 110 MAX UP WT. 04:30 - 06:00 1.50 BOPSUR N SEAL DECOMP pJSM. L/D TUBING HANGER~SECURE ESP CABLE TO TUBING. -C/O ELEVATORS. PREP TO PULL 2 7/8"TUBING. 06:00 - 07:00 1.00 BOPSUR N SEAL DECOMP pU /MU 7" 26# STORM PACKER -PER HALLIBURTON REP -RIH FROM DERRICK (1) STAND AND (1) JOINT TO 123' MD. _ 07:00 - 08:00 1.00 BOPSUR N SEAL DECOMP _ -PUMP 90 BBLS SEAWATER DOWN THE TBG, 3 BPM / 40 PSI AND -15 BBLS IN TO THE IA. TBG AND IA ON A ~ VACUUM. 08:00 - 11:00 3.00 BOPSUR ~ N RREP DECOMP SET AND TEST 7" STORM PACKER -AT 123' MD PUW =95K, SOW = SOK. -POH L/D 4 JOINT 2-7/8" TBG AND RUNNING TOOL. -BLIND/SHEAR RAMS FAILED TO TEST AGAINST THE STORM PACKER. -PU 2-7/8" DONUT TEST JOINT AND TESTED STORM PACKER. -TESTED TO 3500 PSI FOR 10 CHARTED __ _ _ _ _ ~ I -t - MINUTES. GOOD TEST _ 11:00 - 12:00 1.00 BOPSUR N RREP DECOMP DRAIN STACK, MU AND INSTALL TEST PLUG. Printed 8/10/2010 11:20:31AM r~ North America -ALASKA - BP Page 5 of 8 Operation Summary Report __ __ Common Well Name: MPF-50 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/15/2010 End Date: 7/21/2010 X4-0009E-E (400,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 51:50 4/4/2000 12:00 @31.4ft (above Mean Sea Level) Date From - To Hrs Task Code NPT ~ NPT Depth Phase i Description of Operations (hr) __ _ I (ft) 12:00 - 18:00 6.00 BOPSUR N RREP DECOMP PJSM. REMOVE CHOKE LINE TO ENABLE OPENING RAM DOORS. - REMOVE BLIND/SHEAR RAMS AND REPLACE ~ RUBBER SEAL ELEMENT. -RE INSTALL RAM BLOCKS & RE CONNECT - CHOKE LINE TO MUD CROSS. 18:00 - 19:00 1.00 BOPSUR - N -- RREP DECOMP --- ~ CLOSE BLIND SHEAR RAMS, FLUID PACK MUD CROSS. -BLIND SH AR RAM AKIN HORR NDOUSLY WITH JUST CHARGE PUMP ON. -DRAINSTACK, KICK ON CHARGE PUMP AND ~ ~ i OBSERVE FLUID LEAKING BY BLIND SHEAR _ RAMS. 19:00 - 22:00 ~ 3.00 BOPSUR N RREP DECOMP pJSM. REMOVE'CHOKE LINE, OPEN RAM DOORS. -INSPECT'RAM BLOCKS, SEALS NOT TIGHTLY BOUND BY SEAL PROFILE IN RAM BLOCKS. -CONSULT MECHANIC, INSTALL REPLACEMENT SET OFREDRESSED RAM BLOCKS. ~ -RE CONNECT CHOKE LINE TO MUD CROSS. 22:00 - 00:00 i 2.00 BOPSUR P t DECOMP pJSM. FLUID PACK MUD CROSS. CLOSE BLIND -SHEAR RAMS. -TEST BLIND SHEAR RAMS AGAINST HCR VALVES, 250/3500 PSI, GOOD TEST. -CONDUCT FULL BOPE TEST AS PER AOGCC REQUIREMENTS. ~ -WITNESSING OF TEST WAIVED BY BOB NOBLE. ~ I -TEST ALL COMPONENTS @ 250-3500 PSI, 5 MIN EACH TEST. 7/19/2010 _ 00:00 - 03:30 3.50 BOPSUR P _ _ ___ _ DECOMP CONTINUE TO CONDUCT FULL BOPE TEST. -TEST ALL CHOKE VALVES AND VALVES ON MUD CROSS -TEST 2 7/8" X 5" VBRS AND ANNULAR -TEST BLIND SHEARS AND SURFACE SAFETY I VALVE -ALL TESTS 250/3500 PSI, 5 MIN, CHARTED. NO _______ __ _ FAILURES. _ _____ 03:30 - 04:00 04 00 05 00 ~ 050 1 BOPSUR DHB P P DECOMP MP M/U LANDING JOINT, PULL TEST PLUG. " : - : .00 DECO pJSM. RIH W/ (4) JTS 2 7/8 EUE 8 RND TBG & RETRIEVING TOOL. Printed 8/10/2010 11:20:31AM North America -ALASKA - BP Page 6 of e Operation Summary Report Common Well Name: MPF-50 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/15/2010 End Date: 7/21/2010 X4-0009E-E (400,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 51:50 4/4/2000 12:00 @31.4ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations ____ (hr) (ft) 05:00 - 06:00 1.00 _ DHB _ P DECOMP _ _ _ SAFETY VALVE ON LAST JOINT & CLOSED, CIRC HOSE ATTACHED. -TAG TOP OF PACKER @ 123'. POP IN TO START THREADS. -21 TURNS TO THE RIGHT, OPEN SAFETY VALVE, NO PRESSURE ON GAUGE. -CHECK AND OBSERVE STRONG VACUUM ON TUBING. ~ ~ -CLOSE ANNULAR, PICK UP TO RELEASE ~ . PACKER, UP TO 110K & BROKE OVER. -PACKER RELEASED. CHECK FOR PRESSURE VIA KILL LINE, NO PRESSURE. =OPEN ANNULAR,'FLUID STATIC IN FLOW I NIPPLE. i -TURN 114 TURN TO THE LEFT & SLACK OFF, GO ~ DOWN PAST SETTING DEPTH. ~ -FLUID DROPS IN FLOW NIPPLE WHEN GOING ~ DOWN & RISES WHEN PULLING UP. -CLOSE ANNULAR AND PUMP PAST PACKER ELEMENTS DOWN KILL LINE, 1 BPM / 300 PSI. -PUMPED TOTAL OF 25 BBLS SEAWATER. STOP _ __ _ _ __ __ PUMPS OFF, TBG & IA ON A VACUUM. 06:00 - 06:30 0.50 _ DHB P ~ _ DECOMP PJSM-OPEN ANNULAR ,LET ELEMENTS RELAX WHILE PUMPING DOWN KILL LINE PAST PACKER ELEMENTS ~ -AT 1.5 BPM / 300 PSI, -PUMPED TOTAL OF 25 ~ BBLS SEAWATER. ~ ~ ~ -PUMP 90 BBLS DOWN THE TBG, CATCH FLUID j WITH 32 BBLS AWAY ~ ~ _ -4 BPM / 600 PSI. TBG & IA ON A VACUUM ___ _ ___ i __ O 6:30 - 07:30 1.00 _ DHB _ P _ DECOMP pOH (1) STAND AND UD (1) JOINT 2-7/8" TBG -BO / LD 7" STORM P -FEED WELL CONTINUALLY AT 20-30 BPH 07:30 - 09:30 2.00 EVAL P DECOMP pJSM-RIH (2) STANDS FROM DERRICK, P/U (7 ~ JOINTS) 2-7/8" TBG FROM PIPE SHED -AND TAG FILL WITH 5K DOWN WT. WITH 25 FT i IN ON JOINT #8. -TOP OF FILL: 15,343' MD. 09:30 - 16:00 ~ 6.50 PULL P i DECOMP pJSM WITH CENTRILIFT REP -POH FROM 15,343' MD AND UD (8) JTS -POH FROM 15,110' MD WITH ESP COMPLETION. -PULL ESP CABLE OVER SHEAVE IN DERRICK AND ATTACH TO SPOOLER. -STAND 2-7/8" TBG IN DERRICK I -FEED WELL CONTINUALLY AT 20-30 BPH _ _ _ 16:00 - 16:30 _ 0.50 _ PULL P ( ___ DECOMP pOH TO -10,400' MD, PUMPED 50 BBLS j SEAWATER DOWN THE TBG. j ~ -CATCH FLUID AT 46 BBLS AWAY __ 16:30 - 18:00 1.50 PULL P ~ DECOMP RESUME POH W/ ESP COMPLETION ON 2-7/8" I ~ ~ TBG -FEED WELL CONTINUALLY WITH 2O-30 BPH 18:00 - 18:30 I 0.50 PULL P I _ _ DECOMP SERVICE RIG, CHECK CROWN O MATIC, ~ ~ j PERFORM MAINTENANCE DUTIES. Printed 8/10/2010 11:20:31AM r North America -ALASKA - BP Page ~ of 8 Operation Summary Report Common Well Name: MPF-50 DIMS AFE No Event Type: WORKOVER (WO) ~ Start Date: 7/15/2010 End Date: 7/21/2010 X4-OOQ9F-E (400,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 51:50 4/4/2000 12:00 @31.4ft (above Mean Sea Level) Date From - To Hrs Task Code NPT I NPT Depth Phase Description of Operations (hr) (ft) 18:30 - 19:00 0.50 PULL P DECOMP CONTINUE TO POOH W/ 2 7/8" ESP COMPLETION ___ _ ___ STRING. 78 STANDS OUT. 19:00 - 20:00 1.00 PULL P DECOMP PJSM. CHANGE OUT SPOOLS FOR ESP CABLE. 20:00 - 00:00 4.00 PULL P DECOMP CONTINUE TO POOH W/ 2 7/8" ESP COMPLETION I i STRING. ~ -PUMP TUBING VOLUME EVERY 50 STANDS -30 BBLS / HR FED INTO ANNULUS, OVER AND ~ ABOVE PIPE DISPLACEMENT. I -BOP DRILL WHILE POOH. WELL SECURE AND I ALL HANDS ON STATION, 2 MIN 16 SE C. 7/20/2010 00:00 - 03:00 3.00 _ ~ PULL __ ___ P DECOMP _ _ _ CONTINUE TO POOH W/ 2 7/8" ESP COMPLETION. -CONSTANT HOLE FILL @ 30 BPH OVER ___ __ ___ DISPLACEMENT. 03:00 - 05:00 ____ 2.00 __ PULL P DECOMP ___ PJSM. UD MOT CLEAR / CLEANRIG FLOOR. _ 05:00 - 06:00 1.00 ~ PULL P ` DECOMP PUMP 30 BBLS SEAWATER DOWN WELL BORE. -WORK ON MUD PUMP SWABS f -PREPARE TO RIH W/ 2 7/8" ESP COMPLETION ~ STRING. 06:00 - 13:30 7.50 RUNCMM P RUNCMP CONTINUE TO PREPARE TO RUN ESP i I ~ COMPLETION. I -BRING IN NEW PUMP, LA SALLE CLAMPS ~ -CHANGE OUT ESP CABLE SPOOL j -WORK ON MUD PUMP, C/O LINERS & SWABS ~ -PRESSURE TEST MUD PUMP INCREMENTALLY UP TO 3500 PSI. -ADD SEAWATER TO WELLBORE THROUGHOUT OPERA TI ON 13:30 - 18:00 ~ ________ 4.50 ____ _ RUNCOM P _ RUNCMP _ _ PJSM. MAKE UP AND SERVICE ESP PUMP. -PULL ESP CABLE OVER SHEAVE 8 SECURE TO PUMP -M/U PUPS, X NIPPLE & (1) JT TBG, TEST ESP CABLE, OK. -RIH (1) STND, GLM ASSEMBLY & TEST ESP CABLE, OK. ~ 18:00 - 00:00 6.00 RUNCOM P ____ _ _ __ _ RUNCMP RIH ~^!/ 2 7/fl" FI IF R Anin eeo rn•eoi CTlllnl PJSP/] I , ~ STRING -USING BEST O LIFE 2000 PIPE DOPE ~ -TORQUING ALL CONNECTIONS TO 2300 FT/LBS ~ I -CHECK CONDUCTIVITY ON ESP CABLE EVERY ; 20 STANDS -PUMP (5) BBLS DOWN TUBING WHEN CHECKING CONDUCTIVITY. -CONTINUOUSLY FILLING WELL BORE @ 30 BPH. -81 STANDS IN, PUMP (5) BBLS TO CLEAR PUMP, 1 BPM. 7/21/2010 00:00 - 04:00 I 4.00 RUNCOM ( P RUNCMP __ PJSM. MAKE REEL TO REEL SPLICE & C/O SPOOLS ESP CABLE. Printed 8/10/2010 11:20:31AM North America -ALASKA - BP Page 8 of 8 Operation Summary Report ___ Common Well Name: MPF-50 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7115/2010 End Date: 7/21/2010 X4-OOQ9F-E (400,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: NABORS 4ES Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 51:50 4/4/2000 12:00 @31.4ft (above Mean Sea Level) Date i From - To Hrs ~ Task i Code NPT NPT Depth I Phase Description of Operations ' (hr) (n) ---- - - _ _ 04:00 - 06:00 2.00 RUNCMM P -- RUNCMP CONTINUE TO RIH W/ 2 7/8" ESP COMPLETION, CHECKING CONDUCTIVITY EVERY 20 STANDS. I -PUMPING 5 BBLS DOWN TUBING EVERY 20 STANDS -FEEDING WELL BORE 30 BPH, SEAWATER. _ _ ___ 06:00 - 07:00 1.00 RUNCMM P ___ RUNCMP CREW CHANGE. SERVICE RIG -CHECK AND SET PVT ALARMS -ENVIRONMENTAL WALK AROUNDS. 07:00 - 11:00 4.00 ~ RUNCOM P i RUNCMP CONTINUE TO RIH W ESP COMPLETION ON 2-7/8" TUBING FROM DERRICK. I -FEEDING THE WELLBORE CONTINUOUSLY AT I 30 BPH, WITH SEAWATER. -CHECKING CONDUCTIVITY EVERY 20 STANDS. I -PUMPING 5 BBLS DOWN THE TUBING EVERY 20 STANDS. -RUNNING LA SALLE CABLE CLAMPS ON EVERYDTHER JOINT. 11:00 - 11:30 0.50 RUNCOM " P RUNCMP,' RU TO PICK UP TL~?iNr. untir_Fa :CHANGE ELEVATORS. j -RD TUBING TONGS. _ _ ___ 11:30 - 12:00 ~ ___ __ 0.50 RUNCMM P RUNCMP pU AND MU FMC 7-1/16" X 2-7/8" TUBING ; HANGER AND PUP. -INSTALL NEW ESP PENETRATOR IN HANGER ~ BODY. 12:00 - 14:30 2.50 RUNCMM ~ P RUNCMP CENTRILIFT -PREPARE AND MU FIELD SPLICE FOR ESP PENETRATOR. -RIG CREW RD TUBING HANDLING EQUIP__MENT. 14:30 - 15:00 0.50 RUNCOM P _ RUNCMP LAND TUBING HANGER -PUW = 95K LBS; SOW = 50K LBS. -R.I.L.D.S. - ---- 15:00 - 16:00 1.00 WHSUR P RUNCMP TEST TWC IN HANGER PROFILE TO 3500 PSI FOR I 5 CHARTED MINUTES -GOOD TEST. _ 16:00 - 21:30 5.50 WHSUR _ P ~ RUNCMP pJSM N/D 13-5/8 5M BOP STACK AND STAND I ' BACK. -REMOVE 2 7/8" X 5" VBRs, REMOVE BLIND i SHEAR RAMS. -N/D OUTER ANNULUS FLANGES. __ __ 21:30 - 00:00 ___ 2.50 WHSUR P _ RUNCMP pJSM NLU ADAPTER & FMC 2 9/16" X 5M TREE -TEST TREE AND VOID W/ DIESEL TO 5000 PSI, GOOD TEST. I -MAKE FINAL CONDUCTIVITY CHECK ON ESP, OK. -R/U LUBRICATOR, TEST @ 500 PSI, PULL TWC, ~ ~ INSTALL BPV. ( ~ ~ -L/D LUBRICATOR, SECURE WELL, RIG I ~ RELEASED @ 00:00 HRS. Printed 8/10/2010 11:20:31AM STATE OF ALASKA ~ MQY ~, ~ ~~~~ ALA OIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL OPERATIONS Alaska (iii ~~~~• Commiss"p 1.Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other MENT- Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension `~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ >~ 2.Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 1~ Exploratory •~ 197-0580 - 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number. Anchorage, AK 99519-6612 50-029-22756-00-00 7. KB Elevation (ft): 9. Well Name and Number: 41.7 KB MPF-50 - 8. Property Designation: 10. Field/Pool(s): ADLO-355018 • MILNE POINT Field/ KUPARUK RIVER OIL Pool 11. Present Well Condition Summary: Total Depth measured 15685 feet Plugs (measured) None true vertical 7550.86. feet Junk (measured) None Effective Depth measured 15578 feet true vertical 7455 feet Casing Length Size MD TVD Burst Collapse Conductor 78 20" 91.1# H-40 Surface - 110' Surface - 110 1490 470 Surface 9068 9-5/8" 40# L-80 Surface - 9099 Surface - 4603 5750 3090 Production 15635 7" 26# L-80 Surface - 15663 Su 7240 5410 rface - 7531 A / ~/ y- -t F.s#~l ~Yw$.:i~ ~i/'"Y ~~ ~i o Q ~ ~ f i~ V Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 SURFACE - 15141' 0 0 - Packers and SSSV (type and measured depth) NONE 0 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): r „~, '~ ~~ ~ ' . .. ~ ~~u1 `~ ~ 2CQ3 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 148 14 99 283 Subsequent to operation: 148 ~ 14 99 290 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG r GINJ ~ WINJ ~ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature `,.„/ ~ Phone 564-4944 Date 5/13/2009 Form 10-404 Reused 04/2006 ~ { ~ ~ ~ ~ ~ n ~ ~~ubmit Original Only MPF-50 197-058 PRRF ATTerHMFNT • Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPF-50 5/6/97 PER 15,294. 15,314. 7,201.91 7,219.65 MPF-50 5/26/05 PER 15,252. 15,262. 7,164.69 7,173.55 MPF-50 5/26/05 PER 15,272. 15,282. 7,182.41 7,191.27 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED 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 • MPF-50 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 4/18/2009 T/I/0=250/360/140 Pumped 10 bbls crude, 12 bbls 10 % DAD acid, 3 bbls I 60/40 methanol followed by 75 bbls crude down Tbg. DSO notified. swab wing shut, ssv master is oa open FWHP's=300/400/220 FLUIDS PUMPED BBLS 85 DEAD CRUDE 12 10% DAD ACID 3 60/40 METHANOL 100 Total STATE OF ALASKA ~ ~ >~ AL~ OIL AND GAS CONSERVATION COM~ION ~~~ ~ ~ 20 REPORT OF SUNDRY WELL OPERATIONS 08 Alaska rJf! & Gas I^.nnc r`n..,....r 1. Operations Performed: A11Ch01' ~ - ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 197-058 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22756-00-00 7. KB Elevation (ft): KBE = 41.70' ' 9• Well Name and Number: MPF-50 - 8. Property Designation: 10. Field /Pool(s): ADL 355018 ~ Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 15685 ' feet true vertical 7551 ~ feet Plugs (measured) None Effective depth: measured 15578 feet Junk (measured) None true vertical 7455 feet Casing Length Size MD ND Burst Collapse Structural Conductor 78' 20" 110' 110' 1490 470 Surface 9068' 9-5/8" 9099' 4603' 5750 3090 Intermediate Production 15635' 7" 15663' 7531' 7240 5410 Liner ~~~ APR ~ 2008 Perforation Depth MD (ft): 15252' - 15314' Perforation Depth TVD (ft): 7165' - 7220' 2-7/8" 6.5#, L-80 15141' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 1 gg 20 395 280 297 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 N/A if C.O. Exempt: Contact Nick Frazier, 564-5633 N/A Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number: Sign Lure Phone 564-4750 Date ~ '~9'- Sondra Stewman, 564-4750 Form 10-404~e sed 04/2006 ~ Submit Original Only ~~~ ~ ~ (` ~ ~ ~ ~ ~ ~~ ~~~ ~ 2008 Tree:FMC 2 9/16" x 5M M P F ~JO Orig. ev. = 41.7 ' (N 22E) Wellhead:l l" x 7 1116" 5M spool Orig. GL Elev. = 12.4' 7-1/16"x 2-9/16" hng. 3" LH acme ~ RT To Tbg. Spool = 28.50' (N 22E) Top & btm. 2-9/16" ciw BPV ` 20" 91.1 ppf, H-40 112' KOP ~ 600' Max. hole angle = 70 to 75 deg. f/ 3,600' to 13,021' Hole angle thru' perfs = 28 deg. 9 5/8", 40#/ft, L-80 Btrc. 8,099' I Camco 2 718" x 1" sidepocket KBMM GLM 132' 7" 26 ppf, L-80, BTC-Mod production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) Camco 2 7/8" x 1" 14 933' sidepocket KBMM GLM ' 2-7/8" XN Nipple (2.205" I.D.) 15,075' GPDIS Discharge Head 15 091' Pump 160 P11 SDX, 15,092' Gas Separator 15,114' GRSFTXAR Marker Jts 15,088' - 15,129' Centrilift Seal Section r 114 15 GSB3DB UT/LT AB/AB PFSA/FSA CL5 , Centrilift KMH Motor lt 152 HP 2325 40 15,128' Perforation Summary , amp , vo Ref log: GR/CCL 05/06/97 a r^n 2 intervals below added 5/26/05 RWO PumpMate XTO sensor 15,141' w16 fin Centralizer Size SPF Interval (TVD) Sensor TVD 7066' 3 3/8" 6 15252 -15262 7165 -7174' 3 3/8" 6 15272 -15282 7182 -7192' 3 3/8" 6 15294 -15314 7214 -7232' Mid-perf = 7199' tvd 15283' and ( Tagged 7/29/97 15,575' ) 7" float collar (PBTD) 15,578' 7" float shoe 15,663' DATE REV. BY COMMENTS 6 -09 - 97 ~7 / 30 / 97 MDO MD ESP c4mfzletion 4ES 2nd. ESP Completion 4ES 4/6/00 GMH 3rd ESP Completion Nabors 4ES 07/30/04 JRC 4th ESP Completion Nabors 4ES 5/26/05 LH Elective pull and add perf Nabors 4ES 3/29/08 LH ESP CO and FCO Nabors 3S MILNE POINT UNIT API NO: 50-029-22756-00 BP EXPLORATION Digital'Well File Well: MPF-50 Well History Well Date MPF-50 3/9/2008 MPF-50 3/23/2008 MPF-50 3/24/2008 • Summary • T/I/0=200/200/0. (Freeze protect) Freeze protect tbg w/ 15 bbls diesel. Flush prod line w/ 3 bbls neat meth, 3 bbls diesel, & 2 bbls 60/40 meth. Flush test line w/ 3 bbls neat meth, 3 bbls diesel, & 2 bbls 60/40 meth. FWHP=vac/200/0. *** WELL SI ON ARRIVAL **' (RIG PREP ) PULLED 1" BK-DGLV FROM 14929' MD, POCKET OPEN PULLED 1" BEK-DPSOV FROM 128' MD, SET 1" BK-DGLV ***JOB COMPLETED*** ***CONT FROM 3/23/08***RIG PREP RIG DOWN EQUIPMENT ***JOB COMPLETED WELL S/I *** Page 1 of 1 MPF-50 3/25/2008 Flush production line w/ 3 bbls 60/40 meth & 3 bbls diesel followed by 3 bbls 60/40 meth. Flush test line w/ 3 bbls 60/40 meth & 3 bbls diesel followed by 3 bbls 60/40 meth. MPF-50 3/25/2008 Well Support Techs set BPV, pulled wellhouse, flow lines and foundation. ~ A~~ ri t' ***NOTE*** BPV left in hole MPF-50 3/28/2008 *'*RWO Prep **' INSTALLED DUMMY VALVE IN STA #2 MANDREL AND A DPSOV IN STA #1 MANDREL ON SURFACE. FLAGGED ANDTAGGED MANDRELS. MPF-50 3/30/2008 T/I/0=0/0/120. (Post RWO freeze protect). Freeze protect IA w/ 65 bbls crude. Freeze protect tbg w/ 15 bbls crude. FWHP=0/0/140. *** Annulus valves left open*** MPF-50 4/2/2008 Tanker charge for loading and transporting chemical to Milne Point. MPF-50 4/2/2008 (Scale inhibitor treatment) T/I/0= 0/0/0 Rig-Up to IA and load with 160 bbls dead crude. Rig-Up to TBG and pump 9.2 bbls (03VM082) Scale Inhibitor followed by 255 bbls dead crude for overflush. FWHP= x MPF-50 4/2/2008 (Scale inhibitor treatment) T/I/0= 0/0/0 Rig-Up to IA and load with 160 bbls dead crude. Rig-Up to TBG and pump 9.2 bbls (03VM082) Scale Inhibitor followed by 255 bbls dead crude for overflush. FWHP= x MPF-50 4/3/2008 (Scale inhibitor treatment) T/I/0= 0/0/0 Rig-Up to IA and load with 160 bbls dead crude. Rig-Up to TBG and pump 9.2 bbls (03VM082) Scale Inhibitor followed by 255 bbls dead crude for displacement & overflush. Leave well shut in until tie in work is completed. FWHP= 0/0/0. ***Annulus valves left open.*** MPF-50 4/9/2008 The Well Support Techs rigged up and pulled the BPV and set a TWC to test the tree to 5000 psi. They then tested the the flowlines to 1150 psi and pulled the TWC. NOTE: All test were GOOD and the BPV/TWC proflie was left empty. Print Date: 4/19/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 4/19/2008 BP EXPLORATION Page 1 of 2 Operations Summary Report Legal Well Name: MPF-50 Common W ell Name: MPF-50 Spud Date: Event Nam e: WORKO VER Start : 3!23/2008 End: Contractor Name: NABOBS ALASK A DRI LLING I Rig Release: 3/29/2008 Rig Name: NABOBS 3S Rig Number: Date ~~ Frog - To ~ Hours ~~, Task I Code I NPT' Phase ~i - Description of Operations - 3/25/2008 08:00 - 11:30 3.50 MOB P PRE Move from MPH pad after repair of Carrier driveline. 11:30 - 23:00 11.50 MOB P PRE Arrive on location. Wait for WS Techs to run BPV, De-mob IE, pull wellhouse and prepare site. ~ 16:30. Notified AOGCC - John Crisp, for 24 hr notice regarding upcoming BOPE Test. (Wellhouse removed 021:00 hrs.) 23:00 - 00:00 1.00 MOB P PRE Position BOP cradle behind MPF-50, layout rig mats. 3/26/2008 00:00 - 07:00 7.00 MOB P PRE Lay herculite and back carrier over MPF-50 (002:00), jack and level carrier. Spot the Pipe Shed and Pits. Raise and scope up derrick. RU to tree for kill. Rig accepted 007:00 hrs. 3/26/2008. 07:00 - 08:30 1.50 WHSUR P DECOMP PUMU lubricator. Pressure test to 500 psi. Pull 2 1/2" CIW type H BPV. T 1 IA J OA pressures of 380 ! 210 / 20 psi. 08:30 - 10:00 1.50 WHSUR P DECOMP Fish pieces of broken BPV from on top of the master valve. 10:00 - 15:00 5.00 KILL P DECOMP Open well amd bleed gas from IA to tiger tank. Pump 90 Bbls SW down tubing with gas only returns from IA to tank. Close choke and Bullhead 100 Bbls down tubing (no returns). Flow check well, Tubing and IA on vacuum. Bullhead 300 Bbls down IA 0 4 BPM, 90 psi, catch fluid and pressure increase to final injection pressure of 650 psi - IA, 350 psi -Tbg, 4 BPM after BH 500 Bbls total BH down IA. Total fluid loss of 700 Bbls. Tubing and IA on STRONG vacuum. 15:00 - 16:00 1.00 WHSUR P DECOMP John Crisp w/ AOGCC waived State's right to witness BOPE test. Dy rod TWC. Test from above to 3500 psi for 10 minutes and chart. 16:00 - 17:30 1.50 WHSUR P DECOMP ND tree. Check hanger threads with 3" LH acme lifting thread. 5 turns. 17:30 - 21:30 4.00 WHSUR P DECOMP NU DSA, PU ! MU13 518" spacer spoof and BOPE. Hook up accumulator hoses, kill and choke lines. 21:30 - 22:00 0.50 WHSUR P DECOMP Function test BOPE and fill well with 30 bbls seawater. 22:00 - 00:00 2.00 WHSUR P DECOMP Test ROPE 25013500 psi with 2-7l8" test joint. 3/27/2008 00:00 - 05:00 5.00 WHSUR P DECOMP Continue test BOPE with 2-7/8" testjts. 05:00 - 06:00 1.00 WHSUR P DECOMP Blow down lines, RD BOPE test equipment. 06:00 - 08:00 2.00 WHSUR P DECOMP PUMU Opso-Lopso. MU XO to 3" LH acme and torque with rig tongs. Screw into hanger w/ 8 1/2 turns. RU Lo-Torq vale to pump in nipple on OL. PU Lubricator, MU TWC pulling tool. Stab lubricator. IA on vacuum. Pull TWC w!) / 0 / 20 psi on Tbg / IA / OA. BOLD lubricator and TWC. BOLD Opso-Lopso. 08:00 - 09:30 1.50 PULL P DECOMP PUMU landing joint, TIW valve, w/ XO to 3" LH acme. Torque XO with tongs. Screw into hanger, BOLDS. Pull hanger to just below annular preventer w/ 100K PUW. Pump 100 Bbls of SW down tubing (no returns). 09:30 - 10:30 1.00 PULL P DECOMP BOLD landing joint and tubing hanger. Threads on tubing hanger pup jt, galled when breaking out. POH 1 single and lay it down. PUMU new single, attach LaSalle clamp and cut cable just above collar. Band with 2 steel bands. 10:30 - 11:00 0.50 PULL P DECOMP PU 7 sin les of 2 7/8" and RIH. Ta fill 0 15347' 33' of RH . 11:00 - 11:30 0.50 PULL P DECOMP POH and lay down 7 singles. 11:30 - 12:00 0.50 PULL P DECOMP Hang blocks and adjust rollers on draw-works drum for drill line. Prep for pulling and standing back 2 7/8" ESP completion. 12:00 - 22:00 10.00 PULL P DECOMP POH standing back tubing (2 7/8"). LD jewelry to re-dress. Continuous hole fill of 1/2 BPM (30 Bbls/Hr) with charge pump and no returns. 40 stands OOH 0 14:30 hrs / 75 stds OOH 0 Printed: 4/11/2008 12:29:04 PM BP EXPLORATION Page 2 of 2 Operations Summary Report i Date i From - To Hours ii Task ~ Code i, NPT Phase li Description of Operations - -- 3/27/2008 ~ 12:00 - 22:00 10.00 PULL P DECOMP 16:40 / 85 stds OOH, @ 18:30 hrs remove full ESP spool from spooler C~3 22:00 hrs / 168 stds OOH. 22:00 - 00:00 2.00 PULL P DECOMP Seawater injection plant down, get produced water from Milne Point plant. General house cleaning on rig and blow down lines. Pumped 20 bbls down tubing with no returns and Legal Well Name: MPF-50 Common Well Name: MPF-50 Spud Date: Event Name: WORKOVER Start: 3/23/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/29/2008 Rig Name: NABOBS 3S Rig Number: 3/28/2008 00:00 - 01:00 1.00 PULL P DECOMP Continue to wait on seawater. 01:00 - 05:00 4.00 PULL P DECOMP Resume POH (from 168 stds) with ESP and stand 2-7/8" tbg in derrick, continuous hole fill with charge pump @ 1/2 BPM (30 Bbls/hr with no returns. 05:00 - 09:00 4.00 PULL P DECOMP BO/LD ESP pump and motor assembly. Recoverd: 143 LaSalle clamps, 2 Flat guards, 5 Protectolizers. 09:00 - 11:00 2.00 BUNCO RUNCMP Slip and cut drilling line. Set crown-o-matic. 11:00 - 11:30 0.50 BUNCO RUNCMP Lay down elephant trunk. Bi-weekly crew change. Prep for running ESP Assembly 11:30 - 14:30 3.00 BUNCO RUNCMP PUMU ESP pump and motor. Service ESP motor. MU flat guards and protectolators. 14:30 - 22:30 8.00 BUNCO RUNCMP RIH w/ ESP on 2 7/8" 6.5#,EUE 8 rd tubing from Derrick. Install LaSalle Cable protectors on first nine joints then every second joint. Centrilift teck checked conductivity of cable every 2000' , & filled tubing and flush pump with 10 bbls. MU torque of 2300 ft-Ibs. Using Best-O-Life 2000 pipe dope. RIH to joint #123 Continous hole fill of 30 bph with no returns. 22:30 - 00:00 1.50 BUNCO RUNCMP Remove empty ESP cable spool from spooling unit and replace with full spool. Prep ESP cable ends and begin making splice. Continous hole fill of 30 bph. 3/29/2008 00:00 - 03:00 3.00 BUNCO RUNCMP Continue making splice in ESP cables and test conductivity. Tested good. Continous hole fill of 30 bph. 03:00 - 10:30 7.50 BUNCO RUNCMP Continue RIH with ESP completion on 2 7/8" tbg from derrick, fill tubing and flush pump with 10 bbls, while making ESP conductivity test every 2000', Continous hole fill of 30 bph with no returns. Total of 476 jts ran, 1 XN, 2 GLM (1-DGLV on bottom / DPSOV on top). 245 LaSalle clamps, 5 Protectolators, 3 Flat guards. 10:30 - 11:00 0.50 WHSUR P TUBHGR PUMU 3 1/2" IF landing joint, TIW valve, and 3" LH Acme XO for top of hanger. MU tubing hanger. MU to completion string. 11:00 - 14:00 3.00 WHSUR P TUBHGR Centrilift make penetrator splice. Make final checks on cable. 5.8 ohms phase to phase / 353 gig ohms phase to ground / 149.7 deg F C~ intake / 1523 psi BHP. 14:00 - 15:00 1.00 WHSUR P POST Dry rod TWC. Test from above to 3500 psi for 10 minutes and 15:00 - 19:00 4.00 WHSUR P POST Blow down lines, drain BOP stack, unhook turnbuckles, pull riser, unhook koomey lines and N/D BOPE and place stack in cradle. Crew change, perform pre-tour checks. 19:00 - 20:30 1.50 WHSUR P POST NU tree and pressure test the Hanger void with FMC rep to 5,000 psi for 20 mins -good. 20:30 - 00:00 3.50 WHSUR P POST Fill the Tree with diesel and Tree test failed, MU lubricator and change out TWC, test failed, surface equipment tested good. Well tecks installed rebuilt TWC with lubricator and tested 5,000 psi for 10 min. MU lubricator & Pull TWC and set BPV, LD lubricator. Drain the Tree. Norm up Tree. Rig released for move to GPB P-pad ~ 00:00 hrs. Printed: 4/11/2008 12:29:04 PM STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COMMISSION BOPS Test Report Submit to: ,~~'~.,~:~c~,.~>~'_N>I_._ ;_. ~;, Contractor: Nabors Rig No.: 3S DATE: 3/27/2008 Rig Rep.: G.Sweatt/R.Bjorhus Rig Phone: 659-4487 Rig Fax: 659- 4486 Operator: BP Op. Phone: 659- 4485 Op. Fax: 659-4628 Rep.: J.Menke/D.Rhodes Field/Unit & Well No.: MPU F-50 PTD # 9970580 Operation: Drlg: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Annular:. 250!3500 Valves: 250/3500 TEST DATA MISC . INSPECTIONS: Test Result Test Resuk Location Gen.: P Well Sign P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13 5/8 5000 P Pipe Rams 1 2 7/8 x 5 P Lower Pipe Rams Blind Rams 1 Blind P Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8" 5000 P Kill Line Valves 1 2 1/16" 5000 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results FLOOR SAFETY VALVES: Quantity Test RE Upper Kelly 1 NT Lower Kelly 1 NT Ball Type 1 FP Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result' No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P ~ ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3100 P 'i - ' Pressure After Closure 1550 P 200 psi Attained 30sec P Full Pressure Attained 2 min 45 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4@1900 Number of Failures: 2 Test Time: 7_5 Hours Components tested ALL Repair or replacement of equipment will be made within DONE days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervises at: lira .r~_~.~`~s~i~~3~~~,,t~~>, Remarks: Tested with 2 7/8" test point TIW failed replaced with new and tested eood. Tubinn hans~er leaked, tightened lock downs, energize seals. test O.K. 24 HOUR NOTICE GIVEN YES X NO Date 03125/08 Time 1700 hrs start 2200 hrs Finish By John Witness R.Biorhus / D.Rhodes BOP Test (for rigs) (~ N MAR 2 '~ 200 BFL 11/14/07 Nabors 3S BOP Test MP F-50 3-27-08.x1s , STATE OF ALASKA ) ALASKA -/)L AND GAS CONSERVATION COIVIMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program Change Out ESP o Suspend 0 Operation Shutdown 1m Perforate 1m Other 1m Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well 1m Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612. Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 KBE = 41.70' 8. Property Designation: ADL 355018 11. Present well condition summary Total depth: measured 15685 feet true vertical 7551 feet Effective depth: measured 15578 feet true vertical 7455 feet Casing Structural Conductor Surface Intermediate Production Liner Length 78' 9068' 20" 9-5/8" 4. Current Well Class: 1m Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 197-058 6. API Number: 50-029-22756-00-00 9. Well Name and Number: MPF-50 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands Plugs (measured) Junk (measured) None None TVD Burst Collapse 110' 1490 470 4603' 5750 3090 7531' 7240 5410 Size MD 110' 9099' 15635'SCANNEè" JUL 0 Ql ZOOfu663' Perforation Depth MD (ft): Perforation Depth TVD (ft): 15252' - 15314' 7165' - 7220' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): RE(~EI\lE: JUN 2 ~~ 2005 2-7/8" ~\13ska Oil Sl 6.5#, ~1~~¡'¡IT)r~j1](~ 15141' None None RBDMs BFL JUN 3 0 2IJrJ5 Treatment description including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: 365 Subsequent to operation: 366 14. Attachments: 0 Copies of Logs and Surveys run 1m Daily Report of Well Operations 1m Well Schematic Diagram Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casinq Pressure 121 31 380 133 30 360 Tubinq Pressure 345 313 15. Well Class after proposed work: o Exploratory 1m Development 0 Service 16. Well Status after proposed work: 1m Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman Si~~/'>-1fD- Form 10-404 Revised 04/2004 Title Technical Assistant Phone Prepared By Name/Number: DatOcrZl:-o~) Sondra Stewman, 564-4750 Submit Original Only 564-4750 Tree:FMC 2 9/16" x 5M ) Wellhead:11" x 71/16" 5M spool 7-1/16"x 2-9/16" hng. 3" LH acme Top & btm. 2-9/16" ciw BPV HDJ J. I~I 20" 91.1 ppf, H-40 KOP @ 600' Max. hole angle = 70 to 75 deg. f/ 3,600' to 13,021' Hole angle thru' peris = 28 deg. 9518", 40#/ft, L-80 Sire. 19,099' I ~ 7" 26 ppf, L-80, BTC-Mod production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) Marker Jts 15,088' - 15,129' Peñoration Summary Ref log: GRlCCL 05/06/97 Top 2 intervals below added 5/26/05 RWO Size SPF Interval (TVD) 33/8" 6 15252 -1 5262' 7165 -7174' 33/8" 6 15272 -15282' 7182 -7192' 3 3/8" 6 15294 -15314 7214 -7232' - Mid-perf = 719~' tvd 15283' md DATE REV. BY 06 -09 - 97 MDO 07 / 30 / 97 MDO 4/6/00 GMH 07/30/04 JRC 5/26/05 LH COMMENTS M PF -50 x ~ ESP completion 4ES 2nd, ESP Completion 4ES 3rd ESP Completion Nabors 4ES 4tt¡ ESP Completion Nabors 4ES Elective pull and add perf Nabors 4ES Orig. ") Elev. = 41.7' (N 22E) Orig. GL Elev. = 12.4' RT To Tbg. Spool = 28.50' (N 22E) ~ Camco 2 7/8" x 1" sidepocket KBMM GLM I 128' 1 i Camco 2 7/8" X 1" sidepocket KBMM GLM 114,929' 1 2-7/8" XN Nipple (2.205" I.D.) 115,071' I MS-1 Pressure Head Centrilift 159GC1150 ESP, GPMTAR 1:1 Tandem Gas Separator GRSFTXBARH6 Separator - GRSFTXBARH6 Centrilift Seal Section GSB3DB UT/L T AB/HSN PFSA/FSA Centrilift KMH Motor 133 HP, 2205 volt 30 amp Phoenix XTI Sensor w/6 fin Centralizer Sensor TVD 115,087' I 115,088' 1 115,106' I 115,106' I 115,111' I 115,124' 1 \15,137' I 1 7063' I 7" float collar (PBTD) ( Tagged 7/29/97 15,575') 115,578' I 115,663' I 7" float shoe MILNE POINT UNIT WELL MPF-50 API NO: 50-029-22756-00 BP EXPLORATION (AK) ) ) BP EXPLORATION Operations Summary Report Page 1 of 2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-50 MPF-50 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/25/2005 Rig Release: 5/27/2005 Rig Number: Spud Date: End: 5/27/2005 Date From - To Hours Task Code NPT Phase Description of Operations 5/25/2005 00:00 - 03:00 3.00 RIGD P PRE PJSM. Rig down off MP F-57 03:00 - 06:00 3.00 RIGU P PRE PJSM. Rig up on MP-50. Rig accepted @ 06:00 hrs, 05/25/2005. 06:00 - 07:00 1.00 KILL P DECOMP Rig up tiger tank & associated lines. 07:00 - 08:00 1.00 KILL P DECOMP PJSM wI crew, toolpusher & company man. Pull BPV. Test lines @ 250 I 3500 psi, OK. 08:00 - 12:00 4.00 KILL P DECOMP Open up to well. SITP = 380 psi, I/A = 430 psi, O/A = 600 psi. Bullhead (2) tbg volumes @ 5 bpm I 180 psi. Bullhead down II A @ 5 bpm, (1) volume, 450 bbls @ 5 bpm, 700 psi max pressure. Observe well. Still 30 psi & some gas on backside. Line up & pump down tubing 200 bbls, taking returns thru choke to tiger tank.., only gas returns. See pump pressure increse to 1100 psi on tubing, but no fluid returns, gas returns very weak. Line up & bullhead down I/A, (100 bbsl), 4 bpm I 500 psi max pressure. 12:00 - 12:30 0.50 KILL P DECOMP Monitor well, both sides on vacuum. O/A = 750 psi. Set two way check valve. 12:30 - 13:30 1.00 WHSUR P DECOMP PJSM. NID tree. 13:30 - 15:00 1.50 BOPSUR P DECOMP PJSM. N/U 13 5/8" x 5M BOPE. 15:00 - 18:00 3.00 BOPSUF P DECOMP PJSM. Conduct full test on BOPE. Witnessing of test waived by AOGCC rep Chuck Sheve, (24 hour notice given). Testing of BOPE witnessed by BP Company Man Paul Haynes & Nabors Toolpusher Gene Sweatt. 18:00 - 19:00 1.00 WHSUR P DECOMP P/.U lubricator & pull TWC. LID plug & lubricator. 19:00 - 20:00 1.00 PULL P DECOMP P/U landing jt & M/U into hanger. BOLDS. Pull hanger to floor. P/U 85K. Monitor well, well dead. FL out of sight. LID hanger. & landing jt. Pull ESP cable over sheave. Prep to POOH. 20:00 - 23:00 3.00 PULL P DECOMP POOH & stand back 2 7/8" ESP completion. Use double displacement when POOH. 23:00 - 00:00 1.00 PULL P DECOMP Pulled 765 stands. Cut ESP cable @ splice. Change out reels in spooling unit. 5/26/2005 00:00 - 03:00 3.00 PULL P DECOMP Con't to POOH w/2 7/8" ESP completion. Use double displacement. 03:00 - 06:00 3.00 DECOMP Break out, inspect & LID ESP. 06:00 - 07:00 1.00 PULL P DECOMP Clear & clean rig floor. 07:00 - 10:00 3.00 PERF P DECOMP PJSM wi Schlumberger. Rig up SOS wi lubricator, full E-Line BOPE & pack off. PT same to 500 psi, OK. 10:00 - 13:00 3.00 PERF P DECOMP RIH w/1 0' of powerjet, 6 spf gun, ccl & gamma wi roller assembly. Tie in wI 1997 USIT log. Perforate f/15,272' - 15,282'. POOH. ASF. Well stable. 13:00 - 15:30 2.50 PERF P DECOMP PJSM. LID spent gun. Pick up loaded gun. 15:30 - 20:30 5.00 PERF P DECOMP RIH w/1 0' gun assembly. Hanging up @ 9800' ELM. Pick up to 8000' & fill hole wi charge pump to assist getting gun down. Pumped 75 bbls wi working gun, still hanging up @ 9800'. Mix (1) bbl EP Mud Lube in 40 bbls heated water. Chase in hole wi 50 Bbls. Pulled peri gun up to 2500' & then ran back in hole wI no problem. Correlate depth & perforate 15,252' to 15,262' POOH & LID perf guns. All shots fired. 6 spf, Total 122, .45" diameter holes. 20:30 - 22:30 2.00 PERF P DECOMP RID periorators & LID lubricator & equip. Clear Clean rig floor. NID shooting nipple & install bell nipple. 22:30 - 00:00 1.50 RUNCOrvP RUNCMP P/U, M/U & service ESP. I 5/27/2005 00:00 - 01 :00 1.00 RUNCOr RUNCMP Con't to P/U, M/U & service ESP. Pull cable over sheave & Printed: 5/31/2005 8:04:25 AM BP EXPLORATION Ope.rationsSummary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-50 MPF-50 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/25/2005 Rig Release: 5/27/2005 Rig Number: Spud Date: End: 5/27/2005 5/27/2005 00:00 - 01 :00 1.00 RUNCOrvP RUNCMP plug into ESP. Test same, Ok. 01 :00 - 06:00 5.00 RUNCOMP RUNCMP RIH wI new ESP& 27/8" completion. Pump thru ESP & test every 2000'. 06:00 - 08:30 2.50 RUNCOrvP RUNCMP PJSM. Make reel to reel splice. 81 stands in hole @ 7840' (+ -). 08:30 - 13:30 5.00 RUNCOMP RUNCMP Continue in hole wi 2 7/8" ESP completion string. Test pump & cable & pump down tbg, (5 bbls), @ 1 bpm I 100 psi every 2000', OK. 13:30 - 14:00 0.50 RUNCOMP RUNCMP PJSM. Pick up landing jt. Install penetrator. 14:00 - 15:30 1.50 RUNCOrvP RUNCMP PJSM Attach field connection & test, OK. 15:30 - 16:00 0.50 RUNCOMP RUNCMP PJSM. Land hanger. RILDs. UD landing jt. Set two way check valve & test @ 3500 psi, OK. 16:00 - 17:00 1.00 BOPSURP RUNCMP PJSM. N/D BOPE. 17:00 - 18:00 1.00 WHSUR P RUNCMP N/U & test tree & adapter to 5000 psi, OK. 18:00 - 18:30 0.50 WHSUR P RUNCMP P/U lubricator & pull TWC. Install BPV. 18:30 - 19:00 0.50 RUNCOMP RUNCMP Secure well & cellar. Release rig @ 1900 hrs. Printed: 5/31/2005 8:04:25 AM ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSI~I= "- E IVE D REPORT OF SU N DRY WELL OPERATIONS AUG 1 6 2004 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. A dress: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): KBE = 42' 8. Property Designation: ADL 355018 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 78' Surface 9068' Intermediate Production 15635' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): n II Repair Well 0 Plug Perforations II Pull Tubing 0 Perforate New Pool 0 Operation Shutdown 0 Perforate Alaska Oil & 0 Stimulate Anchl~~er 0 Waiver 0 Time Extension 0 Re-Enter Suspended Well 4. Current Well Class: II Development 0 Exploratory 0 Stratigraphic 0 Service 197-058 6. API Number: 50-029-22756-00-00 9. Well Name and Number: MPF-50 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands 15685 7551 15578 7455 feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD Burst Collapse 20" 110' 110' 1490 470 9-5/8" 9099' 4603' 5750 3090 7" 15663' 7531' 7240 5410 15294' - 15314' 7202' - 7220' 2-7/8" 6.5#, L-80 15144' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: -z~~cg ~\F~. ~Uf; t 7 ?mn, 13. Oil-Bbl Re resentative Dail Gas-Met Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run II Daily Report of Well Operations II Well Schematic Diagram 15. Well Class after proposed work: 0 Exploratory II Development 0 Service 16. Well Status after proposed work: II Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL st 0 my no e ge. Sundry Number or N/A if C.O. Exempt: 17. Printed Name Sandra Stewman Title Technical Assistant Prepared By NameiNumbe~ DateCß'"'N -0 Sandra Stewman, 564-4750 Submit Original Only Tree: FMC 2 9/16" x 5M Wellhead: 11" x 7 1/16" 5M spool 7-1/16"x 2-9/16" hng. 3" LH acme Top & btm. 2-9/16" ciw BPV 20" 91.1 ppf, H-40 112' KOP @ 600' Max. hole angle = 70 to 75 deg. fl 3,600' to 13,021' Hole angle thru' perfs = 28 deg. 9 5/8", 40#/ft, L-80 Btrc. 19,099' I 7" 26 ppf, L-80, BTC-Mod production casing (drift 10 = 6.151", cap. = 0.0383 bpf) Stimulation Summary Perforation Summary Ref loa: GRlCCL 05/06/97 Size SPF 6 Interval (TVD) 33/8" 15294 -15314' 7214 -7232' Mid-perf = 7223' tvd 15304' md DATE Ev. BY 05 -02 - 97 MDO 06 -09 - 97 MDO 07/30/97 MDO 4/6/00 GMH 07/30/04 JAC ~ ~, MPU F-50 COMMENTS Cased hole com letion 22E ESP completion 4ES 2nd. ESP Completion 4ES 3rd ESP Completion Nabors 4ES 4th ESP Completion Nabors 4ES Orig. KB Elev. = 41.7' \"¡ 22E) Orig. GL Elev. = 12.4' AT To Tbg. Spool = 28.50' (N 22E) Camc027/8"x1" I I side pocket KBMM GLM 128' Camco 2 7/8" X 1" 114,928 side pocket KBMM GLM 2-7/8" XN Nipple (2.205" 1.0.) 115,071' 1 Centrilift GC 1700 ESP, I 15,085' I series 513, GPMTAR 1:1 151 Stg. Centrilift Tandem Gas I 15,102' I Separator - GASTXBAAH6 Intake TVO 1 7,038' 1 I I Centrilift GST33BHLPFS 15,108' Seal Section Centrilift KMH 562 series, I 15,122' 1 152 hp motor, 2325 v. 140 amps. I I Centrilift PHO w/6 fin 15,142' Centralizer Marker Jts 15,088' - 15,129' (Tagged 7/29/97 15,575') I 15,578' I I 15,663' I 7" float collar (PBTO) 7" float shoe MILNE POINT UNIT WELL F-50 API NO: 50-029-22756-00 BP EXPLORATION AK ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date MPF-50 MPF-50 WORKOVER Nabors Nabors 4ES From - To I Hours I Task 7/26/2004 7/27/2004 03:00 - 05:00 05:00 - 08:30 08:30 - 10:30 10:30 - 12:00 12:00 - 12:30 12:30 - 14:00 14:00 - 14:30 14:30 - 18:00 18:00 - 18:30 18:30 - 19:00 19:00 -19:30 19:30 - 20:30 20:30 - 22:00 22:00 - 00:00 00:00 - 01 :30 01 :30 - 02:00 02:00 - 02:30 02:30 - 03:30 03:30 - 06:00 06:00 - 06:30 06:30 - 08:00 08:00 - 09:00 09:00 - 13:00 13:00 - 14:00 14:00 - 15:30 17:00 - 19:30 19:30 - 22:00 22:00 - 00:00 , I Code NPT! Phase , ----- ---,-, --..,,--.. --,--..- 2.00 MOB PRE P 3.50 MOB P PRE 2.00 MOB 1.50 MOB P P PRE PRE 0.50 KILL P DECOMP 1.50 KILL DECOMP P 0.50 KILL DECOMP P 3.50 KILL DECOMP P 0.50 KILL DECOMP P 0.50 KILL P DECOMP 0.50 WHSUR P 1.00 WHSUA P 1.50 BOPSUF P 2.00 BOPSUF P DECOMP DECOMP DECOMP DECOMP 1.50 BOPSUF P DECOMP 0.50 WHSUA P 0.50 PULL P DECOMP DECOMP 1.00 PULL DECOMP P 2.50 PULL 0.50 PULL 1.50 PULL 1.00 PULL 4.00 PULL DECOMP DECOMP DECOMP DECOMP DECOMP P P P P P 1.00 PULL 1.50 PULL 2.50 PULL DECOMP DECOMP DECOMP P P P 2.50 RUNCO' /P 2.00 RUNCO' /P RUNCMP RUNCMP Page 1 of 2 Start: 7/27/2004 Rig Release: 7/28/2004 Rig Number: Spud Date: End: 7/28/2004 Description of Operations PJSM. Lower & layover derrick. Prep rig components for move. PJSM wI all associated parties. Move rig & rig components from MP E Pad to MP F Pad. PJSM. Spot & berm rig sub & rig components. PJSM. Raise & scope up derrick. Rig accepted @ 12:00 hrs, 7/26/2004. PJSM. Pick up lubricator. Pull BPV. SITP = 1140 psi, SICP = 1100 psi, O/A = 200 psi. Rig up lines to wellhead & tiger tank & test @ 3500 psi, OK. Take on 125 degree seawater. Safety meeting with crew on well killing operation. Stress awareness with regard to heated seawater, fluid monitoring & gas venting. Line up & bleed gas off tubing. Line up & pump heated seawater down tubing @ 2 1/2 - 3 bpm 1150 - 200 psi, taking returns, (gas), through choke to tiger tank. Pump (1) tubing volume & bullhead into formation (25) bbls @ 2 bpm 1100 psi. Resume pumping down tubing @ 4 bpm I 200 psi taking gas & fluid returns up I/A to tiger tank via choke. Monitor O/A & bleed pressure due to thermal exp[ansion form 950 psi to 350 psi...(diesel). SIW & monitor. Well dead. Take on seawater. Gauge tiger tank. No fluid in tiger tank. Pump 60 Bbls of hot seawater down annulus to clean tbg. 4 BPM @ 100 psi. Well on vacum. Set & test TWC. Blow down & RID lines to tree. Bleed void. N/D X-mas tree. N/U BOPE. Pressure test BOPE as per BP/AOGCC requirements. Lp 250 psi, HP 3500 psi. BOP test witnessing waived by Jeff Jones wI AOGCC. Finish BOP test as per BP/AOGCC requirements. Lp 250 psi, HP 3500 psi. Test witnessing waived by Jeff Jones wI AOGCC. P/U lubricator & pull TWC. UD lubricator. M/U landing it. BOLDS. P/U & attempt to pull hanger. Work P/U wt to to 125k. (80% +blocks) No Joy. Mix 20 Bbls EP Mudlube pill & pump down & around tbg. Work pipe & continue pump pill. Tubing string started to pull free after 150 bbls. Pull hanger to floor. UD same. POOH & stand back 2 7/8' tbg. Lubricate & service rig. PJSM. Continue to POOH wI ESP completion. PJSM. CIO ESP spools. Continue to POOH wI ESP completion, standing back tubing & triple displacing on hole fill. Slip and cut drilling line. Cont to POH wI ESP and SIB tbg. Clear and clean rig floor. RlU Centrilift equipment to RIH new ESP Assy. P/U and M/U Centrilift Pump Mate, motor, tandem seal section, tandem gas separator, pump, and discharge head. RIH new Centrilift ESP completion on 2-7/8',6.5#, L-80, EUE 8 Printed: 8/312004 9:15:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 7/27/2004 7/28/2004 ~ ~ Page 2 of 2 BP EXPLORATION Operations Summary Report MPF-50 MPF-50 WORKOVER Nabors Nabors 4ES Spud Date: End: 7/28/2004 Start: 7/27/2004 Rig Release: 7/28/2004 Rig Number: Phase I From - To Hours I Task Code NPT ¡ I 22:00 - 00:00 00:00 - 03:30 03:30 - 06:00 06:00 - 07:00 07:00 - 12:00 12:00 - 13:00 13:00 - 14:00 14:00 - 14:30 14:30 - 15:00 15:00 - 16:30 16:30 - 18:00 0.50 RUNCO 0.50 BOPSU P 1.50 BOPSU P 1.50 WHSUR P RUNCMP RUNCMP RUNCMP AUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP Description of Operations , ,.- ---.---- ---.- Ad tubing. RIH wI new Centrilift ESP completion on 2-7/8., 6.5#, L-80, EUE 8 Rd tubing. Fill tubing every 2000'. MIU reeHo-reel splice to 2nd cable spool. Continue wI reel to reel splice. Continue in hole w/2 7/8" ESP completion. Meg cable every 2000' & pump (10) bbls seawater through pump every 2000', OK. PJSM. M/U landing it. Meg ESP cable. 85K up wt, 45K down wt. PJSM. Make field connection & test, OK. Used 244 Protectralizers, 3 Flat Guards, & 5 La Salle Clamps. PJSM. Land tbg hanger & AILDs. PJSM. Set two way check & test @ 1000 psi, OK. PJSM. N/D BOPE. PJSM. N/U & test adapter flange & tree @ 5000 psi, OK. Secure well, release rig @ 18:00 hrs, 07/28/2004. Printed: 813/2004 9:15:45 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: ACIDIZED FORMATION Operation shutdown_ Stimulate _X Plugging _ Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 3211' FNL, 2679' FEL, Sec. 06, T13N, R10E, UM At top of productive interval 2735' FNL, 2419' FEL, Sec. 25, T14N, R09E, UM At effective depth 2588' FNL, 2478' FEL, Sec. 25, T14N, R09E, UM At total depth 2544' FNL, 2495' FEL, Sec. 25, T14N, R09E, UM Perforate _ Other _ 5. Type of Well: Development __X Explorato~__ Stratigraphic__ Service_ (asp 's 541883, 6035520) (asp's 536926, 6046529) (asp's 536866, 6046676) (asp's 536849, 6046720) 6. Datum elevation (DF or KB feet) RKB 42 feet 7. Unit or Property name Miline Point Unit MPF-50 9. Permit number / approval number 197-058 10. APl number 50-029-22756-00 11. Field / Pool Miline Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical 15685 feet 7551 feet Effective depth: measured 15578 feet true vertical 7455 feet Casing Length Size Conductor 78' 20" Surface 9068' 9-5/8" Intermediate 15635' 7" Plugs (measured) Junk (measured) Cemented Measured Depth True Vertical Depth 250 sx Amticset I (Aprox) 110' 110' 2200 sx PF 'E', 750 sx 9099' 46O3' Class 'G' 235 sx Class 'G' 15663' 7531' Perforation depth: measured Open Perfs 15294' - 15314' true vertical Open Perfs 7214' - 7232' Fubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 2-7/8", 6.5#, L-80 TBG @ 15064'. ESP pump from 15064' to 15115'. No Packer Above ESP pump. Camco 2-7/8" x 1" Sidepocket KBMM GLM @ 108' RECEIVED DEC 0 4 2002 Nas~ 0il & Gas Cons. Commissior, Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 10/04/2002 Subsequent to operation 04/23/2002 OiI-Bbl 555 Representative Dailv Averaqe Production or Iniection Data Gas-Mcf Water-Bbl 342 3 270 285 1 Casing Pressure Tubing Pressure 342 33O 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 the foregoing ~ true and correct to the best of my knowledge. .~,,~¢--~' ~~~.~,.,,,z Title: TechnicalitieS)[~r~ ~L 0 ~O0~Date November 11,2002 DeWayne R. Schnorr Prepared b~ DeWa~ne R. Schnorr 564-5174 "9 ONS BF L DEC 5 2002 ~? '~" ~ ~'; ? ¢ Form 10-404 Rev 06/15/88 * '-~' SUBMIT IN DUPLICATE MPF-50 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 10/14/2002 ACIDIZE FORMATION EVENT SUMMARY 10/14/O2 HB&R RIGGED UP AND PUMPED 208 BBLS DEAD CRUDE DOWN THE IA TO FILL IT. PUMPED AT 2 BPM FROM 650 TO 1000 PSI PUMPING PRESSURE. DOWELL RIGGED UP AND PUMPED 20 BBLS OF 12.5% DAD ACID DOWN TUBING, PUMPED AT 1.5 BPM AT 650 PSI. SWITCHED TO DIESEL FOR DISPLACEMENT, PUMPED 121 BBLS HEATED UP FROM 70 TO 160 DEGREES SLOWLY IN 20 BARREL INCREMENTS. PUMPED FROM 2 TO 1 BPM FROM 650 TO 3000 PSI. NOTE: WHEN THE ACID HIT THE FORMATION, PUMP RATE WENT FROM I BPM AT 3000 PSI TO 1.5 BPM AT 3000 PSI. JOB WAS COMPLETED WITH NO PROBLEMS. WELL WAS STARTED AND FLOWED TO THE PRODUCTION LINE UNTIL ACID STARTED COMING BACK, THEN SWITCHED TO TANK UNTIL WELL CLEANED UP. FLUIDS PUMPED BBLS DISCRIPTION 0 METHANOL 208 ;DEAD CRUDE 121 HEATED DIESEL 20 12.5% DAD ACID 349 TOTAL Page I 90" 91.1 pp[, H-40 I~ I~ CentrJli. GC 1700 E~P, , i',~ ~ series513, GP~AR1:1 ~ 15,0~ ~ I ~ Separator- GRSTXBARH6 P~Stimulati°nario n Summa~m a~ ] I ~ SealCentdli~amps.Centriliff152 hpSeCti°nmotor,GST33BHLPFSKMH 2325562 sedeS,v. 140 I~' ~, ' u ' I 153~' mdl: ~ ( Tagged 7129/97 15,575' ) 7" float shoe I 15,6~' I DATE R~V BY COMMENTS MILNE P T IT ' OIN UN WELL F-50 o6-o9 ~ 97 MbO ESP completion 41 APl NO: 50-029-2275~00 ON OR BEFORE W '-'- STATE OF ALASKA - ALASK~ dlEAND GAS CONSERVATION COIV~, $SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: I-I Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 42' [] Exploratory 7. Unit or Property Name 3, Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2068' NSL, 2680' WEL, SEC. 6, T13N, R10E, UM MPF-50 At top of productive interval 9. Permit Number / Approval No. 197-058 2544' NSL, 2419' WEL, SEC. 25, T14N, R9E, UM 10. APl Number At effective depth 50- 029-22756-00 2691' NSL, 2478' WEL, SEC. 25, T14N, R9E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 2735' NSL, 2495' WEL, SEC. 25, T14N, R9E, UM Sands 12. Present well condition summary Total depth: measured 15685 feet Plugs (measured) true vertical 7551 feet Effective depth: measured 15578 feet Junk (measured) true vertical 7455 feet Casing Length Size Cemented MD TVD Structural Conductor 78' 20" 250 sx Arcticset I (Approx.) 110' 110' Surface 9068' 9-5/8" 2200 sx PF 'E', 750 sx Class 'G' 9099' 4603' Intermediate Production 15635' 26" 235 sx Class 'G' 15663' 7531' Liner ORIGI AL Perforation depth: measured 15294' - 15314' RECEIVED true vertical 7202'- 7220' APR 1 8 2000 Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 15117' AJa~ka 0il & Gas Co~s. Commission Packers and SSSV (type and measured depth) None Ar'l~0r~e 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17.1 hereby certify that the,,~ ~ ,~f°reg°ing~~rrect to the best of my knowledge ~)L//(~ Signed Terrie Uubbe ..- /~,/~14_~. Title Technical Assistant III Date , -,..,,,..~/'~J2~ ~-' i :. ~:.:.::i:. ~!: ~' : ii !iii::ii~. i::. i ~ i ~-i!!~-i:.~ !: :.:. ::!:. i :~ :?. i::i i PreParedByName/Number: Terrie Nubble, 564-4628 \ Form 10-404 Rev. 06/15/88 Submit In Du Facility Date/Time 04 Apr 00 05 Apr 00 06 Apr 00 Progress Report M Pt F Pad Well MPF-50 Page 1 Rig Nabors 4ES Date 11 April 00 12:00-15:00 12:00-15:00 15:00 15:00-16:30 15:00-16:30 16:30 16:30-17:00 16:30-17:00 17:00 17:00-20:00 17:00-20:00 20:00 20:00-22:00 20:00-20:30 20:30 20:30-22:00 22:00 22:00-01:00 22:00-01:00 01:00 O1:00-06:00 O1:00-06:00 06:00 06:00-06:00 06:00-19:00 06:00-19:00 19:00 19:00-06:00 19:00-23:00 23:00 23:00-04:30 04:30 04:30-06:00 06:00 06:00-14:30 06:00-07:30 07:30 07:30-11:30 11:30 11:30-14:30 14:30 14:30-15:30 14:30-15:30 15:30 Duration 3hr 3hr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 3hr 3hr 2hr 1/2 hr 1-1/2 hr 3hr 3hr 5 hr 5hr 24 hr 13hr 13hr llhr 4 hr 5-1/2 hr 1-1/2 hr 8-1/2hr 1-1/2hr 4 hr 3 hr 1 hr lhr Activity Derrick management Rigged up High pressure lines Rig up Surface Lines to Tree & Tiger tank. Equipment work completed Fluid system Fill pits with Seawater Completed operations Test well control equipment Tested High pressure lines Test Lines To 3500 PSI. Pressure test completed successfully - 3500.000 psi Well control Bullhead well Bull Head Tbg. Volume. & Well Psi. O & Bull Head Annulus Volume & Monitor Same Well On Vacumn. Completed displacement at 0.0 psi and 567.000 bbl Wellhead work Installed Hanger plug Install Twc & Test To 2500 PSi. Equipment work completed Removed Xmas tree Equipment work completed Nipple up BOP stack Rigged up BOP stack Equipment work completed Pull Single completion, 2-7/8in O.D. Pulled Tubing in stands to 8500.0 ft Stopped: To hold safety meeting Pull Single completion, 2-7/8in O.D. (cont...) Pull Single completion, 2-7/8in O.D. Pulled Tubing in stands to 0.0 ft pooh with esp completion & lay dn esp assy. Completed operations Run Single completion, 2-7/8in O.D. Rigged up sub-surface equipment - ESP Equipment work completed Ran Tubing in stands to 8200.0 ft stopped to splice esp cable Began precautionary measures Serviced ESP Splice esp cable Stopped: To hold safety meeting Crew change. Run Single completion, 2-7/8in O.D. (cont...) Serviced ESP Splice esp cable Equipment work completed Ran Tubing to 15117.0 ft (2-7/8in OD) Completed run with ESP to 15117.0 ft Installed Tubing hanger Tie-down bolts energised Nipple down BOP stack Rigged down BOP stack Equipment work completed RECEIVED Anchorage Facility M Pt F Pad Progress Report Well MPF-50 Page 2 Rig Nabors 4ES Date 11 April 00 Date/Time 15:30-06:00 15:30-16:00 16:00 16:00-17:00 17:00 17:00-18:00 18:00 Duration 14-1/2 hr 1/2 hr lhr lhr Activity Wellhead work Installed Xmas tree Equipment work completed Tested Xmas tree Pressure test completed successfully - 5000.000 psi Installed Hanger plug remove twc & install bpv & secure tree Equipment work completed RECEIVED APR 1 8 2000 Alaska Oil & Gas Cons. [;omrnissior~ Anchorage PERMIT DATA AOGCC Individual Well Geological Materials Inventory Page: 1 Date: 07/19/99 T DATA PLUS RUN RECVD 97-058 STAT PRESS SR~ ~5304 ~/~/~ F~L 07/03/97 97-058 7730 ~F~PERRY GRC/EWR/CNP/RHOP/ROP 3,4 07/23/97 97-058 DGR/EWR4-MD ~9130-15684 FINAL 07/23/97 97-058 DGR/CNP/SLD-MD ~r130-15684 FINAL 07/23/97 97-058 DSR/ZWR4-TVO ~6iS-?S?~ FINAL 0~/~/~ 97-058 DGR/CNP/SLD-T~ ~4618-7576' FIN~ 07/23/97 ~-oss US~T/S~/CC~ ~00-iS4S0 ~D/~ ~ o~/~i/~7 97-058 MWD SR~ ~PERRY 9100-15685. 12/15/97 10-407 ~'~PLETION DATE @ )/J~lq?l @ /,~llJ'-/ ~/ DAI~,M WE~,', OPS R ~ ~//IAIfFl TO 7/3~1~?/ @)A/OV¢?I Are dry ditch samples required? yes ~?nd received? y~s-~no-- Was the well cored? yes ~ .Analysis & description received? ¥~-~n0 Are well tests required? ~s n~_Received? Well is in compliance Initial COMMENTS T D BOX .... - . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION I/~ E C ~ I V~) WELL COMPLETION OR RECOMPLETION REPORT AND LOG £:EC ? 1. Status of Well Classification of Service Well ' "' ~a~ [~ Oil l--] Gas [] Suspended I~ Abandoned I~ Service AJaska O_/! & ~=.= ,,, .......... .............. ~" ~UliliFJ188 2. Name of Operator 7. Permit Number Anchorage BP Exploration (Alaska)Inc. 97-58 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-661~... ................. 50-029-22756 4. Location of well at surface ~ ~.,:,,,v',/i- :i;.~'i i 1 ~ .......I ~ I 9. Unit or Lease Name ' .~'~/~t }i_ [~i~, ~~~' Milne Point Unit 2068' NSL, 2680 WEL, SEC. 6, T13N, R10E, UM ~ q? ' ~l 10. Well Number At top of productive interval -,.' ........ i ..... ~ 2545' NSL, 2417' WEL, SEC. 25, T14N, ROE, UM i ~ ;;" ~ ' M PF-50 At total depth ~,-.'7;- '.',~".~ ~---' :~ ! 11. Field and Pool 2737' NSL, 2492' WEL, SEC. 25, T14N, R9E, UM Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 42'I ADL 355018 i2. Date Spudded4/13/97 113' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if °ffsh°re 116' N°' °f C°mpleti°ns4/25/97 7/30/97 N/A MSL] One ....... 15685 7551 FTI 15578 7455 FTI [~Yes I--lNo N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, ESS, Gyro, GR/CCL ;~3. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 110' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 31' 9099' 12-1/4" 2200 sx PF 'E', 750 sx Class 'G' 7" 26# L-80 28' 15663' 8-1/2" 235 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 2-7/8", 6.5#, L-80 15101' MD TVD MD TVD 15294'-15314' 7202'-7220' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 90 bbls diesel Frac'd 15294'-15314' 159000# 16/20 Carbolite behind pipe 27. PRODUCTION TESTrb I I I ^ I Date First Production I Method of Operation (Flowing, gas lift, etc.) ~ rf~ I ~ I I ~ ~t L August 15, 1997I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Fiow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL 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. 011 Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Top Kuparuk 15050' 6986' Top Kuparuk 'A' 15231' 7146' Top Kuparuk A1 15273' 7183' ORIGINAL 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby c~hat the foregoing is true and correct to the best of my knowledge Signed\ ~\ ~.,..~"'-----~ .. ,..~.__.__.___~ ~ z_/, z-/~'~ Randy'rhomas t '- Title Drilling Superintendent Date MPF-50 97-58 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No, / Approval No. INSTRUCTIONS GEN£RAL: This form is designed for submitting a complete and correct well completion report and Icg 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 cementing and the location of the cementing tool. ITEM 27.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Performance Enquiry Report Operator BP Exploradon Date 20:44, 28 Oct 97 Page 1 The analysis is from - 06:30, 21 Apr 97 - to - 06:30, 21 Apr 97 Programs in Result Table: MPF-50 Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) MPF-50 Event 06:30, 21 Apr 97 06:30, 21 Apr 97 0 hr 0 min Obtained leak off 12.7 Hole Size MDR 8-1/2 Progress Report Facility M Pt F Pad Well MPF-50 Rig Nabors 22E Page Date 1 12 ~_~ ~9/~, ,'ED Date/Time 12 Apr 97 13 Apr 97 14 Apr 97 15 Apr 97 16 Apr 97 17 Apr 97 18 Apr 97 19 Apr 97 01:00-06:00 06:00-14:30 14:30-20:30 20:30-22:00 22:00-22:30 22:30-01:30 01:30-04:00 04:00-05:00 05:00-06:00 06:00-03:00 03:00-04:00 04:00-04:30 04:30-05:30 05:30-06:00 06:00-22:00 22:00-23:30 23:30-00:30 00:30-01:30 01:30-02:30 02:30-06:00 06:00-16:30 16:30-18:00 18:00-19:00 19:00-22:00 22:00-00:00 00:00-01:00 01:00-01:30 01:30-03:30 03:30-06:00 06:00-03:30 03:30-05:30 05:30-06:00 06:00-07:00 07:00-07:30 07:30-08:00 08:00-06:00 06:00-08:00 08:00-10:00 10:00-14:30 14:30-16:00 16:00-16:30 16:30-20:00 20:00-22:30 22:30-02:30 02:30-05:00 05:00-06:00 06:00-06:45 06:45-07:00 07:00-16:15 16:15-16:30 16:30-19:30 19:30-21:00 21:00-21:45 21:45-22:00 Duration 5hr 8-1/2 hr 6hr 1-1/2 hr 1/2hr 3hr 2-1/2 hr lhr lhr 21 hr lhr 1/2 hr lhr 1/2 hr A6hr 1-1/2 hr lhr lhr lhr 3-1/2 hr 10-1/2 hr 1-1/2 hr lhr 3hr 2hr lhr 1/2 hr 2hr 2-1/2 hr 21-1/2 hr 2hr 1/2 hr lhr 1/2 hr 1/2 hr 22 hr 2hr 2hr 4-1/2 hr 1-1/2 hr 1/2 hr 3-1/2 hr 2-1/2 hr 4hr 2-1/2 hr lhr 3/4 hr 1/4 hr 9-1/4 hr 1/4 hr 3hr 1-1/2 hr 3/4 hr 1/4 hr Activity Rig moved 40.00 % Rig moved 100.00 % (cont...) Rigged up Bell nipple Made up BHA in derrick Held safety meeting Made up BHA in derrick Made up BHA no. 1 Serviced Top drive Circulated at 110.0 ft Drilled to 2321.0 ft Circulated at 2321.0 ft Pulled out of hole to 1112.0 ft Serviced Top drive R.I.H. to 2321.0 ft Drilled to 4656.0 ft Circulated at 4001.0 ft Pulled out of hole to 1110.0 ft Serviced Top drive R.I.H. to 4001.0 ft Drilled to 4656.0 ft Drilled to 5503.0 ft (cont...) Circulated at 5503.0 ft Dropped EMSS survey barrel Pulled out of hole to 1110.0 ft Pulled BHA Serviced Top drive Made up BHA no. 2 R.I.H. to 5503.0 ft Drilled to 5599.0 ft Drilled to 7504.0 ft (cont...) Circulated at 7504.0 ft Pulled out of hole to 6500.0 ft Pulled out of hole to 5500.0 ft (cont...) Serviced Top drive R.I.H. to 7504.0 ft Drilled to 9031.0 ft Drilled to 9120.0 ft (cont...) Circulated at 9120.0 ft Pulled out of hole to 200.0 ft Serviced Block line Serviced Top drive R.I.H. to 9120.0 ft Circulated at 9120.0 ft Pulled out of hole to 1112.0 ft Pulled BHA Rigged up Casing handling equipment Rigged up Casing handling equipment (cont...) Held safety meeting Ran Casing to 9099.0 ft (9-5/8in OD) Rigged up Cement head Circulated at 9099.0 ft Mixed and pumped slurry - 598.000 bbl Displaced slurry - 683.000 bbl Functioned DV collar Alaska Oil & Gas Oor~s. Anchorage ,rnrnission Progress Report .. Facility M Pt F Pad Well MPF-50 Rig Nabors 22E Page 2 Date 12 December 97 Date/Time 20 Apr 97 21 Apr 97 22 Apr 97 23 Apr 97 24 Apr 97 25 Apr 97 22:00-00:00 00:00-01:00 01:00-01:15 01:15-02:30 02:30-03:30 03:30-04:30 04:30-05:00 05:00-05:45 05:45-06:00 06:00-10:00 10:00-13:30 13:30-14:00 14:00-17:30 17:30-18:30 18:30-20:30 20:30-01:30 01:30-02:00 02:00-02:30 02:30-03:30 03:30-05:00 05:00-05:15 05:15-06:00 06:00-06:30 06:30-22:30 22:30-23:00 23:00-00:00 00:00-01:30 01:30-02:30 02:30-06:00 06:00-14:00 14:00-16:00 16:00-20:00 20:00-21:30 21:30-22:00 22:00-23:30 23:30-02:30 02:30-03:30 03:30-04:30 04:30-05:30 05:30-06:00 06:00-07:30 07:30-08:30 08:30-14:00 14:00-15:00 15:00-03:30 03:30-04:00 04:00-04:30 04:30-05:00 05:00-06:00 06:00-06:00 06:00-09:30 09:30-12:00 12:00-13:30 13:30-14:30 Duration 2hr lhr 1/4 hr 1-1/4 hr lhr lhr 1/2 hr 3/4 hr 1/4 hr 4hr 3-1/2 hr 1/2hr 3-1/2 hr lhr 2hr 5hr 1/2 hr 1/2 hr lhr 1-1/2 hr 1/4 hr 3/4 hr 1/2 hr 16hr 1/2 hr lhr 1-1/2 hr lhr 3-1/2 hr 8hr 2hr 4hr 1-1/2 hr 1/2 hr 1-1/2 hr 3hr lhr lhr lhr 1/2 hr 1-1/2 hr lhr 5-1/2 hr lhr 12-1/2 hr 1/2 hr 1/2 hr 1/2 hr lhr 24 hr 3-1/2 hr 2-1/2 hr 1-1/2 hr lhr Activity Circulated at 1311.0 ft Mixed and pumped slurry - 406.000 bbl Displaced slurry - 99.000 bbl Cleared Shaker discharge line Rigged down Cement unit Rigged down Bell nipple Installed Casing head Rigged up BOP stack Tested Casing head Rigged up BOP stack Tested BOP stack Installed Wear bushing Made up BHA no. 3 Singled in drill pipe to 1310.0 ft Drilled installed equipment - DV collar Singled in drill pipe to 7479.0 ft R.I.H. to 9011.0 ft Circulated at 9011.0 ft Tested Casing Drilled installed equipment - Float collar Drilled to 9140.0 ft Circulated at 9140.0 ft Performed formation integrity test Drilled to 11006.0 ft Circulated at 11006.0 ft Pulled out of hole to 9050.0 ft Serviced Top drive R.I.H. to 11006.0 ft Drilled to 11382.0 ft Drilled to 11851.0 ft (cont...) Circulated at 11851.0 ft Pulled out of hole to 127.0 ft Downloaded MWD tool Pulled BHA Made up BHA no. 4 R.I.H. to 9100.0 ft Serviced Block line Serviced Top drive R.I.H. to 11851.0 ft Drilled to 11946.0 ft Circulated at 11946.0 ft Pulled out of hole to 9070.0 fi Repaired Top drive motor R.I.H. to 11946.0 fi Drilled to 13375.0 ft Circulated at 13375.0 ft Pulled out of hole to 11850.0 ft R.I.H. to 13375.0 ft Drilled to 13471.0 ft Drilled to 14709.0 ft (cont...) Drilled to 14899.0 ft (cont...) Circulated at 14899.0 ft Pulled out of hole to 13000.0 ft R.I.H. to 14899.0 ft Facility M Pt F Pad Progress Report Well MPF-50 Rig Nabors 22E Page Date 3 12 December 97 Date/Time 26 Apr 97 27 Apr 97 28 Apr 97 14:30-22:00 22:00-00:30 00:30-03:00 03:00-04:00 04:00-04:30 04:30-06:00 06:00-07:00 07:00-09:30 09:30-10:30 10:30-12:30 12:30-17:30 17:30-18:30 18:30-19:30 19:30-20:30 20:30-21:00 21:00-21:45 21:45-22:00 22:00-23:00 23:00-23:15 23:15-06:00 06:00-06:30 06:30-07:00 07:00-08:30 08:30-09:00 09:00-16:30 16:30-17:00 17:00-19:30 19:30-20:15 20:15-21:45 21:45-22:30 22:30-23:30 23:30-00:30 00:30-01:30 01:30-03:00 03:00-04:30 04:30-05:00 05:00-06:00 06:00-15:00 15:00-16:00 Duration 7-1/2 hr 2-1/2 hr 2-1/2 hr lhr 1/2 hr 1-1/2 hr lhr 2-1/2 hr lhr 2hr 5hr lhr lhr lhr 1/2 hr 3/4 hr 1/4 hr lhr 1/4 hr 6-3/4 hr 1/2hr 1/2 hr 1-1/2 hr 1/2 hr 7-1/2 hr 1/2hr 2-1/2 hr 3/4 hr 1-1/2 hr 3/4 hr lhr lhr lhr 1-1/2 hr 1-1/2 hr 1/2 hr lhr 9hr lhr Activity Drilled to 15685.0 ft Circulated at 15685.0 ft Pulled out of hole to 9050.0 ft Serviced Block line Serviced Top drive R.I.H. to 14750.0 ft R.I.H. to 15685.0 ft (cont...) Circulated at 15685.0 ft Circulated at 15685.0 ft Circulated at 15685.0 ft Pulled out of hole to 500.0 ft Pulled BHA Downloaded MWD tool Pulled BHA Retrieved Wear bushing Worked on BOP - Top ram Tested Top ram Rigged up Casing handling equipment Held safety meeting Ran Casing to 7300.0 ft (7in OD) Held safety meeting Serviced Mechanical brake Ran Casing to 9050.0 ft (7in OD) Circulated at 9050.0 ft Ran Casing to 15663.0 ft (7in OD) Rigged up Cement head Circulated at 15663.0 ft Mixed and pumped slurry - 48.000 bbl Displaced slurry - 595.000 bbl Tested Casing Rigged down Cement head Installed Seal assembly Rigged down Top ram Rigged down BOP stack Installed Xmas tree integral components Tested Xmas tree integral components Installed Hanger plug Laid out 5in drill pipe from derrick Serviced Block line MPU FILE COPY EXPLORATION (ALASKA) INC. BP Milne Point Unit TO: Rossberg/Hill FROM: Dan Robertson DATE: RE: 5/10/97 MP F-50 DATA FRAC AND FRAC SERVICE CO'S.: DS, Peak JOB SUMMARY Note that well was perforated and a bottomhole pressure survey done 5/9/97. Pressure survey indicated 2439 psi at 7223 TVD; pressure dropping at 60 psi/hr during last 10 min of 45 min stop. Well on vaccuum initially. Pumped 109 bbls at 30 bpm, 0 psi for most of the 109 bbls until hole filled to get enough whp to set tree saver cups. Pumped 300 bbl data frac. Leakoff coefficient estimated at 0.0029 based on data frac. Fluid efficiency of 37%. Pumped frac job as redesigned. Began reducing rate with 120 bbls left till shut down in attempt to induce screenout. Last 30 bbls pumped at 6 bpm, 1600 psi. Possibly 30 psi increase prior to shut down. 159M# 16/20 carbolite placed behind pipe. No ISIP increase between data frac and frac after hydrostatic differences considered. Fluids left in wellbore: 100 bbls diesel (2610'), seawater below this to perfs. Frac gel slurry in water bath at 173 F broke in under 2 hrs. INJECTIVITY TEST Design Rate, Bbls Max Rate, Final STP, ISIP, NWB friction, Treat grad, BPM Pumped bpm psi PSI psi psi/ft 40 109 40 1780 820 na 0.51 DATA FRAC Bbls Bbls XL gel Time XL gel on Final STP, psi ISIP, psi NWB friction, Treat grad, Pumped to Perfs perfs psi psi/ff 40 300 7.5 1950 1245 Iow 0.61 06~03/97 10:03 AM DATA FRAC & FRAC SENT VIA MICROSOFT MAIL ANNP WHP PSIG PSIG RATE BPM PUMPI, .. j SUMMARY STAGE CUM BBL BBL COMMENTS FRAC Sand Lead prop Tail prop Design total Treesaver pumped, behind pipe, behind behind pipe, Liner Sand, rubber left in Job was M# M# pipe, M# M# M# hole? /size /size 159.1 Flush 169.3 16/20 n/a 152 10.2 none Ft of sand Estimated Final ISIP, psi ISIP Incr Actual TSO, design, TSO, in Pipe sand top STP, over datafrac pad/total vol min Nolte psi % Plot 440 14850 1600 1220'- 0 16 ? none *including hydrostatic of 100 bbls diesel in hole for comparison to data frac ISIP MPU FILE COPY DATE/TIME OPERATIONS SUMMARY 5/10/97 1000 MIRU frac, vac, pump. Pre job operational and safety meeting. Pressure test at 7000 psi. Set trips at 6000 psi. AMBIENT= 10 F, WIND=20 MPH. SIWHP= 0, CAP= 500 psi 1835 PUMP FRAC AS PER REVISED TSO 2030 SECURE WELL. RDMO frac, vac, pump. PUMPING SUMMARY TIMEI RATE ANNP WHP ISTAGEI CUM COMMENTS BPM PSIG PSIG BBL BBL 5/10/97 DATA FRAC DISPLACEMENT = 585 BBLS to top perf -- 1419 0/40 500 0. 0 Attempt injection to build whp to set tree saver cups. Got pressure increase at 109 bbls i.e 109 bbls to fill hole. Increase to 1400 psi reduce rate and set tree saver cups 1425 40 900 1780 0 145 start injection test 1428 40 900 1780 193 SD for ISIP=820 psi. hammering. FG-0.51 I Start FLA I Start XL 1437 0/40 650 450 0 194 Stg 40# XL gel pad 1445 40 738 1770 325/0 519 stage seawater flush 1451 40 800 2080 260 780 Pad at perfs. 1458 40 790 i 1950 560/0 1080 SD pumps. ISIP-1245 psi, FG=0.61 psi/ft I Monitor WHP. FRAC 1835 0/40 I 268 800 0 0 Establish rate with 40# gel t Start FLA Start XL Stage pad 1839 40.3 620 1600 168/0 168 Stage 1 ppg 16/20 CL 1843 40.1 710 1690 170/0 338 Stage 2 ppg 26/0 364 3 ppg. 1845 40.1 I 7401750 40/0 404 4 ppg I 52/0 456 5 ppg 1847 40.3 745 1820 I 62/0 518 6 ppg 1849 40.1 763 1848 I 71/0 589 7 ppg xlink at perfs at 585 bbls 1851 40.1 770 1931 77/0 666 8 ppg 1852 40.1 780 1995 83/0 749 9 ppg, 1 ppg on perfs at 753 cum 1857 39.9 800 2086 87/0 835 10 ppg 1901 39.9 810 2160 227/0 Stage flush, 7 ppg on perfs, 1907 40.3 910 2570 266 1334 9 ppg on perfs, start bleed in dsl MPU FILE COPY PUMPING SUMMARY 1910 40.0 850 2460 1421 10 ppg on perfs :1911 40 780 2250 399 1464 cut rate to 30 bpm 1912 30 2040 cut to 20 bpm, 15 bpm, 10 bpm 1916 10 600 1650 500 1566 1918 6 570 1560 520 1923 6 550 1600 550/0 1613 Sd pumps. Monitor WHP. ISlP=1420 psi. 100 bbls diesel in hole. MPU FILE COPY L . . Page 5 .... ~' FLUIDS PUMPED DOWNHOLE INJ TEST& DATA FRAC: 1080 Bbls FRAC: 1513 Bbls Diesel: 100 Bbls 2693 TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME 50 bbls diesel to gray diesel tank PETREDAT WIN DOW GEL QUALITY CONTROL CHECK SEA H20 SEA H20 40# GEL 40# GEL PIPE XL XL pH TEMP pH VISCOSITY TIME TIME pH DF/FRAC 7.25 78 8.7 35 14 min 3 min 20 sec 8.8 FLUID ADDITIVES DS YF 140D FRAC FLUID SYSTEM w/ 9.2 gpt J877 Guar LFC, 1 gpt F-75N surfactant, 0.3 Ibs/mgal M275 bactericide, 5 gpt J899 Activator, 2.2 lbs/mgal L10 Boric acid, 1.5 lb/mgal J218 AP breaker, 40 Ib/mgal B1 adomite regain. 40 Ib/mgal adomite regain in data frac and pad only. No ESL. Sieve Analysis: 0% fines, 0.2% passed through 20 mesh but not through 30 mesh, 25.8 % passed through 18 mesh, 69.3% passed through 16 mesh, 4.6% passed through 12 mesh, 0.3 % passed through 8 mesh. Vortex closure times 1:03 min and 00:42 min on 2 samples. Xlink time 3:00 min. MPU FILE coPY SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX/ARCO Well Name: MPF-50 Rig Name: N-4ES AFF# 347069 Accept Date: 05/25/97 Spud Date: . Release Date: 06/04/97 MAY 25, 1997 RIG ACCEPTED @ 0100 HRS. MI/RU & LEVEL DERRICK & BERM & SAFE OUT EQUIPMENT. ND FRAC TREE & NU BOP'S TEST BOP'S TO 5000 PSI (NO RETURN CALL FROM AOGCC) WILL CONTACT & SEND TEST TO AOGCC. MAY 26, 1997 TEST BOP'S 250 LOW & 5000 HIGH. LD TEST JT CONT LOADING 2 7/8" & STRAP & DRIFT SAME IN SHED. PU & RIH W/MULE SHOE & 7" SCRAPER SPACED OUT & TAG SD @ 14842'. FILL HOLE (63 BBL) & CIRC OUT FREEZE PROTECTION. REV CIRC & WASH 14842' TO 14985' (WORK THRU HARD SPOT @ 14842') 4.5BPM @ 1000 PSI LOSS RATE APP 5 BPH. MAY 27, 1997 REV & WASH F/14842', 15016' @ 4 BPM HARD SPOT @ 15016' ATTEMPT TO WASH THROUGH FLUSH W/100 BBL SEA H20 & PSI TO 2600 NO RESULTS. POOH WFFBG CHANGE RAMS IN BOP & TEST SAME TO 5000 MU BHA #2 & PU 3.5" DP & RIH. MAY 28, 1997 LUB RIG TIH PU 3 ~" DRILL PIPE (DRIFT & S.L.M) TAG @ 15010' KELLY UP ROTATE THROUGH HARD SPOT TO 15025' RU REV & WASH DOWN TO 15032' STUCK PIPE @ 15032'. WORK STUCK PIPE FREE ATTEMPT TO REV & WASH NO FOWARD PROGRESS TO PERF TO REV KELLY UP CLEAN OUT TO 15274' REV OUT CLEAN EACH CONN STUCK PIPE @ 15267', 7' ABOVE CLEAN OUT DEPTH 27' ABOVE TOP PERF WORK STUCK PIPE PUMP 1.6% EP MUD LUBE & .6% LUBE TEX AROUND FRAC SAND & LCM W/BU PUMP LOW/HIGH SWEEP, SWEEP CARRIED OUT APPROX. 10 GAL FRAC SAND LCM, SMALL AMOUNT OF SHALE LOOKING MATERIAL THAT CAN BE EASILY BROKEN W/FINGERNAIL. PUMPED 2ND LOW/HI SWEEP BU @ 0600 HRS. NOTE: ABLE TO WRAP MORE TORQUE IN STRING AFTER RUNNING EP/LUBE TEX. WORKING TORQUE IN STRING AFTER RUNNING EP/LUBE TEX. WORKING TORQUE UP & DOWN TO 19000' LBS WORKING STRING UP 250k. FISHING HAND & BACKOFF HAND ON EARLY FLIGHT. MAY 29, 1997 SERVICE RIG CONT WORK STUCK PIPE PU 250k SO 40k CLOSE BAG. PRESS UP TO 2600# BLED OFF WORK PIPE CAME FREE LOST 65k PU WT. TOH LD 47 JTS DP, PMP DRY JOB TOH TIGHT ON CONNS SLIP CUT 84' DRILL LINE TOH W/3.5 DP & SCRAPPER W/BIT. CHANGE OUT/HYDRILL BLADDER. TEST HYDRILL BLADDER TO 2500# OK. RIH W/6" BIT FOR CLEAN OUT. Page 1 of 3 SUMMARY OF DALLY OPERATIONS MAY 30, 1997 LUB RIG TIH FOR CLEAN OUT TAG TOP SAND @ 15267' PU WT 140k, SO 84k REV CIRC BU ROT WASH TO 15295' REV TO SURFACE UNTIL CLN RETURNS FLUID LOSSES 36 BPH. STUCK @ 15295' WORK PIPE 250k UP/50k DOWN PUMP LOW & HIGH SWEEP PRESS UP 2000 ON BACK SIDE/PRESS UP 2000 ON TUBING. NO CHANGE WORK PIPE NOT ABLE TO ROTATE CIRC WK PIPE, SPOT 40 BBL LCM PILL. RIG UP SWS APR RIH W/FREEPOINT TOOL, PUMP W/LINE DOWN 3 BPM/900# LOG/FREEPOINT PIPE FLUID LOSSES 5 BPH. MAY 31, 1997 LOG/FREEPOINT PIPE, INDICATE STUCK @ TOP OF COLLARS @ 15167' POOH W/FREEPOINT RD SAME. SHOT RUN W/BK OFF, RU RIH W/STRING SHOT, PUMP DOWN 3 BPM @ 850# LOG ON DEPTH RD GREASE HEAD WORK LEFT TORQUE IN STRING FIRE BK OFF SHOT BK OFF @ 15167' POOH W/WIRELINE RD SWS MIX PUMP DRY JOB, POOH LD 90 JTS DP POOH W/162 STDS DP LEFT BHA#3 IN HOLE (97.22" BIT/BIT SUB/3 DC. STRAP MU FTA #4 (SCREW IN SUB B. JAR, 0 JAR, 10 4 :~,4 COLLARS, ACC JAR) SLIP 42" DRILL LINE TIH W/FISHING ASSY ON 3.5 DP CK TORQUE ON ALL CONN. JUNE 01, 1997 LUB RIG TIH W/FTA, PU 79 JTS 3.5 DP ENGAGE SCREW INTO FISH @ 15196' WORK PIPE JAR ON FISH. SPOT 3 BBL DIESEL ARUND BHA CONT TO JAR SHUT IN ANNUL PRESS UP TO 1400# NO EFFECT. CONT JAR ON FISH CIRC 3 BPM W/ADDING NUT PLUG. MIX PUMP 40 BBLS HIGH CAUSTIC PILL, PUMP AROUND BHA, WK FISH RIG REVERSE SWEEP CAUSTIC W/JARING, CIRC SWEEP OUT NO EFFECT. CIRC OUT SWEEP JAR WK FISH WHILE W/FOR DIESEL. PUMP 280 BBLS DIESEL, CHASE W/8.5 BRINE BALANCE ACROSS ANNUL WK FISH JAR NO EFFECT. CIC OUT DIESEL 3-5 BPM JUNKING DIESEL TO TT. JUNE 02, 1997 CIRC OUT DIESEL W/8.5 BRINE. RIG UP SWS FOR STRING SHOT BELOW JARS RIH W/STRING SHOT CCL IN PLACE WORK LEFT HAND TORQUE DN MISFIRE W/STRINGSHOT OOH W/WIRELINE STRING SHOT (BAD) SHORT IN LINE, MU NEW STRINGSHOT RIH W/STRINGSHOT LOG IN PLACE. WORK LEFTHAND TORQUE DN FIRE SHOT @ 15196' PU WT 156k LOG BK DOWN W/CCL SHOT SUCCESSFUL POOH W/SWS STRINGSHOT LD SAME. PUMP DRY JOB TOOH W/3.5 DP LD 95 JTS 15-25k DRAG CUT SLIP 84' DRILLINE. TOOH W/3.5 DP, LD 95 JTS 15-25k DRAG CUT SLIP 84' DRILLINE. TOOH W/3.5 DRILLINE TOOH W/3.5 DP & JARS (TORQUE CK EACH JT). JUNE 03, 1997 LUB RIG TOOH BK OFF @ BTM BUMPER SUB, LEFT SCREW IN SUB ON TOP OF COLLARS PULL WEAR BRUSHING TEST BOP PED SSD POLICY, INSTALL WEAR BUSHING STRAP MU FTA & TIH, CK BRKS @ 15196' REV CIRC @ TOF W/20 BBLS HIGH VIS SWEEP 5 BPM/1000# RECIP PIPE FLUID LOSS 35 BPH ATTEMPT TO ROTATE WASH OVER FISH NO GO. CIRC COND FLUID, HEAT 40 BBLS DIESEL Page 2 of 3 SUMMARY OF DALLY OPERATIONS MIX CASING WASH PER WELL PLAN DISPLACE WELL W/CLEAN SEAWATER FOR ESP RUN. JUNE 04, 1997 CIRC W/CSG WASH, CHASE W/CLEAN SW MON WELL 10 MIN STATIC POH W/WASH PIPE LD 3.5 DP. SLIP 42' DRIL LINE. CONT TOOH LD 3.5 DP, FTA #3 LD TSA TOOLS F/FLR, PULL WR SET TEST PLUG. ND 3.5 RAMS NU 2 7/8 RAMS TEST 2 7/8 RAMS TO SSD POLICY. LOAD ESP CABLE SPOOL IN MU SERVICE ESP. TIH W/ESP COMP. JUNE 05, 1997 TIH W/ESP ON 2 7/8 TBG MU REEL TO REEL ESP CABLE SPLICE @ 7300'. CONT RIH W/ESP ASSY MU PIGTAIL SPLICE TO HANGER LD HANGER RILDS, LD LANDING JT SET TWC ND BOP NU ADAPTER FLANGE, COMP TREE TEST HANGER ADAPTER FLNG TREE TO 5000# PULL TWC SET BPV, RD HD LINES TEST TO 3000#. BULLHEAD FREEZE PROTECT W/80 BBLS DIESEL, 1.5 BPM @ 1400# 15 BBLS TUBING 65 BBLS ANNUL. RD CELLAR SECURE WELL. RIG RELEASED @ 2400 HRS. Page 3 of 3 MILNE POINT, ALASKA TO: FROM: Well Name: Main Category: Sub Category: Operation Date: Rossberg/Hill L. M. Hinkel F-50 Completion E-Line O5/06/97 Date: 105109197 Objective: The pre-completion work for this well includes correlation log, gyro, USIT, perforations, and static bottom-hole pressure. Operations: 08:45 10:30 10:35 10:45 12:30 14:30 16:30 17:10 19:50 21:00 05/07/97 04:15 04:30 06:15 07:30 MIRU SWS Unit 8345. PU CCL/GR/USIT tools and pack-off. Hold safety and pre-job meeting. Start RIH using a "marked line". Stop at 15,450' (no trouble getting down hole). Attempt to power-up USlT (checked ok on surface). Having electrical/computer problems. Trouble-shoot problem. Unable to get USlT to work. Decided to start OOH. While pulling out of hole (tools at 7000'), USlT started to work. Run back in hole. Stop at 15,450' Log up to 14,200. Run back in hole and log repeat pass from 15,450' up to 15,000. Top of cement is at 15,244'. End USlT log. Continue out of hole with GR/CCL log. Finish out of hole. Lay down USlT. Pick-up Gryo and start RIH. Make "station stops" as directed by Gyrodata service hand. Gryo log completed. Lay down Gyro. Start to RU for perforation operations. Pick-up pack-off, lubricator, and BOPs. Request radio silence. Hold safety meeting. Having electrical problems with CCL. Trouble shoot. Problem with CCL corrected. Arm and pick-up gun. 08:15 12:00 13:00 05/08/97 18:00 19:45 20:00 20:10 20:45 23:10 23:25 23:35 O5/O9/97 01:00 01:10 02:00 03:20 04:20 05:30 06:30 Attempted to pressure test lubricator. Had "O" ring failure. Lay down lubricator and gun. Safe-out gun. Replace bad "O" ring and inspect all others. Re-arm gun. Pick-up gun and lubricator. Second attempt to get a pressure test also failed. This time the pack-off is leaking. Decide to shut down operations as Nabors 22E Rig will be moving in several hours and SWS equipment will be in the way. Operations will resume after Rig move. Rig move completed. Continue with operations MIRU SWS Unit 8345. Pick up pack-off, lubricator, and BOPs. Hold safety and pre-job meeting Request radio silence. Arm and pick-up gun (20'). Pressure test lubricator and well head connection to 1500 psi. Good test. Open top master and start RIH. Stop at 15,165' Log shorts at 15,091' to 15,132'. Make a (+)20 ft correction. Log repeat pass with no further corrections. Drop back down hole to 15,375'. Log gun into place with TS at 15,294' - BS at 15,314'. Fire gun. Log off Start POOH. Well on vacuum. Finish OOH. LD gun. All shots fired. Release radio silence. Pick-up CPLT for pressure/Temp survey. And start RIH. Parked sensor at 15,304' md/7,223' tvd. Record press/temp for 55 mins. Well still on a slight vacuum. Final pressure recorded was 2439.1 and the final temp was 164.8°F. Pressure dropping at 0.9 psi/min. Start POOH. Finished OOH. (Due to a lower reservoir pressure reading than expected, it was requested that SWS "bench-test" the press/temp tool. It was found to be with-in specs). RDMO. Summary A GR/CCL correlation log was recorded. An Ultrasonic Imager (USIT) log was also recorded to determine the condition of the cement bond and the TOC. TOC is at 15,244' md and there is excellent bond across the Kuparuk formation. A gyro survey was also included. These logs were ran on a "marked line". The Kuparuk "A" sand was perforated from 15,294' md to 15,314 md' using a 3 3/8" gun at 6 spf. A press/temp survey was recorded. However, the well was not completely static. A final pressure of 2439 psi. was measured. This was lower that expected. SWS was requested to "bench-test the press/temp tool in the shop. Tool was with-in specs. Well was shut-in waiting Frac stimulation. Tie in Log GR/CCL USlT dated 05/06/97. Sperry-Sun MWD log dated 04/26/97 used as a reference source TD Tag: None Charge Type' Type 41B UP RDX, 22 gm, EH' 0.56", Pent: 12.89". CCL to Top Shot: 33" - Odometer reading 15,291.3' Interval Measured Depth ......... Top Ft. Base Ft. Gun Dia. Shot Density Orientation Phasing 15,294 II 15,314 ii 3 3/8" !1 6 SPF JL Random 11 60° SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPF-50 Rig Name: N-4ES AFE# 347069 Accept Date: 07/20/97 Spud Date: - Release Date: 07/30/97 July 21, 1997 MIRU. Level derrick & safe out equipment & berm. Pull BPV, take on seawater & set TVVC. Rig accepted 07/20/97 @ 1300 hrs. ND tree, NU BOP's. Test BOP's. Test waived by Chuck Sheve. Change out annular sealing element (would not test). Test annular preventer. Pull TWC, MU landing jt & BOLDS. Pull hanger to floor & lay down same. Change out well bore fluids, suspect GLV leaking & pull 3 jts & lay down GLM & cont to circ. July 22, 1997 POOH & LD 150 jts. tubing & stand back other & LD ESP assy. Clean floor. Change rams to 3-1/2" & test. MU FTA #1 & RIH with same on 3-1/2" DP. July 23, 1997 Cont RIH with FTA #1 to 15114'. Troubleshoot & repair electrical problem in SCR system. Rev ¢irc @ 114' & displace wellbore with viscofied fluid. RIH to 15150' & attempt to wash sand to fish top (no results). POOH & LD FTA #1. TIH with FTA #2, bit to clean out fish top. July 24, 1997 Lube rig. Cont TIH with FTA #2 & DP. Slip/cut drilling line. Finish TIH with FTA #2 & DP. Rotate/wash f/15150' t/15162'. Rev out. Attempt to cont rev/wash, no go. Rotate/wash f/15162' to top of fish at 15208'. Rev out carbolite. Rev until well clean. Start TOOH with FTA #2 & DP. Finish TOOH. PU FTA #3. TIH w/DP. Screw into TOF at 15208'. Attempt to jar fish free. Release "j-joint". TOF now 15170'. Rev circ. LD 7 jt DP. Slip drilling line. Start TOOH with FTA #3. July 25, 1997 Lub rig. Finish TOOH w/DP & FTA #3. PU/MU FTA #4. Start TIH w/FTA #4 & DP. Finish TIH with FTA #4. Start EP mud lube, rotate & washover fish f/15170' t/15260' (Unable to make further progress, trip for new shoe). Pull 4 stds. Stop & cut drilling line. Cont TOOH w/DP & FTA #4. Page July 26, 1997 Lub rig. TOOH w/DP & FTA #4. Clean carbolite from boot baskets, LD shoe #1. PU shoe #2. Repair Cat engine #1. Start TIH w/FTA #5 & DP. Stop at 13433' & rev circ w/hi-vis sweep. Very small amour of carb in returns. Cont in hole with remaining DP to TOF at 15170'. Swallow T©F & resume washover operations at 15260' to 15289'. Unable to make further progress, trip for new shoe. Start TOOH w/DP & FTA #5. Slip drilling line. Cont TOOH. July 27, 1997 Finish TOOH w/FTA #5. LD shoe #2. PU shoe #3. TIH with FTA #6. Washover fish f/15289' t/15307'. Start TOOH w/DP & FTA #6. Finish TOOH w/FTA #6. Clean carbolite from boot baskets. LD washpipe. PU/MU FTA #7. Cut/slip drilling line. TIH w/FTA #7 & DP. Latch J-tool. Pull fish free. Start TOOH w/DP, FTA #7 and fish. July 28, 1997 Lub rig. TOOH w/FTA #7. LD FTA. Recovered fish. LD fish (3 ea. 4-3/4" DC & 6-1/8" bit) MU 4-3/4" mule shoe. Start TIH w/DP. Stop & rev CBU at 4000',8700' & 13400'. No carbolite in returns. Cont in hole w/DP to 15300'. Rev bottoms up. Tag top of carbolite at 15307'. Rev circ down to 15575'. Heavy carb returns. Rev circ sweeps until well clean. LD DP to 15365'. Start rev circ casing wash. July 29, 1997 Rev circ casing wash. Chase with filtered SW. Pump 3 complete circulations. Start TOOH, laying down DP. Finish TOOH w/DP & mule shoe. Set test plug. Change BOP pipe rams to 2-7/8". Test pipe rams per AOGCC. State waived right to witness test - J. Spaulding. Pull test plug. RU for 2-7/8" tubing. PU & service ESP assy. July 30, 1997 Lube rig. Start TIH, w/ESP completion & 2-7/8" tubing. Stop. Change out cable reels. Make reel to reel splice. Cont TIH w/completion. PU tubing hanger & landing jt. Splice in upper pig-tail cable. Check cable, ok. Land hanger. PU wt. RILDS. LD landing jr. Set TVVC. ND BOP's. NU tree. Test tubing hanger & tree, ok. Pull TVVC & install BPV. Freeze protect tubing & annulus with diesel. Check cable, ok. Blow down lines. Secure cellar. Rig released 07/30/97 @ 0300 hrs. Page 2 BP EXPLORATION MILNE POINT / MPF-50 500292275600 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/ SPER 6/97 SUN DRILLING SERVICES DATE OF SURVEY: 042597 MWD SURVEY JOB NUMBER: AK-MM-70096 KELLY BUSHING ELEV. = 41.70 OPERATOR: BP EXPLORATION PAGE FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9100.00 4603.10 4561.40 9167.19 4622.21 4580.51 9259.70 4648.02 4606.32 9352.98 4673.49 4631.79 9445.63 4698.45 4656.75 73 73 74 74 74 27 29 6 11 32 N 23.39 W .00 6106.24N 2801.01W N 22.32 W 1.53 6165.60N 2826.03W N 21.50 W 1.08 6248.01N 2859.18W N 23.68 W 2.25 6330.85N 2893.64W N 23.72 W .37 6412.55N 2929.50W 6716.45 6780.85 6869.66 6959.37 7048.59 9540. 03 4723.42 4681.72 9633 . 37 4747 . 46 4705 . 76 9728 . 43 4771 . 44 4729 . 74 9821 . 45 4796 . 31 4754 . 61 9911.46 4822.15 4780.45 74 75 75 73 73 46 22 24 34 3 N 23.46 W .37 6495.98N 2965.93W N 24.08 W .90 6578.51N 3002.29W N 24.87 W .81 6662.23N 3040.40W N 24.59 W 2.00 6743.63N 3077.89W N 23.28 W 1.50 6822.43N 3112.87W 7139.63 7229.81 7321.78 7411.38 7497.59 10004.90 4849.71 4808.01 10096.65 4877.21 4835.51 10195.59 4907.40 4865.70 10289.19 4936.17 4894.47 10383.50 4965.19 4923.49 72 72 72 72 71 38 28 0 12 56 N 23.10 W .49 6904.50N 3148.03W N 21.71 W 1.46 6985.42N 3181.39W N 22.87 W 1.21 7072.60N 3217.12W N 19.99 W 2.94 7155.50N 3249.66W N 21.81 W 1.86 7239.32N 3281.67W 7586.87 7674.38 7768.58 7857.59 7947.22 10475.00 4993.63 4951.93 10566.18 5022.07 4980.37 10659.74 5051.49 5009.79 10753.52 5081.32 5039.62 10846.96 5110.30 5068.60 71 71 71 71 72 50 48 33 20 30 N 22.18 W .40 7319.96N 3314.24W N 23.18 W 1.04 7399.89N 3347.64W N 21.57 W 1.66 7482.01N 3381.45W N 21.92 W .41 7564.59N 3414.38W N 21.84 W 1.24 7647.02N 3447.49W 8034.17 8120.79 8209.58 8298.45 8387.25 10940.71 5137.41 5095.71 11035.03 5163.87 5122.17 11129.22 5190.71 5149.01 11222.97 5217.68 5175.98 11316.60 5243.99 5202.29 73 73 73 73 74 52 33 19 14 6 N 22.02 W 1.46 7730.26N 3481.00W N 23.04 W 1.09 7813.88N 3515.69W N 22.99 W .24 7896.98N 3550.99W N 24.22 W 1.26 7979.25N 3586.94W N 23.27 W 1.35 8061.49N 3623.12W 8476.95 8567.47 8657.75 8747.54 8837.38 11410.37 5269.60 5227.90 11503.73 5294.92 5253.22 11597.56 5320.18 5278.48 11691.22 5345.74 5304.04 11784.50 5371.42 5329.72 74 74 74 73 74 11 19 25 54 7 N 23.73 W .48 8144.22N 3659.09W N 23.44 W .33 8226.57N 3695.04W N 22.85 W .62 8309.66N 3730.56W N 22.86 W .57 8392.69N 3765.56W N 21.61 W 1.31 8475.69N 3799.49W 8927.59 9017.45 9107.81 9197.92 9287.56 11876.43 5396.51 5354.81 11972.57 5422.48 5380.78 12068.00 5448.61 5406.91 12163.36 5475.10 5433.40 12259.12 5501.03 5459.33 74 74 73 73 74 11 27 45 59 35 N 23.25 W 1.72 8557.43N 3833.23W N 23.23 W .27 8642.49N 3869.75W N 22.28 W 1.21 8727.12N 3905.25W N 21.49 W .83 8812.13N 3939.40W N 22.27 W 1.00 8897.67N 3973.75W 9375.98 9468.55 9560.32 9651.89 9744.04 ORIGINAL SPER~ ~UN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-50 500292275600 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/ 6/97 DATE OF SURVEY: 042597 MWD SURVEY JOB NUMBER: AK-MM-70096 KELLY BUSHING ELEV. = 41.70 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 12354.81 5527.29 5485.59 12449.25 5554.65 5512.95 12543.90 5582.62 5540.92 12639.52 5610.71 5569.01 12734.94 5639.69 5597.99 73 33 72 45 72 52 72 56 71 41 N 22.54 W 1.11 8982.73N 4008.82W N 20.49 W 2.25 9066.81N 4041.97W N 21.25 W .78 9151.30N 4074.18W N 21.86 W .61 9236.30N 4107.76W N 20.96 W 1.60 9320.93N 4140.95W 9836.04 9926.36 10016.70 10108.05 10198.90 12830.77 5670.93 5629.23 70 15 12926.21 5704.05 5662.35 69 8 13021.88 5737.94 5696.24 69 22 13116.10 5772.05 5730.35 68 10 13211.68 5808.79 5767.09 66 35 N 21.15 W 1.51 9405.47N 4173.49W N 21.03 W 1.17 9488.98N 4205.70W N 21.37 W .41 9572.39N 4238.05W N 20.43 W 1.57 9654.43N 4269.38W N 22.75 W 2.78 9736.47N 4301.83W 10289.41 10378.84 10468.24 10555.98 10644.16 13306.45 5846.35 5804.65 66 42 13403.27 5886.09 5844.39 64 49 13498.28 5927.53 5885.83 63 27 13591.99 5970.47 5928.77 62 0 13686.14 6015.91 5974.21 60 16 N 22.49 W .28 9816.79N 4335.30W N 23.84 W 2.33 9897.94N 4370.02W N 24.33 W 1.51 9975.99N 4404.90W N 22.48 W 2.34 10052.41N 4437.99W N 21.48 W 2.05 10128.86N 4468.85W 10731.16 10819.43 10904.91 10988.18 11070.60 13781.79 6064.42 6022.72 13876.87 6115.31 6073.61 13971.45 6168.95 6127.25 14066.02 6225.93 6184.23 14163.07 6287.50 6245.80 58 45 56 30 54 22 51 31 49 42 N 21.56 W 1.59 10205.54N 4499.09W N 21.62 W 2.37 10280.20N 4528.63W N 21.49 W 2.27 10352.63N 4557.24W N 20.98 W 3.03 10422.97N 4584.58W N 19.42 W 2.26 10493.34N 4610.49W 11152.98 11233.23 11311.07 11386.48 11461.36 14258.07 6350.58 6308.88 47 5 14353.64 6417.71 6376.01 43 38 14447.55 6487.97 6446.27 39 28 14543.90 6564.50 6522.80 35 19 14640.15 6644.29 6602.59 32 40 N 19.25 W 2.75 10560.37N 4634.01W N 19.65 W 3.62 10624.49N 4656.65W N 19.80 W 4.44 10683.11N 4677.66W N 21.01 W 4.37 10737.95N 4698.03W N 20.68 W 2.75 10788.24N 4717.19W 11532.21 11600.05 11662.20 11720.62 11774.38 14734.99 6725.32 6683.62 29 14828.91 6806.99 6765.29 29 14925.32 6891.52 6849.82 28 15020.32 6975.22 6933.52 28 15116.40 7059.98 7018.28 27 55 15 13 13 57 N 22.75 W 3.11 10834.03N 4735.38W N 23.21 W .76 10876.72N 4753.49W N 24.65 W 1.28 10919.09N 4772.28W N 22.19 W 1.22 10960.32N 4790.13W N 22.27 W .29 11002.20N 4807.25W 11823.63 11870.00 11916.35 11961.28 12006.50 15212.00 7144.49 7102.79 27 47 15307.81 7229.32 7187.62 27 36 15403.28 7314.13 7272.43 27 2 15499.04 7399.57 7357.87 26 38 15594.68 7485.35 7443.65 25 51 N 21.92 W .24 11043.60N 4824.06W N 21.60 W .24 11084.97N 4840.57W N 21.27 W .61 11125.77N 4856.59W N 20.82 W .48 11166.12N 4872.12W N 20.44 W .84 11205.70N 4887.02W 12051.18 12095.70 12139.51 12182.71 12224.96 SPEP -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 BP EXPLORATION MILNE POINT / MPF-50 500292275600 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/ 6/97 DATE OF SURVEY: 042597 MWD SURVEY JOB NUMBER: AK-MM-70096 KELLY BUSHING ELEV. = 41.70 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 15615.63 7504.22 7462.52 25 40 N 20.94 W 1.35 11214.22N 4890.24W 12234.05 15685.00 7566.74 7525.04 25 40 N 20.94 W .00 11242.29N 4900.98W 12264.07 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 12264.12 FEET AT NORTH 23 DEG. 33 MIN. WEST AT MD = 15685 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 336.60 DEG. TIE-IN SURVEY AT 9,100.00' MD PROJECTED SURVEY AT 15,685.00' MD SPER' -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-50 500292275600 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/ 6/97 DATE OF SURVEY: 042597 JOB NUMBER: AK-MM-70096 KELLY BUSHING ELEV. = 41.70 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 9100.00 4603.10 4561.40 6106.24 N 2801.01 W 4496.9 10100.00 4878.22 4836.52 6988.39 N 3182.57 W 5221.7 11100.00 5182.33 5140.63 7871.21 N 3540.05 W 5917.6 12100.00 5457.57 5415.87 8755.55 N 3916.90 W 6642.4 13100.00 5766.06 5724.36 9640.43 N 4264.16 W 7333.9 724.88 695.89 724.77 691.50 14100.00 6247.07 6205.37 10447.81 N 4594.11 W 7852.9 15100.00 7045.49 7003.79 10995.08 N 4804.34 W 8054.5 15685.00 7566.74 7525.04 11242.29 N 4900.98 W 8118.2 518.99 201.58 63.75 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPER-j-' SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLOR3ATION MILNE POINT / MPF-50 500292275600 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/ 6/97 DATE OF SURVEY: 042597 JOB NUMBER: AK-MM-70096 KELLY BUSHING ELEV. = 41.70 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 9100.00 4603.10 4561.40 6106.24 N 2801.01 W 4496.90 9236.62 4641.70 4600.00 6227.35 N 2851.04 W 4594.92 98.02 9610.55 4741.70 4700.00 6558.35 N 2993.28 W 4868.85 273.93 9978.06 4841.70 4800.00 6880.94 N 3137.98 W 5136.36 267.51 10307.30 4941.70 4900.00 7171.70 N 3255.55 W 5365.60 229.23 10628.82 5041.70 5000.00 7454.73 N 3370.66 W 5587.12 221.52 10956.15 5141.70 5100.00 7744.01 N 3486.56 W 5814.45 227.33 11308.22 5241.70 5200.00 8054.09 N 3619.93 W 6066.52 252.07 11676.67 5341.70 5300.00 8379.81 N 3760.12 W 6334.96 268.45 12043.30 5441.70 5400.00 8705.18 N 3896.26 W 6601.60 266.64 12405.50 5541.70 5500.00 9027.68 N 4027.29 W 6863.80 262.20 12741.35 5641.70 5600.00 9326.61 N 4143.12 W 7099.65 235.84 13032.56 5741.70 5700.00 9581.70 N 4241.69 W 7290.86 191.21 13294.69 5841.70 5800.00 9806.81 N 4331.17 W 7452.99 162.13 13529.98 5941.70 5900.00 10001.83 N 4416.58 W 7588.28 135.29 13737.91 6041.70 6000.00 10170.62 N 4485.29 W 7696.21 107.93 13924.50 6141.70 6100.00 10317.06 N 4543.23 W 7782.80 86.58 14091.37 6241.70 6200.00 10441.50 N 4591.69 W 7849.67 66.88 14244.97 6341.70 6300.00 10551.27 N 4630.83 W 7903.27 53.60 14386.36 6441.70 6400.00 10645.44 N 4664.14 W 7944.66 41.39 14515.72 6541.70 6500.00 10722.48 N 4692.15 W 7974.02 29.36 14637.06 6641.70 6600.00 10786.68 N 4716.59 W 7995.36 21.34 14753.89 6741.70 6700.00 10842.73 N 4739.03 W 8012.19 16.83 14868.68 6841.70 6800.00 10894.56 N 4761.15 W 8026.98 14.79 14982.28 6941.70 6900.00 10943.66 N 4783.34 W 8040.58 13.59 15095.71 7041.70 7000.00 10993.22 N 4803.57 W 8054.01 13.43 15208.85 7141.70 7100.00 11042.24 N 4823.51 W 8067.15 13.14 15321.78 7241.70 7200.00 11090.99 N 4842.95 W 8080.08 12.94 15434.23 7341.70 7300.00 11138.89 N 4861.70 W 8092.53 12.45 15546.14 7441.70 7400.00 11185.82 N 4879.60 W 8104.44 11.91 15657.22 7541.70 7500.00 11231.04 N 4896.68 W 8115.52 11.07 15680.00 7562.23 7520.54 11240.26 N 4900.21 W 8117.77 2.25 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPERRY-SUN DRILLING SERVICES BP EXPLOR3ATION MILNE POINT / MPF-50 500292275600 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/21/97 PAGE DATE OF SURVEY: 041597 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER.- AK-EI-70105 KELLY BUSHING ELEV. = 41.90 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -41.90 170.20 170.20 128.30 259.76 259.76 217.86 349.96 349.95 308.05 440.76 440.75 398.85 0 0 0 15 0 24 0 29 0 31 N .00 E .00 .00N .00E S 22.42 E .15 .36S .15E S 25.72 E .16 .83S .36E S 36.26 E .13 1.43S .73E S 47.88 E .12 2.02S 1.27E .00 -.39 - .91 -1.60 -2.36 532.32 532.31 490.41 623.03 623.01 581.11 715.37 715.33 673.43 806.72 806.61 764.71 896.42 896.18 854.28 0 22 0 35 1 54 2 34 3 26 N 5.68 E .88 2.00S 1.60E N 8.24 E .23 1.24S 1.70E N 14.17 W 1.50 .73N 1.39E N 24.07 W .84 4.08N .18E N 25.41 W .96 8.35N 1.80W -2.47 -1.81 .11 3 .67 8.38 986.85 986.30 944.40 1080.94 1079.70 1037.80 1174.07 1171.71 1129.81 1267.94 1264.02 1222.12 1361.55 1355.48 1313.58 5 44 8 0 9 42 11 10 13 20 N 25.71 W 2.54 14.88N 4.92W N 23.36 W 2.42 25.13N 9.56W N 22.69 W 1.84 38.32N 15.16W N 23.15 W 1.56 53.99N 21.79W N 21.74 W 2.34 72.36N 29.35W 15.61 26.86 41.19 58.20 78.06 1453.85 1444.62 1402.72 1545.99 1532.50 1490.60 1639.97 1621.44 1579.54 1733.18 1708.84 1666.94 1825.40 1794.46 1752.56 16 38 18 17 19 23 21 13 22 23 N 18.62 W 3.69 94.78N 37.52W N 21.27 W 1.98 120.77N 46.98W N 22.32 W 1.24 148.95N 58.26W N 22.84 W 1.96 178.81N 70.68W N 23.04 W 1.28 210.36N 84.04W 101.89 129.49 159.83 192.18 226.44 1918.51 1880.52 1838.62 2011.51 1965.54 1923.64 2105.33 2049.34 2007.44 2197.96 2130.04 2088.14 2291.50 2209.50 2167.60 22 29 25 17 28 8 30 36 33 2 N 22.26 W .33 243.17N 97.73W N 21.86 W 3.02 278.08N 111.87W N 21.73 W 3.04 317.24N 127.52W N 21.70 W 2.67 359.44N 144.33W N 22.60 W 2.65 405.11N 162.93W 261.98 299.63 341.79 387.20 436.50 2384.72 2285.95 2244.05 2478.15 2359.21 2317.31 2570.73 2428.70 2386.80 2664.36 2495.62 2453.72 2758.66 2559.87 2517.97 36 44 39 57 42 44 46 0 48 5 N 23.88 W 4.05 454.08N 183.99W N 23.76 W 3.45 507.11N 207.39W N 22.64 W 3.11 563.33N 231.47W N 22.46 W 3.48 623.79N 256.57W N 23.77 W 2.44 687.25N 283.67W 489.81 547.77 608.92 674.38 743.38 2851.22 2619.84 2577.94 2945.20 2678.33 2636.43 3038.17 2735.29 2693.39 3133.04 2790.81 2748.91 3226.10 2841.40 2799.50 51 8 51 52 52 32 55 47 58 19 N 24.25 W 3.32 751.64N 312.36W N 23.64 W .94 818.87N 342.21W N 22.65 W 1.11 886.43N 371.08W N 23.01 W 3.44 957.31N 400.93W N 24.04 W 2.87 1028.91N 432.11W 813.87 887.43 960.90 1037.81 1115.90 O[ IGIN L SPE'~---Y-SUN DRILLING SERVICES ANCHORAGE ALAS KA PAGE BP EXPLORATION MILNE POINT / MPF-50 500292275600 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/21/97 DATE OF SURVEY: 041597 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70105 KELLY BUSHING ELEV. = 41.90 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST 3319.28 2887.84 2845.94 61 52 N 24.52 W 3.84 1102.54N 465.33W 3412.48 2929.53 2887.63 64 58 N 24.20 W 3.33 1178.46N 499.70W 3505.51 2967.42 2925.52 66 56 N 23.43 W 2.26 1256.18N 533.99W 3599.89 3003.12 2961.22 68 35 N 23.31 W 1.74 1336.37N 568.64W 3693.21 3035.28 2993.38 71 4 N 23.32 W 2.67 1416.79N 603.30W VERT. SECT. 1196.66 1279.99 1364.94 1452.29 1539.87 3786.70 3064.25 3022.35 72 49 N 22.16 W 2.20 1498.76N 637.66W 3878.10 3091.29 3049.39 72 45 N 22.71 W .58 1579.46N 670.98W 3970.84 3118.58 3076.68 73 0 N 22.68 W .27 1661.23N 705.17W 4001.00 3127.34 3085.44 73 13 N 21.98 W 2.35 1687.93N 716.14W 4064.56 3145.49 3103.59 73 34 N 22.49 W .95 1744.31N 739.19W 1628.74 1716.03 1804.66 1833.51 1894.41 4156.56 3171.08 3129.18 74 7 N 22.57 W .59 1825.93N 773.05W 4250.03 3196.21 3154.31 74 41 N 22.50 W .61 1909.08N 807.55W 4344.33 3220.72 3178.82 75 10 N 22.88 W .65 1993.09N 842.68W 4438.97 3245.99 3204.09 73 50 N 22.69 W 1.42 2077.17N 878.01W 4532.99 3271.82 3229.92 74 15 N 22.21 W .65 2160.72N 912.53W 1982.77 2072.79 2163.84 2255.03 2345.42 4626.59 3297.25 3255.35 74 13 N 22.59 W .39 2244.01N 946.85W 4720.24 3323.99 3282.09 72 34 N 22.59 W 1.76 2326.86N 981.32W 4813.79 3352.97 3311.07 71 19 N 22.63 W 1.35 2408.96N 1015.52W 4907.31 3383.41 3341.51 70 41 N 22.79 W .68 2490.54N 1049.66W 4938.60 3393.86 3351.96 70 16 N 22.96 W 1.44 2517.71N 1061.13W 2435.49 2525.22 2614.15 2702.57 2732.06 4969.89 3404.39 3362.49 70 22 N 22.47 W 1.50 2544.89N 1072.50W 5001.20 3414.97 3373.07 70 7 N 22.74 W 1.11 2572.09N 1083.83W 5032.47 3425.25 3383.35 71 28 N 23.10 W 4.45 2599.29N 1095.33W 5063.76 3435.11 3393.21 71 46 N 23.77 W 2.24 2626.54N 1107.14W 5095.05 3445.02 3403.12 71 18 N 23.74 W 1.47 2653.70N ll19.10W 2761.53 2790.99 2820.52 2850.21 2879.89 5126.22 3454.97 3413.07 71 27 N 23.55 W .75 2680.76N 1130.94W 5157.39 3464.87 3422.97 71 31 N 23.13 W 1.31 2707.90N 1142.66W 5188.56 3474.68 3432.78 71 46 N 23.54 W 1.49 2735.06N 1154.37W 5220.48 3484.40 3442.50 72 48 N 23.26 W 3.33 2762.97N 1166.45W 5252.40 3493.64 3451.74 73 31 N 23.62 W 2.50 2790.99N 1178.60W 2909.43 2938.99 2968.57 2998.98 3029.53 5284.32 3502.84 3460.94 72 59 N 23.18 W 2.13 2819.05N 1190.74W 5316.19 3512.07 3470.17 73 19 N 22.82 W 1.52 2847.13N 1202.66W 5348.06 3521.20 3479.30 73 24 N 22.95 W .45 2875.26N 1214.53W 5379.93 3530.25 3488.35 73 34 N 22.99 W .55 2903.39N 1226.46W 3060.09 3090.60 3121.13 3151.69 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3151.81 FEET AT NORTH 22 DEG. 54 MIN. WEST AT MD = 5379 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 336.60 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD LAST SURVEY STATION AT 5,379.93' MD SPE~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-50 500292275600 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/21/97 DATE OF SURVEY: 041597 JOB NUMBER: AK-EI-70105 KELLY BUSHING ELEV. = 41.90 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION .00 .00 -41.90 .00 N .00 E .00 1000.00 999.38 957.48 16.06 N 5.49 W .62 2000.00 1955.12 1913.22 273.54 N 110.05 W 44.88 3000.00 2712.08 2670.18 858.46 N 359.41 W 287.92 4000.00 3127.05 3085.15 1687.04 N 715.78 W 872.95 .62 44.27 243.04 585.03 5000.00 3414.56 3372.66 2571.05 N 1083.39 W 1585.44 5379.93 3530.25 3488.35 2903.39 N 1226.46 W 1849.68 712.49 264.24 THE'CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPF~-'~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-50 500292275600 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/21/97 DATE OF SURVEY: 041597 JOB NUMBER: AK-EI-70105 KELLY BUSHING ELEV. = 41.90 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASD VERTICAL DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION .00 .0 41.90 41.9 141.90 141.9 241.90 241.9 341.91 341.9 0 -41.90 .00 N .00 E .0 0 .00 .00 N .00 E .0 0 100.00 .24 S .10 E .0 0 200.00 .72 S .31 E .0 0 300.00 1.38 S .69 E .0 .00 .00 .00 .00 441.91 441.9 541.91 541.9 641.92 641.9 741.96 741.9 842.05 841.9 0 400.00 2.03 S 1.27 E .0 0 500.00 1.94 S 1.61 E .0 0 600.00 1.04 S 1.73 E .0 0 700.00 1.59 N 1.18 E .0 0 800.00 5.54 N .47 W .1 .00 .00 .00 .04 .09 942.23 941.9 1042.77 1041.9 1143.83 1141.9 1245.40 1241.9 1347.60 1341.9 0 900.00 10.91 N 3.01 W .3 0 1000.00 20.25 N 7.45 W .8 0 1100.00 33.62 N 13.19 W 1.9 0 1200.00 49.97 N 20.07 W 3.5 0 1300.00 69.37 N 28.16 W 5.7 .18 .54 1.06 1.57 2.20 1451.02 1441.9 1555.89 1541.9 1661.66 1641.9 1768.64 1741.9 1876.72 1841.9 1400.00 94.04 N 37.26 W 9.1 1500.00 123.66 N 48.11 W 13.9 1600.00 155.61 N 60.99 W 19.7 1700.00 190.65 N 75.67 W 26.7 1800.00 228.38 N 91.66 W 34.8 3 .42 4.87 5.77 6.98 8.07 1985.46 1941.9 2096.91 2041.9 2211.74 2141.9 2330.52 2241.9 2455 . 71 2341. 9 1900.00 267.92 N 107.78 W 43.5 2000.00 313.57 N 126.06 W 55.0 2100.00 365.96 N 146.92 W 69.8 2200.00 425.14 N 171.39 W 88.6 2300.00 494.04 N 201.64 W 113.8 8.74 11.46 14.83 18.78 25.19 2588.82 2441.9 2731.75 2541.9 2886.39 2641.9 3049.13 2741.9 3227.09 2841.9 2400.00 574.75 N 236.23 W 146.9 2500.00 668.92 N 275.60 W 189.8 2600.00 776.62 N 323.61 W 244.4 2700.00 894.49 N 374.46 W 307.2 2800.00 1029.70 N 432.47 W 385.1 33.11 42.94 54.64 62 . 74 77.97 3441.73 2941.9 3713.62 3041.9 4051.84 3141.9 4424.27 3241.9 4779.19 3341.9 2900.00 1202.64 N 510.56 W 499.8 3000.00 1434.52 N 610.95 W 671.7 3100.00 1733.04 N 734.52 W 909.9 3200.00 2064.15 N 872.56 W 1182.3 3300.00 2378.71 N 1002.91 W 1437.2 114.64 171.88 238.23 272.43 254.92 SPEP~¥-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 BP EXPLORATION MILNE POINT / MPF-50 500292275600 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/21/97 DATE OF SURVEY: 041597 JOB NUMBER: AK-EI-70105 KELLY BUSHING ELEV. = 41.90 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 5085.31 3441.90 3400.00 5379.93 3530.25 3488.35 2645.25 N 1115.38 W 1643.41 206.11 2903.39 N 1226.45 W 1849.68 206.27 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 7 B.P. EXPLORATION F PAD, WELL NO. MPF-50 MILNE POINT FIELD, ALASKA Gyro Multishot Survey Inside 7"CASING Survey date: 6 - MAY, 1997 Job number :A0597GCE395 CONTENTS JOB NUMBER :A0597GCE395 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT 1. DISCUSSION , SURVEY CERTIFICATION SHEET DISCUSSION JOB NUMBER · A0597GCE395 Tool 758 ~ run in WELL# MPF-50 on SCHLUMBERGER 3/8" wireline inside casing. SURVEY CERTIFICATION SHEET JOB NUMBER: ^0597GCE395 T'ne data for th~s survey and the calculations for this survey were obtained and performed by me ac~ to s~dards and procedures as set forth by Gyrodata Limited, true and correct to the best of TOIl STOOOARD OPERATIONS ENGINEER The clara and ~ for this survey have been checked by me and conform to the standards and pmg:eglm'es as se{ forth by Gyrodata Limited. Th, s report refxese~ts a directional survey of this well based on the original data obtained at the wellsite. ROB SHOUP OPERATK)NS MANAGER 2. SURVEY DETAILS SURVEY DETAILS JOB NUMBER: A0597GCE395 CLIENT: B.P. EXPLORATION SCHLUMBERGER LOCATION: F PAD. ALASKA LATITUDE: 70.505 N L~DE: 149.5 W SURVEY DATE: 06. MAY. 1997 TYPE : GYRO MULTISHOT IN 7' CASING DEPTH REFERENCE: 41.7' MAX. SURVEY DEPTH: ROTARY TABLE ELEVATION 15531' SURVEY TIED ONTO: NA SURVEY INTERVAL: 0-15531' APl NUMBER: 050-029-22756 T~ DIRECTION: 336.60 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STOODARD 3. OUTRUN SURVEY LISTING A G¥ roda t a Direct i Olla I SU rvey for B.P. EXPLORATION F PAD, WELL NO. MPF-50 MILNE POINT FIELD, ALASKA Job Number: A0597GCE395 Run Date: 6-May-97 21:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from vertical Reference: 41.7 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 336.600 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gy roda t a Direct i ona ! Survey B.P. EXPLORATION F PAD, WELL NO. MPF-50 MILNE POINT FIELD, ALASKA Job Number: A0597GCE395 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet 0.0 0.00 0.00 0.0 100.0 .22 127.63 100.0 200.0 .24 146.05 200.0 301.0 .57 146.65 301.0 400.0 .62 109.54 400.0 500.0 .16 88.76 500.0 600.0 .45 41.44 600.0 700.0 1.55 357.14 700.0 800.0 2.47 341.66 799.9 900.0 3.53 337.10 899.8 1000.0 5.97 335.81 999.4 1100.0 8.37 336.00 1098.6 1200.0 10.12 335.16 1197.3 1300.0 12.02 336.51 1295.5 1400.0 15.06 338.06 1392.7 1450.0 16.45 338.58 1440.8 1500.0 17.88 337.95 1488.6 1550.0 18.59 337.12 1536.1 1600.0 19.23 336.89 1583.4 1650.0 19.89 335.55 1630.5 1700.0 20.77 335.40 1677.4 1750.0 21.56 335.22 1724.0 1800.0 22.01 335.27 1770.4 1850.0 22.46 335.39 1816.7 1900.0 22.76 335.72 1862.9 0.0 -1.3 -2.1 -2 -2 -1 2 7 15 28 44 63 87 100 115 131 147 164 181 199 217 236 256 .5 .4 .0 .4 .7 .9 .4 .5 .7 .1 .7 .4 .0 .2 .0 .3 .4 .9 .8 .1 DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. .00 0.0 0.0 .22 .2 127.6 .08 .6 134.1 .32 1.3 140.9 .38 2.3 135.1 .47 2.9 128.3 .36 3.0 119.1 .27 2.8 86.6 .06 4.1 30.5 .09 8.4 1.5 2.44 16.3 349.0 2.40 28.6 343.4 1.76 44.6 340.5 1.92 63.7 339.1 3.05 87.1 338.7 2.81 100.7 338.6 2.87 115.5 338.6 1.51 131.1 338.5 1.29 147.3 338.3 1.59 164.0 338.1 1.76 181.4 337.8 1.59 199.4 337.6 .90 218.0 337.4 .89 236.9 337.2 .66 256.1 337.1 H O R I Z O N T A L COORDINATES feet 0.00 N 0.00 E .12 S .15 E .41 S .43 E 1.01 S .82 E 1.60 S 1.59 E 1.77 S 2.24 E 1.48 S 2.65 E .17 N 2.84 E 3.56 N 2.10 E 8.44 N .22 E 16.02 N 3.11 W 27.41 N 8.20 W 42.03 N 14.85 W 59.56 N 22.69 W 81.17 N 31.70 W 93.78 N 36.71 W 107.49 N 42.18 W 121.94 N 48.16 W 136.86 N 54.49 W 152.17 N 61.24 W 167.97 N 68.45 W 184.37 N 75.99 W 201.22 N 83.76 W 218.41 N 91.65 W 235.91 N 99.61 W Page A G¥ roda t a D i r ec t i ona I Survey B.P. EXPLORATION F PAD, WELL NO. MPF-50 MILNE POINT FIELD, ALASKA Job Number: A0597GCE395 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. H O R I Z O N T A L COORDINATES feet 1950.0 23.77 336.11 1908.8 2000.0 25.62 336.51 1954.2 2050.0 26.68 336.71 1999.1 2100.0 28.27 336.43 2043.5 2150.0 29.79 336.47 2087.2 275.8 296.7 318.7 341.8 366.1 2.05 275.8 337.0 3.72 296.7 337.0 2.11 318.7 336.9 3.20 341.8 336.9 3.04 366.1 336.9 253.94 N 107.66 W 273.07 N 116.05 W 293.29 N 124.80 W 314.46 N 133.97 W 336.70 N 143.66 W 2200.0 30.79 336.31 2130.4 2250.0 31.71 336.27 2173.1 2300.0 33.59 336.19 2215.2 2350.0 35.98 335.44 2256.3 2400.0 37.30 334.93 2296.4 391.3 417.2 444.2 472.7 502.5 2.00 391.3 336.9 1.84 417.2 336.8 3.77 444.2 336.8 4.86 472.7 336.7 2.71 502.5 336.6 359.81 N 153.76 W 383.55 N 164.19 W 408.24 N 175.06 W 434.25 N 186.75 W 461.34 N 199.28 W 2450.0 39.55 334.76 2335.5 2500.0 40.87 334.55 2373.7 2550.0 42.55 334.68 2411.1 2600.0 43.97 334.98 2447.5 2650.0 45.95 334.99 2482.8 533.6 565.9 599.1 633.4 668.7 4.51 533.6 336.5 2.65 565.9 336.4 3.37 599.1 336.3 2.87 633.4 336.2 3.95 668.7 336.2 489.46 N 212.49 W 518.63 N 226.31 W 548.69 N 240.57 W 579.70 N 255.14 W 611.72 N 270.07 W 2700.0 47.33 334.13 2517.2 2750.0 48.30 333.92 2550.7 2800.0 49.87 333.83 2583.5 2850.0 51.09 333.75 2615.3 2900.0 52.22 333.89 2646.3 705.0 742.0 779.7 818.3 857.4 3.04 705.0 336.1 1.96 742.1 336.0 3.13 779.8 335.9 2.46 818.4 335.8 2.27 857.5 335.7 644.54 N 285.69 W 677.85 N 301.92 W 711.78 N 318.55 W 746.38 N 335.59 W 781.57 N 352.89 W 2950.0 52.24 334.02 2676.9 3000.0 52.96 334.04 2707.3 3050.0 53.01 334.41 2737.4 3100.0 55.29 334.40 2766.7 3150.0 56.29 333.88 2794.8 896.9 936.6 976.5 1017.0 1058.3 .20 897.1 335.6 1.44 936.8 335.6 .61 976.7 335.5 4.56 1017.2 335.5 2.18 1058.5 335.4 817.08 N 370.25 W 852.79 N 387.64 W 888.75 N 405.00 W 925.30 N 422.51 W 962.51 N 440.55 W A Gy rod8 ~ ~ Di rec t i ona I Survey B.P. EXPLORATION F PAD, WELL NO. MPF-50 MILNE POINT FIELD, ALASKA Job Number: A0597GCE395 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. HORIZONTAL COORDINATES feet 3200.0 57.99 333.30 2821.9 3250.0 59.34 332.93 2847.9 3300.0 61.64 332.90 2872.6 3350.0 63.31 332.94 2895.7 3400.0 64.79 333.31 2917.5 1100.2 1142.9 1186.3 1230.5 1275.4 3.54 1100.5 335.3 2.76 1143.2 335.3 4.60 1186.7 335.2 3.34 1231.0 335.1 3.04 1275.9 335.0 1000.12 N 459.23 W 1038.21 N 478.54 W 1076.95 N 498.35 W 1116.43 N 518.53 W 1156.53 N 538.86 W 3450.0 66.19 333.79 2938.3 3498.0 67.29 334.32 2957.2 3550.0 68.19 335.21 2976.9 3600.0 68.65 335.27 2995.3 3650.0 70.48 335.46 3012.8 1320.8 1364.9 1413.0 1459.5 1506.3 2.93 1321.4 335.0 2.52 1365.5 334.9 2.34 1413.6 334.9 .93 1460.1 334.9 3.68 1506.9 335.0 1197.26 N 1236.91 N 1280.44 N 1322.67 N 1365.25 N 559.12 W 578.41 W 598.92 W 618.39 W 637.92 W 3700.0 71.25 335.55 3029.2 3750.0 72.44 335.90 3044.8 3800.0 72.59 336.10 3059.8 3850.0 72.85 336.25 3074.6 3900.0 72.83 336.33 3089.4 1553.5 1601.0 1648.7 1696.5 1744.3 1.54 1554.2 335.0 2.48 1601.7 335.0 .48 1649.4 335.0 .60 1697.1 335.1 .16 1744.9 335.1 1408.24 N 1451.55 N 1495.11 N 1538.79 N 1582.53 N 657.51 W 677.04 W 696.44 W 715.73 W 734.94 W 3950.0 73.01 336.32 3104.1 4000.0 73.29 336.25 3118.6 4050.0 73.53 336.24 3132.8 4100.0 73.56 336.01 3147.0 4150.0 74.03 335.82 3161.0 1792.0 1839.9 1887.8 1935.8 1983.8 .37 1792.6 335.1 .58 1840.5 335.2 .47 1888.4 335.2 .43 1936.3 335.2 1.01 1984.4 335.2 1626.30 N 1670.11 N 1713.97 N 1757.82 N 1801.65 N 754.13 W 773.37 W 792.68 W 812.09 W 831.68 W 4200.0 74.43 335.90 3174.6 4250.0 74.65 335.99 3187.9 4300.0 74.81 336.00 3201.0 4350.0 75.03 335.96 3214.1 4400.0 74.16 336.22 3227.3 2031.9 2080.1 2128.3 2176.6 2224.8 .82 2032.5 335.2 .46 2080.7 335.3 .32 2128.9 335.3 .46 2177.2 335.3 1.82 2225.4 335.3 1845.56 N 1889.57 N 1933.63 N 1977.73 N 2021.80 N 851.36 W 871.01 W 890.63 W 910.28 W 929.82 W A Gy r oda L a D t r ec ~ I ona 1 S u r v~y B.P. EXPLORATION F PAD, WELL NO. MPF-50 MILNE POINT FIELD, ALASKA JOb Number: A0597GCE395 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. HORIZONTAL COORDINATES feet 4450 . 0 73 . 86 336 · 31 3241 . 1 4500 . 0 74 . 18 336 · 25 3254 . 9 4550 . 0 74 . 25 336 . 34 3268 . 5 4600 . 0 74 . 16 336 · 13 3282 . 1 4650 . 0 73 . 92 335 . 96 3295 . 8 2272.9 2320.9 2369.0 2417.1 2465.2 · 62 2273.4 335.3 · 65 2321.5 335.3 .23 2369.6 335.4 .44 2417.7 335.4 · 59 2465.8 335.4 2065.80 N 2109.80 N 2153.86 N 2197.89 N 2241.82 N 949.16 W 968.50 W 987.84 W 1007.23 W 1026.75 W 4700.0 72.71 336.01 3310.2 4750.0 71.98 336.05 3325.4 4800.0 71.23 336.02 3341.1 4850.0 71.39 336.00 3357.2 4900.0 70.92 335.99 3373.3 2513.1 2560.7 2608.2 2655.6 2702.9 , 41 2513.7 335.4 47 2561.3 335.4 50 2608.7 335.4 32 2656.1 335.4 94 2703.4 335.4 2285.57 N 2329.11 N 2372.46 N 2415.74 N 2458.96 N 1046.24 W 1065.59 W 1084.86 W 1104.11 W 1123.36 W 4950.0 70.40 335.85 3389.9 5000.0 70.24 335.96 3406.7 5050.0 71.46 335.58 3423.1 5100.0 71.53 335.37 3439.0 5150.0 71.51 335.31 3454.8 2750.0 2797.1 2844.3 2891.8 2939.2 . 07 2750.6 335.5 40 2797.7 335.5 55 2844.9 335.5 42 2892.3 335.5 13 2939.7 335.5 2502.04 N 2545.01 N 2588.08 N 2631.22 N 2674.32 N 1142.62 W 1161.83 W 1181.22 W 1200.90 W 1220.68 W 5200.0 71.76 335.24 3470.6 5250.0 73.32 335.28 3485.6 5300.0 73.15 335.89 3500.0 5350.0 73.55 335.90 3514.3 5400.0 73.60 335.96 3528.5 2986.6 3034.3 3082.2 3130.1 3178.0 51 2987.2 335.5 11 3034.9 335.5 20 3082.8 335.5 82 3130.7 335.5 15 3178.6 335.5 2717.42 N 2760.74 N 2804.33 N 2848.06 N 2891.85 N 1240.53 W 1260.49 W 1280.28 W 1299.85 W 1319.41 W 5450.0 73.57 336.02 3542.6 5500.0 74.21 336.00 3556.5 5550.0 74.17 335.78 3570.1 5600.0 74.15 335.89 3583.7 5650.0 73.74 335.89 3597.6 3226.0 3274.0 3322.1 3370.2 3418.3 12 3226.6 335.5 28 3274.6 335.5 42 3322.7 335.5 22 3370.8 335.5 81 3418.9 335.5 2935.66 N 2979.55 N 3023.46 N 3067.34 N 3111.20 N 1338.92 W 1358.46 W 1378.11 W 1397.80 W 1417.43 W A Gy roda t a D i r ect i o,~a I Su r vey B.P. EXPLORATION F PAD, WELL NO. MPF-50 MILNE POINT FIELD, ALASKA Job Number: A0597GCE395 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. H O R I Z O N'T A L COORD I NATES feet 5700.0 73.29 335.95 3611.7 5750.0 73.56 336.01 3626.0 5800.0 73.69 335.91 3640.1 5850.0 73.45 336.04 3654.2 5900.0 73.02 336.18 3668.7 3466.2 .91 3466.8 335.5 3514.1 .55 3514.7 335.5 3562.1 .32 3562.7 335.5 3610.0 .54 3610.7 335.5 3657.9 .90 3658.5 335.5 3154.98 N 1436.99 W 3198.75 N 1456.50 W 3242.56 N 1476.04 W 3286.37 N 1495.56 W 3330.14 N 1514.95 W 5950.0 72.59 336.06 3683.4 6000.0 72.73 336.11 3698.3 6050.0 72.87 336.12 3713.1 6100.0 73.01 335.89 3727.8 6150.0 73.08 336.15 3742.4 3705.7 .89 3706.3 335.5 3753.4 .29 3754.0 335.6 3801.2 .29 3801.8 335.6 3849.0 .50 3849.6 335.6 3896.8 .50 3897.4 335.6 3373.82 N 1534.28 W 3417.45 N 1553.63 W 3461.12 N 1572.98 W 3504.79 N 1592.42 W 3548.49 N 1611.85 W 6200.0 73.50 336.20 3756.8 6250.0 74.19 336.15 3770.7 6300.0 74.01 336.37 3784.4 6350.0 74.06 336.29 3798.1 6400.0 74.33 336.25 3811.7 3944 . 7 . 84 3945 . 3 335 . 6 3992.7 1.40 3993.3 335.6 4040 . 8 . 55 4041 . 4 335 . 6 4088.9 .18 4089.5 335.6 4137 . 0 . 54 4137 . 6 335 . 6 3592.29 N 1631.20 W 3636.22 N 1650.60 W 3680.24 N 1669.96 W 3724.27 N 1689.26 W 3768.31 N 1708.62 W 6450.0 74.28 336.25 3825.3 6500.0 74.01 336.14 3838.9 6550.0 73.67 336.65 3852.8 6600.0 73.75 336.54 3866.9 6650.0 73.46 336.46 3881.0 4185.1 .11 4185.7 335.6 4233.2 .58 4233.8 335.6 4281.2 1.18 4281.8 335.6 4329.2 .27 4329.8 335.6 4377.2 .60 4377.8 335.7 3812.37 N 1728.01 W 3856.38 N 1747.42 W 3900.38 N 1766.65 W 3944.43 N 1785.71 W 3988.41 N 1804.84 W 6700.0 73.28 336.64 3895.3 6750.0 72.86 336.72 3909.9 6800.0 72.48 336.81 3924.7 6850.0 72.32 336.79 3939.9 6900.0 72.19 336.72 3955.1 4425.1 .52 4425.7 335.7 4472.9 .84 4473.5 335.7 4520.6 .78 4521.2 335.7 4568.3 .31 4568.9 335.7 4615.9 .29 4616.5 335.7 4032.37 N 1823.91 W 4076.29 N 1842.84 W 4120.15 N 1861.67 W 4163.95 N 1880.45 W 4207.71 N 1899.25 W A Gy r oda t a D i r ec t i ona 1 Su r vey B.P. EXPLORATION F PAD, WELL NO. MPF-50 MILNE POINT FIELD, ALASKA Job Number: A0597GCE395 Page MEASURED ! N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. H O R I Z O N T A L COORDINATES feet 6950.0 71.93 336.55 3970.5 7000.0 71.56 336.49 3986.2 7050.0 71.75 336.40 4001.9 7100.0 71.74 336.51 4017.6 7150.0 72.30 335.28 4033.0 4663.5 4711.0 4758.4 4805.9 4853.5 .61 4664.1 335.7 .75 4711.5 335.7 .41 4759.0 335.7 .21 4806.5 335.7 . 60 4854 . 0 335.7 4251.38 N 4294.93 N 4338~44 N 4381.97 N 4425.38 N 1918.11 W 1937.03 W 1956.00 W 1974.96 W 1994.38 W 7200.0 72.19 335.02 4048.2 7250.0 72.25 335.17 4063.5 7300.0 72.24 335.10 4078.8 7350.0 72.04 335.15 4094.1 7400.0 71.82 335.04 4109.6 4901.1 4948.7 4996.3 5043.9 5091.4 . 54 4901 . 6 335 . 7 .31 4949.2 335.7 · 14 4996 . 9 335.7 .42 5044.5 335.7 .48 5092.0 335.7 4468.59 N 4511.77 N 4554.97 N 4598.15 N 4641.26 N 2014.40 W 2034.45 W 2054.48 W 2074.49 W 2094.51 W 7450.0 71.32 334.82 4125.4 7500.0 71.37 334.49 4141.4 7550.0 71.70 334.29 4157.2 7600.0 72.10 334.29 4172.8 7650.0 72.03 334.48 4188.2 5138.8 5186.1 5233.5 5281.0 5328.5 · 10 5139.4 335.7 · 62 5186.8 335.7 .76 5234.2 335.7 .81 5281.7 335.7 · 38 5329.3 335.7 4684.23 N 4727.04 N 4769.81 N 4812.63 N 4855.53 N 2114.61 W 2134.89 W 2155.38 W 2176.00 W 2196.56 W 7700.0 72.61 334.27 4203.4 7750.0 73.18 334.18 4218.1 7800.0 72.85 334.18 4232.7 7850.0 72.38 333.95 4247.6 7900.0 72.23 333.85 4262.8 5376.1 5423.9 5471.7 5519.3 5566.9 .22 5376.9 335.6 .16 5424.7 335.6 .66 5472.5 335.6 .05 5520.2 335.6 .36 5567.8 335.6 4898.48 N 4941.51 N 4984.56 N 5027.47 N 5070.24 N 2217.17 W 2237.95 W 2258.77 W 2279.64 W 2300.60 W 7950.0 71.71 333.87 4278.3 8000.0 72.86 333.91 4293.5 8050.0 72.63 333.95 4308.3 8100.0 72.36 333.90 4323.4 8150.0 71.99 333.60 4338.7 5614.4 5662.0 5709.7 5757.3 5804.9 .03 5615.3 335.6 .30 5662.9 335.6 .46 5710.6 335.6 .55 5758.3 335.5 .94 5805.9 335.5 5112.93 N 5155.69 N 5198.59 N 5241.42 N 5284.11 N 2321.54 W 2342.50 W 2363.49 W 2384.45 W 2405.50 W A Gyrodat a DIrect t on~ 1 Survey B.P. EXPLORATION F PAD, WELL NO. MPF-50 MILNE POINT FIELD, ALASKA Job Number: A0597GCE395 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. de9. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 8200.0 73.24 333.73 4353.6 8250.0 73.22 333.95 4368.0 8300.0 72.71 333.57 4382.7 8350.0 72.74 333.50 4397.5 8400.0 74.21 333.71 4411.8 5852.5 2.51 5853.6 335.5 5900.3 .42 5901.4 335.5 5948.1 1.25 5949.2 335.5 5995.7 .16 5996.9 335.5 6043.6 2.99 6044.8 335.5 5326.87 N 2426.67 W 5369.84 N 2447.78 W 5412.72 N 2468.92 W 5455.46 N 2490.20 W 5498.39 N 2511.51 W 8450.0 74.44 333.73 4425.3 8500.0 74.11 333.52 4438.8 8550.0 73.87 333.48 4452.6 8600.0 74.40 334.23 4466.3 8650.0 74.34 334.16 4479.7 6091.7 .46 6093.0 335.4 6139.8 .78 6141.1 335.4 6187.8 .48 6189.1 335.4 6235.8 1.78 6237.2 335.4 6283.9 .17 6285.3 335.4 5541.56 N 5584.68 N 5627.69 N 5670.86 N 5714.21 N 2532.82 W 2554.21 W 2575.65 W 2596.85 W 2617.81 W 8700.0 74.19 333.81 4493.3 8750.0 74.35 334.43 4506.9 8800.0 74.60 335.43 4520.2 8850.0 74.06 335.08 4533.8 8900.0 74.26 334.93 4547.4 6332.0 .73 6333.4 335.4 6380.1 1.23 6381.5 335.4 6428.2 2.00 6429.7 335.4 6476.3 1.28 6477.8 335.4 6524.4 .49 6525.9 335.4 5757.46 N 5800.76 N 5844.39 N 5888.11 N 5931.71 N 2638.92 W 2659.92 W 2680.33 W 2700.49 W 2720.81 W 8950.0 74.09 335.16 4561.0 9000.0 73.83 334.66 4574.9 9050.0 73.55 335.71 4588.9 9100.0 73.46 336.61 4603.1 9150.0 73.69 336.37 4617.2 6572.5 .56 6574.1 335.4 6620.5 1.09 6622.1 335.4 6668.5 2.09 6670.1 335.4 6716.4 1.74 6718.0 335.4 6764.4 .65 6766.0 335.4 5975.32 N 6018.84 N 6062.40 N 6106.24 N 6150.22 N 2741.11 W 2761.49 W 2781.63 W 2801.01 W 2820.14 W 9200.0 73.69 336.26 4631.3 9250.0 74.03 336.25 4645.2 9300.0 74.24 336.10 4658.8 9350.0 74.16 335.78 4672.5 9400.0 74.38 335.76 4686.0 6812.4 .22 6814.0 335.4 6860.4 .68 6862.0 335.4 6908.5 .51 6910.1 335.4 6956.6 .64 6958.2 335.4 7004.7 .44 7006.3 335.4 6194.17 N 6238.13 N 6282.13 N 6326.06 N 6369.94 N 2839.42 W 2858.76 W 2878.19 W 2897.80 W 2917.55 W A Gy roda t a D i r ec t i ona I S u r ve¥ B.P. EXPLORATION F PAD, WSLL NO. MPF-50 MILNE POINT FIELD, ALASKA Job Number: A0597GCE395 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HOR I ZON'TAL COORDINATES feet 9450.0 74.65 335.90 4699.4 9500.0 74.93 335.88 4712.5 9550.0 74.76 335.38 4725.6 9600.0 74.89 335.34 4738.7 9650.0 75.32 335.42 4751.5 7052.9 .60 7054.5 335.4 7101.2 .56 7102.7 335.4 7149.4 1.03 7151.0 335.4 7197.7 .28 7199.2 335.4 7246.0 .86 7247.6 335.4 6413.90 N 6457.94 N 6501.90 N 6545.77 N 6589.69 N 2937.28 W 2956.99 W 2976.91W 2997.02 W 3017.15 W 9700.0 75.22 335.39 4764.2 9750.0 75.29 334.62 4777.0 9800.0 74.92 334.62 4789.8 9850.0 73.11 335.12 4803.6 9900.0 73.24 335.33 4818.0 7294.3 .21 7295.9 335.4 7342.7 1.50 7344.3 335.4 7390.9 .73 7392.6 335.4 7439.0 3.75 7440.7 335.4 7486.8 .47 7488.5 335.4 6633.66 N 6677.49 N 6721.14 N 6764.66 N 6808.12 N 3037.27 W 3057.70 W 3078.42 W 3098.83 W 3118.88 W 9950.0 72.82 335.95 4832.6 10000.0 72.55 335.72 4847.5 10050.0 72.55 335.53 4862.5 10100.0 72.31 336.62 4877.6 10150.0 72.20 336.93 4892.8 7534.7 1.45 7536.3 335.4 7582.4 .69 7584.1 335.4 7630.1 .38 7631.8 335.4 7677.7 2.14 7679.4 335.4 7725.4 .62 7727.0 335.4 6851.68 N 6895.23 N 6938.68 N 6982.25 N 7026.01 N 3138.61 W 3158.15 W 3177.83 W 3197.16 W 3215.94 W 10200.0 72.00 336.73 4908.2 10250.0 71.61 336.28 4923.8 10300.0 71.98 337.44 4939.4 10350.0 71.81 337.39 4955.0 10400.0 71.75 337.15 4970.6 7772.9 .55 7774.6 335.4 7820.4 1.15 7822.1 335.4 7867.9 2.32 7869.6 335.4 7915.5 .35 7917.1 335.4 7962.9 .47 7964.5 335.5 7069.76 N 7113.32 N 7156.99 N 7200.87 N 7244.68 N 3234.67 W 3253.60 W 3272.27 W 3290.52 W 3308.87 W 10450.0 71.55 336.95 4986.4 10500.0 71.66 336.79 5002.1 10550.0 71.59 336.76 5017.9 10600.0 71.61 336.61 .5033.7 10650.0 71.50 336.62 5049.5 8010.4 .56 8012.0 335.5 8057.8 .38 8059.4 335.5 8105.3 .15 8106.9 335.5 8152.7 .29 8154.3 335.5 8200.2 .22 8201.7 335.5 7288.38 N 7332.01 N 7375.61 N 7419.18 N 7462.72 N 3327.38 W 3346.02 W 3364.73 W 3383.50 W 3402.33 W A Gy r oda t a D i r e c t i ona I S u r vey B.P. EXPLORATION F PAD, WELL NO. MPF-50 MILNE POINT FIELD, ALASKA Job Number: A0597GCE]95 Page MEASURED DEPTH feet N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. HORIZONTAL COORDINATES feet 10700.0 10750.0 10800.0 10850.0 10900.0 71.30 336.30 5065.4 8247.6 71.28 336.14 5081.5 8294.9 71.20 336.01 5097.6 8342.3 72.26 336.38 5113.2 8389.7 72.51 336.32 5128.4 8437.4 .73 8249.1 335.5 .30 8296.4 335.5 .29 8343.8 335.5 .23 8391.3 335.5 .51 8438.9 335.5 7506.16 N 7549.50 N 7592.77 N 7636.21 N 7679.86 N 3421.26 W 3440.36 W 3459.56 W 3478.73 W 3497.85 W 10950.0 11000.0 11050.0 11100.0 11150.0 73.60 336.24 5142.9 8485.2 73.62 336.01 5157.0 8533.2 73.42 335.76 5171.2 8581.1 73.20 335.60 5185.6 8629.0 73.20 335.33 5200.0 8676.9 .20 8486.7 335.5 .45 8534.7 335.5 .61 8582.6 335.5 .54 8630.5 335.5 .52 8678.4 335.5 7723.65 N 7767.51 N 7811.27 N 7854.92 N 7898.46 N 3517.09 W 3536.50 W 3556.10 W 3575.82 W 3595.70 W 11200.0 11250.0 11300.0 11350.0 11400.0 73 . 20 335 . 18 5214 . 5 8724 . 7 73 . 20 335 . 01 5228 . 9 8772 . 6 73 . 67 335.30 5243 . 2 8820 . 5 74 . 04 335 . 50 5257.1 8868 . 5 74 . 16 335 . 35 5270 . 8 8916 . 6 .29 8726.3 335.5 .32 8774.1 335.5 .10 8822.1 335.5 .83 8870.1 335.5 .37 8918.2 335.5 7941.93 N 7985.35 N 8028.84 N 8072.50 N 8116.23 N 3615.74 W 3635.89 W 3656.03 W 3676.03 W 3696.03 W 11450.0 11500.0 11550.0 11600.0 11650.0 74.11 335.30 5284.5 8964.7 74.20 335.31 5298.1 9012.8 74.24 335.33 5311.7 9060.9 74.30 335.39 5325.3 9109.0 74.07 336.00 5338.9 9157.1 .12 8966.3 335.5 .17 9014.4 335.5 .10 9062.5 335.5 .16 9110.6 335.5 .26 9158.7 335.5 8159.94 N 8203.64 N 8247.36 N 8291.10 N 8334.95 N 3716.11 W 3736.20 W 3756.29 W 3776.35 W 3796.15 W 11700.0 11750.0 11800.0 11850.0 11900.0 73 . 76 336 . 98 5352 . 8 9205 . 1 73 . 80 336 . 99 5366 . 7 9253 . 1 73 . 98 337 . 21 5380 . 6 9301 . 2 74 . 18 337 . 24 5394 . 3 9349 . 2 74 . 22 337 . 07 5407.9 9397 . 3 .99 9206.8 335.5 .08 9254.7 335.5 .56 9302.8 335.5 .41 9350.8 335.5 .35 9398.9 335.6 8379.00 N 8423.19 N 8467.44 N 8511.77 N 8556.11 N 3815.32 W 3834.08 W 3852.78 W 3871.39 W 3890.07 W A Gy r oda t a D i r ec t i ona 1 Su r vey B.P. EXPLORATION F PAD, WELL NO. MPF-50 MILNE POINT FIELD, ALASKA Job Number: A0597GCE395 Page 10 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERT I CAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg. / feet deg. 100 ft. HORIZONTAL COORDINATES feet 11950 . 0 74 . 35 336 . 89 5421 . 5 12000 · 0 74 . 43 336 . 69 5434 . 9 12050 . 0 74 . 17 336 · 88 5448 . 5 12100.0 73 . 74 338 · 00 5462 . 3 12150 . 0 73 . 88 337 . 79 5476 . 2 9445.5 .42 9447.0 335.6 9493.6 .42 9495.2 335.6 9541 . 8 · 63 9543 . 3 335 · 6 9589.8 2.31 9591.3 335.6 9637.8 .48 9639.3 335.6 8600.41 N 8644.67 N 8688.90 N 8733.28 N 8777.77 N 3908.89 W 3927.86 W 3946.84 W 3965.27 W 3983.34 W 12200.0 74.09 337.67 5490.0 12250.0 74.42 337.43 5503.6 12300.0 74.61 337.22 5516.9 12350.0 74.00 337.66 5530.4 12400.0 73.68 337.58 5544.4 9685.9 .48 9687.3 335.6 9734.0 .82 9735.4 335.6 9782.2 .55 9783.6 335.6 9830.3 1.47 9831.7 335.6 9878.3 .67 9879.7 335.6 8822.24 N 8866.72 N 8911.18 N 8955.64 N 9000.04 N 4001.55 W 4019.93 W 4038.50 W 4056.97 W 4075.26 W 12450.0 73.19 338.33 5558.6 12500.0 72.88 338.53 5573.2 12550.0 72.89 338.48 5587.9 12600.0 72.92 338.37 5602.6 12650.0 72.88 338.17 5617.3 9926.2 1.73 9927.6 335.6 9974.0 .73 9975.4 335.7 10021.8 .08 10023.1 335.7 10069.5 .22 10070.8 335.7 10117.3 .40 10118.6 335.7 9044.46 N 9088.94 N 9133.40 N 9177.84 N 9222.24 N 4093.24 W 4110.83 W 4128.34 W 4145.91 W 4163.60 W 12700.0 73.07 337.87 5632.0 12750.0 71.72 338.77 5647.1 12800.0 71.70 338.70 5662.8 12850.0 70.36 338.82 5679.0 12900.0 70.55 338.46 5695.8 10165.1 .69 10166.3 335.7 10212.7 3.20 10213.9 335.7 10260.2 .13 10261.3 335.7 10307.4 2.69 10308.6 335.8 10354.5 .78 10355.6 335.8 9266.57 N 9310.85 N 9355.09 N 9399.17 N 9443.05 N 4181.50 W 4199.11 W 4216.32 W 4233.45 W 4250.61 W 12950.0 68.93 338.36 5713.1 13000.0 69.33 338.12 5730.9 13050.0 69.45 337.88 5748.5 13100.0 69.41 337.81 5766.1 13150.0 67.97 337.41 5784.2 10401.4 3.25 10402.5 335.8 10448.1 .92 10449.2 335.8 10494.9 .51 10495.9 335.8 10541.7 .14 10542.7 335.8 10588.3 2.97 10589.3 335.8 9486.66 N 9530.05 N 9573.44 N 9616.80 N 9659.87 N 4267.87 W 4285.19 W 4302.72 W 4320.38 W 4338.12 W A Gy r oda t a D i r ec t i ona 1 Survey B.P. EXPLORATION F PAD, WELL NO. MPF-50 MILNE POINT FIELD, ALASKA Job Number: A0597GCE395 Page ll MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 13200.0 67.81 337.02 5803.0 13250.0 66.43 336.42 5822.5 13300.0 66.64 336.29 5842.4 13350.0 66.87 336.11 5862.1 13400.0 65.62 335.94 5882.3 10634.6 .80 10635.6 335.8 10680.6 2.98 10681.6 335.8 10726.5 .49 10727.5 335.8 10772.5 .57 10773.4 335.8 10818.2 2.52 10819.2 335.8 9702.58 N 4356.06 W 9744.89 N 4374.26 W 9786.90 N 4392.66 W 9828.94 N 4411.20 W 9870.75 N 4429.80 W 13450.0 64.77 335.62 5903.2 13500.0 64.07 336.34 5924.8 13550.0 62.81 335.77 5947.2 13600.0 62.15 336.73 5970.3 13650.0 61.77 337.40 5993.8 10863.6 1.79 10864.6 335.8 10908.7 1.90 10909.7 335.8 10953.4 2.72 10954.4 335.8 10997.8 2.17 10998.7 335.8 11041.9 1.39 11042.9 335.8 9912.14 N 9953.34 N 9994.21 N 10034.80 N 10075.44 N 4448.42 W 4466.78 W 4484.93 W 4502.79 W 4519.98 W 13700.0 60.29 338.38 6018.0 13750.0 60.41 337.65 6042.7 13800.0 58.75 338.06 6068.1 13850.0 58.15 337.76 6094.2 13900.0 56.15 337.63 6121.3 11085.6 3.42 11086.6 335.8 11129.1 1.30 11130.0 335.9 11172.2 3.39 11173.1 335.9 11214.8 1.29 11215.7 335.9 11256.8 4.02 11257.6 335.9 10115.97 N 10156.26 N 10196.19 N 10235.67 N 10274.53 N 4536.45 W 4552.72 W 4568.97 W 4585.00 W 4600.94 W 13950.0 56.21 337.63 6149.2 14000.0 53.93 338.57 6177.8 14050.0 53.44 338.63 6207.4 14100.0 50.78 339.06 6238.1 14150.0 50.93 339.21 6269.7 11298.3 .12 11299.2 335.9 11339.3 4.80 11340.1 335.9 11379.5 1.00 11380.4 335.9 11418.9 5.35 11419.8 335.9 11457.7 .37 11458.5 335.9 10312.95 N 10350.97 N 10388.49 N 10425.28 N 10461.51 N 4616.75 W 4632.04 W 4646.74 W 4660.98 W 4674.79 W 14200 . 0 48 . 93 340 . 53 6301 . 9 14250 . 0 48 . 54 340 . 33 6334 . 8 14300 . 0 45 . 74 340 . 67 6368 . 9 14350 . 0 44 . 81 340 . 51 6404 . 0 14400 . 0 42 . 07 339 . 72 6440 . 3 11495.9 4.47 11496.7 335.9 11533.4 .84 11534.1 335.9 11569.9 5.62 11570.7 336.0 11605.4 1.87 11606.1 336.0 11639.7 5.59 11640.4 336.0 10497.43 N 10532.85 N 10567.39 N 10600.90 N 10633.23 N 4687.97 W 4700.55 W 4712.79 W 4724.59 W 4736.28 W A Gy r oda t a Di r ec t i ona 1 Survey B.P. EXPLORATION F PAD, WELL NO. MPF-50 MILNE POINT FIELD, ALASKA Job Number: A0597GCE395 Page 12 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. H O R I Z 0 N T A L COORDINATES feet 14450.0 40.49 339.82 6477.9 14500.0 37.72 339.94 6516.7 14550.0 35.85 339.71 6556.7 14600.0 34.94 339.30 6597.5 14650.0 33.02 339.63 6639.0 11672.6 3.16 11673.3 336.0 11704.1 5.54 11704.7 336.0 11734.0 3.76 11734.6 336.0 11762.9 1.87 11763.5 336.0 11790.8 3.86 11791.4 336.0 10664.18 N 10693.79 N 10721.89 N 10749.02 N 10775.19 N 4747.69 W 4758.54 W 4768.87 W 4779.01 W 4788.81 W 14700.0 32.23 339.24 6681.1 14750.0 30.05 337.60 6723.9 14800.0 29.52 336.71 6767.3 14850.0 29.35 336.73 6810.8 14900.0 28.89 337.33 6854.5 11817.8 1.64 11818.3 336.0 11843.6 4.67 11844.2 336.1 11868.4 1.38 11869.0 336.1 11893.0 .34 11893.6 336.1 11917.3 1.09 11917.9 336.1 10800.43 N 10824.47 N 10847.36 N 10869.94 N 10892.34 N 4798.28 W 4807.78 W 4817.42 W 4827.13 W 4836.63 W 14950.0 28.82 337.63 6898.3 15000.0 28.39 337.97 6942.2 15050.0 28.25 338.03 6986.2 15100.0 27.99 337.85 7030.3 15150.0 27.88 337.65 7074.5 11941.5 .32 11942.0 336.1 11965.4 .93 11965.9 336.1 11989.1 .29 11989.6 336.1 12012.7 .54 12013.2 336.1 12036.1 .28 12036.6 336.1 10914.63 N 10936.79 N 10958.78 N 10980.62 N 11002.30 N 4845.87 W 4854.91 W 4863.80 W 4872.65 W 4881.52 W 15200.0 27.78 337.66 7118.7 15250.0 27.72 337.86 7162.9 15300.0 27.49 337.64 7207.2 15350.0 27.66 338.18 7251.6 15400.0 27.10 338.25 7296.0 12059.4 .22 12059.9 336.1 12082.7 .22 12083.2 336.1 12105.9 .50 12106.4 336.1 12129.0 .61 12129.5 336.1 12152.0 1.12 12152.5 336.1 11023.89 N 11045.44 N 11066.88 N 11088.33 N 11109.69 N 4890.39 W 4899.20 W 4907.97 W 4916.68 W 4925.21 W 15450 . 0 26 . 79 338 . 63 7340 . 5 15500 . 0 26 . 60 338 . 73 7385 . 2 15531 . 0 26 . 41 338 . 96 7412 . 9 12174.7 .72 12175.1 336.1 12197.1 .38 12197.6 336.1 12210.9 .71 12211.4 336.1 11130.76 N 11151.69 N 11164.59 N 4933.54 W 4941.71 W 4946.70 W Final Station Closure: Distance: 12211.38 ft Az: 336.10 de9. A Gyroda t a Di rec t i onal Survey for B.P. EXPLORATION F PAD, WELL NO. MPF-50 MILNE POINT FIELD, ALASKA Job Number: SUB395 Run Date: 6-May-97 21:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 41.7 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 336.600 deg Vertical Section Calculated from Well Mead Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyroda t a Di rec t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-50 MILNE POINT FIELD, ALASKA Job Number: SUB395 Page SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet -41 100 200 300 400 .7 .0 .0 .0 .0 .00 0.00 0.0 .23 135.31 141.7 .38 146.30 241.7 .59 131.40 341.7 .43 100.88 441.7 0.0 0.00 0.0 0.0 - .3 .16 .6 130.3 -.8 .18 1.3 136.9 -1.6 .35 2.3 138.5 -2.3 .42 2.9 132.3 0.00 N 0.00 E .24 S .27 E .66 S .59 E 1.25 S 1.14 E 1.67 S 1.86 E 5OO 600 700 8O0 900 .0 .28 69.02 541.7 .0 .91 22.96 641.7 .0 1.93 350.67 741.7 .0 2.91 339.75 841.7 .0 4.56 336.56 941.7 -2.5 .42 3.0 124.5 -1.8 .74 2.8 105.5 .5 1.18 4.1 63.2 4.6 1.07 8.4 18.4 11.1 1.66 16.3 356.3 1.65 S 2.41 E .93 N 2.73 E 1.59 N 2.53 E 5.60 N 1.31 E 11.63 N 1.44 W 1000 1100 1200 1300 1400 .0 .0 .0 .0 .0 6.99 335.89 1041.7 9.13 335.63 1141.7 10.98 335.77 1241.7 13.47 337.25 1341.7 16.48 338.57 1441.7 21.3 2.42 28.6 346.6 35.4 2.12 44.6 342.1 53.2 1.83 63.7 339.9 74.8 2.46 87.1 338.9 100.9 2.81 115.5 338.6 20.88 N 5.27 W 33.79 N 11.10 W 49.96 N 18.39 W 69.84 N 26.98 W 94.04 N 36.81 W 1500 1600 1700 1800 1900 .0 .0 .0 .0 .0 18.66 337.09 1541.7 20.10 335.52 1641.7 21.73 335.24 1741.7 22.62 335.57 1841.7 25.11 336.40 1941.7 133.0 1.49 147.3 338.4 168.1 1.63 181.4 338.0 206.5 1.33 218.0 337.5 247.3 .76 256.1 337.2 290.9 3.26 296.7 337.0 123.72 N 48.91 W 155.95 N 62.96 W 190.80 N 78.95 W 227.89 N 95.96 W 267.80 N 113.74 W 2000.0 2100.0 2200.0 2300.0 2400.0 28.21 336.44 2041.7 31.03 336.30 2141.7 35.13 335.70 2241.7 39.76 334.73 2341.7 43.75 334.94 2441.7 340.9 3.16 341.8 336.9 398.2 1.96 417.2 336.9 462.6 4.47 472.7 336.8 538.8 4.21 565.9 336.5 627.9 2.94 633.4 336.3 313.62 N 133.61 W 366.11 N 156.53 W 425.03 N 182.61 W 494.16 N 214.72 W 574.80 N 252.83 W A Gyrodat a Di r ec t ional Survey B.P. EXPLORATION F PAD, WELL NO. MPF-50 MILNE POINT FIELD, ALASKA Job Number: SUB395 Page SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 2500.0 2600.0 2700.0 2800.0 2900.0 48.04 333.98 2541.7 732.0 52.06 333.87 2641.7 851.6 53.35 334.41 2741.7 982.4 59.01 333.02 2841.7 1132.7 66.39 333.88 2941.7 1328.8 2.25 742.1 336.0 2.30 857.5 335.7 1.19 1017.2 335.5 2 . 95 1143 . 2 335 . 3 2.86 1365.5 335.0 668.88 N 776.33 N 894.10 N 1029.09 N 1204.39 N 297.55 W 350.31 W 407.57 W 473.92 W 562.59 W 3000.0 3100.0 3200.0 3300.0 3400.0 72.20 335.83 3041.7 1591.7 73.55 336.10 3141.7 1917.8 73.87 336.31 3241.7 2274.9 71.24 336.02 3341.7 2609.9 71.53 335.36 3441.7 2899.9 2.29 1601.7 335.0 .45 1936.3 335.2 .62 2321.5 335.3 1.46 2656.1 335.4 .37 2939.7 335.5 1443.04 N 1741.37 N 2067.68 N 2374.00 N 2638.63 N 673.21 W 804.81 W 949.99 W 1085.54 W 1204.30 W 3500.0 3600.0 3700.0 3800.0 3900.0 73.57 336.01 3541.7 3222.9 73.66 335.93 3641.7 3567.5 73.08 336.13 3741.7 3894.5 73.94 336.24 3841.7 4242.8 72.31 336.78 3941.7 4574.0 .12 3226.6 335.5 .34 3610.7 335.5 .50 3897.4 335.6 .70 4281.8 335.6 .31 4616.5 335.7 2932.90 N 3247.51 N 3546.44 N 3865.15 N 4169.23 N 1337.70 W 1478.24 W 1610.94 W 1751.25 W 1882.72 W 4000.0 4100.0 4200.0 4300.0 4400.0 72.23 335.13 4041.7 4880.7 71.38 334.49 4141.7 5187.0 72.57 334.04 4241.7 5500.5 72.25 333.63 4341.7 5814.5 74.06 333.51 4441.7 6149.8 1.42 4901.6 335.7 .62 5234.2 335.7 .89 5520.2 335.6 1.26 5853.6 335.5 .72 6189.1 335.4 4450.06 N 4727.84 N 5010.50 N 5292.80 N 5593.70 N 2005.82 W 2135.27 W 2271.39 W 2409.80 W 2558.70 W 4500 . 0 74 . 17 334 . 99 4541 . 7 4600 . 0 73 . 94 336 . 25 4641 . 7 4700 . 0 74 . 99 335 . 36 4741 . 7 4800 . 0 72 . 66 335 . 81 4841 . 7 4900 . 0 71 . 95 337 . 43 4941 . 7 6504.3 6848.4 7209.1 7563.7 7874.9 .82 6525.9 335.4 .57 6862.0 335.4 .42 7247.6 335.4 .99 7584.1 335.4 2.03 7917.1 335.4 5913.50 N 6227.13 N 6556.17 N 6878.23 N 7163.39 N 2712.32 W 2853.92 W 3001.79 W 3150.52 W 3274.93 W B.P. EXPLORATION F PAD, WELL NO. MPF-50 MILNE POINT FIELD, ALASKA Job Number: SUB395 A Gy r o d a t a D i r e c t i o n a 1 Survey Page SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 5000.0 71.56 336.61 5041.7 5100.0 73.51 336.24 5141.7 5200.0 73.62 335.27 5241.7 5300.0 74.01 336.20 5341.7 5400.0 74.30 336.79 5441.7 8176.8 .25 8201.7 335.5 8481.2 2.05 8486.7 335.5 8815.5 1.01 8822.1 335.5 9166.8 1.41 9206.8 335.5 9517.7 .52 9543.3 335.6 7441.27 N 7719.94 N 8024.27 N 8343.85 N 8666.80 N 3393.06 W 3515.46 W 3653.92 W 3800.02 W 3937.36 W 5500.0 73.74 337.60 5541.7 5600.0 72.20 338.45 5641.7 5700.0 69.40 337.97 5741.7 5800.0 66.63 336.29 5841.7 5900.0 63.12 335.91 5941.7 9869.1 .83 9879.7 335.6 10195.8 2.31 10213.9 335.7 10476.8 .67 10495.9 335.8 10724.9 .58 10727.5 335.8 10942.4 2.52 10954.4 335.8 8991.54 N 9295.08 N 9556.70 N 9785.42 N 9984.18 N 4071.75 W 4192.83 W 4295.96 W 4392.01 W 4480.47 W 6000.0 60.40 337.68 6041.7 6100.0 56.19 337.63 6141.7 6200.0 50.80 339.07 6241.7 6300.0 47.98 340.40 6341.7 6400.0 42.01 339.72 6441.7 11127.2 1.39 11130.0 335.9 11287.1 1.17 11299.2 335.9 11423.3 4.79 11458.5 335.9 11540.7 1.80 11570.7 336.0 11640.9 5.50 11673.3 336.0 10154.55 N 10302.63 N 10429.39 N 10539.81 N 10634.35 N 4552.03 W 4612.50 W 4662.55 W 4703.02 W 4736.70 W 6500 . 0 36 . 55 339 . 80 6541 . 7 6600 . 0 32 . 97 339 . 60 6641 . 7 6700 . 0 29 . 83 337 . 23 6741 . 7 6800 . 0 29 . 02 337.16 6841 . 7 6900 . 0 28 . 39 337 . 97 6941 . 7 11722.8 4.43 11734.6 336.0 11792.6 3.71 11818.3 336.0 11853.8 3.32 11869.0 336.1 11910.2 .87 11917.9 336.1 11965.1 .92 11965.9 336.1 10711.33 N 10776.83 N 10833.88 N 10885.78 N 10936.55 N 4764.99 W 4789.43 W 4811.74 W 4833.85 W 4854.81 W 7000.0 27.96 337.80 7041.7 7100.0 27.75 337.76 7141.7 7200.0 27.63 338.06 7241.7 7371.2 26.41 338.96 7412.9 12018.7 .47 12036.6 336.1 12071.5 .22 12083.2 336.1 12123.9 .58 12129.5 336.1 12210.9 .71 12211.4 336.1 10986.22 N 11035.10 N 11083.56 N 11164.59 N 4874.94 W 4894.97 W 4914.74 W 4946.70 W Final Station Closure: Distance: 12211.38 ft Az: 336.10 deg. 4. QUALITY CONTROL QUALITY CONTROL REPORT JOB NUMBER: A0597GCE395 TO(~ NUMBER: 758 MAXlMU~ GYRO TEMPERATURE: 79.9 C MAXIMUM AMBIENT TEMPERATURE: 81.0 C MAXIMUM INCLI~TI~: 75.32 WlREUNE REZ~RO VALUE: N/A REZERO ERROR I K: N/A CAUBRATION USED FOR FIELD SURVEY: 1857 C, ALI~~ USED FOR FINAL SURVEY: 1857 PRE JOB MASS BALANCE OFFSET CHECK: .3 POST JOB ~ BALANCE OFFSET CHECK~: USED 0_G/N/A CONTINUOUS ~ OF SHOCK WATCHES .25 ARRIVAL AT RIG: OFF UPON COMPLETION OF SURVEY: OFF UPON RETURN TO ATLAS OFF BOTTOM UNE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING MW~ 15499 26.64 339.18 7409 11187 -4822 FINAL SURVEY 155(X) 26.60 338.73 7385 11151 -4941 FUNCTION TEST JOB NUMBER: A0597GCE395 S~xvey stalx)ns were collected at the measured depth shown below. The tables show the repeatability the gyro tool in bolh inclination and azimuth at one measured depth. INCUNATION MD. fi1 2 3 4 5 14430 15.06 1506 15.06 15.06 15.06 MDft I 2 3 4 5 1400 338 13 338.06 338.10 338.14 338.12 5. EQUIPMENT AND CHRONOLOGICAL REPORT EQUIPMENT REPORT JOB NUMBER; ^0597GCE395 SURFACE ELECTRONICS PRIMARy TOOL No. 758 GYRO SECTION DATA SECTK)N POWER SEC~ON TOOL No. 768 GYRO SECTION DATA SEC~ POWER SEC~ION A0147 C0100 C0040 A0159 CO089 CO086 COMPUTER A0349 POWER SUPPLY PRINTER A0079 INTERFACE A0087 COMPUTER A0222 POWER SUPPLY PRINTER A0029 INTERFACE A0055 A0085 A0107 WtREUNE COMPANY: SCHLUMBERGER RUN~NG GEAR SCHLUMBERGER 3 3/8' HOUSING WI ROLLERS TOP AND BOTTOM TOTAL LENGTH OF TOOL :25' MAXIMUM O.D.: 5.5 INCHES TOTAL WEIGHT OF TOOL: 500 POUNDS CHRONOLOGICAL REPORT JOB NUMBER: A0597GCE395 TI'ESDAY. 05:05 9% FINISti INHOLE REFERENCE NIAKUK 25 CttECK TOOLS FOR MPF-50. O.K. ~'E DN ESDA Y.05 06 ~97 IO:?,O 12.00 14:7,O 2O:OO 2O:?,0 21.-OO TO I.OCATION ARRIVF. I.OCATION MI.' TOOl_. STANDBY I.D [.'SIT. ~'ARM UP GYRO PI' GYRO. START INRUN SURVEY TiltRSDAY.05 07 97 00:?,0 03:?,0 O4:15 05:?,0 i .;:OO ! 6.'O0 SURVEY CONTINUOUS TO 15531' OI.'TR17N CONTINUOUS RIG DO~.~ R TN TO ATI.AS PROCESS SURVEY/CttECK TOOl. RETURN TO MII.NE POINT FIELD WITH RESULTS. RETURN TO ATI.AS. STAND BY FOR F-17 Schlumberger- GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) July 29, 1997 TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the USIT/GR/CCL (PDC) for well MPU F-50, Job # 97296, was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 1 CH LIS Tape 1 Film 3 Bluelines State of Alaska Alaska dj! & Gas Consen/ation Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 1 CH LIS Tape ! Bh,:t'~line 1 RFolded Sepia OXY USA, Inc. Attn: 'Darlene Fairly P.O. Box 50250 Midland, TX 79710 1 CH LIS Tape 1 Blueline 1 RFolded Sepia Sent Certified Mail P 067 695 365 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska __9,9.5.1~@:~,, 1,~2. j Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received b~'~'"""~~ rli:t ICl__! N G WELL LOG TRANSMITTAL -- To: State of Alaska July 23, 1997 Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 l%E: MWD Formation Evaluation Logs - ~MPF-50, AK-MW-70096 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention off Yma Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 MPF-50: 2" x 5" ~MD Resistivity and Gamma Ray Logs: 50-029-22756-00 2"x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22756-00 2"x 5" MD Neutron and Density Logs: 50-029-22756-00 2" x 5" TVD Neutron and Density Logs: 50-029-22756-00 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 _ A Dresser Industries, inc. Company 0 !::! I I_t-- I IM G c: ~:: !:t ~/I r' ~::: S WELL LOG TRANSNHTTAL _ -- To: State of Alaska July 23, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPF-50, AK-MW-70096 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention off Yan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted LIS Tape with verification listing. APl#: 50-029-22756-00 __ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 6~3O~97 GeoQueSt 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11118 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Milne Point (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape MPU B-14 L~t ( ..... INJECTION PROFILE 970607 I 1 MPU E-07 ~,~- t (L. INJECTION PROFILE 970606 I 1 MPU E-16 ~ INJECTION PROFILE 970605 1 1 MPU F-05 /-* PERFORATION RECORD 97051 7 I 1 MPU F-05 v- TEMP & PRESSURE SURVEY 97051 7 I 1 MPU F-05 ~" GR/CCL LOG 970517 I 1 MPU F-26 ~-~' !GR/CCL LOG 970525 I 1 MPU F-26 ~.~' STATIC PRESS &TEMP 970527 I 1 -- MPU F-26 v~ PERFORATION RECORD 970527 1 1 -- MPU F-50 ~ / PERFORATION RECORD 970508 I 1 MPU F-50 ,"" STATIC PRESSURE SURVEY " 970509 I 1 MPU F-57 '/* PERFORATION RECORD 970512 1 1 MPU F-62 ~/ (.~.l C INJECTION PROFILE 970608 I 1 MPU F-65 ./ PERFORATION RECORD 97051 I I 1 MPH -07 ~ .... GR/CCL RECORD 970424 I 1 MPH -07 '~ GPJCCL RECORD 970427 I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 TONY KNOWLE$, GOVERNOR ALASI~ OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 4, 1997 Randy Thomas Drilling Superintendent BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Milne Poi~nt Unit MPF-50 BP Exploration (Alaska) Inc. Permit No: 97-058 Sur. Loc.: 2068'NSL, 2680'WEL, Sec. 6. T13N, R10E, UM Btmhole Loc: 2764'NSL, 2395'WEL, Sec. 25, T14N, R9E, UM Dear Mr. Thomas: 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 permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David ~ohnston ~ -'~ dlffenclosures cc: Department of Fish & Game. Habitat Section ~'/o encl. Department of Envinornment Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COIW~vllSSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work [] Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE - 41.9' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 355018 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2068' NSL, 2680' WEL, SEC. 6, T13N, R10E Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 2574' NSL, 2313' WEL, SEC. 25, T14N, R9E MPF-50 At total depth 9. Approximate spud date Amount $200,000.00 2764' NSL, 2395' WEL, SEC. 25, T14N, R9E 04/09/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 355021, 2516'I No Close Approach 5083 15645' MD / 7560' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)} Kick Off Depth 500' Maximum Hole Angle 73.15 o Maximum surface 2858 psig, At total depth (TVD) 7160' / 3574 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btm 8628' 31' 31' 8659' 4485' 1675 sx PF 'E', 767 sx 'G' 8-1/2" 7" 26# L-80 Btrc-Mod 15615' 30' 30' 15645' 7560' 225 sx Class 'G' 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 MD TVD Structural Conductor Surface Ipnrtoe luC id ante R E C E IV E D Liner t',~AR ~. 8 1997 Alaska Oil & Gas Cons. Commission Perforation depth: measured ,i~chorage true vertical 20. 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 Contact Engineer Name/Number: James Robertson, 564-5159 Prepared By Name/Numbec Kathy Campoamor, 564-5122 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Randy ~ ~'~'~~Thomas Title Drilling Superintendent Date Commission Use Only Permit Number t APINumber ApprovalDate I Seecoverletter ~ "7 - 0 J" ~ 50- 0 2,. c~. ~ ~ "7 ,~- (~ ,~7~--~ ..~z~"'~ 'for other requirements Conditions of Approval: Samples Required [] Yes ,~ No Mud Log Required [] Yes ~ No Hydrogen Sulfide Measures []Yes ~;;~No Directional Survey Required ,0ir'Yes [] No Required Working Pressure for DOPE [] 2M; []3M; [] 5M; [] 10M; [] 15M Other: Original Signed By by order of Approved By David W. Johnston Commissioner the commission Date-'/7 Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared Services Drilling Contact: I Well Name: James E. Robertson J MP F-50 I Well Plan Summary 564-5159 IType of Well (producer or injector): IKUPARUK PRODUCER Surface Location: 2067 NSL 2680 WEL Sec 06 T13N R10E UM., AK Target Location: 2574 NSL 2313 WEL Sec 25 T14N R09E UM., AK Bottom Hole Location: 2764 NSL 2395 WEL Sec 25 T14N R09E UM., AK [AFE Number: 1337069 Estimated Start Date: I 09APR97 I I D: I I TVD: Rig: I Nabors 22-E Operating days to complete: 17,560' bkb I [16 [ KBE: 141.9' IWell Design: IMilne Point Ultra Slimhole Longstring 9-5/8", 40# Surface X 7", 26# Longstring Formation Markers: Formation Tops L MD TVD (bkb) base permafrost 1,825 1,792 NA 6922 3981 Top of Schrader Bluff Sands/8.3 ppg) . . Seabee Shale 8509 4441 Base of Schrader Bluff Sands (8.3 ppg) HRZ 14771 6803 High Resistivity Zone , , MK-19 14979 6983 Top Kuparuk 15072 7063 Kuparuk Cap Rock Target Sand -Target 15231 7201 Target Sand (9.6 ppg) Total Depth 15645 7560 . . Casing/Tubing Program' Hole ~ize ' Csg'/ WtJFt Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 20." 91.1 # H-40 ' 'Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 btm 8628 31/31 8659/4485 8-1/2" 7" 26# L-80 btm- 15615 30/30 15645/7560 mod Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at +7160 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3574 psi (9.6 ppg EMW) is 2858 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface MWD Directional surface to TD. Intermediate N/A Final Cased Hole Logs: MWD Directional F/drillout to TD. LWD Triple Combo(GR/RES, Density, Neutron) MAD PASS across reservoir after TD. N/A Mudloggers are NOT required for this well. RECEIVED MAR 2 8 199T .0il & Gas Cons. Commission Anchorage Mud Program: I Special design considerations I None-SPUD MUD Surface Mud Properties: I Density Marsh Yield i0 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.4 150 ''35 15 30 10 15 Intermediate Mud Properties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel geI Loss 8.6 35 6 3 7 8.5 6-12 to to to to to to to 10.6 50 20 10 20 9.5 4-6 Well Control: Shared Services Drilling requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (7)(b) "Secondary Well Control: Blowout Prevention Equipment (BOPE) Requirements" based upon historical drilling experience on 'F' Pad in the Milne Point Unit. To date, there have been 32 wells drilled on Milne Point 'F' Pad. None of these wells experienced any difficulty with shallow gas in the interval prior to placement of surface casing to depths not exceeding 5000' TVD Sub Sea. In light of the historical evidence indicating virtually no risk due to shallow gas at Milne Pt. 'F' Pad within the above mentioned interval, it is requested that forthcoming wells on the pad - for as long as the drilling on 'F' Pad remains continuous - can be drilled without the installation of the diverter system. A 20" riser will be installed to act as a conduit to facilitate drilling mud flow. Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed after setting surface casing and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 1500' Maximum Hole Angle: Close Approach Well: 73.15 NONE Disposal: Cuttings Handling: Cuttings and drilling waste fluids should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. . , 4. 5. 6. 7. 8. o 10. 11. 12. 13. 14. 15. MP F-50 Proposed Summary of Operations Drill and Set 20" Conductor. Weld a starting head on conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. NU 20" riser. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD only from surface to TD. Run and cement 9-5/8" casing. ND riser. NU and test 13-5/8" BOP. MU a PDC bit on a motor, with Directional MWD. RIH, Drill out Float Equipment and 20' of new formation. Perform LEAKOFF TEST. If LOT EMW is less than 12.5 ppg contact appropriate superintendent. Drill 8.5" hole to TD as per directional plan. POOH. LD MWD Directional and PU LWD Triple Combo LWD CDR/CDN (GR/RES/Dens/Neu). RIH and make MAD pass across reservoir. POOH to run 7" casing. Run and Cement 7", 26#, L-80, Buttress-Modified casing. Displace cement with completion fluid and enough diesel to cover from the base of permafrost to surface. Test casing to 3500 psig for 30 min. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. MIRU completion rig. NU & Test BOPE to 5000 psig. Complete well with 2-7/8" tubing. Install Surface Lines and Wellhouse and turn well over to production. DRILLING HAZARDS AND RISKS: Seethe updated Milne Point F-Pad Data Sheet prepared by Pete Van Dusen for information on F pad and review recent wells drilled on F Pad. Most of the trouble time on recent wells has been due to equipment mechanical problems with the surface equipment, rather than formation drilling problems. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. Close Approach: BY DESIGN - in an effort to validate a software package that will permit calculation of position of close approach wells while drilling - MP F-22 is a close approach well associated with the drilling of MP F-50. Approximately 15,500' of e-line conductor will be run into MP F-22 from a skid mounted E-line unit. A wireline BOP and grease packoff will be mounted on the tree. After getting the wire to depth the cable will be hung off. A DC power supply will be attached to the cable through the skid unit logging panel. When a directional survey is required in MP F-50 a 10 amp current will be switched on down through the cable in MP F-22. This excitation current will ground to the tubing at the bottom of the cable and will bleed off within a few thousand feet of the wireline TD. With this current passing through the conductor cable a temporary magnetic field will be created around MP F-22. This magnetic field will be detectable in MP F-50 and will allow MP F-50 to be steered away from MP F-22 when necessary. The excitation current will be turned off between surveys. Lost Circulation: There has not been any appreciable amount of lost circulation on any of the F Pad wellls to date. Stuck Pipe Potential: Well MPF-53 was stuck coming out on the short trip at surface casing point. Proir to this incident there was only minor indications that the gravel and coal were present. It appears that we dragged the gravel up into the bottom of the curve and reduced our ability to move up or down. Then we lost the ability to circulate when the hole collapsed. If significant gravels are encountered stop and raise funnel viscosity to 150 cp viscosity immediately. Formation Pressure: The maximum expected pore pressure for this well is 9.6 ppg EMW (3,574 psi @ 7,160' TVDss). There has been no injection in this region, therefore the reservoir pressure should not exceed this estimate and it is likely the area is somewhat depleted. MP F-50 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 60 deg F at 2840' TVDSS. SPACER: 75 bbls spacer weighted to mudweight in the hole. STAGE1 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder + CELLO-FLAKES (1/4 lb/sack) 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 1112 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANUULAR VOLUME FROM 100 FEET TVD ABOVE SCHRADER BLUFF TO BASE OF PERMAFROST AT 1800' MD +30% EXCESS +ANNULAR VOLUME FROM 1800' MD TO STAGE COLLAR AT 1300' MD +200% EXCESS. STAGE1 TAIL CEMENT TYPE: ADDITIVES: WEIGHT: APPROX #SACKS: FLUID LOSS: PREMIUM 'G' 0.2% CFR-3 + 0.20% HALAD-344 + CELLO-FLAKES 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 767 THICKENING TIME: Greater than 4 hrs at 50° F. 100-150 cc FREE WATER: 0 TAIL CEMENT FROM TD TO 100 FEET TVD ABOVE TOP of Schrader Bluff + 30% EXCESS + 80'md 9-5/8", 40# capacity for float joints. STAGE2 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 563 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANUULAR VOLUME FROM STAGE COLLAR AT 1300' MD TO SURFACE+ 200% EXCESS. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLFJPRACTICAL CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on bottom 15 joints of casing (1.5 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/Spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 - 15 bpm. Mix slurry on the fly -- batch mixing is not necessary. RECEIVED M .R 28 19,97 Alaska 011 & Gas Cons. Commission Anchorage MP F-50 Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON SINGLE STAGE CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: SPACER: 140° F BHST 170° F at 7040' TVDSS. 20 bbls fresh water 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: WEIGHT: 15.8ppg APPROX # SACKS: FLUID LOSS: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk 225 SACKS THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F < 50cc/30 min @ 140° FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the bottom 19 joints of 7" casing (38). This will cover +300' above the KUPARUK Sand. 2. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1. Single stage cement job is calculated to cover 1000 FT MD above the Kuparuk 'C' Sand with 30% excess. · . . i' FEASIBiLITY'PLAN }~ NOT APPROVED FOR EXECUTION ..... ..... i Pt. AN. - MP.F-.5.0 (.P 5) ...... VF_-H-Ti-i'C'AL-"-SECT ION-'~-E~/ ......... i. i i i i - Section at: 338.60 IYD Scale.' t inch: 1600' leer Dep $cal-e.' I inch ~-"1600' leer. ' ' ' Ora~Mn .... ' Ig Ilar 1997 · . ii ~ iii lllI i . i I ", ................................................... ! ......... ' -~ .............. Al- KG ......................... O .......... O- ; I I 8) KOP/EIUtLO t/100 500- 500 O R - -. .. ~ i . ~,) 8U%.LD 1.5/100 701) 700 3 2,0~ ....................../ I 3) P, tt[LD ;~/ll)O lOOi) 999 26 6.5~ D ~[ j I i £) BILl) ;),[i/tOO 1400 1392 99 14.5 ' J" i - "j-- G) BUILD Z-.5/f~ limb 18~9 259 24. ! ',, I ......... ,_ · /, ,,,, .,,,, · ' ii ! 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Sect.~on De Jre .................... ' .J~def!i..l¢J§Z f~lS.~l.~C I]: J~_.IN ~) ...... . ......... ' ............... ". ........ ..................... .... ~] o ]) z ;;o 14:88 FRO_H` ANADRILL . ! - " [ SHARED'. SERVICES :i; TO DR.~ ,lNG· 5645195 I. i i' ,I ':i i MPFL50 tP~5) YEF:I:I'IC~[ SECTION ~IE Section .at:. 336.~o ' " TVD Scal. e..' ~ ~qcb =:~00 feet: · Oep Scale..:. ~ ~dch -'100 feet , '. , .. BI TA~T. CI 7' CASING ~OINT' 'I : · ~477~. 680a 1183,0 1523,1:7~0~ ~p !564.5 756: 1~45 7~: 1~6~ :i l 'l INCLN' :' 30. O0 ', 30,00 ,, 30,00, 30 .oo I I. :: , I · Section Departure ~2350 MRR-27-1997 14: Iai FROM ANADR ILL TO ~.. ' , ' · ~, ~ :~ ~ , ~ '.. SHARED, SERVICES ,DRILLING. [[In [ne an I ' ~,t t I '' '' ~ ; [ [ ' ~ t '1 - ' [ · '~ .. ~ BUILD 2.5/~ ;laDD ; ~ N : m W )CLOSURE. ': 'f~B~ feet a':: AzJ6qtn 336.50 : H)'E~ ~.5/~ ~ILD '8826 ' i~47 N 6~ W SCAL~. 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I ', · · · · · : · ~: · ~' ~ · '. ' · WELL PERMIT CHECKLISToo Y F -LD. POOL 5--2- F/ PROGRAM: expn dev ~ redrlD serv~ wellbore seg~ ann disp para req~ ADMINISTRATION APPR DATE 1. Permit fee attached ................... ~ N 2. Lease number appropriate ................ ~ N 3. Unique well name and number ............... ~ N 4. Well located in a defined pool ............. ~ N 5. Well located proper distance from drlg unit boundary.. ~ N 6. Well located proper distance from other wells ...... 7. Sufficient acreage available in drilling unit ...... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... ~__~N 11. Permit can be issued without conservation order ..... ~N 12. Permit can be issued without administrative approval.. ~ N 13. Can permit be approved before 15-day wait ........ ~ N ENGINEERING 14. Conductor string provided ............... ~N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg. ~ N 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ..... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved.~-~ 22. Adequate wellbore separation proposed ......... ~.~N 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ............ ~,, ...... 26. BOPE press rating adequate; test to ~OC~-~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... -- ~N ~~ 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............ REMARKS GEOLOGY DATE 30. Permit can be issued w/o hydrogen sulfide m~ 31. Data presented on potential ov~nes ..... Y N 32. Seismic analysis ofsh_~_Lew-~s zones .......... Y N 33. Seabed con~i~-~urvey (if off-shore) ......... Y N 34. ~a~name/phone for weekly progress reports ..... Y N [exploratory only] GEOLOGY: ENGINEERING: COM~SION: JDH ~ mcm Comments/Instructions: HOWldlf - A:~FORMS~cheklist rev 01197 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. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... RECEIVED ,JUL ~ 1 199~ AlBs~a Oil & Gas Cons, Commi~k)r~ Anchorage COMPANY NAME '. BP EXPLORATION WELL NA~iE : MPU F-50 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292275600 REFERENCE NO : 97296 'LIS Tap'e Verification Listing Schlumberger Alaska Computing Center 25-JUL-1997 09:29 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/07/25 ORIGIN : FLIC REEL NAME : 97296 CONTINUATION # : PREVIOUS REEL : COF~4FJfr : BP EXPLORATION, MILNE POINT, MPU F-50, API# 50-029-22756-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/07/25 ORIGIN · FLIC TAPE NAME : 97296 CONTINUATION # '. 1 PREVIOUS TAPE : COM~_2~T : BP EXPLORATION, MILNE POINT, MPU F-50, API# 50-029-22756-00 TAPE HEADER Milne Point CASED HOLE WIRELINE LOGS WELL NAME.. MPU F-50 API NUMBER: 500292275600 OPERATOR: BP EXPLORATION LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 24-JUL-97 JOB 1FUM~ER : 97296 LOGGING ENGINEER: Carlo Yon OPERATOR WITNESS: Lee Hinkel SURFACE LOCATION SECTION: 6 TOWNSHIP: 13N RANGE: 10E FNL: FSL: 2068 FEL: 2680 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 42.70 DERRICK FLOOR: 41.70 GROUND LEVEL: 12.40 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 15663 . 0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) TIS Tap'e Verification Listing Schlumberger Alaska Computing Center 25-JUL-1997 09:29 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMi~ER : DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CET REMARKS: CONTAINED HEREIN IS THE GR, TENS, AND CCL DATA ACQUIRED ON BP EXPLORATION WELL MPU F-50. THE DATA WAS ACQUIRED WITH THE ULTRASONIC IMAGING TOOL (USIT) . THIS IS THE PRIMARY DEPTH CONTROL .DATA. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE iVO?4~ER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUFiBER: 1 DEPTH INCREMENT: 0.5000 FILE SUFk~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 15423.0 4182.0 CET 15452.0 4182.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CET LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUL-1997 09:29 PAGE: ~S: THIS FILE CONTAINS THE CLIPPED AND EDITED GRCH, TENS, AND CCL DATA FROM PASS #1. NO DEPTH SHIFTS WERE APPLIED TO THIS DATA AS IT IS THE PRIMARY DEPTH CONTROL. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** 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 560199 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CET GAPI 560199 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CET LB 560199 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CET V 560199 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 15452.000 GRCH. CET -999.250 TENS.CET 4684.000 CCL.CET DEPT. 4182.000 GRCH. CET -999.250 TENS.CET 1190.000 CCL.CET 0.294 0.009 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUL-1997 09:29 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 97/07/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NOY4~ER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NU~ER : 1 DEPTH INCREMENT: 0.5000 FILE SUFff4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 15486.0 4180.5 USIT $ LOG HEADER DATA DATE LOGGED: 6-MAY-97 SOFTWARE VERSION: 8C0- 609 TII4~ LOGGER ON BOTTOM: 1300 6-MAY-97 TD DRILLER (FT) : 15685.0 TD LOGGER (FT) : 15450.0 TOP LOG INTERVAL (FT) : 500.0 BOTTOM LOG INTERVAL (FT) : 15450.0 LOGGING SPEED (FPHR): O. 0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : TOOL NUMBER ........... SGT-L 8.500 15663.0 ~LIS TapJ Verification Listing Schlumberger Alaska Computing Center 25-JUL-1997 09:29 PAGE: 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) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) '. Produced Fluids 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): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): REM~APJfS: This is the primary depth referenced for this well Log was referenced to a Sperry-Sun MWD log, dated 26-April-1997 USIT was run from 15450 to 14200 ft, and a small strip was logged through the 9 5/8 casing shoot from 9200-8800 ft. GR/CCL log was run from 15450 to 4200 ft. Ail correlations and logging sections approved by company rep. THIS FILE CONTAINS THE RAW GR, TENS, AND CCL DATA FOR PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JUL-1997 09:29 PAGE: 6 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 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 ELE~ CODE (HEX) DEPT FT 560199 O0 000 O0 0 2 1 1 4 68 0000000000 GR PS1 GAPI 560199 O0 000 O0 0 2 1 1 4 68 0000000000 TENS PS1 LB 560199 O0 000 O0 0 2 1 1 4 68 0000000000 CCL PS1 V 560199 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 15468.000 GR.PS1 DEPT. 4180.500 GR.PS1 98.182 TENS.PSi 1453.000 CCL.PS1 0.351 20.432 TENS. PSi 1191.000 CCL.PS1 -999.250 ** END OF DATA ** ~IS Tape~'Verification Listing Schlumberger Alaska Computing Center 25-JUL-1997 09:29 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE . FLIC VERSION . O01CO1 DATE : 97/07/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/07/25 ORIGIN : FLIC TAPE NAME : 97296 CONTINUATION # : 1 PREVIOUS TAPE : CO~Ff . BP EXPLORATION, MIL1VE POINT, MPU F-50, API# 50-029-22756-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/07/25 ORIGIN . FLIC REEL NAI~E : 97296 CONTINUATION # : PREVIOUS REEL : CO~-ENT : BP EXPLORATION, MILNE POINT, MPU F-50, API# 50-029-22756-00 Sperry-Sun Drilling Services LIS Scan Utility Wed Jul 16 15:51:34 1997 Reel Header Service name ............. LISTPE Date ..................... 97/07/16 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 97/07/16 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA 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 MWD RUN 3 AK-MW-70096 PIEPER ANGLAN Date_ Ol - o3- o I MPF-50 500292275600 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 16-JUL-97 MWD RUN 4 AK-MW-70096 PIEPER ANGLAN 6 13N 10E 2068 2680 .00 41.70 12.40 OFEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 112.0 12.250 9.625 9099.0 8.500 15685.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ANNULAR HYDRAULICS ARE CALCULATED USING THE POWER LAW MODEL. 3. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 4. MWD RUNS 3 AND 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO DENSITY (SLD). 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15684'MD, 7576'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PPLASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE-SIZE). SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBDC = SMOOTHED BULK DENSITY (CALIPER CORRECTED). SCOR = SMOOTHED STANDOFF CORRECTION. SFPE = SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC A~SORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED FOR NUCLEAR/NEUTRON LOG PROCESSING: HOLE SIZE = 8.5" MUD FILTRATE SALINITY = 1000 PPM MUD WEIGHT = 8.4 - 9.90 PPG FORMATION WATER SALINITY = 14545 PPM FLUID DENSITY = 1.0 G/CC MATRIX DENSITY = 2.65 G/CC LITHOLOGY = SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START RPD 9101 RPM 9101 RPS 9101 RPX 9101 GR 9101 NCNT 9102 NCNT 9102 NPHI 9102 PEF 9105 DRHO 9105 RHOB 9105 FET 9136 ROP 9137 $ BASELINE CURVE FOR SHIFTS: .5000 DEPTH STOP DEPTH 5 15591.0 5 15591.0 5 15591.0 5 15591.0 5 15611.0 0 15565.0 0 15565.0 0 15565.0 5 15600.0 5 15600.0 5 15600.0 0 15591.0 5 15684.0 CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 9101.5 9103.5 9105.5 9122.5 9124.0 9131.5 9137.0 9431.5 9438.5 9443.5 9452.5 9476.5 9481.0 9487.0 9492.5 9496.5 9787 5 9791 0 10559 0 10564 0 10568 0 11748 5 11756 0 12272 5 12279 0 12284 5 12583.0 12585.0 12587.0 12595.0 12602.5 12618.0 14030.5 GR 9095 9097 9098 9117 9118 9125 9130 9426 9434 9439 9445 9467 9471 9475 9482 9485 9770 9774 10550 10555 10560 11739 11746 12257 12263 12269 12571 12573 12575 12581 12587 12603 14017 - EQUIVALENT UNSHIFTED DEPTH -- 14034 5 14043 5 14047 5 14056 0 14059 0 14216 0 14279 5 14351 0 14354 5 14356 5 14422 0 14427 0 14435 5 14442 0 14449.0 14503.5 14509.0 14624.5 14649.5 14803.0 14810.5 14832.0 14844.5 14857.5 14873.0 14875.0 14885.5 14887.5 14891.5 14898.5 14919.5 14930.5 14947.0 14951.0 14961.5 14986.0 15011.5 15041.5 15063.0 15067 5 15070 5 15077 0 15083 5 15085 5 15092 5 15225.0 15227.0 15230.0 15236.0 15238.5 15244 0 15246 5 15252 5 15255 0 15258 0 15260 0 15263 0 15263 5 15267 0 15270 5 14024.0 14032.0 14038.5 14042.5 14044.5 14200 5 14262 5 14337 0 14340 0 14342 0 14414 5 14419 0 14429 5 14437 0 14441 0 14495 0 14502.0 14606 0 14633 5 14786 0 14798 0 14816 0 14828 0 14844 0 14859 5 14860 5 14871 0 14874 0 14877 5 14883 5 14907 0 14914 5 14933 5 14936 5 14947 0 14971 5 14997 5 15027.0 15048.5 15052.5 15055.0 15062.5 15068.0 15071.5 15077.0 15208.0 15211.0 15213.5 15221.5 15222.5 15228.0 15231.5 15236.0 15240.0 15242.0 15244.5 15246.5 15247.5 15250.5 15255.0 15272.0 15275.5 15279.0 15291.5 15294.0 15310.5 15315.0 15323.0 15331.0 15336.5 15352.5 15414.5 15416.5 15427.0 15438.5 15684.0 MERGED DATA SOURCE ?BU TOOL CODE MWD MWD REMARKS: 15257.0 15260.0 15266.0 15276.5 15278.5 15302.5 15307 0 15314 5 15320 0 15332 0 15349 5 15413 0 15415 5 15430 0 15438.5 15684.0 BIT RUN NO MERGE TOP MERGE BASE 3 9130.0 11851.0 4 11851.0 15684.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OHM~ 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD P.U. 4 1 68 NCNT MWD CTS/ 4 1 68 FCNT MWD CTS/ 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max DEPT 9101.5 15684 Mean Nsam 12392.8 13166 First Reading 9101.5 Last Reading 15684 ROP GR RPX RPS RPM RPD FET NPHI NCNT FCNT RHOB DRHO PEF 5 4265 33 1021 1 1595 0 1236 0 0894 1 2171 0.2823 11.4913 2112 433 1.4847 -0.193 1.3386 876.365 200.469 13094 170.649 87.6467 13020 2000 3.42088 12980 51.862 3.37264 12980 59.3829 3.53118 12980 2000 4.90145 12980 25.5977 1.60496 12911 81.7622 39.254 12927 4136 2766.75 12927 1203 649.397 12927 2.8392 2.31085 12990 0.5033 -0.00235218 12990 6.1417 1.90161 12990 9137.5 9101.5 9101.5 9101.5 9101.5 9101.5 9136 9102 9102 9102 9105.5 9105.5 9105.5 15684 15611 15591 15591 15591 15591 15591 15565 15565 15565 15600 15600 15600 First Reading For Entire File .......... 9101.5 Last Reading For Entire File ........... 15684 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/16 Maximum Physical Record..65535 File Type ................ LO Next File Name..~ ........ STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD 9095.0 RPM 9095.0 RPS 9095.0 RPX 9095.0 GR 9095.0 FCNT 9095.5 NCNT 9095.5 NPHI 9095.5 PEF 9098.5 STOP DEPTH 11758 0 11758 0 11758 0 11758 0 11778 0 11732 0 11732 0 11732 0 11767 0 DRHO 9098.5 RHOB 9098.5 FET 9129.5 ROP 9130.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 11767.0 11767.0 11758.0 11851.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHM>4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down 22-APR-97 4.96 CIM 5.46 MEMORY 11851.0 9130.0 11851.0 71.4 75.4 TOOL NUMBER P0706CRDGP6 P0706CRDGP6 P0706CRDGP6 P0706CRDGP6 8.500 8.5 PAC/GEL 9.00 40.0 10.0 1000 9.0 1.500 1.100 1.400 2.500 44.5 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 3 AAPI 4 1 68 RPX MWD 3 OHMS4 4 1 68 RPS MWD 3 OHM~ 4 1 68 RPM MWD 3 OHMM 4 1 68 ROP MWD 3 FT/H 4 1 68 RPD MWD 3 OHMM 4 1 68 FET MWD 3 HOUR 4 1 68 NPHI MWD 3 P.U. 4 1 68 NCNT MWD 3 CNTS 4 1 68 FCNT MWD 3 CNTS 4 1 68 RHOB MWD 3 G/CC 4 1 68 DRHO MWD 3 G/CC 4 1 68 PEF MWD 3 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean DEPT 9095 11851 10473 GR 27.0043 110.072 80.832 RPX 1.3877 2000 3.67889 RPS 0.1236 26.9115 3.46026 RPM 0.0894 59.3829 3.701 ROP 5.4265 876.365 223.147 RPD 1.9447 2000 6.83003 FET 0.2823 5.012 1.1051 NPHI 11.4913 66.2295 40.2681 NCNT 2240 4136 2732.12 FCNT 433 1203 624.428 RHOB 1.4847 2.7039 2.28768 DRHO -0.102 0.5033 0.0173325 PEF 1.811 6.1417 2.37534 Nsam 5513 5367 5327 5327 5327 5442 5327 5258 5274 5274 5274 5338 5338 5338 First Reading 9095 9095 9095 9095 9095 9130.5 9095 9129.5 9095.5 9095.5 9095.5 9098.5 9098.5 9098.5 Last Reading 11851 11778 11758 11758 11758 11851 11758 11758 11732 11732 11732 11767 11767 11767 First Reading For Entire File .......... 9095 Last Reading For Entire File ........... 11851 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI FET RPD RPM RPS RPX PEF DRHO RHOB GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. 4 .5000 START DEPTH 11733.5 11733.5 11733 5 11759 5 11759 5 11759 5 11759 5 11759 5 11768 5 11768 5 11768 5 11779 5 11853 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 15565.0 15565.0 15565.0 15591.0 15591.0 15591.0 15591.0 15591.0 15600.0 15600.0 15600.0 15611.0 15684.0 25-AP R- 97 4.96 CIM 5.46 MEMORY 15684.0 11851.0 15684.0 25.7 74.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMIqA RAY P0696CRDGP6 EWR4 ELECTROMAG. RESIS. 4 P0696CRDGP6 CNP COMPENSATED NEUTRON P0696CRDGP6 SLD STABILIZED LITHO DEN P0696CRDGP6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 8.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMS4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type~ ................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined 7Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 PAC/GEL 9.90 45.0 9.5 1000 4.4 1.700 .969 1.275 2.550 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 RPX MWD 4 OHMM 4 1 68 8 3 RPS MWD 4 OHMM 4 1 68 12 4 RPM MWD 4 OHMM 4 1 68 16 5 RPD MWD 4 OHM~ 4 1 68 20 6 NPHI MWD 4 P.U. 4 1 68 24 7 ROP MWD 4 FT/H 4 1 68 28 8 FET MWD 4 HOUR 4 1 68 32 9 FCNT MWD 4 CNTS 4 1 68 36 10 NCNT MWD 4 CNTS 4 1 68 40 11 RHOB MWD 4 G/CC 4 1 68 44 12 DRHO MWD 4 G/CC 4 1 68 48 13 PEF MWD 4 BARN 4 1 68 52 14 72.8 First Name Min Max Mean Nsam Reading DEPT 11733.5 15684 13708.8 7902 11733.5 GR 34.3207 170.649 92.4102 7664 11779.5 RPX 1.1595 65.2672 3.26197 7664 11759.5 Last Reading 15684 15611 15591 RPS RPM RPD NPHI ROP FET FCNT NCNT RHOB DRHO PEF 1 1766 1 1729 1 2171 13 9099 5 8038 0 3759 453 2112 1.8414 -0. 193 1.3386 51.862 3.34085 7664 47.1558 3.42707 7664 45.7406 3.57423 7664 81.7622 38.5922 7664 616.406 183.595 7663 25.5977 1.93797 7664 1051 666.201 7664 3984 2789.45 7664 2.8392 2.32688 7664 0.3904 -0.016355 7664 2.7559 1.57055 7664 11759.5 11759.5 11759.5 11733.5 11853 11759.5 11733.5 11733.5 11768.5 11768.5 11768.5 15591 15591 15591 15565 15684 15591 15565 15565 15600 15600 15600 First Reading For Entire File .......... 11733.5 Last Reading For Entire File ........... 15684 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/07/16 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 97/07/16 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File